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187-040
Originated: Delivered to:26-Aug-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2Z-20 50-029-21876-00 910220628 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 12 2Z-20 50-029-21876-00 910219502 Kuparuk River Packer Setting Record Field- Final 12-Aug-25 0 13 3K-102 50-029-23378-00 910262525 Kuparuk River Leak Detect Log Field- Final 19-Aug-25 0 14 3M-13 50-029-21720-00 910219405 Kuparuk RiverLeak Detect LogField- Final 8-Aug-25 0 15 3M-13 50-029-21720-00 910219403 Kuparuk River Multi Finger Caliper Field & Processed 1-Aug-25 0 16 3M-13 50-029-21720-00 910219405 Kuparuk River Plug Setting Record Field- Final 8-Aug-25 0 17 3Q-07 50-029-21682-00 910180539 Kuparuk River Multi Finger Caliper Field & Processed 13-Jul-25 0 18910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:188-124207-165187-040186-194T40834T40834T40835T40836T40836T40836T408378/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:54:51 -08'00'207 165187-040186 1943M-1350-029-21720-00 910219405Kuparuk RiverLeak Detect LogField- Final8-Aug-250153M-1350-029-21720-00 910219403Kuparuk RiverMulti Finger CaliperField & Processed1-Aug-250163M-1350-029-21720-00 910219405Kuparuk RiverPlug Setting RecordField- Final8-Aug-2501 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-08-18_24023_KRU_3M-13_VividLeakDetect_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 24023 KRU 3M-13 50-029-21720-00 VIVID Leak Detect 18-Aug-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 187-040 T40799 8/25/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.25 10:24:39 -08'00' ,0'%040 WELL LOG TRANSMITTAL #906140308 To: Alaska Oil and Gas Conservation Comm. January 17, 2020 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Patch Setting Record: 3M-13 Run Date: 12/10/2019 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 3M-13 Digital Data in LAS format, Digital Log Image file 50-029-21720-00 7YCC.MEED JAS! 2 2 2020 A®CCC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny San 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: 7 Signed: ADL0025512 KRU 3M-13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool Total Depth measured r cill-IVCD feet N/A STATE OF ALASKA 6518' feet ALASKA OIL AND GAS CONSERVATION COMMISSION Effective Depth measured REPORT OF SUNDRY WELL OPERATIONS DEC 19 2019 feet Packer true vertical Operations Abandon Ll Plug Perforations L1 Fracture Stimulate Ij Pull Tubing Lj AOCKwOsshutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate Alter Casing El Change Approved Program true vertical Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: Tubing Patch Operator ConocoPhillips Alaska, Inc. 4, Well Class Before Work: 5. Permit to Drill Number: me: Liner 5.5"x4.5" 3425 Development ❑r Exploratory ❑ 187-040-0 4ddress: PO Box 100360 7" Straligraphic ❑ Service ❑ 6. API Number: Measured depth Anchorage, AK 99510 feet 9015 True Vertical depth N/A feet 50-029-21720-00-00 property Designation (Lease Number): Packers and SSSV (type, measured and true vertical depth) 8. Well Name and Number: ADL0025512 KRU 3M-13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool Total Depth measured 9797' feet N/A true vertical 6518' feet ZXPN Effective Depth measured 9123' feet Packer true vertical 6099' feet feet Casing Length Size true vertical Conductor 77 16" Surface 4850 95/8" Liner 5.5"x4.5" 3425 5.5" Production 9674 7" Perforation depth Measured depth N/A feet 9015 True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) 6520 Packers and SSSV (type, measured and true vertical depth) tz. bamuiadon or cement squeeze summary: Nb Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 3-1/2" Plugs 8804' measured N/A feet 3624' MD Junk ZXPN measured N/A feet 8803' MD Packer Baker 7" FS -1 measured 9003' feet 9181'—MD true vertical 6015' feet MD TVD Burst 115 115 4887 3416 9015 6023 9,707 6520 3-1/2" L-80 8804' Tubing Patch Owen Permanent Patch 3624' MD Liner Top Packer ZXPN 5601' MD Tubing Seal Assembly Baker 80-40 8803' MD Packer Baker 7" FS -1 9003' MD Packer Baker SA6-3 9181'—MD Collapse arcs 2705' TVD 3818' TVD 5876'TVD 6015' TVD 6140' TVD mepresemauve uaey Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development P ❑ Service ❑ Straligraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 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 Authorized Name: Rachel Kautz Contact Name: Rachel KaulLSara Carlisle Authorized Title: Well Integrity Specialist Contact Email: N2549(a)conocoohillios com Authorized Signature: Date: lZ —I g `' % Contact Phone: 659-7126 Form 10-404 Revised 4/2017 /-r RBDMa—yc+ !fi"�np(` 1 Q 91170 Submit Original Only _ Date Event Summary Executive Summary 10/09/19 10/10/19 12/06/19 12/07/19 12/10/19 Kuparuk well 3M-13 was previously identified with a tubing leak at 3634'. The well has remained shut- in awaiting a rig workover. CPAI recently decided to attempt to repair the tubing without the rig. A permanent tubing patch was installed across the leak and a subsequent passing MIT and TIFL confirmed integrity of the tubing was restored. Spinner log confirmed there is still only one tubing leak: LRS PERFORMED CIRC OUT. SET AVA CATCHER ON TOP OF SAND @ 9043' RKB. SET 1" BTM LATCH DV @ 8780' RKB. LOG SPINNER LDL FROM 9036' RKB TO SURFACE FOUND KNOWN LEAK @ 3634' RKB NO OTHER LEAKS FOUND. IN PROGRESS, ine unsecured well in preparation for patch attempt: 2 1/2 OK -1 KOT (OD 2.21") UNABLE TO LOCATE. BAILED SILICA SAND OFF TOP OF CA2 PLUG @ RKB. EQUALIZED 2.25 CA -2 PLUG @ 9053' RKB. IN PROGRESS. PULLED 2.25 CA -2 PLUG @ 9053' RKB, BRUSH n' FLUSHED TBG FROM 3600' TO 3650' RKB. READY FOR PATCH. IN PROGRESS. Slickline prepared well for patch: BRUSH n' FLUSH PATCH AREA FROM 3700' TO 3600' RKB W/ 40 BBLS HOT DIESEL TBG OPEN 2.80". IN PROGRESS. RELAY performed CMIT to confirm no tubing leaks below known leak point and installed nipple reducer: RAN CCL & 3 1/2 SLIP STOP HOLE FINDER TIE INTO LDL LOG CMIT TBG x IA 2500 PSI PASS WITH HOLE FINDER SET @ 3650' RKB. PULLED 2.75 x 2.25 NIPPLE REDUCER @ 9054' RKB. SET 2.75 x 1.81 NIPPLE REDUCER @ 9054' RKB. IN PROGRESS. (PATCH PREP) CMIT TxIA to 2500 PSI (PASS) PRE CMIT T/I/0= 1600/1500/260, INITIAL T/I/0= 2500/2450/270, 15 MIN T/1/0=2440/2415/265, (-60/-35) 30 MIN T/I/0= 2430/2405/263 (-10/-10) L permanent patch and confirmed integrity with MITIA: F 27.4'x 2.72" OWEN X -SPAN PERMANENT PATCH @ 3625' RKB (ME), MIT IA 2500, PASS, DRAW DOWN TO 500 PSI MONITOR OVER NIGHT. IN PROGRESS. MIT -IA TO 2500 PSI (PASS) PRE TESTT/I/0= 1600/1550/260 (.08 BBLS TO PRESSURE UP) INITIAL T/I/0= 1600/2500/260 15 MIN T/I/0= 1600/2490/260 30 MIN T/I/0= 1600/2490/260 BLEED IA TO 500 PSI MONITOR OVER NIGHT FOR CHANGE 12/11/19 12/15/19 Set live valve post permanent patch set: DRAW DOWN TEST OVER NIGHT GOOD, SET 3 1/2 AVA CATCHER ON X -SPAN PATCH @ 3650' RKB, PULLED DV @ 3245' RKB, SET 1" OV (1/4" PORT @ SAME. COMPLETE. TIFL confirmed tubing integrity after gas lift brought online: (AC EVAL) RE TIFL (PASSED) Initial T/I/O = 200/780/500 IA FL @ 3245' Sta # 1 OV 51 WH @ WV Double block lift gas in manifold bldg Stack T x IA 30 minutes T/I/O = 760/760/400 IA FL @ same Bled AIL and monitored Bled IA 50 minutes to T/I/O = 850/240/280 15 min T/I/O = 860/240/275 30 min T/I/O = 900/240/275 IA FL @ same 45 min T/I/O = 900/240/275 60 min T/I/O = 910/240/275 IA FL @ same Final T/I/O = 910/240/275 K U P PROD WELLNAME 3M-13 WELLBORE 3M-13 ConoeoNhillips en wnnnutes Max Angle & MD TO em Name W¢Ipb a,lNW, W,Gue Son_ Iel(-) Mp MIR IXKB) `1 Penn Aldska.lrtC. KUPARU VER UNIT MO 92172MO PROD 742 2,800.00 9,734.0 Connot355VeNPPLE xxs (ppm) Dam gnnot¢non End Dare KBcm IRI RIP Release Dale Lest WO: 11/29/2012 41.81 5/31/198) 3 ,' PM Last Tag Vatearect-tan,' N.wlxdemmi (actual) pnnolailm peplM1 (nK0) Entl Dele We11 None Last Mod By L..1T" SLM 9,101.0 11/22/2019 3M-13 Dberr, 1MNGER azs Last Rev Reason gnnomnon Ene Dare IN )lose Leat NOV BY ftev Reason; ClO Npple Reducer, Patch, CV 12/11/2019 9M-13 pta, Casing Stdng5 - CasmPDescdptlan OD 'In) 0(1,) TOP lnua) Set Depth HAD) set.."", IND)...."An fl.. .,ad. Top Thr¢ad CONDUCTOR 16 15.06 38.0 1150 1150 62.58 H4D WELDED C0NpI1CTOR: b.a115n Casln g Desctlptlon OO IIn) ID(in) TOP pdCB) Se[pepiM1 IXKB) set Depin IND)... WYLen (I... Grade Top Th sed SURFACE 9518 8.92 37.0 4,8868 3,416.0 36.00 J-55 BTC MPPLE: aa3.t Casing U-nodlen OD(10 ID(in) Top IRKB) set Oepm (XKB) set Depin(ND)... WMIen 11... Grade Top Thnsad PRODUCTION 7 6.28 33.0 9,70)1 6,519.7 2600 755 BTC Casing Description OD Is")10 (In) Top(. It) Sat Depth IXKB) Bat Depth GVp)... Mg.e I_ Grade Top TEN. SCAB LINER 4.5'x3.5" 51/2 4.95 5,5900 9,014.9 6,023.5 15.50 L-80 BTCM CASUPT:3,i052 Liner Detaris Top,Hd., TOP(TV.) DIKS) Topincl(") He. Des Com Nominal ID (In) 5,690.0 3,812.1 55.50 SLEEVE ZXPN LINER SETTING SLEEVE 5500 TURING UPMC sax. PATCH;36340 5,601.1 3,818.4 5550 PACKER ZXPN LINER TOP PACKER 4.870 5,605.6 3,8214 5550 HANGER HMC LINER HANGER (PINNED TO 2500 PSI) 4.830 8,803.3 5,875.9 4fi 08 XO Retluring CROSSOVER 55"x 5" SOLD suRPACE; Bzaa ease-� 8,804.3 5,8768 4647 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 6,822.9 5,889.5 46.33 XO Retlucin9 CROSSOVER SRX 4.5- 4500 GAS OPT: SSRI 8,873.9 5,924.8 4596 CMT VLV BAKER HM CEMENTING VALVE 3.900 8,9959 6,010.2 4524 XO Retlucing CROSSOVER 4.5'x35" 3.500 8,997.5 6.011.2 45.23 LOCATOR LOCATOR 2,960 9,004.3 6016.1 4523 SEPL ASSV BAKER CT40 LOCATOR SEAL ASSEMBLY 2,990 Tubing Strings TUMID Des.nptlon sting Ma... IDlln) Top IRKB) Bel Depth ltt„bel OepIM1 )TVD)(... WIIIdR) Gratle Toptonnecllon TUBING 312 2.99 32.9 6,804.3 5,876.6 9.30 L-60 EVE Completion Details GAC LIFT;].131] Top (TVD) Topincl amial n Top (RKS) (aK3) I°) Item Des Co. ID( 32.9 32.9 0.02 HANGER I FMC GEN IV TUBING HANGER 2,9999 2 GAS UFT,&Inn 493.1 493.1 1.61 NIPPLE CAMCO DB NIPPLE 2875 8,803.4 5,676.0 46.48 SEALASSV BAKER 80-40 LOCATOR SEAL ASSEMBLY 3.000 G4s LIFT: O.7180 Tubinp Dea.dpdon PACKERASSY -11119 Me... ID HH)Top IRK.l I Bat Dapht(I.. Isal DepinlNO)(.., Wl(IWRI Gratle Top Cann-n- 31/2 2.99 9,002.5 9,059.4 6,054.8 9.30 L-80 EUEfiRDM00 Completion Details Top(XKB To ) Topincl ( RKBIminal 15 I Co.Des 10 (i,) 9,002.5 6,014.8 4523 PACKERER BAKER 7"FB-1 PERMANENT PACKER 4000 .6AL.1. a.Om.4 9,005.8 601 J.1 45.24 SBE BPHER ep-0O SEAL BORE EXTENSION 4.000 9,053.6 6,050) 45.40 NIPPLE C,VVI D NIPPLE 2.750 9,056.9 6,054.5 45.41 WLEG WIRELINE ENTRY GUIDE 2992 Tu Olnp pesc,iptlon Shcng M a... ID (in) Top IXKB) set DepthIn-Bel Depth (Np11...W1(IWX) Grade Top Conner Ilan TUBING FISH 1998 5.62 9,124.0 9,206.6 6,1577 Completion Derails H.%Nl up:((:1 I") Ihm DeaCom turn) p IRKB) T1(("T D) Topincl=PACKER.X22 9,124.0 6ID0.1 4539 SFAL ASSV CEMRI40 HL PFS PARTIAL TANDEM SEAL 0.000 SECTIO PACKER: IT.a 9,137.6 6,16F7 45.29 ESP MOTOR OENTRIP KMH 22-815ERIES 562 MOTOR 0000 ea.;DOPF.0 W/CENTco A6uNER4........... 9,181.4 6,140.5 4500 PACKER BAKER9,.fa9 MANENT PACKER _4(22 ANCHOR SEAL 30110 ASSEM9,1882 61453 44.95 XOReducing CROSSUCING 35"#875" 2.8759,1958 9.536 NIPPLE RFNIPPLE 9.0638 WLec.. C98 - 6,1508 44.90 NIPPLE CAMCOE NO GO 2250NIPPLE; 9204.8 6,1571 4483 SOS BAKER T SUB 2441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) TopIND) Topincl SEALASsy;9.1240 Top IRKB) (RKBI )') Des Co. Run Dell KIM) 3,6240 2,7050 55.11 PATCH 27_4'x2)2"OWE- X -Span permanent patch�3,625' RKB(ME) 12/101201 g 2.250 ESP MpioR; 9,137 s 3,634.0 2,719.7 55.14 TUBING LEAK Turing Leak Identified W/Relay LDL,RECONFIRMED W1 RELAY ON IO/ -19, NO OTHER LEAKS OBSERVED 1-11/201 9 2.992 PACKER:91811 NIPPLE;9.1a5.0 SUG.6 6,050.7 45.40 NIPPLE REDUCER 277Dx1.81" D,,Cfilenipple red.60r 1202019 1.810 .......2.ae pertorations & slots - Shot Dea n TVD) ptmzm Top (RKB) film (RKB) IND' Linked Zone Delta ) Type 9,269.0 9,2830 6,212.9 C-0, A-3, 3M-13 &2911991 6.0 RPERF 21I8'EnerJeto0 tleg ph APERE', 92M,09,AV.0- 4npRE;e,2e3.a9.3pB.0- 9,283.0 9,3030 6,227.3 A -2,3M-13 829/1931 6.0 RPERF 21R" EnerJep O deg ph J5,252.46.2K.7 9,3170.0 9,3320 6,246.1 A -2,3M-13 -2-1991 6.0 DEERE 21re'EnerJel;Odeg ph RPERF, 9 soa.a9332.. IpER9B,3d.Cg SpP 9,320.0 9,323.0 ,241.7 A -2,3M-13 8117/1987 le )PERF 4" Cap Gun; 120 deg ph 9,3380 9,380.0 6,282.7 A-1, Set 13 82911991 6.0 RPERF 2118"EnerJetO deg ph 9,340.0 93790 6,281.9 A-1, 3M-13 -D/19W 101PERF 4'Csg Guq 120 deg ph Mandrel Inserts ERPERE%iUA93a (PERF: III x9]]90 atl sl N Top(PKI) Top DVD) (RKS) Make Model OD Rn) Sery WI: Type :. LHI Type ponslle (In) TRO Run (psl) Run Dal¢ Cam 1 3,245.2 2,496.7 CAMCO KBMG 1 GAS LIFT BK -5 0.250 0.0 12/112019 8:00 PRo.ucnDN s+..9.].]t KUP PROD WELLNAME 3M-13 WELLBORE 3M-13 ConocoPhillips Alaska.lnc, 3M 16, 1VIWD19 RW34 PM Mandrel Inserts vent .'ada.Elenuep S1 e9 .. ................. .......... NViGER 32H on N Top )ttKB) Top COL) MNe ous) Make Model OD (in) Be, Type Lunch Typo Por[31ee TRORun )In) )pal) Run Done Com 5,533.4 3.780.0 CAMCO KBMG 1 GASLIFT OMY BK -5 0.000 00 31162015 11:00 3 7,131.7 4,745KB .4 CMACC G-2- 1 GASLIFT DMY INT 0.000 UT1612015 7:30 9 4 8,192.6 5,459.4 CAMCO KBG2- 1 GAS TFT DMY INT 0.000 0.0 112&2012 1:30 9 CAN8UCT8R; 3e.wtso I 5 0,779.8 5,859.7 CAMCO KBG-2- 1 Ed LIFT DMY INT 0.000 10/912019 8:00 9 NIPPLE; 493.1 Notes: Genml&Safety End OneAn..aron 1Ifi12014 NOTE: ConBUDeb leek in whin, between34]8'-3634'SLM. G4511Ff; 3.245.2 12/&2012 NOTE: NORDI03 WORKOLAER p4 6132012 NOTE: Welded 6575" casing 1075".400 wall thickness, 45.5 sleeve on SC QD bIXwm of sorter M1eaE. TUBING LEAK, 3,SS10 PATCN, 38M0 6URFACE,32¢4,RHEe GAs uFT:ss33.a GA6 LIFT: ],131.% GA611FT: 8,1P1.6 . LIFT; RTR.H 6EAl AS6Y; k8834 PACKER: SEE B. B SCAB LINER 45 v315.. D. 9.01(9 NIPPLE:9,Ui.6 NIPPLE REOUCER', 8. UPS WlEG', R0609 6E4 PSSY; 9,1]48 ESP MOTOR: 8.131.6 PACKFA: 9.161A NIPPLE', 9.1938 605; 9,314 -------- ADEN, ADERF. APE RF 9,20309,3)3,8— RPERF', 9.3]9¢8,3,Q0 PERF; 8,3A.09,323.8� RPERF', 9,33669,}W.0 I PERF; 8.3W.09,3]9a P oDoCTION; 3].09,282.1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 18, 2019 Commissioner Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7h Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski: Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the permanent tubing patch set across a tubing leak in producer KRU 3M-13 (PTD 187-040). Please contact Sara Carlisle or me at 659-7126 if you have any questions. Sincerely, )ZaA� Rachel Kautz Well Integrity Specialist ConocoPhillips Alaska, Inc. WELL LOG TRANSMITTAL #906028438 To: Alaska Oil and Gas Conservation Comm. Arm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 3M-13 Run Date: 10/9/2019 107040 31595 November 21, 2019 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 3M-13 Digital Data in LAS format, Digital Log file RECEIVED DEC 0 9 2019 1 CD Rom 50-029-21720-00 qq .ri000Ci 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 FRS—ANC@halliburton.com Date: Vjnolq Signed: Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700main (907)273-4760fax Delivered to: rr ♦/ AOGCC . ATTN: Natural Resources Technician II Alaska oil & Gas Conservation Commision \! 333 W. 7th Ave, Suite 100 .Ir Anchorage, AK 99501 7TRANSIVIITTTAL DATE SMITTAL# 187040 WELL NAME API 4 ORDERSERVICE # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATELOGGED Prints CD's 1H-114 1H-111 1H•105 1 H•113 1H-116 3M-19 3G -07A 50-029-23584-00 50-029-23581.00 50.029-20727.07 50.029-23588-00 50-029-23594-00 50.029.21737.00 50-103-20127-01 EOSH-00071 EA18-00022 El 18.00075 E118-00076 E118-00077 E118.00078 E118-00079 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL WL IPROF IPROF-WFL IPROF-WFL IPROF-WFL [PROF-WFL Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15 -Jul -19 17-Jul•19 19 -Jul -19 20 -Jul -19 21 -Jul -19 22 -Jul -19 23 -Jul -19 1 1 1 1 1 1 1 3G-11 50-103-20733-00 E118-00081 KUPARUK RIVER WL (PROF FINAL FIELD 25 -Jul -19 1 3M-13 7B-16AL1 1A•17 1C-121 3N -14A 3G-08 50.029-21720-00 50-029-22457-60 50-029-22102-00 50.029-23015-00 50-029-21589-01 50-103.20128-00 E118-00084 EDEA -00009 E118-00085 E118-00086 EOSH-00074 EOSH-00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL WL WL WL Caliper PPROF LDL [PROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 28•Jul-19 28 -Jul -19 29 -Jul -19 1 -Aug -19 2 -Aug -19 3 -Aug -79 1 1 1 1 1 1 2N-317 50-103-20266.00 EOSH-00076 KUPARUK RIVER WL LDL FINAL FIELD 4•Aug-19 1 15 A Transmittal Receipt signature confirms that a package (box, V(EW� envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. ame Sign toe Date specific content of the CDs and/or hardco / py prints may or may not have been verified for correctness or quality level at this return via courier or sign/scan and email a copy to Sc leberger and CPAI. point. 'TSPrintCenter slb.com Tom.osterkam mnoco hilli 1c,B Auditor- J'Lj SCANNEDSchlumberger-Private AUG 0 7 2019 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. J~".~- O y_0 Well H~istory File Identifier / Organization(done) ~Two-SidedIIIIIIIIIIIIIIIIII [] Rescan Needed IIIIIIIIIIIIIIIIlll RESCAN DIGITAL DATA ' OVERSIZED (Scannable) ,~'Color items: m Diskettes No. [] Maps: Grayscale items: [] Other, NoFrype D Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds q [] Other NOTES: BEVERLY BREN VINCENT SHERYL MARIA LOWELL TOTAL PAGES: ORGANIZED BY; DATE: Is/ Project Proofing [] Staff Proof By: Date: PROOFED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ SCANNED BY; BEVERLY BRE~HERYL MARIA LOWELL DATE: RESCANNEDBY: BEVERLY BREN VINCEN~ARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd STATE OF ALASKA AL.A OIL AND GAS CONSERVATION CONOSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell Plug Perforations r Perforate f Other 17- Sca'' 6 Alter Casing Fy Rill Tubing F` Stimulate - Frac r Waiver f Time Extension r Change Approved Program r Operat. Shutdow n fl Stimulate - Other r Re -enter Suspended Well j"` 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory 187 -040 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service — 50 029 - 21720 - 00 --CQ 7. Property Designation (Lease Number): 8. Well Name and Number: _ ADL 25523, 25512 3M -13 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River oil Pool 11. Present Well Condition Summary: Total Depth measured 9734 feet Plugs (measured) 9054', 9080' true vertical 6539 feet Junk (measured) 9206 Effective Depth measured 9598 feet Packer (measured) 5601, 9003, 9181 true vertical 6439 feet (true vertical) 3818, 6015, 6141 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 4850 9.625 4887 3416 LINER 5.5 "X4.5" 3425 5.5 9015 6023' RECEIVED PRODUCTION 9674 7 9689 6507 DEC 072012 Perforation depth: Measured depth: 9269'- 9303', 9308'- 9332', 9338' -9380' AO `'" "' C True Vertical Depth: 6203'- 6228', 6231'- 6248', 6253' -6283' MANNED MAR 1 120'3, Tubing (size, grade, MD, and TVD) 3.5, L -80, 8804 MD, 5877 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 7" FB -1 PERMANENT PACKER @ 9003 MD and 6015 TVD PACKER - BAKER SAB -3 PERMANENT PACKER W /K22 ANCHOR SEAL ASSEMBLY @ 9181 MD and E PACKER - ZXPN LINER @ 5601' MD and 3818 TVD .. -- SSSV - CAMCO DS NIPPLE @ 493 MD and 493 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut -in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development Service r Stratigraphic r 16. Well Status after work: , Oil iv Gas r WDSPL r Daily Report of Well Operations XXX GSTOR WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -242 Contact Brett Packer @ 265 -6845 Email J. Brett.Packer(cr�,conocophillips.com Printed Name Brett Packer Title Sr. Wells Engineer Signature ... - X__ Phone: 265 -6845 Date / Z /' ` 1 /12. RBDMS DEC 0 7 2011 ' r '' Form 10-404 Revised 12/2012 /Z ' (s Submit Original Only # l y1 KUP • 3M -13 ConocoPhillips 0- Well • Attributes Max Angle & MD TD AI.iShai, Kr.. Wellbore API/DWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) Gomm Phillips 500292172000 KUPARUK RIVER UNIT PROD 57.42 2,800.00 9,734.0 L... Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: NIPPLE 190 11/8/2010 Last WO: 11/29/2012 41.81 5/31/1987 Weii Conga: - 3M -13, 12/5/2012 433.56 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: WORKOVER ninam 12/5/2012 HANGER, 33 : ^" Casing Strings i+" Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 115.0 115.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37.0 4,886.8 3,416.0 36.00 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 15.0 9,689.1 6,506.6 26.00 J -55 BTC CONDUC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 3 -115 LINER 5.5 "x4.5" 5 1/2 4.950 5,590.0 9,014.9 6,023.5 15.50 L -80 BTCM Liner Details NIPPLE, 493 Top Depth (TVD) Top Inc, Nom/... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 5,590.0 3,812.1 55.50 SLEEVE ZXPN LINER SETTING SLEEVE 5.500 GAS LIFT, tt 3.246 ' ■'. 5,601.1 3,818.4 55.50 PACKER ZXPN LINER SETTING SLEEVE 4.870 5,606.6 3,821.4 55.50 HANGER HMC LINER HANGER (PINNED TO 2500 PSI) 4.830 1 8,803.3 5,875.9 46.48 XO Reducing CROSSOVER 5.5" x 5" 5.000 8,804.3 5,876.6 46.47 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 5 37 -4,887 , ` 8,822.9 5,889.5 46.33 XO Reducing CROSSOVER 5" x 4.5" 4.500 8,873.9 5,924.8 ' 45.96 CEMENTER BAKER HM CEMENTING VALVE 3.900 GAS LIFT, 5,533 8,995.9 6,010.2 45.21 X0 Reducing CROSSOVER 4,5" x 3.5" 3.500 _ 8,997.5 6,011.2 45.21 LOCATOR LOCATOR 2.960 9,004.3 6,016.1 45.23 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY 2.990 . 1 Tubing Strings Tubing Description Strin 0... Strin To ID ... ftKB Set Depth f... Depth (TVD) ... Strin Wt... Strin Top Thrd .. - TUBING p 1 3 1/2 I 2.992 I Top ) 32.9 8,804.3 I Set D N) 5,876.6 9.30 I L -80 I Strin g EUE Completion Details Top Depth GAS LIFT. 1 (ND) Top Incl Nomi... 7,132 ? - Top (ftKB) (ftKB) (1 Item Description Comment ID (in) _ 32.9 32.9 0.02 HANGER FMC GEN IV TUBING HANGER 2.992 493.1 493.1 1.45 NIPPLE CAMCO DS NIPPLE 2.875 GAS 8.193 -- 8,803.4 5,876.0 46.48 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY 3.000 _ Tubing Description String 0... 'String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PACKER ASSY 1 3 1/2 Str 2.992 I 9,002.5 I 9,059.4 I 6,054.8 I 9.30 I L -80 I EUE8RDMOD GAS LIFT, Completion Details 8,780 Top Depth 1111 (ND) Top Incl Noml,,, III Top (ftKB) (ftKB) (°) Item Description Comment ID (In) 9,002.5 6,014.8 45.23 PACKER BAKER 7' FB -1 PERMANENT PACKER 4.000 SEAL ASSY, - -- 9,005.8 6,017.1 45.24 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 8,803 -- 9,053.6 6,050.7 45.40 NIPPLE CAMCO D NIPPLE w/ CA -2 BLANKING PLUG & CATCHER INSTALLED 2.750 9,059.0 6,054.5 45.41 WLEG WIRELINE ENTRY GUIDE 2.992 Tubing Description String 0... Top (ftKB) Set Depth (f... Depth (TVD) ... String ... String Top Thrd TUBING FISH 1998 I 5.62 I String ID ... I 9,124.0 I 9,205.6 'Set D 6,157.7 'String Wt... I Completion Details Top Depth (TVD) Top Incl Noml... Top (ftKB) (KM (°) Item Description Comment ID (in) 9,124.0 6,100.5 45.52 SEAL ASSY CENTRILIFT GST34B HL PFS PARTIAL TANDEM SEAL SECTION 0.000 AI 9,137.6 6,109.9 45.40 ESP MOTOR CENTRILIFT 304 HP KMH 229/81 SERIES 562 MOTOR 0.000 PACKER, 9,003 w /CENTRALIZER SSE. 9,006. T„lirn 9 6 45 PACKER BAKER SAB -3 PERMANENT PACKER w/K22 ANCHOR SEAL 3.000 LINER s.sx4. ASS 5.5)4.5". 5s96 -9,015 9,188.2 6,145.3 44.97 X0 Reducing CROSSOVER REDUCING 3.5 "x2.875" 2.875 ft 9,195.8 6,150.8 44.91 NIPPLE CAMCO 'D' NIPPLE NO GO 2.250 CATCHER, 1 9,204.8 6,157.1 44.83 SOS BAKER SHEAR OUT SUB 0.005 9,048 PLUG, 9,054 `! Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) NIPPLE, 9,054 Top Depth Mt (TVD) Top Inc! WLEG, 9,059 SI k. Top (ftKB) (8165) (a) Description Comment Run Date ID (in) 9,048 6,046.8 45.38 CATCHER 11/17/2012 0.000 SAND, 9,089 9,054 6,050.7 45.40 PLUG CA -2 BLANKING PLUG 11/17/2012 0.000 PLUG. 9,080 - - - - - -- - 9,069 6,061.5 45.45 SAND SAND PLUG 9/22/2012 0.000 SEAL ASSY, - _.____ 9,124 9,080 6,069.2 45.48 PLUG INFLATABLE BRIDGE PLUG 9/21/2012 0.000 ESP MOTOR, 9.138 erforations & Slots 1g Shot PACKER, 9,181 '®� Top (ND) Btm (TVD) Dens Ilk I, _ Top (ftKB) Min (ftKB) (ftKB) (ftKB) Zone Date (eh... Type Comment NIPPLE, 9,196 ■ , 9,269 9,283 6,202.9 6212.9 C-4, A - 3, 3M - 13 8/29/1991 6.0 APERF 2 1/8" EnerJeC 0 deg ph E a 9,283 9,303 6,212.9 6,227.6 A -2, 3M -13 8/29/1991 6.0 APERF 2 1/8" EnerJet; 0 deg ph SOS, 9,205 Mandrel Details Top Depth Top Port (ND) loci OD Valve Latch Size TRO Run APERF, Stn Top(ftKB) (ftKB) (°) Make Model (,n) Sery Type Type ON (psi) Run Date Com... 9289-9,283 ----, - - 1 3,245.2 2,496.7 57.17 CAMCO KBMG 1 GAS LIFT SOV BK -5 0.000 0,0 11/28/2012 APERF, __ 9,283 -9,303 - 2 5,533.4 3,780.0 55.47 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/28/2012 RPERF, 9,308 -9,332 - -- - 3 7,131.7 4,7457 49,05 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 11/28/2012 IPERF, 9,320 -9,323 4 8,192.6 5,459.4 47.48 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 11/28/2012 5 8,779.8 5,859.8 46.65 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 11/28/2012 RPERF. 9,338 -9,380 IPERF. 9,340 -9,379 1 1 PRODUCTION, 15 -9,889 TO, 9,734 KUP • 3M -13 Conoc i f Alaska, Inc C.an0Cden Alps .. KB-Grd y0 Rig Release Date "' _ 41.81 5/31/1987 Well Conk,. -3M- 13,12/5/20124'33 - 56 PM Schematic - Actual Perforations & Slots HANGER, 33 Shot Top 69) Btm (TVD( Dens Top (RKB) Btm (ttKB( (ftK8( (ttKB( Zone Date lah..• Type Comment I 9,308 9,332 6,231.2 6,248.3 A -2, 3M -13 8/29/1991 6.0 RPERF 2 1/8" EnerJet; 0 deg ph 9,320 9,323 6,239.7 6,241.9 A -2, 3M -13 9,338 9,380 6,252.6 6,282.7 A -1, 3M -13 8/17/1987 1.0 IPERF 4 " Csg Gun; 120 deg ph CONDUCTOR, 8/29/1991 6.0 RPERF 2 1/8" EnerJet; 0 deg ph 38'115 9,3 9,379 6,254.0 6,282.0 A -1, 3M -13 8/17/1987 1.0 IPERF 4" Csg Gun; 120 deg ph SI NIPPLE, 493 Notes: General & Safety E Da te Annotation 6/20/1997 NOTE: NORDIC 2 WORKOVER #1 6/23/1998 NOTE: NORDIC 2 WORKOVER #2 GAS 3245 • - �. 5/18/2005 NOTE: 7' CASING LEAK @ 8635' -8658' 5/22/2005 NOTE: CTD WORKOVER #3 7/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 10/13/2011 NOTE: LOCATED POSSIBLE LEAK IN 7" CASING STARTING @ 6747 RKB w/ ELINE LDL SURFACE, 37 - 4,887 - - ', 6/3/20121 NOTE: Welded 65.75" Casing 10.75" .400 wall thickness, 45.5 sleeve on SC @ bottom of starter head. GAS LIFT, 12/5/2012 NOTE: NORDIC 3 WORKOVER #4 5,533 IIIIII GAS LIFT, 7.132 ON GAS LIFT, 8,193 I_ GAS LIFT, 8,780 SEAL A55Y, 8,803 PACKER, 9,003 SBE, 9.008 -tea LINER r---1 5.5.94.5", 5,590 -9,015 IIIIII CATCHER. ,tW opts PLUG, 9,054 NIPPLE, 9,054 ;FA WLEG. 9,059 SAND.9.069 PLUG, 9,080 SEAL ASSV. 9.124 ESP MOTOR, 1 1 V 1 . 1 9,138 IMII PACKER, 9,181 ' II- E NIPPLE,9,198 ir SOS. 9,205 APERF, 9,289 -9,283 - '= APERF. 9,283 -9,303 - _ RPERF. 9,3089,332 _ -- IPERF, 9,320-9,323 RPERF, 9,338 -9,380 IPERF, 9,340 -9,379 PRODUCTION, 15 -9,889 TD, 9,734 DATE SUMMARY 6/29/12 (PRE RWO) : POT -T PASS PPPOT -T PASSED, POT -IC PASSED, OT -IC PASSED, FUNCTIONED TESTED LDS'S (ALL GOOD). 7/6/12 Pumped 262 bbls 9.6# NaCI brine down tbg and up IA to fllowline, displacing out 10.5# CaCl2. (see scanned pump report for more info). 7/10/12 GAUGED TBG TO 2.78" TO 6759' SLM. PULLED 2.69" WRP @ 6759' SLM. BAILED FILL OFF CATCHER, f/8970' TO 8970' SLM. IN PROGRESS. 7/11/12 BAILED FILL OFF CATCHER @ 8985' SLM. PULLED AVA CATCHER @ 8985' SLM. ATTEMPTED PULL 2.81" CA -2 @ 8987' SLM. IN PROGRESS. 7/12/12 BAILED SAND OFF 2.81" CSA -2 BLANKING PLUG @ 9010' RKB. PULLED PLUG. IN PROGRESS. 7/13/12 MEASURED BHP @ 9100' RKB: 4384 PSI. READY FOR E/L TBG CUT. 7/22/12 PUMP CEMENT IN WELLHEAD CONDUCTOR (COMPLETE) 7/27/12 Unable to perform job tasks due to well conditions. Too high a WHP to snub coil in and could not lower WHP by bullheading seawater due to high IA pressures. Could not bleed down IA quick enough to hold below 2,000psi when pumping into wellbore. E -Line will set IBP. 8/11/12 ATTEMPTED TO SET BAKER 2.5" IBP IN 7" CASING BELOW TUBING TAIL. IBP DIDN'T SET PROPERLY AND BECAME STUCK IN THE TUBING TAIL WHEN ATTEMPTING TO POOH TO INSPECT. PULLED OFF OF IBP AT 9017' RKB AND LEFT IT IN THE TUBING TAIL. POST -JOB PRESSURE INDICATES IBP IS SEALING THE TUBING TAIL. * * * ** FISH IN HOLE * * * ** OAL 11.04' IBP WITH 1.375" FISHING NECK"' 8/13/12 ATTEMPTED PULL IBP @ 8944' SLM. UNABLE TO LATCH UP OR MOVE DOWNHOLE. IN PROGRESS. 8/14/12 ATTEMPTED PULL BAKER IBP @ 9017' RKB. MOVED PLUG UP HOLE 30' W/ BAILER. IN PROGRESS 8/15/12 EQUALIZE BAKER IBP @ 8940' SLM. LOST 31.5' TOOLSTRING, APPEARED TO HAVE RECOVERED ALL WIRE. IN PROGRESS P � 8/16/12 RECOVERED LOST TOOLSTRING & 2' OF WIRE. PULLED BAKER IBP @ 8419' SLM, MISSING PART OF ELEMENT. BRUSH TBG, RECOVERED REST OF ELEMENT & 1' OF WIRE. BRUSH TBG OUT OF TTL TO 9050' SLM. COMPLETE 9/20/12 LOCATED D- NIPPLE AT 9010' AND FLAGGED PIPE. CIRCULATED OUT IA AND TBG FROM OPEN POCKET AT 6697' MD TO 9.6 POUND NaCI. SECURED WELL FOR THE NIGHT. JOB IN PROGRESS. 9/21/12 SET IBP AT 9090' MD FROM CORRECTED DEPTH AT FLAG. ATTEMPTED SAND DUMP AND PACKED OFF COIL. RECOVERED ROCKS FROM DISCONNECT AND CHECK VALVES. PUMPED SAND OUT OF COIL. FREEZE PROTECTED TBG IA AND COIL. JOB IN PROGRESS. 9/22/12 LAYED IN 25' SAND DUMP ON TOP OF IBP MID ELEMENT AT 9090' MD. FREEZE PROTECTED WELL. READY FOR S /L. 9/23/12 TAGGED SAND @ 9046' SLM / 9069' RKB. DRAWDOWN TEST ON TBG & IA FAILED. 9/24/12 FIRED STRING SHOT 8985 -8995' ACROSS PREMIER PACKER AT 8987' FOR UPCOMING CHEMICAL CUT. .LOGGED CALIPER ACROSS PACKER TO LOCATE PORTS AS A DEPTH REFERENCE. UPFLOW DETECTED IN TUBING WHILE FLOWING WELL TO TIGER TANKS, INDICATING IBP AT 9090' IS LEAKING. BOTTOM OF FREEZE PROTECT FOUND AT 545' WHILE LOGGING OUT. LOST SMALL SCREW AND NUT IN HOLE FROM STRING SHOT CARRIER. 9/25/12 ATTEMPTED TO CHEMICAL CUT PREMIER PACKER. TOOLS STOPPED FALLING AND BECAME STUCK AT 5510', TOOLS EVENTUALLY WORKED FREE. WILL REATTEMPT AFTER SLICKLINE CLEARS TUBING. 9/25/12 ENCOUNTERED OBSTRUCTION W/ 2.5" BAILER @ 5670' SLM. APPEAR TO HAVE KNOCKED OBSTRUCTION DOWNHOLE. CLEAN DRIFT TO 9032' SLM W/ 2.65" CENT. AND 17' x 2.5 ". READY FOR E -LINE. 9/27/12 PERFORMED CHEMICAL CUT TO FREE PREMIER PACKER. FIRED CUTTER AT 8991.7', CCL TO CUTTER OFFSET 10.9', CCL STOP DEPTH 8979.8'. FREEZE PROTECTED TUBING W/ DIESEL TO 2500'. • • ConocoPhiIIips Time Log & Summary Wellview Web Reporting Report Well Name: 3M - 13 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 11/5/2012 4:00:00 AM Rig Release: 11/29/2012 11:00:00 AM Time Logs « r. Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/08/2012 24 hr Summary Breaking down 11" 5M BOPE stack on 3H -Pad. Begin Rig move to 3M -Pad from 3H -Pad moving off mats to 3A access entrance, on mats for remainder of move. 04:00 07:00 3.00 DEMOB MOVE DMOB P Breaking down 11" 5M BOP Stack and racking on skid. Prep to move rig. 07:00 09:30 2.50 MIRU MOVE MOB P PJSM- Rig move over mats. Begin Rig move to 3M -pad off mats from 3H -pad to 3A -pad entrance. 09:30 11:30 2.00 MIRU MOVE MOB P Set down at 3A -pad access entrance to move mats around and place in front of rig, we will be shuffling on mats the remainder of move towards 3M -pad. Call at 09:31 from CPF -3 Lead to not move rig until further notice due to STP unexpected shut down. Call back from CPF -3 Lead at 10:55, OK to proceed ahead. 11:30 00:00 12.50 MIRU MOVE MOB P Continue to move rig on mats towards 3M -pad, Spine road open to Pioneer at 12:00 hrs. 10/09/2012 Continue Moving Rig to 3M -Pad for Maintenance. 00:00 12:00 12.00 MIRU MOVE MOB P Continue to Move rig on mats from 3M access towards 31 Pad = 7 /10ths mile 12:00 00:00 12.00 MIRU MOVE MOB P Continue to Move rig on mats from 3M access towards 31 Pad = 9 /10ths mile 10/10/2012 Continue Moving Rig to 3M -Pad for Maintenance. Rig camp off high line at 14:00 hrs on 10 -11 -2012 00:00 05:00 5.00 MIRU MOVE MOB P Continue to move rig on mats from 3M access to 31 Pad = 1.6 miles in 41 hrs. 05:00 08:00 3.00 MIRU MOVE OTHR P Shuffle mats around rig towards 3M Pad. 08:00 00:00 16.00 MIRU MOVE MOB P Continue to move rig on mats from 31 towards 3M -pad (2.0 miles Left to travel) 10/11/2012 Moved Nordic Rig 3 on to 3M Pad and seamed pit liners together 00:00 03:00 3.00 MIRU MOVE MOB P Continue to move rig on mats from 31 towards 3M -pad (1.0 miles Left to travel) Page 1 of 22 • Time Logs 'Date From To Dur ' . S Depth E. Death Phase Code Subcode T Comment 03:00 22:30 19.50 MIRU MOVE MOB P Continue to move rig on mats from 31 towards 3M -pad 22:30 00:00 1.50 MIRU MOVE OTHR P Nordic Rig 3 on 3M -pad setting down on mats. Spread out 2x100 -ft x 100 -ft Pit liners and seam together. 10/12/2012 Continue to seam pit liners together and spot rig and set down. Berm up and begin summer maintenance schedule. 00:00 03:30 3.50 MIRU MOVE OTHR P Continue to Seam together 2 - 100 x 100 -ft pit liners. move mats around rig and place in containment. 03:30 05:00 1.50 MIRU MOVE MOB P Pull rig in on mats and set down. Nordic Rig 3 Summer Maintenance started as of 05:00 hrs on 10- 12 -12. 11/05/2012 MIRU Nordic Rig 3. Spot Support Equipment. Load and Kill well with 14.1 PPG KWF. ND Tree and inspect Lift Threads. 03:00 05:00 2.00 MIRU MOVE RURD P Move Rig Over 3M -13. Called Out Valve Crew and Remove Valve Remover Plug From IA. Spot Kill Tanks and RU Hardline to Same. Start Loading KWF into Pits. Called out FMC Rep to Remove BPV when Ready. RU Circulating Hoses for Well kill. Rig Accepted at 04:00 am on 11/05/2012 02:00 04:30 2.50 MIRU WHDBO MPSP P PJSM- Valve service remove VR plug from IA, continue to load pits w/ KWF, build containment around rig, RU of circulating hoses. ✓ 04:30 05:30 1.00 MIRU WHDBO MPSP P PJSM- RU to lubricate out BPV. FMC lubricator pump not working. Call to Valve Shop for truck support to pull BPV. 05:30 08:30 3.00 MIRU WHDBO MPSP P PJSM- Sim -ops with FMC, Valve Crew and N3 personnel pulling BPV under pressure. Lubricate BPV out. Rig down lubricator, RU circulating hoses. Initial T /IA/OA pressures= 900/1000/40 psi on tree gauges and BPV lubricator guage. 08:30 09:00 0.50 MIRU WELCTL SFTY P PJSM- Change out day, crew change. Discussed killing of high pressure well and associated hazards. Pre Spud Mtg. 09:00 10:30 1.50 MIRU WELCTL KLWL P Attempt to blow down hardline to kill tank, hardline to kill tank free of obstruction, check line on tank, good, 6" perferated intake on Kill Tank has 2" of sediment/ice on bottom of pipe covering perfs. Page 2 of 22 • • Tunis Logs: `Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:30 2.00 MIRU WELCTL RURD T Place 2 heaters on Kill tank lines to free up obstruction and blow down kill line 12:30 13:30 1.00 MIRU WELCTI PRTS P Pressure test kill line, fill and test pumps and circulating lines to 3,000 13:30 17:00 3.50 MIRU WELCTL KLWL P Begin Well Kill: SITP, 0 psi, SICP, 700 psi. Start Circulating 14.1 KWF down TBG taking returns up the IA at 3 bpm, 250 psi while holding back pressure on choke manifold. Circulated a total of 322 bbls with 313 bbls returned , FCP 700 psi. 17:00 19:00 2.00 MIRU WELCTI OWFF P Blow down hardline to kill tank and monitor well for flow. After 1 hour, well on vac. R/D Circulating hoses in cellar and set BPV. 19:00 20:00 1.00 MIRU WHDBO NUND P PJSM. Discuss hazard for Nipping down tree. 20:00 21:00 1.00 MIRU WHDBO MPSP T Install Blanking Plug. Wrong Profile on threads. Wait on Different Plug 11/06/2012 Install Blanking plug, NU BOPE and Test Same to 250/3000 psi. Change out Annular element and test with 3 1/2 & 5 1/2 test joints. - Good test. 00:00 00:30 0.50 MIRU WHDBO MPSP P Install Correct Blanking Plug 00:30 01:30 1.00 MIRU WHDBO NUND P PJSM. Nipple Up 11" x 11" 5k Drilling Spool. 01:30 08:00 6.50 MIRU WHDBO NUND P NU BOPE. Install VBR's in the bottom cavity and 5 1/2" Ram's in the Upper Cavity. 08:00 14:30 6.50 MIRU WHDBO PRTS P Function and PT BOP Rams, choke manifold and annular to 250/3,000 psi with 3 1/2" and 5 1/2" Test Joint, draw down test complete. As per contract if NU and testing of BOPE takes more than 12 hrs, the time will be at contractors expense until the complete BOP system is tested to the full working pressure. 15 hrs for NU and Testing - 3 hrs against Billable R &M. 14:30 15:30 1.00 MIRU WHDBO RURD T Attempt to rig down test equipment, donut on 3 -1/2" test joint will not pass annular bag element, drain stack, element balled up around test joint, work donut past element, RD test equipment. 15:30 21:00 5.50 MIRU WHDBO NUND T Nipple down floor riser and flow nipple, change out Annular element, test breaks, test with 3 -1/2" and 5 -1/2" test joints all on chart. 21:00 23:30 2.50 MIRU WHDBO BOPE T PJSM, Function test annular, fill stack w/ water. Test annular with 3 1/2 and 5 1/2 Test joints at 250 / 3,000 psi - good test. 23:30 00:00 0.50 COMPZ WHDBO MPSP P PJSM, Pull blanking plug. Page 3 of 22 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/07/2012 24 hr Summary Pull ISA BPV, Circulate 1 1/2 hole volumes. Rack and Tally 3 1/2 DP, POOH laying down 3 1/2" Tubing with seal assembly. 00:00 01:00 1.00 COMPZ WHDBO MPSP P Locate ISA BPV and verify no pressure below, slight fluid Toss. Retrieve ISA BPV. 01:00 02:00 1.00 6,764 6,737 COMPZ RPCOM PULL P Make up landing jt to hanger and top drive. BOLDS, Unland hanger at 95K, Pull out of PBR at 145K and Pull hanger to rig floor at 90K UP wt. 02:00 05:00 3.00 6,737 6,737 COMPZ RPCOM CIRC P Bring pump online, 12.5 bbls to fill hole increase pump rates in 1 bbl increments to 5 bpm @ 850 psi. 14.1 ppg IN, 13.7 ppg OUT. Circulate 356 bbls 13.7 ppg IN, 13.7 ppg OUT. Increase mud wt to 13.9 ppg in /out with 12 bph losses. Returns spotty on weight, circulate 178 bbls to level out IN and out weights. 05:00 06:00 1.00 6,737 6,737 COMPZ RPCOM OWFF P Monitor welll, losses .6 bph on trip tank. leave completion in place and monitor while rack and tally 3 -1/2" IF DP and 4 -3/4" DC's. 06:00 10:30 4.50 6,737 6,737 COMPZ RPCOM OTHR P PJSM- hand placement. Load, drift and tally DP and DC's. From 05:30 to 08:00 fluid losses were 1.32 bph, well static w/ fluid to surface on trip tank from 08:00 to 10:30 when started POOH w/ de- completion 10:30 00:00 13.50 6,737 0 COMPZ RPCOM PULL P PJSM- Overhead loads, dead zone. POOH laying down 3 -1/2" de- completion and jewelery strapping and noting condition of tubing before kicking out. Recovered seal assembly. Found no holes or corrosion. 11/08/2012 Clean and clear work area. PU and MU BHA #1 and RIH PU 3 1/2 DP to 6,750 -ft. CBU, Engage and release packers. Circulate 1.5 hole volume. POOH w/ fish f/ 9,017 -ft to 8,470 -ft. 00:00 01:45 1.75 COMPZ RPCOM OTHR P Fiish tallying decompletion. Offload pipeshed, change over to DP equipment. Clean and clear work area. Install wear ring. 01:45 02:00 0.25 COMPZ RPCOM SFTY P PJSM on picking up fishing bha. 02:00 03:30 1.50 0 221 COMPZ RPCOM PULD P PU, MU and RIH w/ BHA #1 to 221 -ft. 03:30 10:30 7.00 221 6,734 COMPZ RPCOM PULD P Continue to RIH w/ BHA #1 picking 3 -1/2 Drill Pipe to 6,734 -ft. 125k Up wt. 73k Dn wt. 10:30 12:00 1.50 6,734 6,734 COMPZ RPCOM CIRC P Kelly up to joint #203, Circulate Bottoms Up 13.7 ppg KWF, ICP 830 psi at 3 bpm, FCP 720 psi at 3 bpm, 186 bbls. 12:00 12:30 0.50 6,734 6,734 COMPZ RPCOM OWFF P Monitor well for flow Page 4 of 22 Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 12:30 14:30 2.00 6,734 9,015 COMPZ RPCOM PACK P RIH and engage PBR at 6,757 -ft, Up wt 125k, 73k Dn wt, Pull up to 200k, work PU wts slowly to 235k and upper FHL packer released, monitor well, SO to 100k and PU to 225k no movement, SO to 100k, PU to 155k and straddle is free, monitor well, no gains or losses observed. 14:30 18:00 3.50 9,015 8,995 COMPZ RPCOM CIRC P PU Fish to 6,734 -ft, CBU 1 bpm at 550 psi, 2 bpm at 740 psi 3 bpm at 850 psi, seeing gas at 130 bbls, shut down and shut in bag and circ thru gas buster, reduce pump rate to 1 bpm at 540 psi, 230 bbls pumped shut down and monitor 10 min, no gas, bring pumps back up to 1 bpm at 540 psi, bump up to 1.5 bpm at 630 psi, 13.5 ppg in, 13.0 ppg out at bottoms up circulated out. 88.6 bbls fluid loss while circulating. 18:00 20:00 2.00 8,995 8,995 COMPZ RPCOM COND P Condition mud in pits from 13.3 ppg to 13.7 ppg 20:00 22:00 2.00 8,995 8,995 COMPZ RPCOM CIRC P Gather SPR Pump 1 23 spm © 600 psi / 42 spm @ 720 psi Pump 2 23 spm @ 540 psi / 42 spm @ 680 psi Circulate 240 bbls w/ 85.9 bbl loss circulating @ 3 bpm @ 820 psi. 22:00 22:30 0.50 8,995 8,995 COMPZ RPCOM OWFF P Monitor well for flow for 30 minutes - static 22:30 23:00 0.50 8,995 8,960 COMPZ RPCOM PULD P POOH from 8,995 -ft to 8,960 -ft, pull up to 150k and seen packer release - possible hydraulic while circulating causing fluid loss.- monitor well for flow - static 23:00 00:00 1.00 8,960 8,470 COMPZ RPCOM TRIP P POOH on trip tank monitoring for swabbing from 8,960 -ft to 8,470 -ft. Hole fill was accurate. Note: Seen 6k over pull © 8,525 -ft on wt indicator. Premier PKR @ 8,495 -ft ± and FHL PKR @ 6,273 -ft ± 11/09/2012 Continue to POOH f/ 8,470 and lay down 765 -ft of straddle de completion. TBG found to be parted 3 -ft above cplg. TOF @ 7,523 -_ ft. Discuss options with town engineers, call out Fishing tools and hot shot to rig. Load in pipe shed , PU and RIH w/ wash over assembly to 3,830 -ft staging in the hole @ 2,500 -ft intervals and conditioning hole volume. 00:00 05:00 5.00 8,470 2,703 COMPZ RPCOM TRIP P Continue to POOH f/ 8,470 -ft to 2,703 -ft to BHA #1. 05:00 06:00 1.00 2,703 2,481 COMPZ RPCOM TRIP P POOH w/ BHA #1 to 2,481 -ft. Release from fish. 06:00 07:00 1.00 2,481 2,481 COMPZ RPCOM OPNW P Change over floors to pull 3 -1/2" tubing. Page 5 of 22 1 Time Logs Date From. To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:00 1.00 2,481 1,525 COMPZ RPCOM PULL P POOH laying down and strapping 3 1/2" Straddle de completion, started seeing major erosion starting in joint #61 at 7,091.29 -ft, progressively getting more erosion and build up of de- hydrated hydrocarbons / scale on tubing, only 28.11 -ft of joint #48 on surface. Tubing in Straddle parted due to major erosion at 7523.69 -ft . 3.22 -ft eroded stub looking up, 1499.85 -ft of Straddle still in hole. 08:00 15:30 7.50 0 0 COMPZ RPCOM OWFF T Monitor well on trip tank, get pictures (see attachments) and confer with town engineers, Baker fishing for plan forward, order out fishing tools while continuing monitoring well, well holding 13.6 ppg collum of KWF 15:30 16:30 1.00 0 0 COMPZ RPCOM OTHR T Load Baker wash over assembly in pipe shed and gather ID, OD and length's. 16:30 18:00 1.50 0 253 COMPZ RPCOM PULD T PU and MU BHA #2 (6.125" OD x 5.0" ID Washover shoe) to 253 -ft. 18:00 22:00 4.00 253 2,660 COMPZ RPCOM TRIP T RIH w/ BHA #2 @ 30 -fpm do to fluid coming over the top of DP to 2,660 -ft 65k up wt 50k dn wt. 22:00 23:00 1.00 2,660 2,660 COMPZ RPCOM CIRC T Attain SPR's and reverse circulate surface to surface at 4 bpm @ 500 psi to condition hole volume as planned in 3 stages of 2,500 -ft. Pump 1 20 spm @ 250 psi 40 spm @ 400 psi Pump 2 20 spm @ 275 psi 40 spm @ 420 psi 23:00 00:00 1.00 2,660 3,830 COMPZ RPCOM TRIP T Continue to RIH from 2,660 -ft to 3,830 -ft w/ BHA #2 (Wash over Assembly) 85k up wt, 68k dn wt. 11/10/2012 Continue to RIH w/ BHA #2, conditioning hole volume every 2,500 -ft to TOF @ 7,523 -ft, wash over to 7,551 -ft. CBU, monitor well for flow. Pump out of the hole to 5575 -ft. due to swabbing. Hole fill incorrect. Pump 1 DP vol. (41 bbls) w/ 5 bbl gain. Monitor well for flow - recovered 7 bbls. Prepare to change hole over from 13.8 ppg to 14.2 ppg. PT kill line to kill tank @ 250 / 3,000 psi. 00:00 01:30 1.50 3,830 5,085 COMPZ RPCOM TRIP T Continue to RIH from 3,830 -ft to 5,085 -ft w/ BHA #2 (Wash over Assembly) 100k up wt, 70k dn wt. 01:30 03:00 1.50 5,085 5,085 COMPZ RPCOM CIRC T Circulate Surface to Surface at 3 bpm @ 630 psi 13.7ppg In; 13.6 ppg Out 03:00 04:30 1.50 5,085 6,730 COMPZ RPCOM TRIP T RIH from 5,085 -ft to 6,730 -ft w/ BHA #2 (Wash over Assembly) 125k up wt, 70k dn wt. (67 stds in hole) 04:30 05:30 1.00 6,730 7,295 COMPZ RPCOM PULD T PJSM, Begin PU and RIH with 3 1/2 DP from 6,730 -ft to 7,295 -ft - took wt. 138k up wt, 75k dn wt. 5,000- ft/Ibs free torque. Page 6 of 22 • • TimeLogs Date ` " From To Dur S. Depth . E. Depth Phase Code Subcode T Comment 05:30 09:00 3.50 7,295 7,551 COMPZ RPCOM FCO T PU and begin rotating at 40 rpm w/ 4,500 ft/Ibs torque w/ 90k rot wt. Circulating at 3 bpm @ 950 psi ICP with 24 bph losses. wash down to 7,551 -ft 3 bpm @ 900 psi, lay down 2 joints.3.5 DP. 09:00 10:30 1.50 7,504 7,504 COMPZ RPCOM CIRC T Recipricate and ROT 40 rpm, 4.5k torque, 138k up wt, 90k do wt. while CBU 3 bpm, 950 psi ICP, getting small amounts of BAR and paraffin across shakers, at bottoms up 13.8 ppg in, 14.4 ppg out, same across shakers, Continue to recip and circ 3 bpm @ 940 psi. FCP 940 psi with 250 bbl circulated w/ average 50.9 bph loses, 229.1 bbl losses, 13.8 ppg in, 13.8 ppg out. 10:30 11:00 0.50 7,504 7,504 COMPZ RPCOM OWFF T Monitor well on trip tank, BDTD. well static. 11:00 13:00 2.00 7,504 7,027 COMPZ RPCOM TRIP T POOH standing back 3 -1/2" DP, PU clean 140k, 5 stands pulled to 7,027 -ft, Swab in 4.8 bbl gain, monitor well 30 min, well static. 13:00 14:00 1.00 7,027 7,507 COMPZ RPCOM TRIP T RBIH from 7,027 -ft to 7,507 -ft on 3 -1/2" DP, no gains or losses, visual fluid level stayed same while RIH, Kelly up. 14:00 14:30 0.50 7,507 7,507 COMPZ RPCOM CIRC T Attain SPR's, 50 bbls pumped w/ 50% return. monitor, well static Pump 1 21 spm @ 620 psi 42 spm @ 740 psi Pump 2 21 spm @ 590 psi 42 spm @ 720 psi 14:30 18:00 3.50 7,507 6,040 COMPZ RPCOM TRIP T POOH pumping out of hole, 138k up wt, fluid isolated in pit #1 w/ 56 bbls start, pump .75 bpm at 500 psi, 20 fpm standing back 5 stands DP to 7,027 -ft, monitor well, 54 bbls strapped, Pull 5 stands at same rates to 6,525 -ft, 53 bbls in pit, pump 1 bpm 510 psi while POOH standing back DP, pit has 47 bbls, 13.8 ppg in, 13.8 ppg out. 125k up wt. 18:00 18:30 0.50 6,040 6,040 COMPZ RPCOM OWFF T Monitor well 30 minutes, well static. 18:30 19:30 1.00 6,040 5,575 COMPZ RPCOM TRIP T Pump out of the hole from 6,040 -ft to 5,575 -ft. Hole fill was incorrect. 19:30 20:30 1.00 5,575 5,575 COMPZ RPCOM CIRC T Circulate 41 bbls (1 DP Vol.) @ 2 bpm @ 530 psi - had 5 bbl gain during circulation. 20:30 21:00 0.50 5,575 5,575 COMPZ RPCOM OWFF T Monitor well for flow for 30 minutes - recovered 7 bbls. Close annular in preparation of reverse circulating w/ 14.2 ppg WBM. Page 7 of 22 Time togs Date From .: To Dur S. Depth E Depth Phase Code Subcode T Comment 21:00 23:00 2.00 5,575 5,575 COMPZ RPCOM OTHR T Call town and discuss option of swapping hole over to 14.2 ppg WBM and displacing 13.8 ppg WBM from hole. Offload 230 bbls from pits of 13.8 ppg WBM and Bring on 240 bbls of 14.2 ppg WBM. 23:00 00:00 1.00 5,575 5,575 COMPZ RPCOM OTHR T Mix up 40 bbl of 9.8 ppg brine, flush line to kill tank. Pressure test line to 250 / 3,000 psi due to ice plug removal. 11/11/2012 Continue to prep for hole change over. Swap well with 14.2 ppg WBM recovering 13.8 ppg WBM. Monitor well Pump out of the hole to 1,214 -ft. 1.8% displacement. 00:00 01:45 1.75 5,575 5,575 COMPZ RPCOM OTHR T Continue to offload 230 bbls from pits of 13.8 ppg WBM and Bring on 240 bbls of 14.2 ppq WBM. 01:45 06:30 4.75 5,575 5,575 COMPZ RPCOM CIRC T Begin reverse circulating @ 1 bpm @ 450 psi - took 6 bbls to catch circulation. Increase PR to 2 bpm @ 500 psi. then to 2.5 bpm @ 450 psi. At 3200 strokes volume pumped was 151 bbls and 64 bbls loss = 72% returns. At Surface to Surface stks 190 bbls pumped 89 bbls = 65% returns. Shutdown to bring on 250 bbls of 14.2 ppg WBM. ISIIAP = 220 psi and 110 psi after 1 hr. Continue to reverse circulate @ 2.5 bpm @ 450 psi. At 9700 stks total 458 bbls shut down out of 14.2 ppg mud, 13.5 ppg returns up DP, 280 psi on IA, 0 psi on open DP. while waiting on KWF. 06:30 08:00 1.50 5,575 5,575 COMPZ RPCOM OWFF T IA pressure drop from 280 psi to 200 psi, 0 psi on open DP. 08:00 10:00 2.00 5,575 5,575 COMPZ RPCOM OWFF T Bled IA to 0 psi and monitor on trip tank (8.1 bbls) 0 psi on open DP with no sign of flow while waiting on KWF. 30 minutes 0 psi on IA and DP well static no change in trip tank volume. Same results at 1 hr while waiting on KWF. 10:00 10:30 0.50 5,575 5,575 COMPZ RPCOM OTHR T Bring on 253 bbls of 14.2 ppg KWF. pressures on IA and DP 0 psi with no flow from open DP. Page 8 of 22 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 5,575 5,575 COMPZ RPCOM CIRC T Reverse circulate 14.3 ppg 2 bpm at 500 psi, caught pressure immediately, returns at choke at 21.2 bbls away, 50 bbls pumped and returns at choke unable to overcome hydrostatic head and dump gas buster, pick up rate to 2.5 bpm at 540 psi, same results, shut down at 105 bbls, FCP 2.5 bpm at 540 psi, 13.3 ppg KWF at choke, no retuns to pits. ISIIAP = 220 psi, falling slowly, bleed to 0 psi and monitor on trip tank. DP= 0 psi 12:00 12:30 0.50 5,575 5,575 COMPZ RPCOM OTHR T Confer with town engineer, rig up to circulate long way. 30 minutes IA 0 psi static, DP 0 psi static. 12:30 15:00 2.50 5,575 5,575 COMPZ RPCOM CIRC T Circulate 14.3 ppg WBM 1 bpm at 350 psi, caught pressure immediately, returns at 6.6 bbls, shut down at 120 bbls pumped with 25 bbl (20 %) return 14.4 in, 13.1 out at flowline in pits, RD circ hoses and take sample rotary table of 13.6 PP9• 15:00 16:00 1.00 5,575 5,575 COMPZ RPCOM OWFF T Confer with town engineer, agreed WBM to heavy, reduce weight of WBM to 13.7 ppg. Monitor well for flow while waiting on KWF. well static after 1 hr. 16:00 17:00 1.00 5,575 5,575 COMPZ RPCOM OTHR T Bring on 250 bbls 14.2 ppg WBM, reduce to 13.7 ppg WBM. 17:00 00:00 7.00 5,575 1,214 COMPZ RPCOM TRIP T Attempt to POOH on elevators - hole not taking proper hole fill. Pump out of the hole from 5,480 -ft at 1 bpm @ 230 psi. - (equivalent to 1.73% displacement) to 1,214 -ft. 11/12/2012 Continue to Pump out of the hole w/ BHA #2. Conduct weekly BOP test @ 250 / 3,000 psi. PU and RIH w/ BHA #3 (3 1/2 Mule shoe joint) Circulate to condition active mud system. not able to obtain circulation. Confer with Town engineer to pump LCM pill and lighten mud wt from 14.2 ppg to 13.7 ppg. Begin mixing LCM pill , weighted sweep and lighten surface volume. 00:00 01:00 1.00 1,214 253 COMPZ RPCOM TRIP T Continue to Pump out of the hole from 1,214 -ft at 1 bpm @ 230 psi. - (equivalent to 1.73% displacement) to 253 -ft. 01:00 03:00 2.00 253 0 COMPZ RPCOM TRIP T POOH w/ BHA #2 on trip tank, lay down jar, BS and 1 jt wash pipe. Recovered 64.45 -ft of 3 1/2 TBG - leaving 1.51 -ft of jt #46. New TOF @ 7,587.25 -ft corrected back to Doyon 9 RKB 03:00 04:00 1.00 0 0 COMPZ WHDBO OTHR P PJSM, Pull wear ring and set test plug. Page 9 of 22 • 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 09:30 5.50 0 0 COMPZ WHDBO BOPE P RU and Conduct weekly BOP test @ 250 / 3,000 psi with 3 1/2 and 5 1/2 Test joints. Notice was given to AOGCC for closure of Annular @ 21:00 hrs on 11- 10 -12. We also asked to perform Weekly test due on 11- 13 -12. Permission granted and right to witness was waived by John Crisp at 20:50 PM on 11- 11 -12. Rd test equipment. 09:30 10:00 0.50 0 0 COMPZ WHDBO OTHR P Pull test plug and set wear ring. 10:00 11:00 1.00 7,580 COMPZ RPCOM OTHR T Blow down hard line to kill tank. Rack and tally 3 -1/2" IF muleshoe joint. 11:00 11:15 0.25 0 0 COMPZ RPCOM SFTY T PJSM- Discussed hazards of Tripping Pipe. 11:15 15:30 4.25 0 7,580 COMPZ RPCOM TRIP T MU 3 -1/2" DP muleshoe on 3 -1/2" DP and RIH to 7,580 -ft, 132k up wt, 78k do wt, hole lost 12 bbls while rih. 15:30 15:45 0.25 7,580 7,580 COMPZ RPCOM SFTY T PJSM- Discused high pressures associated with circulating. 15:45 16:15 0.50 7,580 7,580 COMPZ RPCOM CIRC T Bring on Pump 1 bpm at 450 psi, 2 bpm at 560 psi, 3 bpm at 650 psi no returns at 25 bbls, 4 bpm at 1060 psi getting returns at 30 bbls, pump 78 bbls with 5 bbl return, shut down pump. 16:15 21:00 4.75 7,580 7,580 COMPZ RPCOM OWFF T Confer with town engineer while monitoring well and waiting on LCM material from Prudhoe. 21:00 00:00 3.00 7,580 7,580 COMPZ RPCOM COND T Pre mix 40 bbls of 15.8 ppg weighted sweep and move to Pit 4. Pre -mix 40 bbls Calcium Carbonate LCM pill in pill pit. Pre -mix 150 bbls of 13.7 ppg WBM in pit 3 Move and top off pit 2 with 150 bbls of 14.2 ppg WBM Leave remaining 14.2 ppg WBM in pit 1. 11/13/2012 Continue to mixing LCM pill and lighten surface volume. Pump as per schedule and change hole volume over to 13.7 ppg WBM. Condition active circulating system to 13.7 ppg. RIH and CIO to 7,580 -ft. Monitor well for 30 minute. POOH w/ BHA #3. Pick up and RIH w/ BHA #4 Washover pipe w/ T dog Overshot to 1,444 -ft. 60k up wt; 55k do wt. 00:00 03:00 3.00 7,580 7,580 COMPZ RPCOM COND T Continue to - Pre -mix 40 bbls Calcium Carbonate LCM pill in pill pit. Pre -mix 150 bbls of 13.7 ppg WBM in pit 3 Move and top off pit 2 with 150 bbls of 14.2 ppg WBM Leave remaining 14.2 ppg WBM in pit 1. Page 10 of 22 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:15 0.25 7,580 7,580 COMPZ RPCOM SFTY T Held PJSM on pumping LCM and Weighted sweep. Discuss fluid movements and communication, know your fluid paths. 03:15 09:00 5.75 7,580 6,520 COMPZ RPCOM CIRC T Pump while rotating @ 40 rpms - 34 bbls of 40 bbl 14.2 ppg Calcium Carbonate LCM pill @ 3 bpm @ 610 psi. followed by 41 of 43 bbls 14.2 ppg WBM @ 3 bpm @ 590 psi. Spotting as a balanced plug. POOH from 7,586 -ft to 6,520 -ft. Pump 20 bbls of 20 bbl 13.7 ppg WBM spacer @ 2 bpm @ 460 psi. Followed by 37 bbls of 40 bbl 16.0 ppg weighted sweep @ 2 bpm @ 460 psi, caught circulation @ 10.5 bbls away, Chase w/ 106 bbls of 13.7 bbls for Total pumped 238 bbls pumped and 140 bbls returned - 98 bbl loss. SD and condition 150 bbls of 13.7 ppg WBM. Continue pumping @ 3 bpm @ 780 psi 09:00 11:00 2.00 6,520 7,580 COMPZ RPCOM TRIP T PJSM, RIH from 6520' to 7580' while circulating at 3 bpm and rotating 40 rpm. Up 138k #, Dwn 78k# 11:00 12:30 1.50 7,580 7,580 COMPZ RPCOM CIRC T Circulating at 3bpm ICP 760 psi, BU. FCP 760 psi, 13.7 ppg Up and Down 12:30 13:00 0.50 7,580 7,580 COMPZ RPCOM OWFF T Monitor Well, Static 13:00 16:00 3.00 7,580 0 COMPZ RPCOM TRIP T PJSM, POOH with BHA #3 w/ Mule Shoe from 7580' up at 138k# 16:00 17:00 1.00 0 0 COMPZ RPCOM PULD T Clean and Clear Floor, R/U to run BHA #4 17:00 17:15 0.25 0 0 COMPZ RPCOM SFTY T PJSM on PU, MU and RIH w/ 5 3/4" Wash pipe 17:15 23:00 5.75 0 573 COMPZ RPCOM PULD T PU Baker "T -Dog" Overshot w/ 6" x 4.625" ID Reverse sawtooth shoe and RIH on 12 jts of 5 3/4 TSS Wash Pipe, TS, BS, Jars, 6 - 4 3/4" DC's to 566 -ft. 23:00 00:00 1.00 573 1,444 COMPZ RPCOM TRIP T RIH w/ BHA #4 from 573 -ft to 1,444 -ft 60k up wt; 55k do wt. 11/14/2012 Continue to RIH w/ BHA #4 from 1,444 -ft to 6,570 -ft. Lost 3 charge pumps - Suspend operations and replace two charge pumps. RIH to 7,541 -ft. CBU. 00:00 06:30 6.50 1,444 6,570 COMPZ RPCOM TRIP T RIH w/ BHA #4 from 1,444 -ft to 6,570 -ft 127k up wt; 73k do wt. 06:30 19:00 12.50 6,570 6,570 COMPZ RIGMN1 RGRP T Charge pumps 1,3 and 4 went down. Removed charge pumps and found 3 to be different failures. CP #1 had pin hole in snail housing. CP #3 lost shaft bearings. CP #4 lost main seal. 19:00 22:30 3.50 6,570 7,541 COMPZ RPCOM OTHR T Circulate charge pumps and slowly rotate wash pipe for 90 ft. Start P/U stand # 63 and trip in hole. Up weight 128K. to break gel strength in hole from setting for 12 hrs. Page 11 of 22 Time Logs 4110 • Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 7,541 7,541 COMPZ RPCOM TRIP T CBU @ 3 bpm @ 1,010 psi with 142 bbls pumped and 11 bbl losses. 11/15/2012 Wash down to 7,587 -ft (TOF) and wash over to 7,948 -ft. PU and engage T dog overshot and release fish. POOH and lay down fishin• tools and 13 jts of 3 1/2 de completion. 00:00 01:30 1.50 7,541 7,541 COMPZ RPCOM CIRC T Continue to circulate for a total surface to surface. SPR Pump 1 21 spm @ 520 psi 42 spm @ 710 psi Pump 2 21 spm @ 520 psi 42 spm © 690 psi Gather Parameters: 150k up wt. 75k dn wt. ROT up wt 115k 86k dn. Rotating 20 rpms @ 5,500 ft/lbs - 40 rpms @ 5,500 rpms. 01:30 05:00 3.50 7,541 7,945 COMPZ RPCOM FISH T Wash down to TOF at 7,587 -ft to 7,945 -ft. @ 3bpm @ 1,030psi, rotating @ 20 rpms. 05:00 05:30 0.50 7,945 9,000 COMPZ RPCOM FISH T PU while circulating @ 3 bpm @ 1,030 psi and engage T dogs on TBG cplg @ 7,929 -ft. Pull 20k OSW of 130k and allow jars to release. PU to 175k and seen no movement, increase to 225k and release pkr. move up hole 10 -ft and allow elements relax. Weight fell back to 165k, 35k over work string. With fish tail @ 9,000 -ft.±. 05:30 08:00 2.50 9,000 9,000 COMPZ RPCOM CIRC T Circulate 1.5 volumes @ 3 bpm @ 1,020 psi. FCP 1150 psi 08:00 08:30 0.50 9,000 9,000 COMPZ RPCOM OWFF T Monitor well for flow for 30 minutes. Static. 08:30 16:00 7.50 9,000 605 COMPZ RPCOM TRIP T PJSM, POOH from 7923' DPM, Up 165 k#, Circulate out at 1.5 bpm to BHA #4. Zero gains or losses over displacement. 16:00 16:15 0.25 605 605 COMPZ RPCOM SFTY T PJSM, LD BHA#4 T -Dog Overshot while monitoring well for flow at the BHA. 16:15 00:00 7.75 605 0 COMPZ RPCOM PULD T POOH w/ 605 -ft of fishing BHA, standing back 6 - 4 3/4" OD Drill collars, lay down fishing jars and bumper sub. Begin stripping out of the hole with 12 jts of 5 3/4" OD wash pipe and recovering 374 -ft of the 1,437 -ft of 3 1/2 TBG to 1,062 -ft left to pull as of midnight. 11/16/2012 Offload fishing tools and and continue to lay down 1,062 -ft of 3 1/2 de completion. PU, MU and RIH w/ BHA #5 csg scraper assy. RIH to 9,060 -ft, Circulate surface to surface x2. POOH to 4,190 -ft. 00:00 02:30 2.50 0 0 COMPZ RPCOM OTHR T Clean and clear work area, Offload Baker fishing tools and load BHA #5 02:30 04:30 2.00 0 0 COMPZ RPCOM PULL P POOH laying down 3 1/2 de completion, packer and tail pipe. Page 12 of 22 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:00 1.50 0 0 COMPZ RPCOM OTHR P Change over to DP equipment, clean and clear work area, Offload Baker fishing tools basket. 06:00 06:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM for PU and MU of BHA #6 (CSG scraper Assy) 06:15 07:00 0.75 0 217 COMPZ WELLPF PULD P PU, MU BHA #6 (CSG scraper Assy)- 6 1/8" Bit, 7" CSG scraper, 2 -Boot baskets, BS, Jars, 6-4 3/4" DC's to 217'. 07:00 09:00 2.00 217 2,500 COMPZ WELLPF TRIP P RIH to 2500'. Up 70k# and 65k# down. 09:00 09:30 0.50 2,500 2,500 COMPZ WELLPF CIRC P PJSM, Circulate BU at 3 bpm at 400 psi. 09:30 13:00 3.50 2,500 6,320 COMPZ WELLPF TRIP P Continue to RIH and work through tight spots at 3435, 3507', and 3770'. Circulating at 3 bpm at 440 psi surface to surface. Continue to 6320'. Up 110k# and down 75k #. 13:00 14:00 1.00 6,320 6,320 COMPZ WELLPF CIRC P Circulate BU at 3bpm at 760 psi. 14:00 16:30 2.50 6,320 9,015 COMPZ WELLPF TRIP P Continue RIH to 9015'. Stack out 25k# and 10k# overpull. Two attempts and unable to pass. 16:30 16:45 0.25 9,015 8,995 COMPZ WELLPF TRIP P PUH 20' to circule BU. 16:45 18:15 1.50 8,995 8,995 COMPZ WELLPF CIRC P Circulate BU at 3BPM. ICP at 1500 psi. 18:15 19:30 1.25 8,995 9,060 COMPZ WELLPF FCO P Continue to clean out to 9,060 -ft Circulating @ 4 bpm @ 1,640 psi w/ minimal returns. Estimated losses @ 156 bph. 19:30 20:00 0.50 9,060 9,024 COMPZ WELLPF OWFF P Monitor well for flow on trip tank volume of 36 bbls - Static 20:00 00:00 4.00 9,024 4,190 COMPZ WELLPF TRIP P Drop 2.125" OD drift w/ 90 -ft wire and POOH w/ BHA #5 from 9,024 -ft to 4,190 -ft 93k up wt 11/17/2012 Continue to POOH and lay down DC's and BHA #5. RU E -line and caliper log 7" csg 9,063 -ft on wireline. RD E -line. PU, MU and RIH w/ FB -1 Lower Pkr assy to 107 -ft. 3k 00:00 02:45 2.75 4,190 224 COMPZ WELLPF TRIP P Continue to POOH w/ BHA #5 from 4,190 -ft 93k up wt to 224 -ft. 02:45 03:00 0.25 224 224 COMPZ WELLPF OWFF P Monitor well for flow at BHA - - Static 03:00 04:30 1.50 224 0 COMPZ WELLPF PULD P POOH laying down BHA #5 04:30 07:00 2.50 0 0 COMPZ WELLPF OTHR P Clean and Clear Rig floor and bring FB -1 Completion. Install Dutch riser 07:00 09:00 2.00 0 0 COMPZ EVALWE ELOG P PJSM, Load Tools on Rig, RU Eline, PT Dutch Riser and Packoff to 1000 psi, OK. 09:00 09:15 0.25 0 0 COMPZ EVALWE ELOG P RIH with HES SRO Eline 40 arm Caliper to -3500'. 09:15 10:15 1.00 0 0 COMPZ EVALWE ELOG T Knuckle Joint shorted out at -3500', POOH and swap out. RBIH to 3500'. 10:15 16:00 5.75 0 0 COMPZ EVALWE ELOG P Continue RIH from 3500' with 40 Arm Caliper. Log up Caliper from 9063' to Surface. 16:00 17:30 1.50 0 0 COMPZ EVALWE ELOG P PJSM. RD HES Eline, LD Dutch Riser, Off Load from Rig. Page 13 of 22 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 20:30 3.00 0 0 COMPZ RPCOM SLPC P PJSM, Hang traveling blocks, slip and cut 94 -ft of 1 -1/8" drill line. 20:30 22:30 2.00 0 0 COMPZ RPCOM OTHR P Strap Bottom Baker Packer completion and Retrievamatic test packer and lay out in run order. QC tally and hold PJSM on PU and MU of equipment. 22:30 00:00 1.50 0 0 COMPZ RPCOM PULD P PU and MU FB -1 Lower packer assy and "J" Hydrualic setting tool. RIH on 1 jt of 3 -1/2 DP to 107 -ft. Continue to PU and MU retrievamatic test packer - surface test to verify setting direction. RIH on 1 stand of DP to 221 -ft 11/18/2012 Continue to PU retrievamatic test packer and RIH to 9,057 -ft RKB Corrected depth. Set FB -1 at 9,002 -ft and release off. POOH to 8,967 -ft w/ setting tool and 8,919 -ft w/ Test pkr - set and test down DP against FB -1 pkr @ 3,000 psi for 30 min. and chart - good test. Change hole over to 10.5 ppg KWF. Monitor well while cleaning pits to accept 10.5 ppg Brine. 00:00 00:30 0.50 0 220 COMPZ RPCOM TRIP P Continue MU Lower Completion FB -1 Packer Assy to 220' 00:30 01:00 0.50 220 220 COMPZ RPCOM OTHR P CO Floor Equipment 01:00 08:30 7.50 220 9,059 COMPZ RPCOM TRIP P Continue RIH from 220' with Lower Completion to 9059'. Up 155 k# and down 80k #. 08:30 10:30 2.00 9,059 9,059 COMPZ RPCOM PACK P PJSM. RU to set Packer, Break Circ, Drop Ball and Pump to Seat. Pressure up to 3600 psi and set FB -1 Packer at 9002' and shear off. 10:30 11:30 1.00 9,059 8,919 CQMPZ RPCOM TRIP P Pull up and set Test Packer at 8,919' 11:30 12:30 1.00 8,919 8,919 COMPZ RPCOM PRTS P RU and PT between FB -1 and Test Packer to 3000 psi and chart. Good test. 12:30 13:00 0.50 8,919 8,919 COMPZ RPCOM PRTS P RD Test Equipment, Release Test Packer 13:00 14:30 1.50 8,919 8,919 COMPZ WELLPF OTHR P Offload/ Clean Pits, prepare to displace well. 14:30 17:30 3.00 8,919 8,919 COMPZ WELLPF CIRC P PJSM. Circulate 70 bbls of 13.7 ppg high vis mud sweep at 3 bpm down the DP up the IA. Follow with 125 bbls of 8.5 ppg high vis fw at 3 bpm. After fluid turned the corner, getting 80% returns and progressed to 1:1 returns. Swap over a pump 320 bbls of 10.5 ppg brine. Get 10.5 ppg back. 17:30 00:00 6.50 8,919 8,919 COMPZ WELLPF OTHR P BDTD,Monitor Well while Cleaning Pits to accept 10.5 ppg 11/19/2012 Continue to clean pits. CBU, Monitor well and Continue to POOH laying down to 5,746 -ft. Set test packer @ 5,693 -ft and test IA at 3,500 psi for 30 minutes on chart. 00:00 10:00 10.00 8,919 8,919 COMPZ WELLPF OTHR P Continue to monitor well while cleaning pits to accept 10.5 ppg Brine. Load Baker Tools in Pipe Shed. Monitor Well, Gain 2.5 bbls. Page 14 of 22 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:30 2.50 8,919 8,919 COMPZ WELLPFCIRC P PJSM, Circulate 10.5 ppg Hi -Vis Pill followed by 320 bbls of 10 ppg Brine down Tubing returns up IA at 3 bpm at 700 psi. FCP 650 psi. Lost 24 bbls. Returns of 10.7 ppg noted by mud eng. 12:30 16:45 4.25 8,919 8,919 COMPZ WELLPF OWFF P Monitor Well and U- tubing up DP. Flow rate from DP approx 1/2 bpm and dropping slightly in Annulus. Attempt to Reverse Circ up DP and plugged off immediately. Swap around and re- establish circ long way. Prepare NaCI /Br Pill for dry job while monitoring Well. Static for 30 minutes and start to pull and get slight flow, screw on TD and pump pill down DP. 16:45 20:30 3.75 8,919 6,840 COMPZ WELLPF PULD P Well static and POOH dry. Fill Hole after 15 jts and Well took 0.8 bbls over displacement. Continue POOH. Second 15 jts and additional 0.2 bbls over to 7,800 -ft as of 18:00 hrs. Crew change and continue to POOH laying down to 6,840 -ft. 20:30 21:30 1.00 6,840 5,746 COMPZ WELLPF TRIP P Continue to POOH to 5,746 -ft, Lay down 1 jt. Set packer at 5,692 -ft. 21:30 21:45 0.25 5,746 5,746 COMPZ WELLPF SFTY P Held PJSM with rig crew on rigging up for pressure test on 7" CSG from 5,692 -ft to surface. 21:45 00:00 2.25 5,746 5,746 COMPZ WELLPF PRTS P RU to IA valve with hose from rig floor thru mouse hole. Attempt to PT 3 1/2 x 7" IA from 5,692 -ft to surface with LPR's closed @ 3,500 psi. 11/20/2012 Continue to attempt Pressure test from 5,693 -ft and test IA at 3,500 psi for 30 minutes on chart. - failed. Continue to POOH and lay down "J" hydraulic setting tool. Pull wear ring and install test plug. Conduct weekly BOP test at 250 / 3,000 psi w/ 2 7/8, 3 1/2 and 5 1/2. MU & RIH with Clean Out Assembly. 00:00 02:30 2.50 5,746 5,651 COMPZ WELLPF PRTS T Continue to attempt to PT 3 1/2 x 7" IA from 5,692 -ft to surface with LPR's closed @ 3,500 psi on 1st test - lost 75 psi in 10 minutes. Attempt to pt again and lost 125 psi in 15 minutes. Bled off and move packer 5 -ft up to 5,687 -ft, pt @ 3,500 psi and 154 psi in 5 minutes. Bled off and attempt to release packer, not able "J" back in for downward movement. Have to POOH. RD test equipment. 02:30 02:45 0.25 5,651 5,651 COMPZ WELLPF SFTY T Held PJSM on tripping out w/ failed test packer. 02:45 07:00 4.25 5,651 0 COMPZ WELLPF TRIP T POOH and lay down test packer and FB -1 Packer setting tool Page 15 of 22 Time Logs • • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 07:00 16:00 9.00 0 0 COMPZ WHDBO BOPE P RU and Conduct weekly BOP test @ 250 / 3,000 psi with 3 -1/2 ", 2 -7/8" and 5 -1/2" Test joints. Email notice was given to AOGCC to perform Weekly test @ 07:20 hrs on 11- 18 -12. Right to witness was waived by Chuck Scheve at 07:39 hrs on 11 -18 -12 via email. At 18:08 hrs on 11 -19 -12 notice was given to AOGCC via email that operations were taking longer than expected, Chuck Scheve called back and verbally acknowledged. Mr Scheve requested further update if test time was pushing past 06:00 hrs. Following email notice was furnished to AOGCC at 05:38 am on 11/20/12: "Update as per request by Chuck Scheve via call back on 11 -19 -12 © 18:20 hrs. Currently POOH from 2,200 -ft and rigging up for weekly BOP test as of 05:30 hrs on Tuesday November 20, 2012. Had trouble with the test packer not going back into run mode allowing downward movement, unable to pull wear ring and set test plug resulting in trip out from 5,700 ft." 16:00 17:00 1.00 0 0 COMPZ WHDBO MPSP P PJSM. Pull Test Plug. Set Wear Ring. 17:00 17:30 0.50 0 0 COMPZ WELLPF PULD T Load Tools For Clean Out Run. 17:30 19:30 2.00 0 103 COMPZ WELLPF PULD T PJSM. MU Clean Out Assembly. 3 1/2" x 2 7/8" XO, 2 7/8" x 2 3/8" XO, eue 511 Collar, (1) 2 3/8" Mule Shoe Joint, (1) 2 3/8" Working Joint and (1) Joint of 3 1/2" Drill Pipe, RKB 6.50 -ft total clean out Assembly 102.51 -ft. 19:30 00:00 4.50 7,650 7,650 COMPZ WELLPF TRIP T PJSM. Check Handling Equipment. Trip in hole with C/O Assembly on Drill Pipe. Current Depth as of Midnight 7,650 -ft, Up Wt 135k / Dn _ Wt88k 11/21/2012 Perform Fill Clean Out down to top of catcher sub at 9040 -ft. TOOH and UD Clean Out Assembly. NU & RIH with Test packer and Started Casing Evaluation Test. 00:00 01:27 1.45 7,650 9,040 COMPZ WELLPF TRIP T Continue In Hole with Clean Out Assembly f/ 7,650 -ft on Drill Pipe. 01:27 04:45 3.30 9,040 9,046 COMPZ WELLPF CIRC T Up Wt 155k / Dn Wt 88k. Wash down to 9,046 -ft at 3-4 BPM, 840 psi down drill pipe. Shut down and set up to reverse circulate x3 at 3 bpm, 420 psi. Seen trace of fine sand across shakers. Page 16 of 22 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 12:00 7.25 9,046 1,164 COMPZ WELLPF TRIP T Blow down top drive. TOOH with clean out assembly from 9042'. Up 124k #. POOH to 1164'. Up 50k #. Getting some flow up drillpipe, out of balance. Rig up to reverse circ a DP Volume 8 bbls at 2bpm, 80 psi. 12:00 12:30 0.50 1,164 1,164 COMPZ WELLPF CIRC T At 1164', rig up to reverse circ a DP Volume 8 bbls at 2bpm, 80 psi. 12:30 13:30 1.00 1,164 0 COMPZ WELLPFTRIP T Continue POOH from 1164' to Surface. 13:30 14:30 1.00 0 0 COMPZ WELLPF PULD T PJSM, LD BHA #6, MU BHA #7 Test Packer. 14:30 18:45 4.25 0 5,700 COMPZ WELLPFTRIP T RIH with BHA #7 Retreivamatic Test Packer to 5700' 18:45 19:15 0.50 5,700 5,700 COMPZ WELLPF MPSP T On Depth to Set Test Packer. Set Test Packer and RU Testing Equipment to test 7" Casing Integrity, fill drill pipe. Pressure up on IA to 3500 psi, Lost 250 psi in 5 Minutes. Bleed down pressure and PUH for next test. 19:15 19:45 0.50 5,700 5,013 COMPZ WELLPFTRIP T PUH with Test Packer to 5,013 -ft. Up Wt100k /DnWt76k 19:45 20:30 0.75 5,013 5,013 COMPZ WELLPF MPSP T Set Test Packer. RU testing equipment and fill drill pipe. Pressure up on 7" Casing to 3500 psi. Lost 250 psi in 5 minutes. 20:30 23:00 2.50 5,013 3,300 COMPZ WELLPFTRIP T Release Test Packer and PUH for another test. 23:00 23:30 0.50 3,300 3,300 COMPZ WELLPF MPSP T Set Test Packer and RU testing equipment and fill drill pipe. Pressure up 7" Casing to 3500 psi again. Same results as pass test. 23:30 00:00 0.50 3,300 3,000 COMPZ WELLPFTRIP T RD Test equipment. Release Test Packer and TOOH f/ 3,300 -ft to Inspect Packer. 11/22/2012 7" Casing Evaluation. Used Test Packer to Locate Casing Leak. MU & RIH with Storm packer. 00:00 02:00 2.00 3,000 0 COMPZ WELLPFTRIP T Continue OOH with Test Packer for Inspection. 02:00 02:30 0.50 0 0 COMPZ WELLPF RURD T OOH with Test Packer. Remove and Inspect Packer. No Damage. 02:30 03:30 1.00 0 492 COMPZ WELLPFTRIP T NU & TIH with Test Packer down to 1000 -ft 03:30 04:30 1.00 492 492 COMPZ WELLPF PRTS T Set Test Packer. RU Testing Equipment and Fill Drill Pipe. Perform Casing Evaluation Pressure Test on 7 inch. 04:30 05:30 1.00 492 1,498 COMPZ WELLPFTRIP T Was able to obtain a passing pressure test for 30 minutes at 3500 psi on the 7" casing at 492 -ft. Release test packer and continue in hole down to 1,498.0 -ft for another test. Page 17 of 22 • Time Logs • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 05:30 10:30 5.00 1,498 2,814 COMPZ WELLPF PRTS T Set Test Packer. RU Testing Equipment and Fill Drill Pipe. Perform Casing Evaluation Pressure Test on 7 inch to 3500 psi- 1498' test pass and chart for 30 min. 10:30 14:00 3.50 2,814 1,944 COMPZ WELLPF PRTS T Set Test Packer at 2814'- fail. Set at 2430' - fail. Set at 2208' - fail. Set at 2044' - fail. Set at 1800' - pass and chart for 30 minutes. Set at 1944' - pass and chart for 30 minutes. Leak determined to be between 1944' - 2044'. 14:00 15:30 1.50 1,944 15 COMPZ WELLPF PRTS T PJSM. POOH Up 60k #. 15:30 16:00 0.50 15 0 COMPZ WELLPF PULD T LD BHA #8 16:00 20:00 4.00 0 1,194 COMPZ WELLPF TRIP T PJSM. MU BHA #9. Mule Shoe and DP to 1194', Wait on Storm Packer. Rig up Bleed Hose to OA. 20:00 22:30 2.50 1,194 1,194 COMPZ WELLPFOWFF T Storm Packer On Location. Inspect and load to Rig Floor. Continue to Observe OA for Flow. Load 5 1/2" Casing for scab liner. 22:30 22:45 0.25 1,194 1,194 COMPZ WELLPFSFTY T PJSM. Discuss Hazard for Making Storm Packer on Drill pipe 22:45 23:30 0.75 1,194 1,220 COMPZ WELLPF PULD T PU & MU Model "L" Retrievamatic Storm Packer. 23:30 00:00 0.50 1,220 1,300 COMPZ WELLPF TRIP T TIH w/ Storm Packer and Set at 2,200 -ft. 11/23/2012 Set Storm Packer. Observe well for flow, unable to obtain no -flow test. RIH and Pulled Storm packer. Started Running 5 1/2" Liner. 00:00 01:15 1.25 1,300 2,229 COMPZ WELLPFTRIP T Continue with Storm Packer on Drill pipe. 01:15 01:45 0.50 2,229 2,229 COMPZ WELLPF MPSP T On Depth for setting storm packer. Set Packer at 2,229 -ft 01:45 03:00 1.25 2,229 0 COMPZ WELLPFTRIP T Seen good indication that packer set. TOOH standing back drill pipe. 03:00 03:15 0.25 0 0 COMPZ WELLPF PULD T OOH, Lay down setting assembly for storm packer. 03:15 06:30 3.25 0 0 COMPZ WELLPF OWFF T Observe Well for flow prior to ND Stack for Cement Packoff Swap. 06:30 08:00 1.50 0 2,225 COMPZ WELLPFTRIP T PJSM. RIH to 2225' to Retreive Packer. Down 62k #, Up 63k #. Tag 3' high. Rig up to Circulate. 08:00 09:00 1.00 2,225 3,440 COMPZ WELLPF TRIP T Circulate 4 bpm down DP and engage and Release Packer at 2230' + 1194' DP Below. Up 75k #, Dwn 66k# 09:00 10:00 1.00 3,440 3,350 COMPZ WELLPFTRIP T POOH to 3350' and BDTD, Reverse Circulate 26 bbls to equalize DP. 10:00 10:30 0.50 3,350 3,350 COMPZ WELLPF OWFF T Monitor Well- Static 10:30 13:00 2.50 3,350 0 COMPZ WELLPFTRIP T POOH from 3350' to 1194'. LD BHA Storm Packer. Continue POOH to 420'. Monitor Well- Static. Finish LD Mule Shoe Page 18 of 22 Time Logs • �. Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 16:00 3.00 0 0 COMPZ RPCOM OTHR P Clear and Clean Floor, C/O Floor Equipment and prep for Scab Liner Run, PJSM 16:00 20:30 4.50 0 0 COMPZ RPCOM OTHR T Wait On Orders from Town. 20:30 20:45 0.25 0 0 COMPZ RPCOM SFTY X PJSM. Discuss Hazard for Making Up Liner 20:45 00:00 3.25 0 2,113 COMPZ RPCOM PULD X MU and RIH 5 -1/2" Liner Assembly. Up Wt 62k 11/24/2012 RIH w/ 5.5" Scab Liner and set same. MU & RIH with Cement Work String. 00:00 01:45 1.75 2,113 3,403 COMPZ RPCOM RCST X Continue in Hole with 5 1/2" Liner 01:45 02:15 0.50 3,403 3,414 COMPZ RPCOM PULD X PU and MU 5 1/2" x 7" HMC Liner Hanger, 5 1/2" x 7" ZXPN Liner top Packer and ZXPN Liner setting sleeve. 02:15 02:45 0.50 3,414 3,414 COMPZ RPCOM PULD X C/O Handling Equipment to Hander Drill Pipe. 02:45 14:30 11.75 3,414 9,000 COMPZ RPCOM TRIP X Continue in hole with 5 1/2" Liner on 3 1/2" IF Drill Pipe. Fill DP at 7785', 8080'. 14:30 16:00 1.50 9,000 9,000 COMPZ RPCOM CIRC X At 9000', circulate 35 bbls 1% CRW -132 corrosion inhibited 10.5 ppg Brine, followed by 110 bbls of 10.5 Brine at 2bpm at 170 psi, FCP 340 psi. Up wt 150k #, dwn 95k#. 16:00 16:30 0.50 9,000 9,005 COMPZ RPCOM PACK X RIH and NoGo at 9005'. Pull up 1' off NoGo above up neutral weight and set Liner Hanger at 900 psi. Liner Top depth at 5590'. 16:30 17:00 0.50 9,005 5,583 COMPZ RPCOM TRIP X Rotate release Running Tool. Free Wt moving up 95k #. DP remaining after realease 5583'. 17:00 19:00 2.00 5,583 5,525 COMPZ RPCOM CIRC X Pull remaining Stand of DP and DP out of balance. Reverse Circ a DP volume at 2 bpm, still out of balance, Circ around Long Way at 3 bpm, 320 psi. 19:00 20:00 1.00 5,525 5,525 COMPZ RPCOM OWFF X Observe Well for Flow. 20:00 23:00 3.00 5,525 0 COMPZ RPCOM TRIP X POOH standing back DP & L/D Setting Assembly. 23:00 23:30 0.50 0 0 COMPZ RPCOM PULD X Arrange Tools in Pipe Shed for cement string. C/O Handling Equipment for 2 7/8" Hydril 511 Tubing. 23:30 00:00 0.50 0 29 COMPZ CEMEN" PULD X PJSM. Discuss Hazard for MU BHA. P/U BHA #12 Baker Cup Inflation Assembly. 11/25/2012 RIH with 2 7/8" x 3 1/2" Inner Cement string with Baker Inflation tool assembly and space out across 5 1/2" Liner. Made several unsuccessful attempt to shear HMCV. The decision was made to move forward without pumping the cement job on the 5 1/2" liner. Set ZXPN Packer and tested same to 1000 psi and chart. Peform Slip and Cut on Drilling Line. 00:00 05:30 5.50 29 3,337 COMPZ CEMEN" TRIP X RIH w/ 2 7/8" 511 Hydril Tubing. (Cement String) 05:30 06:30 1.00 3,337 3,337 COMPZ CEMEN" PULD X C/O Handling Equipment to run Drill Pipe. Page 19 of 22 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 10:30 4.00 3,337 8,767 COMPZ CEMEN' TRIP X Continue in hole with cement work string on drill pipe. 10:30 11:00 0.50 8,767 8,767 COMPZ CEMEN' CIRC X Circulate down DP at 1 bpm at 80 psi, 2 bpm at 280 psi, and 3 bpm 480 psi. Total 14 bbls pumped. 11:00 13:00 2.00 8,767 8,767 COMPZ CEMEN' OTHR X Prep for Cement Job, spot Trucks. 13:00 13:45 0.75 8,767 8,875 COMPZ CEMEN' OTHR X RIH to 8875'. RU SLB Cementers and PT Lines to 4700 psi. 13:45 16:45 3.00 8,875 8,990 COMPZ CEMEN'CMNT XT Locate HMCV 8859' (14' high) . Locate the Liner Top Hanger at 5590' (on depth). RIH 20' below HMCV at 8859' to test Dual Cups. Drop 29/32" Ball and RU with rig pumps to chase with 30 bbls of 10.5 brine. Swap over to 1% CRW132 - 10.5 ppg Brine and pump 17 bbls and seat ball early. Good test to 3500 psi. Pull back up and Locate HMCV again, RBIH 7' and attempt to Shear 3000 psi Rupture Disks. Staged up to 3700 psi x4 and unable to shear. 16:45 17:15 0.50 8,990 8,990 COMPZ CEMEN' OTHR XT Confer with Town 17:15 18:30 1.25 8,990 8,772 COMPZ CEMEN' OTHR XT Release SLB and Prep to POOH. 18:30 21:00 2.50 8,772 8,772 COMPZ CEMEN' CIRC XT PU to 8,772 -ft, CIRU 157 bbls at 3 bpm, 500 psi. Monitor Well (Static) 21:00 22:30 1.50 8,772 8,900 COMPZ CEMEN' PACK XT RIH and Set down 40k and Set ZXPN Packer. RU Testing Equipment and tested to 1000 psi for 15 minutes and chart. 22:30 23:00 0.50 8,900 8,775 COMPZ CEMEN'TRIP XT TOOH to 8,775 -ft and Parked. 8,775 8,775 COMPZ CEMEN'SLPC X PJSM. Cut Slip Drilling Line. 11/26/2012 Finished slip -n -cut on drilling line. TOOH standing back 3 1/2" drill pipe and laying down 2 7/8" 511 Hydril. M/U & RIH with test packer and tested Casing to 2500 psi for 30 minutes. Perform passing C -MIT to 1200 psi. Load and Tally 3 1/2" Completion. RIH down to 1,580 -MD with and installed storm packer at -30 -ft for tubing head pack -off change out. 00:00 02:00 2.00 8,775 8,775 COMPZ CEMEN' SLPC X Continue to Slip & Cut drilling line. 02:00 02:15 0.25 8,775 8,775 COMPZ CEMEN' SFTY XT PJSM, Discuss hazard for tripping ooh with drill pipe. 02:15 05:00 2.75 8,775 3,333 COMPZ CEMEN' TRIP XT TOOH standing back drill pipe and laying down 2 7/8" 511 Hydril TBG. LJD Setting Tool. 05:00 06 :15 1.25 3,333 3,333 COMPZ CEMEN' PULD XT C/O Handling Equipment for 2 7/8" 511 Hydril. 06:15 12:00 5.75 3,333 0 COMPZ CEMEN'TRIP XT Continue OOH laying down 2 7/8" 511 Hydril and Cementting Tool. 12:00 14:30 2.50 0 0 COMPZ WELLPF PRTS T PJSM, RU to test Casing to 2500 psi, Good test charted for 30 minutes. RU Hose and perform MIT -OA to 1200 psi. Passing test: Intial Pressure - 1240 psi / 15 minutes - 1200 psi / 30 minutes - 1185 psi. RD Hose. Page 20 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 21:00 6.50 0 0 COMPZ RPCOM OTHR P Prep to run Completion. Load Jewelry and Completion Equipment. Load Tubing and Strap and Tally. 21:00 23:00 2.00 0 1,580 COMPZ RPCOM TRIP P PJSM. RIH w/ 3 1/2" Completion with lower seal assembly. 23:00 00:00 1.00 1,580 1,580 COMPZ WELLPF MPSP P PJSM. M/U & RIH Storm Packer and set at 30 -ft. Test Packer to 500 psi for 5 minutes. Tested Good. 11/27/2012 ND BOPE. ND tubing head with 6 "growth to 7" casing. Spear 7" Casing and pull 100k with additional 7" growth, set in slips at 50k. Install and test new pack -off to 3000 psi. NU BOPE. C/O UPR's. Preform weekly BOPE test. 00:00 02:00 2.00 1,580 1,580 COMPZ WHDBO NUND P Drain BOP Stack, ND and Stand onto stump. 02:00 03:30 1.50 1,580 1,580 COMPZ WHDBO RPTH T Wellhead Rep on Location at 0330 hours.Remove Tubing head and replace pack -off. 03:30 06:00 2.50 1,580 1,580 COMPZ WHDBO RPTH P N/D Tubing Head using long all threads to control casing growth. (6" total growth). 06:00 08:30 2.50 1,580 1,580 COMPZ WHDBO RPTH T Wait on 7" Casing spear. 08:30 10:00 1.50 1,580 1,580 COMPZ WHDBO RPTH P Load Spear, MU BHA. Spear 7" Casing and pull 100k on CSG, had another 7" of CSG growth, install slips and set in tension. Release spear and UD same. 10:00 14:00 4.00 1,580 1,580 COMPZ WHDBO NUND P Install new pack -off and test same to 3000 psi for 15 minutes. Install new Tubing Head. 14:00 19:00 5.00 1,580 1,580 COMPZ WHDBO NUND P Nipple Up BOPE and Riser, change out 5 -1/2" UPR's to VPR's. 19:00 00:00 5.00 1,580 1,580 COMPZ WHDBO BOPE P RU Testing equipment, fill stack and Perform weekly BOP test to 250/3000 psi. 11/28/2012 Continue to preform weekly BOPE test. Pull storm packer. Continue RIH with 3 -1/2" gas lift completion. Locate SBE and space out with pups. Load well with corrosion inhibited SW. Land Hanger. Test annulus and tubing. Shear SOV. Set BPV and test barriers. ND BOPE. NU Tree and Adapter. Test void 5000 psi. 00:00 02:30 2.50 1,580 1,580 COMPZ WHDBO BOPE P Continue to Perform weekly BOP W y test to 250/3000 psi. RD test equipment. 02:30 03:30 1.00 1,580 1,580 COMPZ WELLPF MPSP P PJSM- RU, RIH and POOH with Test Packer, LD same. 03:30 11:45 8.25 1,580 8,804 COMPZ RPCOM RCST P PJSM- Continue RIH with 3 -1/2" gas lift completion installing jewelry as per running order. Located and No -Go at 8,804 Corrected Depth. 11:45 12:15 0.50 8,804 8,804 COMPZ RPCOM RURD P PJSM. RU Circulating Equipment 12:15 13:30 1.25 8,804 8,804 COMPZ RPCOM CIRC P Circulate 100 bbls of 10.5 PPG Corrosion Inhibited Seawater down 3 1/2" Completion into 3 1/2" x 5 1/2" Liner and 3 1/2" x 7" Casing at 3 bpm, 500 psi. 13:30 14:45 1.25 8,804 8,804 COMPZ RPCOM HOSO P PUH and make Up 15 -ft of space out pups and hanger assembly. 14:45 15:15 0.50 8,804 8,804 COMPZ RPCOM HOSO P Land 3 1/2" Completion. RILDS. Up Wt 98k / Dn Wt 75k. Page 21 of 22 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 17:30 2.25 8,804 8,804 COMPZ RPCOM PRTS P PJSM. RU Testing Equipment and PT IA to 2500 psi for 30 minutes and chart same. PT TBG to 3000 psi for 30 minutes and chart same. Ramp up and shear SOV from TBG to CSG. 17:30 18:00 0.50 8,804 8,804 COMPZ RPCOM OWFF P Monitor Well. 18:00 19:00 1.00 0 0 COMPZ RPCOM MPSP P Back out landing joint. Install BPV. Pressure up IA to 1,000 psi for min. to test BPV from below. Bleed IA to zero. 19:00 21:30 2.50 0 0 COMPZ WHDBO NUND P ND BOPE, stand back on stump. 21:30 23:30 2.00 0 0 COMPZ WHDBO NUND P NU new tree adapter and tree, DSO on site to witness alignment. 23:30 00:00 0.50 0 0 COMPZ WHDBO PRTS P Test tubing hanger void to 5000 psi, good. 11/29/2012 Pull BPV and Set TWCV. Test tree 5000 psi. Pull TWCV. RU LRS. Freeze protect well. Set BPV. Secure cellar. RDMO. 00:00 00:30 0.50 0 0 COMPZ WHDBO MPSP P PJSM- Pull BPV and Set TWCV, fill tree and RU test equipment 00:30 01:30 1.00 0 0 COMPZ WHDBO PRTS P Pressure test tree 250/5000 on chart, RD test equipment. 01:30 02:00 0.50 0 0 COMPZ WHDBO MPSP P Pull TWCV. 02:00 04:00 2.00 0 0 COMPZ WHDBO FRZP P PJSM- MIRU Little Red Services, Pump 90 bbls diesel down IA. 04:00 08:00 4.00 0 COMPZ WHDBO FRZP P Let U -tube around and equilize. RD LRS. 08:00 08:30 0.50 0 0 COMPZ WHDBO MPSP P Set BPV. 08:30 11:00 2.50 0 0 COMPZ MOVE DMOB P Secure cellar and RDMO. Release Rig Page 22 of 22 • RECEIVED ConocoPhillips i iCl 0 9 2012 Alaska AOGCC P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 5, 2012 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 1. 0 - 4 Anchorage, AK 99501 ;;;it y {_, 4 L E lJ Commissioner Dan Seamount: 31- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the summer /fall of 2012. The corrosion inhibitor /sealant was pumped in the month of September 2012.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, Martin Walters 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 10/05/2012 1D,WSW,1F,2F 2L,2T,2Z,3G,31 & 3M PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft _ gal 1D-113 50029229170000 1981780 2" n/a 8" n/a 5.1 9/27/2012 1D-117 50029228440000 1972370 7' 0.80 25" 7/22/2012 8.7 9/27/2012 WSW -11 50029208820000 1822120 SF n/a 8" n/a 2.9 9/30/2012 1F-11 50029209930000 1831150 19'8" 3.40 12" 7/22/2012 3.4 9/27/2012 2F -19 50029227280000 1962010 7'5" 1.30 18" 9/19/2012 19 9/27/2012 2L -305 50103202790000 1982400 SF n/a 7" n/a 4.4 9/28/2012 2T -28 50103202250000 1950920 9" n/a 27" n/a 13.6 9/27/2012 2Z -10 50029213780000 1851370 5'9" 0.80 23" 9/19/2012 7.7 9/30/2012 3G -03 50103202450000 1961220 2" n/a 12" Na 7.5 9/28/2012 31 -06 50029219350000 1890380 7' 0.80 11" 7/22/2012 6 9/28/2012 3M 13 50029217200000 1870400 7'7" 0.50 12" 7/22/2012 4.7 9/28/2012 .2\9 33 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Leak Detect Log/Shot Rod: 3M -13 Run Date: 9/24/2012 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 3M -13 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21720 -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: Signed: • • 2A9 WELL LOG TRANSMITTAL • To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Chemical Cutter Record: 3M -13 Run Date: 9/27/2012 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 3M -13 S Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21720 -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: \ � � Signed: C��) I • • [LE [F ALANKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMI►IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brett Packer Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 3M -13 Sundry Number: 312 -242 St.,001NED JUL 1 0 2012 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount Commissioner DATED this / 0 day of July, 2012. Encl. • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 E° CE / June 29, 2012 JUL 0 2 2412 Commissioner AQQ f V 1 n State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover Kuparuk Well 3M -13 (PTD# 187 -040). Producing well 3M -13 was originally completed in August 1987 as a single 2 7 /8" gas lift completion. This well has been a phenomenal producer, averaging over 1200 bopd for the first 10 years. Regardless of its sordid past with multiple workovers, . even today it remains a good well and is capable of over 200 bopd. The first completion lasted ten years. In preparation for the upcoming re -frac, somewhere between March 13 – May 16 1997, the packer released and fell downhole 125 feet. A workover ( #1) was done in June 1997 to fish the packer and re- install a new completion. During this workover, they encountered trouble pulling the packer, requiring multiple fishing runs, but eventually got it out of the well. The new completion was installed, the well was re- fracced, and brought back online in July 1997. In 1998, after step -rate tests were performed, it was determined that the A -sand was capable of producing at much higher flow rates. Therefore, another workover ( #2) was done in June to replace the completion with an ESP in hopes to draw down the bottom hole pressure and increase rates. During this workover, the tubing was cut above the packer and the packer left in the hole, no attempts were made to fish this packer because of the difficulty they experienced during the previous workover. The ESP was brought online, but only lasted –4 months before the ESP went down due to a broken shaft. The well was converted back to gas lift and placed back on production. In 2005, another workover ( #3) ensued, this time to install a new gas lift completion with a packer to optimize gas lift. During this workover, the ESP was stuck downhole and would not pull free. They cut the tubing and then proceeded to fish the ESP. After multiple attempts, eventually the ESP parted in the upper seal section and could not be fished. The remaining ESP fell down to land on top of the previous packer left in the hole. During this workover, they tested the casing w/ a bridge plug & test packer and located a leak in the 7" casing between 8,635' - 8,656'. A UCI log was also run and indicated the casing was in poor condition up to 6,800' MD. Therefore, a straddle packer assembly was installed to span the leak and the ratty 7" casing. Unfortunately, due to the straddle, the lowest gas lift point was moved up hole - -2000' and thus the gas lift was not optimized as was the original intention. Regardless, the well was brought back online. In March 2011, the well was shut -in due to a failed TIFL. Further diagnostics determined multiple leaks in the tubing —one just �i above the PBR and another in the straddle section. The upcoming workover plans are to pull the tubing and straddle section, install a 5 'h" straddle which will allow us to gas lift deeper in the well, and re- install a 3 '/2" tubing completion. This Sundry is intended to document the casing repair as well as request approval to workover the well. If you have any questions or require any further information, please contact me at 265 -6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells STATE OF ALASKA • ti7 ALFA OIL AND GAS CONSERVATION COMMIT • N p APPLICATION FOR SUNDRY APPR 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell I✓ , Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing d Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate Al ter casing g r Other: 1"" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J ' Exploratory r 187 - 040 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21720 - 00'. 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Num , where ownership or landownership changes: I QED Spacing Exception Required? Yes r No F. 3M -13 . 9. Property Designation (Lease Number): 10. Field /Pool(s): JUL 0 2 2012 ADL 25523, 25512' Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY AC� Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (mea ��ii 9734 . 6539 - 9010' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 4850 9.625 4887' 3416' PRODUCTION 9674 7 9689' 6507' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9269 - 9303, 9308 - 9332, 9338 - 9380' 6203 - 6228, 6231 - 6248, 6253 - 6283' 3.5 J - _ 9017 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL HYD SINGLE STRING PACKER FOR 7" CS1 MD= 6765 TVD= 4509 PACKER - BAKER PREMIER PACKER WITH TCII CONNECTION MD= 8987 TVD= 6004 PACKER - BAKER SAB -3 PERMANENT PACKER W /K22 ANCHOR MD= 9181 TVD= 6141 SSSV - CAMCO LANDING NIPPLE MD =289 TVD =489 12. Attachments: Description Summary of Proposal p- 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/13/2012 Oil P' ` Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265 -6845 Printed Name Brett Packer Title: Sr. Wells Engineer Signature . W` + Phone: 265 -6845 Date e(0 Z- Commission Use Only Sundry Number:,/ / n � Conditions of approval: Notify Commission so that a representative may witness n J/ Un'( Plug Integrity r BOP Test iV/ Mechanical Integrity Test r Location Clearance r Other: 5 'PL' t2-5f t L' 3 / ,S i `a/'. A/vf7ry �`',CiCG ,05pa tc'/z -, = ‘ /die' / l'ec. ie Subsequent Form Required: all APPROVED BY 7/ Approved by: COMMISSIONER THE COMMISSION Date: „ vL.r. RSDM JUL 1 0 , p� \ Form 10 -403 Revised 1/2010 7 / 1 l 1 v oRIGINA : �� _ Submit in Duplicate AO P/41.2_ . t KUP • 3 M -13 ConocoPhillips = Well Attributes Max Angle & MD TD Azt«a,11u.; Wel!bore API /UWI Field Name Well Status Intl ( °) MD (ftKB) Act Btm (ftKB) cnrnmvl+allps 500292172000 KUPARUK RIVER UNIT PROD 57.42 2,800.00 9,734.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date Wenctarq - 3M 136t25!201244423P5 SSSV: NIPPLE , 190 11/8/2010 Last WO: 5/22/2005 41.81 5/31/1987 schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,110.0 3/12/2011 Rev Reason: SC REPAIR NOTE ninam 6/24/2012 Casing Strings �. Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 26 .- CONDUCTOR 16 15.062 38.0 115.0 115.0 62.58 H WELDED ® Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37.0 4,886.8 3,416.0 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd N p PRODUCTION 7 6.276 15.0 9,689.1 6,506.6 26.00 J -55 BTC Tubin. Strin.s Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 I 2.992 26.0 I 9,017.0 6,025.0 I 9.30 L -80 EUE8rdMOD all Completion Details Top Depth CONDUCTOR, (ND) Top Inc! Nomi... 38.115 Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) 26.0 26.0 0.01 HANGER FMC TUBING HANGER 3.500 NIPPLE, 488 1:$ 488.5 488.5 1.26 NIPPLE CAMCO LANDING NIPPLE 2.875 6,751.4 4,5002 50.75 PBR BAKER PBR - SHEARED 2.940 GAS LIFT, 6,764.8 4,508.7 50.72 PACKER BAKER FHL HYD SINGLE STRING PACKER FOR 7' CSG LEAK 3.960 3,769 8,987.4 6,004.2 45.18 PACKER BAKER PREMIER PACKER WITH TCII CONNECTION 2.875 9,009.7 6,019.8 45.25 NIPPLE CAMCO DS NIPPLE 2.812 9,016.7 6,024.8 45.28 WLEG WIRELINE ENTRY GUIDE 2.992 Tubing Description String 0... Top (ftKB) Depth (5... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING FISH 1998 I 5.62 I String ID ... I 9,124.0 I Set 9,205.6 I 6 SURFACE, Completion Details 37 -4,887 Top Depth L __ (ND) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) GAS LIFT, ( 9,124.0 6,100.5 45.52 SEAL ASSY CENTRILIFT GST3 4B HL PFS PARTIAL TANDEM SEAL SECTION 0.000 5,923 - -- 9,137.6 6,109.9 4640 ESP MOTOR CENTRILIFT 304 HP KMH 229/81 SERIES 562 MOTOR 0.000 w /CENTRALIZER 9,181.4 6,140.6 45.03 PACKER BAKER SAB -3 PERMANENT PACKER w/K22 ANCHOR SEAL 3.000 ASSEMBLY GAS LIFT, 9,188.2 6,145.3 44.97 X0 Reducing CROSSOVER REDUCING 3.5 "x2.875" 2.875 6s97 C 9,195.8 6,150.8 44.91 NIPPLE CAMCO 'D' NIPPLE NO GO 2.250 9,204.8 6,157.1 44.83 SOS BAKER SHEAR OUT SUB 0.005 IMF Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth P8R, 6,751 (ND) Top Intl Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) PACKER, 6,765 t/ ./ 6,781 4,519.0 50.69 WRP 2.69" WEATHERFORD WRP 4/28/2012 0.000 F t „ p 9,010 6,019.9 45.25 PLUG 2.81" CA -2 PLUG 4/21/2011 0.000 a '`"' WRP, 6,787 ' Perforations & Slots VVV Shot Top (ND) Btm (TVD) Dens ® f ,. Top (ftKB) Btm (MB) (ftKB) (ftKB) Zone Date (oh ... Type Comment 9,269 9,283 6,202.9 6,212.9 C-4, A -3, 3M -13 8/29/1991 6.0 APERF 21/8" EnerJet; 0 deg ph PACKER, 8,967 x5 011 9,283 9,303 6,212.9 6,227.6 A -2, 3M -13 8/29/1991 6.0 APERF 21/8" EnerJet; 0 deg ph 9,308 9,332 6,231.2 6,248.3 A -2, 3M -13 8/29/1991 6.0 RPERF 21/8" EnerJet; 0 deg ph ° 9,320 9,323 6,239.7 6,241.9 A -2, 3M -13 8/17/1987 1.0 IPERF 4" Csg Gun; 120 deg ph PLUG, 9,010 j, NIPPLE, 9,010 - f.`'. 9,338 9,380 6,252.6 6,282.7 A -1, 3M -13 8/29/1991 6.0 RPERF 2 1/8" EnerJet; 0 deg ph 9,340 9,379 6,254.0 6,282.0 A -1, 3M -13 8/17/1987 1.0 IPERF 4" Csg Gun; 120 deg ph WLEG,9,017 Notes: General & Safety • End Date Annotation SEAL ASSY, 1/5/1995 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 9.124 6/20/1997 NOTE: NORDIC 2 WORKOVER #1 c 4, 1 7 I ESP MOTOR, 9,138 i - 6/23/1998 NOTE: NORDIC 2 WORKOVER #2 5/18/2005 NOTE: 7' CASING LEAK @ 8635' -8658' 5/22/2005 NOTE: CTD WORKOVER #3 PACKER, 9,181 7/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 5/15/2011 NOTE: LDL FOUND TUBING LEAK @ 6745', JUST ABOVE PBR @ 6751' NIPPLE, 9,196 go 6/19/2011 NOTE: LDL LOCATED TUBING LEAK AT 7239' RKB , 10/13/2011 NOTE: WRP & CATCHER MOVED DOWNHOLE TO 6895' RKB SOS, 9,205 10/13/2011 NOTE: LOCATED POSSIBLE LEAK IN 7' CASING STARTING 0 6747' RKB w/ ELINE LDL 6/3/2012 NOTE: Welded 65.75" casing 10.75" .400 wall thickness, 45.5 sleeve on SC @ bottom of starter head. APERF, 9,269-9,283 APERF, 9,283 -9,303 M an d rel D et ail s RPERF, T D ep t h T o p Port 9,308 - 9,332 (TV I OD Valve Latch Size TRO Run IPERF, S t n Top (RK8 (ftKB) ( °) Make Model (in) Sery Tyne Type (in) (psi) Run Date Com... 9.320 - 9,323 - = 1 3 ,769. 3 2 ,7 8 7 .8 55.19 CAMCO KBUG -M 1 GAS LIFT DMY BK 0.000 0.0 4/22/2011 2 5,922.8 4,000.8 55.41 CAMCO KBUG -M 1 GAS LIFT DMY BK 0.000 0.0 4/22/2011 3 6,697.3 4,466.2 51.20 CAMCO KBUG -M 1 GAS LIFT OPEN 0.000 0.0 8/5/2011 RPERF, 9,3389,380 N IPERF, 9,340 -9,379 l PRODUCTION, 15 -9,669 70,9,734 • 3M -13 Rig Workover gw Pull & Replace 3 ' /2" Tubing, Install 5 '/2" Straddle Patch (PTD #: 187 -040) Current Status: This well has been SI since March 2011 due to multiple tubing leaks. Scope of Work: Pull the 3 ' /2" tubing and straddle packer assembly which is currently straddling a 7" casing leak which was found during the 3 workover in 2005. Plans are to straddle the casing leak located between 8,635'- 8,656' with a 5 ' /2" scab liner, therefore allowing us to gas lift deeper in the well. General Well info: Well Type: Producer MPSP: 2,646 psi Reservoir Pressure /TVD: 3,270 psi / 6,242' TVD (10.1 ppg) from Panex on 8/4/11. Wellhead type /pressure rating: FMC Gen IV, 7- 1/16" 5M psi top flange / c . BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -OA passed on 6/2/12. TIFL— Failed on 3/8/11. Earliest Estimated Start Date: August 13, 2012 Production Engineer: Evan Reilly / Jeremy Mardambek Workover Engineer: Brett Packer (265 -6845 / j. brett.packer @conocophillips.com) Pre -Rig Work 1. RU LRS: Circulate out 10.5 ppg CaC1 that is currently in the well with 9.6 ppg NaC1 brine. ( -235 bbls) 2. RU Slickline: a. Pull 2.69" WRP @ 6,781' MD. ✓ b. Pull catcher sub @ 9,010' MD. c. Pull CA -2 plug @ 9,010' MD. ✓ d. RIH w/ dual Panex gauges, obtain combined A &C sand 30 min. SBHP at 9,100' MD (6,083' TVD), pull uphole to 8,957' MD (5,983' TVD) and obtain 15 min. gradient stop. e. RDMO. 3. RU E -line: RIH w/ 2.5" RCT cutter w/ electromagnetic anchors and CCL /GR, correlate depth with tubing collars, cut the mandrel of the Premier packer (Top of Packer is 6,987.4' RKB, consult w/ Baker rep for exact depth of cut). RDMO. 4. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU Nordic 3. 2. Pull BPV. Circulate 235 bbls 10.5 ppg NaBr brine through open GLM at 6697' MD. Bullhead an additional 35 bbls to the formation. Verify well is dead. _ vt) G.) 5 i 3. Set BPV & FMC blanking plug, ND tree, NU BOPE & test, pull blanking plug & BPV. 7 1" BGi C '� h 4. MU landing joint, BOLDS, and attempt to pull tubing from the PBR. / 17) / 17) �� f 466 EC- >N 5 �?�` a C v e e - a. If tubing does not pull free, RU E -line and RIH w/ the RCT and cut the tubing at 6729' RKB (middle of the full joint above the PBR). POOH. RDMO E -line. 5. POOH laying down 3 -1/2" tbg. 6. MU overshot and single in on 3 -1/2" IF drillpipe. a. If tubing was cut, latch onto tubing and jar seal assembly from the PBR. POOH standing back drillpipe, lay down fish. RBIH w/ overshot dressed for 5.125" OD PBR. • 3M -13 Ri g Workover Pull & Replace 3 1 /2" Tubing, Install 5 1 /2" Straddle Patch (PTD #: 187 -040) 7. Latch onto PBR and jar FHL & Premier packer free. POOH standing back drillpipe. a. If both packers do not pull free, POOH standing back drillpipe. I b. Single in w/ 3 -1/2" tubing and overshot, latch onto the PBR and pull in tension c. RU E -line and RIH w/ the RCT and cut the tubing mid joint above the Premier packer. POOH. d. POOH w/ PBR, FHL packer and tubing down to cut joint. e. RBIH w/ 3 -1/2" drillpipe, latch tubing stub and pull Premier packer free, POOH standing back drillpipe. 8. RIH w/ 7" casing scraper, cleanout down to top of ESP fish at 9113' RKB. POOH standing back drillpipe. ' C7 9. MU Retrievamatic test packer, RIH on 3 -1/2" drillpipe. Set test packer at 8,930' MD. PT the Premier packer to ( J 2500 psi. Pressure up back side and get injection rate /pressure. L, 10. Work test packer up hole testing IA, recording injection rates /pressures, verify casing leak between 8635'- 8656', check for other casing leaks above 8,635' MD. 11. Release test packer, POOH standing back drillpipe, lay down test packer. 12. Unload old tubing and rack & tally new tubing in pipe shed. 13. RIH w/ Premier packer, 5 -1/2" straddle, and 5 -1/2" Liner top packer on 3 -1/2" drillpipe. 14. Spot corrosion inhibited brine in the IA behind the straddle assembly. 15. Pressure up to set the packers. • 16. Release from the 5 -1/2" liner top packer and POOH laying down 3 -1/2" drillpipe. a. On TOH, set a storm packer at —100' w/ drillpipe hanging below. b. NDBOP & Tubing head c. Replace tubing head and IC packoffs. d. NU BOP & test e. Release storm packer and POOH laying down storm packer. 17. Single in w/ 3 -1/2" tubing string and seal assembly, sting into SBE, PT IA to verify seals are engaged, space out 7', pull seals from SBE. 18. Space out w/ pups, MU hanger. Spot corrosion inhibited brine in the IA below the bottom GLM. Land the hanger, RILDS. 19. PT the tubing to 3,000 psi, bleed tubing to 2500 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 20. Pull the landing joint, install two -way check. 21. ND BOPE. NU and test tree. Pull two -way check. 22. Swap well over to corrosion inhibited seawater. 23. Freeze protect through the SOV, set BPV. 24. RDMO Nordic 3 Post -Rig Work 1. Pull BPV. 2. RU Slickline: Install catcher sub Pull SOV from bottom mandrel, run GLD. Pull catcher sub. Pressure up tubing to shear the shear - out -sub. 3. Turn well over to operations. • • ■ • • Conoco Phillips Well: 3M -13 2012 RWO Proposed Completion 'ieri 2.875" DS Nipple 1 3 -1/2" 9.3 #, EUE Tubing 16 "62 #H -40 shoe at115'MD b i ll' 3 -1/2" x 1" KBMG GLM's, EUE -Mod 9 -5/8" 36# J -55 shoe at 4887' MD , XO, 3 -1/2" EUE -Mod x 3 -1/2" IBT BxP Upper Straddle Packer @ 6600' MD = f-- 5 -1/2" x 7" Liner Hanger & Packer Malt" MI pp ,. 3 -1/2" x 1" KBG2 -9 GLM's, IBT -2200' of 5 -1/2" Casing ,• 3 -1/2" 9.3 #, IBTM -SCC Tubing ,I 5 -1/2" BTCM -SCC Casing .!-- Holes in Casing, 8635' - 8656' MD Tim 2.813" DS Nipple 7 XO, 5 -1/2" x 5" BTCM BxB 1 5" OD x 4" ID SBE, BTC PxP, 20' Long /• XO, 5" BTCM box x 3 -1/2" EUE Pin 4 3 -1/2" 9.3 #, EUE Tubing Lower Straddle Packer @ -8900' MD 4— 3 -1/2" x 7" Premier Packer • 2.75" D Nipple C) • SOS A &C sand perfs, 9269' - 9379' MD ;'` 1 _ KC A 7" 26# L -80 shoe at 9689' MD 1 • • • • ConocoPhillips Alaska P.O. BOX 100360 � � ANCHORAGE, ALASKA 99510 -0360 �� C v oil June 04, 2012 AOGGG Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 JUN 2 9 201 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 3M -13, PTD 187 -040, Sundry 312 -082 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, f Martin Walters ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate r Other p SC Repair Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r " 187 - 040 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50- 029 - 21720 -00 --'001 7. Property Designation (Lease Number): r 8. Well Name and Number: I ADL0025512 - 3M - 13 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9734 feet Plugs (measured) None true vertical 6539 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 6765 true vertical 0 feet (true vertucal) 4509 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 1640 630 SURFACE 4850 12 4887 3416 3520 2020 PRODUCTION 9674 7 9689 6507 4980 4330 Sleeve 65.75" 10.75" .400 wall 45.5# RECEIVED Perforation depth: Measured depth: 9269' - 9379' JUN 12 2012 True Vertical Depth: 6203' - 6282' AOGCC Tubing (size, grade, MD, and TVD) 3.5, L - 80, 9017 MD, 6157 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL HYD SINGLE STRING PACKER @ 6765' MD and 4509' TVD SSSV - CAMCO LANDING NIPPLE @ 489' MD and 489' tvd 11. Stimulation or cement squeeze summary: Intervals treated (measured): n/a 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 n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n/a n/a n/a 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p - Service r Stratigraphic r 15. Well Status after work: r Oil F Gas r WDSPL r Daily Report of Well Operations X GSTOR r 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: 312 -082 Contact MJ Loveland /Martin Walters Printed Name Martin Walters Title Well Integrity Proiect Supervisor Signature . d 4 _, — . Phone: 659 -7043 Date: 6/4/12 D S �' ` 3 I Iv /4 (if / (v UN 12 y p� to I Submit Ori final Onl Form 10 -404 t t'tv°'/ ised 10/2010 9 Only ` • 3M -13 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/05/11 Cut two windows on the conductor for sealant prep and reveled a fair amount of corrison.UT results came back 77% Toss grade D in 1 area. 05/19/12 Cut dust ring and landing ring off wellhead with torch. cut 6' of conductor off wellhead and chipped remaining cement off SC. Buffed SC for upcoming inspection from Kakivik. 05/20/12 (Call stateman (Bob Noble) for opportunity to witness damage to SC - he waived. 05/31/12 Welded A &B bands onto SC. 06/01/12 I Welded 65.75" long 10.75" .400 wall 45.5# sleeve onto surface casing. 06/02/12 'Insulators installed denso wrap over SC sleeve. 06/02/12 Pressured up OA to 1800 psi with 1 bbls of diesel for one hour test.Starting T /I/O= siO/20/1820. 15 min T /I/O= si0/20/1810. 30 min T /I/O= si0/20/1810. 45 min T /I/O= si0/20/1810. 60 min T /I/O= si0/20/1810. Bled OA back to 0 psi. 06/03/12 Welded 7' 4" long 16" .375 wall 62.58# pipe, conductor extension onto existing conductor. • . 4 _ _.. __ ..J • t tit 1 ©ConocoPhillips Alaska, Inc 1 This photo is copyright by ConocoPhillips Alaska, Inc. i and cannot be released or — published without express written consent of --,.. ConocoPhillips Alas - a a 0 14 ' 3.11•111 0ww # s e w.» 1 �" .. $ t aA t� t if Z * 1 t 147 + t r i► di e,I. it 4 e ..*'....r t-, .0r, .. fr *,;...,,, .0„, , 4 0,, ‘ , , .1-. 4., —ir . .. o lett . ..41k , , t . ' ' ilk: N 't« ''' II i 4`. .— '''' f ' 1 ,, :. :411 50,40Ir , 0 , , f 4 d ,,, Q -" 1 1, : - , - ..„. i �` it, ,,„fiK' / eiisely sdipiydoaouo3 Jo auasuoo ue I M ssaJdxa ;noyaIM paysiignd Jo pasealai aq louueo pue oul 'evsely sdllpyd000uoo Aq 1y6uI(doo si oloyd sm oui 'e)lsely sdllllyd000uo0p t t I ? i a i t t - i f e t vi r . i t 1 ew I, • 24 b1,7 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 30, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3M -13 ��� '�� Run Date: 4/28/2012, t 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 3M -13 Digital Data (LAS), Digital Log file 1 CD Rom 50- 029 - 21720 -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: 5 11 a- Signed: / //, • • 1. N {, 14 , 4 [ ' p ra, ` "'' SEAN PARNELL, GOVERNOR Ln R ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 < Y Martin Walters D L d Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3M -13 Sundry Number: 312 -082 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 Daniel T. Seamount, Jr. Chair DATED this 2 - %ay of February, 2012. Encl. • . . STATE OF ALASKA " e ALAI OIL AND GAS CONSERVATION COMM I CI ON , �� _\'� APPLICATION FOR SUNDRY APPROVALS tii ' 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate Alter casing 9 r Other:SC Repair 17. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r . Exploratory r 187 - 040 - 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21720 -00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 3M - ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025512 ' Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9734 ' 6539 ` Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' 1640 630 SURFACE 4850 9 -5/8 4887' 3416' 3520 2020 PRODUCTION 9674 7 9689' 6507' 4980 4330 RECEIVED Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubin�e 8 g MD (ft): 9269' - 9379' 6203' - 6282' 3.5 L - 80 9017 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER = BAKER FHL HYD SINGLE STRING MD = 6765, TVD = 4509 Alaska Oil & Gas Co ns. Commission, SSSV = CAMCO LANDING NIPPLE MD = 489, TVD = 489 Anchorage 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/15/2012 Oil 1.7 Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland /Martin Walters Printed Name Martin Walters Title: Well Integrity Project Supervisor Signature eGri 77 a�C �A Phone:659 -7043 Date: 02/23/12 Commission Use Only Sundry Number:, 20$2 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r l i o rk Other: — "c _ . Sb G e. eS iK c � eJ of' Subsequent Form Required: /b — Li 01 APPROVED BY ' ZI Approv :..�' _ COMMISSIONER THE COMMISSION Date: ) t MAR N 1011 2 / L y� /L Form 10 -403 Revised 1/201 OR1u1NAL e ! Ilcate 7 ..ti Si Si • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 23, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3M-13, PTD 187 -040 surface casing inspection and repair. Please contact MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, /742;?7kVA Martin Walters ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska, Inc. Kuparuk Well 3M -13 (PTD 187 -040) SUNDRY NOTICE 10 -403 APPROVAL REQUEST February 23, 2012 This application for Sundry approval for Kuparuk well 3M -13 is for the inspection and repair of surface v casing with reduced wall thickness. Currently part of the surface casing on this well is exposed to the atmosphere and it appears there is corrosion taking place. 3M -13 was found to have 77% wall loss to the surface casing during the process of applying corrosion l inhibiting sealant. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with a plug(s) and/or BPV. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Remove gravel around well head and build —9' working cellar. 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA /QC will verify the repair for a final integrity check. 8. Perform MITOA 9. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and /or BPV and return the well to production. • 13. File 10 -404 with the AOGCC post repair. . I I Well Integrity Project Supervisor 2/23/2012 AA 1 ,, a KUP • 3M -13 Conoco ! 1iilips '`s°'r Well Attributes Max Angle & MD TD AI6 iro:. Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ttKB) ccx,o�w+,�n;ps 500292172000 KUPARUK RIVER UNIT PROD 57.42 2,800.00 9,734.0 - '---- �� �� - '� "- - -' - -- " Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "° SSSV: NIPPLE 190 11/8/2010 Last WO: 5/22/2005 41.81 5/31/1987 Well Conde -3M -19 1/26/201212'26:25 PM - -- -- - - - - -- Schematic - Actual Annotation Depth (ttKB) End Date Annotation Lest Mod ... End Date Last Tag: SLM 9,110.0 3/12/2011 Rev Reason: NOTES ninam 1/26/2012 - - Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... /String Wt... String ... String Top Thrd HANGER, 26 411111, CONDUCTOR 16 15.062 38.0 115.0 115.0 62.58 H-40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37,0 4,886.8 3,416.0 36.00 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 4 p PRODUCTION 7 6.276 15.0 9,689.1 6,506.6 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd • TUBING 31/2 2.992 26.0 9,017.0 6,025.0 9.30 L EUE8rdMOD i . Completion Details _.. Top Depth CONDUCTOR, (ND) Top Incl Noml... 38 -115 Top (it(B) (ftKB) (°) Item Description Comment ID (in) NIPPLE, 468 26.0 26.0 0.01 HANGER FMC TUBING HANGER 3.500 III 488.5 488.5 1.26 NIPPLE CAMCO LANDING NIPPLE 2.875 6,751.4 4,5002 50.75 PBR BAKER PBR-SHEARED 2.940 GAS LIFT. 6,764.8 4,508.7 50.72 PACKER BAKER FHL HYD SINGLE STRING PACKER FOR T' CSG LEAK 3.960 9769 8,987.4 6,004.2 45.18 PACKER BAKER PREMIER PACKER WITH TCII CONNECTION 2.875 ill 9,009.7 6,019.8 45.25 NIPPLE CAMCO DS NIPPLE 2.812 9,016.7 6,024.8 45.28 WLEG WIRELINE ENTRY GUIDE 2.992 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING FISH 1998 5.62 9,124.0 9,205.6 6,157.7 SURFACE, & Completion Details 37 -4.887 Top Depth (TVD) Top Inc' Nomi... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) GAS LIFT, 9,124.0 6,100.5 45.52 SEAL ASSY CENTRILIFT GST34B HL PFS PARTIAL TANDEM SEAL SECTION 0.000 5 9,137.6 6,109.9 45.40 ESP MOTOR CENTRILIFT 304 HP KMH 229/81 SERIES 562 MOTOR 0.000 Elk w /CENTRALIZER ME 9,181.4 6,140.6 45.03 PACKER BAKER SAB-3 PERMANENT PACKER w/K22 ANCHOR SEAL 3.000 ® ASSEMBLY GAS LIFT, 9,188.2 6,145.3 44.97 XO Reducing CROSSOVER REDUCING 3.5 "x2.875" 2.875 6,697 9,195.8 6,150.8 44.91 NIPPLE CAMCO'D' NIPPLE NO GO 2.250 A 9,204.8 6,157.1 44.83 SOS BAKER SHEAR OUT SUB 0.005 O ther In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) PBR, 8,751 Top Depth (ND) Top Intl PACKER. 8,785 _ Top (ttKB) (ftKB) ( °) Description Comment Run Date ID (In) 6,790 4,524.7 50.67 CATCHER 2.73" x 88" JUNK CATCHER 8/5/2011 0.000 6,792 4,525.9 50.67 PLUG 2.69 WRP 8/5/2011 0.000 CATCHER, 9,010 6,019.9 45.25 PLUG 2.81" CA -2 PLUG 4/21/2011 0.000 6.790 ' PLUG. 8,792 5 I Perforations & Slots Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ttKB) Zone Date Oh.- Type Comment PACKER, 9,987 9,269 9,283 6,202.9 6,212.9 C-4, A -3, 3M -13 8/29/1991 6.0 APERF 2 1/8" EnerJet; 0 deg ph I ' 9,283 9,303 6,212.9 6,227.6 A -2, 3M -13 8/29/1991 6.0 APERF 21/8" EnerJet; 0 deg ph 9,308 9,332 6,231.2 6,248.3 A -2, 3M -13 8/29/1991 6.0 RPERF 21/8" EnerJet; 0 deg ph PLUG. 9,010 - ip h 9,320 9,323 6,239.7 6,241.9 A -2, 3M -13 8/17/1987 1.0 IPERF 4" Csg Gun; 120 deg ph NIPPLE. 9,010 Y ;�fi 9,338 9,380 6,252.6 6,282.7 A -1, 3M -13 8/29/1991 6.0 RPERF 2 1/8" EnerJet; 0 deg ph WLEG, 9917 9,340 9,379 6,254.0 6,282.0 A -1, 3M -13 8/17/1987 1.0 IPERF 4" Csg Gun; 120 deg ph Notes: General & Safety End Date Annotation ASSY. , a 1/5/1995 NOTE: WAIVERED WELL: IA x OA COMMUNICATION ESP MOTOR, � 6/20/1997 NOTE: NORDIC 2 WORKOVER #1 9.138 6/23/1998 NOTE; NORDIC 2 WORKOVER #2 5/18/2005 NOTE: 7' CASING LEAK @ 8635' - 8658' PACKER, 9,181 5/22/2005 NOTE: CTD WORKOVER #3 r 7/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 NIPPLE. 9.196 }Iii 5/15/2011 NOTE: LDL FOUND TUBING LEAK @ 6745', JUST ABOVE PBR @ 6751' II 6/19/2011 NOTE: LDL LOCATED TUBING LEAK AT 7239' RKB SOS, 9,205 10/13/2011 NOTE: WRP & CATCHER MOVED DOWNHOLE TO 6895' RKB 10/13/2011 NOTE: LOCATED POSSIBLE LEAK IN 7" CASING STARTING @ 6742" RKB w/ ELINE LDL APERF, 9,2694,283 M. APERF, 9,283-9,303 Mandrel Details Top Depth Top Port RPERF. " (TVD) Intl OD Valve Latch Site TRO Run 9,30 \ 04 IPERF, , Stn Top (ttKB) (ttKB) (°) Make Model (In) Sery Type Type ( (Pei) Run Date Com... 9,3209,323 1 3,769.3 2,787.8 55.19 CAMCO KBUG-M 1 GAS LIFT DMY BK 0.000 0.0 4/22/2011 • 2 5,922.8 4,000.8 55.41 CAMCO KBUG -M 1 GAS LIFT DMY BK 0.000 0.0 4/22/2011 3 6,697.3 4,466.2 51.20 CAMCO KBUG -M 1 GAS LIFT OPEN 0.000 0.0 8/5/2011 RPERF, 9,3384,380 IPERF. 9.340 -9.379 I 1 Y PRODUCTION. 15-9.689 • T0, 9,734 1 %1 -0 • 11957 (.0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 18, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 JUL 0 2 2012, RE: Leak Detect Log: 3M -13 Run Date: 10/13/2011 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 3M -13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21720 -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: ks. %\, Signed: �.. ..- • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 17, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 3M -13 Run Date: 5/15/2011 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 3M -13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21720 -00 l� g 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. ra , Y ;t Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 3 1 I Signed: C • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 24, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 3M -13 Run Date: 6/19/2011 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 3M -13 Digital Data in LAS format, Digital Log Image file 1 CD Rom r 50- 029 - 21720 -00 1 Cl SEp 3 U 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: ) t- t 1 Signed: 13 °q° • • 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(Caliper/ WIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 -1 900 Benson Blvd. 41 "gl i tlek MAY 2 z 2 Anchorage, Alaska 99508 �) and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airpo Road Suite C 1 � ��� Anchorage, AK 99518 1 Fax: (907) 245 -8952 ao3 ao9v1 Caliper Report 19- Apr -11 1C-178 1 Report / EDE 50-029 - 23144 -00 2) Caliper Report 2appr~11 3M r--- -11r- 1 Report _'� i►,r • Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-MAIL: dsanchoracePir "Je€583I":loq.:.orn WEBSITE :www. www.memoriloa.com C:\Documents and Settings'Diane Williams \Desktop\BP_Transmit.docx I I • • PA Memory Multi-Finger Caliper i � Log Results Summary 1 . C ompany: ConocoPhillips Alaska, Inc. Well: 3M -13 Log Date: April 23, 2011 Field: Kuparuk Log No.: 6300 State: Alaska I Run No.: 1 API No.: 50-029-21720-00 Pipet Desc.: 3.5" 9.3 Ib. L -80 EUE 8RDMOD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 9,000 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : 1 This caliper data is tied into the GLM -3 @ 6,697' (Driller's Depth) This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. I Multiple holes are recorded in 19 joints from —6,744 if to —7,867 ft. A 3 -D log plot of the caliper recordings across this interval is included in this report. I The caliper recordings indicate the 3.5" tubing logged appears to be in good to poor condition with respect to corrosive and mechanical damage. Wall penetrations ranging from 86% to 100% wall thickness are recorded in 19 joints of the 295 joints logged. Additional wall penetrations ranging from 20% to 85% wall thickness are recorded in 65 joints of the 295 joints logged. Recorded damage appears as isolated pitting, I line corrosion and holes. Cross - sectional wall loss of 16% is recorded in an area of line corrosion in joint 234 (7,457'). No significant restrictions are recorded throughout the tubing logged. 1 MAXIMUM RECORDED WALL PENETRATIONS: I Multiple Holes (100 %) Jt. 230 @ 7,328 Ft. (MD) Hole (100 %) Jt. 227 @ 7,239 Ft. (MD) Multiple Holes ( 100 %) Jt. 239 @ 7,596 Ft. (MD) I Multiple Holes (100 %) (100 %) Jt. 235 @ 7,469 Ft. (MD) Hole Jt. 246 @ 7,832 Ft. (MD) MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 Line Corrosion ( 16 %) Jt. 236 @ 7,519 Ft. (MD) No other significant cross - sectional wall loss are recorded throughout the tubing logged. 1 MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. 1 1 1 Field Engineer: D. Cain Analyst: C. Lucasan Witness: C. Fitzpatrick 1 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDSrg�memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 M'i -mod 9o91/0 I • • r PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3M -13 Date : April 23, 2011 I Description : Detail of Caliper Recordings Across Multiple Holes from - 6,744' to - 7,867' Comments Depth Maximum Pen. Maximum I.D. 3 -D Log Image Map 1 1ft:240ft 0 % 100 1 inches 5 —I 0° 0° 90° 180° 270° 0° Minimum I.D. 2.5 inches 3.5 I 2.5 Nominal I.D. inches 3.5 Pup Joint 212.1 6750 -'741/0111 s — ■r- - I 6760 11111111 PBR 212.2 - i p =.-_-,, 1 i 1111 t — I Packer 212.3 6770 _ ■ >•E mummim -- 6780 t--4411 I♦IIIMM -4E- .IIIIII C` ..1M /E1.. Joint 213 6790 6 800 "' 1 6810 !, 6820 r — C- – Joint 214 k lit 6830 � - r�� e 6840 6850 f Joint 215 �` � _ � � r�r - 6860 c� s� c�1W :_-_ I IBC�a 6870 `� — g . 6880 I w I ;6115_ Joint 216 — — j .._— C 6890 1.1V- 1 — — _ - -- I I • • 6900 -- -■ ...[ \F -.I.. _ - ��_ ...cI�_�.. -- __ ...c ; 6910 � ...c : _— - Joint 217 _ 1.,-..- - 6920 g ���.� - 6930 = -� — — -- 6 940 po w er -- .J..w__ .■. ...[ -�.... . I Joint 218 E _� 6950 ���F �� ..a `- ...EI[ J :-���- I ___«� _ 6960 6 -- -- -_,�� ...E _,il ...1 -_ I 6970 ' = �m - -- -i - Joint 219 6980 =_-41 `� ..aar�.. ...SIF -1��� 6990 ILI ...c4E - -- I ...a L_ 7000 ��int — r' .. - I Joint 220 7010 11V- - _ .. =\ o - - _ - 1 t 7020_ - - 4 _ 7030 -- -- - _7 D.,411 ...E - _ - Joint 221 7040 ,_ : : :11fF ' _ � ... \[C �m" ...[t�l. __ -� ...DIr_�. 7050 = ...[[F :MINN IMI__Fik f. _ - _ - 1 ...E[lI. - - I — - -� ...\ F -411 - 7060 � � ' ...rE •.. ...EIEF�.. � V_-:-_,-.2 ...Ffr_.. _ .. afG;l. - .� ...EfL.. _ _ II 7 070 '- — „' L__. Joint 222 -- _� - � ...G F ■ - t I + = 1 7080 — _ =1. ...\lit:? - - 7090 -- �� �..r�� _ I • 0 .- - rte 11111tu . - ---..File911111•111 - II 7100 ����E4Ci�� Joint 223 � L� MMIM1F *� •` , 111111M11111111111111F--MINI --- II � I 7110 I�i�__fa.: -JIB ====r2111 MIN - -____ 11111M1111111kIr•ESIN -� ����t _ 7120 . __II•_f�F ,ilk �Eati�� 7130 r - - PIE '�� Joint 224 ..�= _ 1 4111PPS ! , -_ 7140 _ a I�I�I��t�r>.il� - . _ �� = =f3 AIM= _ 1 I 150 ����[� __ 7 " "` � =MMMit AWN = = = =EEL: - - .... MINIM= Elhh-'1 7160 - I.I.I�I�[Eta Joint 225 - --�— 11` i _ •. i. i. y. 7170 11111•11111111111111P � - � — G- - 111111111111111111E-MIN ._._. MN, ����tEE Ai� — �- -. C _____ ___i. s_ 7180 - -- -Fad- _ - U.. ...M«i.�. II 7190 •r . i ����� {E � ..:,. I Joint 226 .F . ���� # � � ..�� - .....'. 1111111L—".,1 M�M�[�rt7 7200 - MINI�IMILF M I II ��I•�CIG1�� 7210 11111111111110111111W11111M11 . . 7220 �_ 1 ��mmr &r+mmi �.� I•���L1LJ� Joint 227 ____r►� jl_ MNIMINFIf IMM 7230 MIIMIIIIIIII«F,11111•1 = = =E &E 'MM ' ..11 ESC 7240 _ br��•1•11=== - - I -� = 7250 �'..; — - 1 ` � Joint 228 Ci oll 7260 -u, �� r .._ ij ,,� 7270 l _.. .-..-Ai , , 7280 -- °"- 111 iiii===initKAINI • Joint 229 �m_ � 1 •� ■ 11 1 --. o--z 7290 .. -_ - I I _ • • „....," ....[i:�.. _ _ , 1 7300 ....��[ _ ....tat _ ....[tkA.. �� ....[i. a�� _ ....rEN-f.31111111 7310 t _1 ....frI G� - J i ....0 *c ....Ft► 1.. 3. E .... 1gEt»! Joint 230 7320 1111,,, III!!! « ...IIIfEt -• 111 _ ....tIt-1111M ....[.G -.. A IIIIL.I M KIN.. 7330 i i-i-,111111111111111111mEm•mwm• . ...VIIE -A �a _ - - ■ --- ____Et � _� ....M SiB.. —_ _ 7340 ____ ' ....CfL11.. =- , r - .....f7 --- 7 350 ....r cam.. — Joint 231 ...aS6 �= ....:fI � i .. 4 ......... .....F'... ....t2 7360 s. -�. , i IMMUNISE- _ �' ....Ef �. 7370 - �� �... >E._. _ ... ...aE:. ....ELF MINI 3 ....r,.sI... _ - II Joint 232 7380 .= a ---- �! �---- ....[EEA.... - �- ...a#ri.... 7390 ....►ec -i.... ....►IE -...� � ....caL . - ...E�I.:M_.. f` .. 7400 ...a !!.lc4� �... ....E,�a.• F'i E•.�1i�-iN... 7410 E ...aS[7.... _ Joint 233 ��� M111ft -m �� �,,, ....E�r.� r . ....iii.. -_ .... ��t l. 1 7420 � F -� �_ ..a aL� .... ....F 1: • - _A m _ � �_. --- 7430 �'" I , -mmi n ....1111. LT ....t� _ 7440 t �� .... :ft.'. E�� 1 ....r�F>r. Joint 234 Mr_ 1111►f` 7. _ _ ....[4F -a. --' 1111 «L�� 7450 - =- =►2���. - -s ...ast -I.! _ - = -- ••• ••.P:• Mil - .- — =AI .a- �F,... _ _ =M11111111111M 11== 7 460 - -- ..s IF �_ _ ....!f� a ... � -,..... .... r 11.11 7 470 — = - _ ��..um.....ft -- - - - -- - ....Efts - !. _ --`mi i IM...NI ....Fii.��... Joint 235 I li .. .f* -- ra .. 7480 1 TIMM" 2M=111111 r- .iii.. 7490 _ = �ni■■ �_ :- ,_�� I I . _ � �■.1 �I : = 1 7500 I----1 �« r,..r --- ... ___.. ,.... Joint 236 ii - `�`, 1 7510 J UUEILII 7520 =s � =W,:. - - G ■.MM= __ - i I - MMMr���MM 7530 mi— 1IG - Joint 237 - �L>>€F= 7540 - �MIE-• �[EF7 r ∎[lEF_�M 7550 1.---� : _lit-i ., III I _ _ �'iELII... • 75so -� �'�f —�- — MIIMMI -..t - ____ _ ___ _ ,„,„;.:.„ Joint 238 7570 . 'I ■tElb-+ �� 1111111111111111111L.-• - yam; 7580 .=-1011111 ■i11111 - ■«� -- �F� _�� -- �� �iICiM - 7590 = — IIIIIIIIIIMEk"MI 111■111F- Joint 239 7600 ,--A-aill -- - •� -� r 7610 -- - - - -- -- - C' S. 1 7620 " :� _ -- i 7630 i,::-..94--1.471 240 7640 �� EE�� — 4,011111 SLAM �- 'ELT— 7650 i EEaM — - 4b, M _ ��MM - . 1i�� f 7660 tAM __ Joint 241 It l'M ,. I 7670 _ I i. � - iS - 7680 - -- mac- �_ 1 7690 I I • I =� !!al Joint 242 !!l lF : ! — _ !!lti -- 7700 NM— !!!lr .Wri! =� !!!li:1i�4!! - — i !!!mitt! i! M1111111111111010_41111= I 7710 F "- !!!ltir - _ = - ... !!!lii� +r! t� !!!!_s' -7,2111/ G. --- !!milt E�!! - 7720 !!! !!!war -ii. a Joint 243 i!llii i !!!l►i. t _. !!!!!IF 9!! 7730 = 41 !!!lF���!! = 111111•11111111111116--MM i IIIIIIIIIIMINEIL-7. :1:1 .-� 11,!!!lEfr 5! 7740 !!llrr`'. —! - _am. ■..=!!!m-s- vim.. !!!!tom ∎••• ...• !!MWS: 7750 � _! 11111111111=1•111,1-..2 __ !!!!ta_� Joint 244 �� !!!!tE i!` I 7760 r`I !!!lic�E.!! —� !!!!11f` i! _ !!!! «'�i! t =um !!!lt4t - J!! �_- !!!lifer �� 7770 �a� �� !!! i!! - !!! r!! ri !!!ltf� 7780 !!!![�.. _ .. �mi !!!liaFn!! . Joint 245 I ' -.mg !!lliii! -'" _ 7790 vii !!!li:it►� _ -- 11111111=111M16 :mgr I -_� !!lliEF �!! !!!lift -!! !!lli1r�!! - 7800 !!llFIEr41!! — l!!liriikl _ ■■ !!!litF��� I !!!_«F_�. .,..� ... r --IR■■ !!!!«c��! - - 7810 � -- !!!!►m!r ! = �'�� !!!lLf�_ l E � !!!!«c4 [- !!!!17€11! I Joint 246 7820 Ei !lllFit it !! 1` + � !![fi qtr !!!l1Ir�! _ MINIM MI 7830 E±�!!! -- -- = I -- :.�. -t.— _ �,� IN r - 7840 r ! - !!lr�� — I - a te !!l !ift !!!!l4.s � - llll�>€h • !!i!lSir - - Joint 247 7850 _ l!!!14C _ —' �4, fF� !!!!E1`! —' 111 E:4-1-41 llll� _ ■1 !!!li.11i<,!! 7860 F _ !!!!LfF -+ Gam. --_� !!lIMML. �i !► ! - I - -_ - !!! !!!! ►EF ;aV__! ■ ■ ■■ !!!lie �! I I I I 0 • Correlation of Recorded Damage to Borehole Profile I • Pipe 1 3.5 in (9.1' - 8992.2') Well: 3M -13 Field: Kuparuk I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 23, 2011 I 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 " 14 I Wm— 25 790 6 ,_ 1572 1 50 75 - __ 2350 111 100 1 3129 GLM 1 I 125 lir 3938 150 pi 4 4722 Q I 117 �— - 175 5504 • GLM 2 z — -_ 200 6312 Q, AP I GLM 3 0 0 225 —v.-9 '57 7148 1 250 ' .) 7927 I 275 8705 283.2 8992 0 50 100 I Damage Profile (% wall) / Tool Deviation (degrees) I I Bottom of Survey = 283.2 I I I s • I PDS Report Overview (.. Body Region Analysis Well: 3M -13 Survey Date: April 23, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 1 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE8RDMOD Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 EUE8RDMOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) I 250 mil Penetration body gm Metal loss body 0 50 100 200 0 150 100 1 50 47 0 0 to 20 to 40 to over 20% 40% 85% 85% 97 Number of joints analysed (total = 295) 211 18 47 19 GLM 1 I Damage Configuration (body) 145 -� 200 ---- U 150 ---- GLM 2 _ 193 100 ---- GLM 3 _ I 50 _ 0 240 I Isolated General Line Other Hole / - Pitting Corrosion Corrosion Damage Pos. Hole I Number of joints damaged (total = 267) 194 2 53 0 18 Bottom of Survey = 283.2 I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE8RDMOD Well: 3M -13 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 23, 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 0.1 9 0.03 0.03 11 1 2.94 Pup • 1 14 0.04 0.03 13 .5 2.97 Shallow Pitting. II 1.1 46 0 0.03 13 6 2.95 Pup Shallow Line of Pits. u 1.2 56 0.03 0.03 11 3 2.93 Pup • 1.3 64 0 0.03 13 it 2.94 Pup Shallow Line of Pits. • I 2 73 0 0.03 12 3 2.93 Shallow Pitting. Lt. Deposits. • 3 104 0 0.04 15 4 2.95 Shallow Line of Pits. ■ 4 135 0 0.04 15 5 2.97 Shallow Line of Pits. • 5 166 0 0.04 15 5 2.95 Shallow Line of Pits. ■ I 6 197 0 0.03 11 4 2.95 • 7 228 0 0.03 12 3 2.95 Shallow Line of Pits. ■ 8 260 0 0.03 13 4 2.93 Shallow Line of Pits. Lt. Deposits. • 9 291 0 0.03 12 3 2.94 Shallow Pitting. • 10 323 0 0.04 16 4 2.95 Shallow Pitting. • 11 354 0.03 0.03 13 5 2.96 Shallow Line of Pits. • ■ 12 385 0 0.04 15 3 2.90 Shallow Line of Pits. Lt. Deposits. ■ 13 416 0 0.04 18 4 2.95 Shallow Line of Pits. • I 14 446 0 0.03 12 4 2.94 Shallow Pitting. 14.1 477 0 0 0 0 2.88 Carrico Landing Nipple 15 478 0.03 0.04 17 5 2.96 Shallow Line of Pits. • 16 510 0.03 0.04 17 4 2.94 Shallow Pitting. • 17 541 0.03 0.03 13 4 2.94 Shallow Line of Pits. ■ 18 572 0.04 0.04 15 5 2.96 Shallow Line of Pits. • 19 603 0.03 0.04 16 6 2.95 Shallow Pitting. • 20 634 0.04 0.03 13 6 2.96 Shallow Pitting. II 21 666 0 0.03 12 4 2.96 Shallow Line of Pits. • I 22 697 0 0.03 13 4 2.94 Shallow Line of Pits. • 23 728 0.03 0.04 15 4 2.96 Shallow Line of Pits. • ■ 24 759 0 0.03 12 4 2.95 Shallow Line of Pits. • 25 790 0 0.04 15 3 2.96 Shallow Line of Pits. ■ I 26 821 0 0.04 15 4 2.95 Shallow Line of Pits. ■ 27 852 0 0.04 15 4 2.96 Shallow Line of Pits. • ■ 28 883 0 0.03 11 2 2.93 • 29 915 0.03 0.03 12 5 2.96 Shallow Pitting. II 30 946 0 0.03 11 4 2.94 • I 31 977 0.03 0.04 17 4 2.95 Shallow Pitting. ■ 32 1009 0.03 0.03 12 4 2.95 Shallow Pitting. ■ 33 1040 0 0.04 16 4 2.95 Shallow Line of Pits. • 34 1072 0 0.04 15 5 2.95 Shallow Line of Pits. ■ I 35 1103 0.03 0.03 13 4 2.95 Shallow Line of Pits. • 36 1134 0.05 0.04 15 4 2.96 Shallow Line of Pits. ■ 37 1166 0.04 0.03 11 5 2.96 ■ 38 1 197 0 0.03 13 4 2.96 Shallow Pitting. ■ I 39 1229 0 0.03 12 4 2.96 Shallow Line of Pits. • 40 1260 0.04 0.04 15 4 2.95 Shallow Line of Pits. • 41 1292 0.04 0.03 13 4 2.95 Shallow Line of Pits. ■ 42 1323 0.03 0.04 17 5 2.96 Shallow Line Corrosion. Ii I 43 1353 0 0.03 12 2.94 Shallow Pitting. • 44 1385 0 0.03 12 3 2.95 Shallow Line of Pits. • 45 1416 0.03 0.03 13 5 2.94 Shallow Line of Pits. Penetration Body I Metal Loss Body Page 1 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE8RDMOD Well: 3M -13 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: April 23, 2011 I Joint Jt. Depth Per Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 46 1446 0 0.04 15 5 2.96 Shallow Line of Pits. ■ ' 47 1478 0 0.03 12 5 2.96 Shallow Line of Pits. • 48 1509 0 0.03 11 4 2.97 • 49 1541 0.04 0.03 12 4 2.95 Shallow Pitting. ■ 50 1572 0.04 0.03 13 4 2.96 Shallow Pitting. • I 51 1603 0.04 0.03 13 5 2.96 Shallow Pitting. II 52 1633 0 0.04 16 4 2.92 Shallow Line of Pits. Lt. Deposits. ■ 53 1664 0.03 0.03 12 4 2.95 Shallow Pitting. • 54 1695 0.04 0.03 11 4 2.95 • I 55 1726 0.04 0.03 13 5 2.95 Shallow Pitting. • 56 1757 0 0.05 20 8 2.95 Isolated Pitting. 57 1789 0.03 0.03 13 4 2.95 Shallow Pitting. ■ 58 1820 0 0.04 16 7 2.94 Shallow Line of Pits. 1 I 59 1852 0.04 0.03 11 5 2.94 ■ 60 1884 0.03 0.03 12 3 2.94 Shallow Pitting. ■ 61 1914 0.04 0.03 13 4 2.95 Shallow Line of Pits. ■ 62 1945 0.03 0.04 15 4 2.95 Shallow Pitting. • I 63 1977 0 0.04 15 5 2.94 Shallow Line of Pits. ■ 64 2008 0.04 0.04 16 4 2.94 Shallow Line of Pits. ■ 65 2039 0.03 0.04 17 10 2.96 Shallow Pitting. 66 2071 0.04 _ 0.05 19 11 2.95 Shallow Pitting. 67 2103 0.04 0.03 12 4 2.96 Shallow Line of Pits. ■ I 68 2133 0.04 0.05 19 9 2.95 Shallow Pitting. 69 2164 0 0.03 13 3 2.95 Shallow Line of Pits. • 70 2194 0.04 0.05 19 6 2.93 Shallow Pitting. Lt. Deposits. • 71 2225 0.03 0.04 16 10 2.96 Shallow Pitting. I 72 2256 0.03 0.04 16 4 2.96 Shallow Line of Pits. • 73 2287 0 0.05 18 8 2.94 Shallow Line of Pits. 74 2319 0.04 0.03 12 4 2.95 Shallow Line of Pits. • 75 2350 0 0.03 13 6 2.94 Shallow Pitting. 1 I 76 2382 0.03 0.03 12 4 2.93 Shallow Pitting. ■ 77 2413 0 0.04 17 11 2.96 Shallow Line of Pits. 78 2445 0.04 0.03 13 6 2.96 Shallow Line of Pits. 1 79 2476 0.04 0.04 17 7 2.95 Shallow Line of Pits. 1 80 2508 0.03 0.03 13 6 2.96 Shallow Line of Pits. ■ I 81 2538 0.03 0.03 , 12 4 2.95 Shallow Pitting. • 82 2570 0.04 0.03 12 4 2.94 Shallow Line of Pits. • 83 2601 0.04 0.03 12 4 2.94 Shallow Line of Pits. ■ 84 2632 0.04 0.04 15 4 2.94 Shallow Line of Pits. • I 85 2663 0.03 0.04 17 10 2.96 Shallow Pitting. 86 2695 0.03 0.04 15 3 2.95 Shallow Pitting. • 87 2726 0 0.03 12 5 2.93 Shallow Pitting. Lt. Deposits. ■ 88 2758 0 0.03 11 3 2.95 • I 89 2789 0.04 0.03 12 4 2.92 Shallow Pitting. Lt. Deposits. • 90 2819 0.03 0.03 13 5 2.93 Shallow Line of Pits. Lt. Deposits. • 91 2851 0.04 0.04 16 6 2.95 Shallow Line of Pits. ■ 92 2881 0.06 0.06 24 7 2.93 Line of Pits. Lt. Deposits. ■ 93 2912 0.05 0.03 11 3 2.95 • I 94 2943 0 0.03 11 2 2.92 Lt. Deposits. ■ 95 2974 0 0.03 11 3 2.94 rat I Metal Loss ion Body Page 2 Penet I I I . is PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE8RDMOD Well: 3M -13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 23, 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 96 3006 0.03 0.04 15 7 2.95 Shallow Pitting. 97 3037 0.04 0.04 15 5 2.96 Shallow Pitting. ■ 98 3068 0.04 0.04 15 7 2.95 Shallow Line of Pits. 1 99 3098 0.04 0.04 17 4 2.94 Shallow Line of Pits. • 100 3129 0 0.04 15 8 2.94 Shallow Pitting. 1 I 101 3161 0.05 0.03 12 3 2.95 Shallow Line of Pits. • 102 3191 0 0.03 11 2 2.95 • 103 3222 0.05 0.03 13 3 2.95 Shallow Pitting. 104 3254 0.03 0.02 9 4 2.95 I 105 3285 0 0.03 10 2 2.94 • 106 3316 0.05 0.04 16 4 2.93 Shallow Line of Pits. Lt. Deposits. • 107 3348 0.04 0.04 16 4 2.94 Shallow Line of Pits. ■ 108 3379 0.04 0.04 16 6 2.94 Shallow Pitting. ■ I 109 3411 0.03 0.04 15 4 2.94 Shallow Line of Pits. • 110 3442 0.04 0.05 19 0 2.95 Shallow Line of Pits. i 111 3473 0.04 0.04 17 3 2.94 Shallow Line of Pits. • 112 3504 0.03 0.03 11 3 2.95 • 1 111 113 3535 0 0.03 12 4 2.93 Shallow Pitting. Lt. Deposits. • 114 3567 0 0.04 15 6 2.95 Shallow Pitting. il 115 3598 0.03 0.03 13 6 2.95 Shallow Line of Pits. ■ 1 111 116 3629 0.05 0.04 16 7 2.94 Shallow Pitting. 1 117 3660 0.04 0.05 19 10 2.95 Shallow Pitting. I 118 3691 0.05 0.04 16 5 2.94 Shallow Line of Pits. • 119 3723 0.05 0.05 19 10 2.96 Shallow Pitting. 119.1 3755 0.05 0.05 19 9 2.94 Pup Shallow Pitting. 119.2 3765 0 0 0 0 2.90 GLM 1 (Latch @ 11:30) 1 19.3 3771 0.26 0.04 17 8 2.94 Pup Shallow Line of Pits. 120 3781 0.04 0.04 16 5 2.94 Shallow Line of Pits. • 121 3813 0.13 0.03 13 4 2.95 Shallow Pitting. • 122 3845 0.04 0.03 13 4 2.95 Shallow Line of Pits. • I 123 3876 0.03 0.04 15 3 2.94 Shallow Line of Pits. • 124 3907 0.03 0.04 15 4 2.94 Shallow Line of Pits. • 125 3938 0.04 0.04 16 6 2.96 Shallow Line of Pits. ■ 126 3970 0.04 0.03 13 3 2.95 Shallow Pitting. • 127 4001 0 0.03 11 4 2.94 ■ I 128 4032 0.03 0.03 11 3 2.95 • 129 4064 0.03 0.04 15 3 2.95 Shallow Line of Pits. ■ 130 4095 0.04 0.03 13 7 2.95 Shallow Pitting. 1 131 4126 0 0.04 18 8 2.95 Shallow Line of Pits. 1 I 132 4158 0.04 0.05 19 3 2.96 Shallow Line of Pits. • 133 4189 0 0.03 12 4 2.94 Shallow Pitting. • 134 4221 0 0.03 11 4 2.94 • 135 4251 0.03 0.07 26 4 2.96 Line of Pits. • I 136 4282 0.10 0.04 15 .5 2.94 Shallow Line of Pits. ■ 137 4313 0.25 0.04 17 6 2.94 Shallow Pitting. • 138 4345 0.05 0.03 13 6 2.98 Shallow Pitting. • 139 4376 0.04 0.05 19 7 2.95 Shallow Pitting. 1 140 4408 0.03 0.05 19 10 2.94 Shallow Line of Pits. I 141 4439 0.03 0.05 19 3 2.93 Shallow Line of Pits. Lt. Deposits. • 142 4470 0 0.03 11 2 2.94 rat I Metal Loss ion Body Page 3 Penet I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE8RDMOD Well: 3M -13 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 23, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % L oss I.D. Comments (% wall) (Ins.) (Ins.) °/, (Ins.) 0 50 100 143 4502 0 0.03 13 2 2.93 Shallow Line of Pits. Lt. Deposits. • 144 4534 () 0.03 10 2 2.94 • 145 4565 0 0.04 15 4 2.95 Shallow Pitting. ■ 146 4597 0.04 0.04 15 4 2.94 Shallow Line of Pits. • 147 4627 0.03 0.04 16 6 2.95 Shallow Line of Pits. ■ I 148 4659 0.04 0.03 11 2 2.94 • 149 4690 0.04 0.03 12 2 2.93 Shallow Pitting. Lt. Deposits. ■ 150 4722 0.03 0.04 16 3 2.94 Shallow Line of Pits. • 151 4753 0.05 0.04 16 6 2.95 Shallow Line of Pits. . I 152 4784 0.04 0.04 15 4 2.94 Shallow Line of Pits. II 4816 0.03 0.04 16 5 2.96 Shallow Line of Pits. ■ 154 4847 0.04 0.04 17 6 2.94 Shallow Line of Pits. ■ 155 4878 0 0.05 18 9 2.94 Shallow Pitting. 1 I 156 4909 0.03 0.07 26 5 2.94 Line of Pits. ■ 157 4942 0 0.04 17 6 2.95 Shallow Pitting. ■ 158 4973 0.04 0.03 12 2 2.93 Shallow Pitting. Lt. Deposits. • 159 5003 0 0.03 11 2 2.93 Lt. Deposits. ■ I 160 5035 0.05 0.03 13 3 2.94 Shallow Line of Pits. • 161 5066 0.05 0.04 15 3 2.93 Shallow Pitting. Lt. Deposits. ■ 162 5097 0.03 0.04 16 8 2.93 Shallow Pitting. I 163 5128 0.03 0.03 12 2 2.94 Shallow Pitting. • 164 5159 0.0:3 0.04 16 4 2.93 Shallow Line of Pits. Lt. Deposits. • I 165 5191 0.04 0.05 20 2 2.93 Line of Pits. Lt. Deposits. mum 5222 0.04 0.06 25 3 2.94 Line of Pits. • 167 5254 0 0.03 13 6 2.94 Shallow Pitting. ■ 168 5285 0 0.04 15 4 2.94 Shallow Pitting. • I 169 5317 0 0.04 17 i 2.94 Shallow Pitting. ■ 170 5347 0.04 0.05 19 6 2.95 Shallow Pitting. a 171 5379 0.03 0.04 17 4 2.94 Shallow Line of Pits. • 172 5410 0.03 0.03 12 2 2.94 Shallow Pitting. • 173 5441 0 0.04 18 5 2.93 Shallow Pitting. Lt. Deposits. ■ 174 5473 0.04 0.04 17 3 2.95 Shallow Pitting. • 175 5504 0 0.03 11 2 2.94 ■ 176 5535 0.04 0.04 16 4 2.93 Shallow Line of Pits. • 177 5567 0.04 0.03 13 4 2.93 Shallow Pitting. • I 178 5598 0.05 0.04 16 , 4 2.94 Shallow Pitting. • 179 5630 0.04 0.04 16 4 2.93 Shallow Line of Pits. Lt. Deposits. • 180 5661 0.05 0.04 15 4 2.94 Shallow Line of Pits. ■ 181 5693 0.04 0.04 16 7 2.94 Shallow Line of Pits. 1 I 182 5724 0.04 0.04 17 3 2.94 Shallow Line of Pits. • 183 5755 0.04 0.03 12 3 2.93 Shallow Pitting. Lt. Deposits. • 184 5787 0.04 0.03 13 3 2.94 Shallow Line of Pits. • 185 5818 0.04 0.04 17 3 2.93 Shallow Line of Pits. Lt. Deposits. • I 186 5850 0.05 0.06 22 6 2.96 Line of Pits. ■ 187 5881 0.04 0.04 17 4 2.95 Shallow Line of Pits. ■ 187.1 5912 0 0.03 11 2 2.93 Pup 187.2 5922 0 0 0 0 2.90 GLM 2 (Latch @ 1:30) I 187.3 5929 0 0.03 11 1 2.93 Pup Lt Deposits. • I 188 5939 0 0.06 25 4 2.94 Line of Pits. • 189 5969 0 0.04 15 3 2.95 Shallow Line of Pits. ' Penetration Body I Metal Loss Body Page 4 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L-80 EUE8RDMOD Well: 3M-13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 23, 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 50 100 190 6001 0.03 0.04 16 6 2.94 Shallow Line of Pits. 191 6032 0.05 0.05 19 7 2.94 Shallow Pitting. 192 6063 0.05 0.04 17 6 2.96 Shallow Line of Pits. ,1 193 6095 0.03 0.05 19 4 2.94 Shallow Line of Pits. ■■ 194 6126 0.03 0.05 19 5 2.93 Shallow Pitting. Lt. Deposits. ■■ I 195 6156 0.04 0.05 20 6 2.93 Line of Pits. ir 196 6188 0.04 0.03 13 3 2.93 Shallow Line of Pits. ■ 197 6219 0.05 0.04 16 2 2.96 Shallow Line of Pits. • 198 6250 0 0.05 18 3 2.92 Shallow Pitting. Lt. Deposits. • 199 6281 0.04 0.04 16 3 2.95 Shallow Line of Pits. ■ 200 6312 0.03 0.04 16 4 2.93 Shallow Line of Pits. ■ I 201 6343 0.03 0.05 20 6 2.93 Isolated Pitting. Lt. Deposits. sz 202 6375 0.04 0.05 18 8 2.94 Shallow Line of Pits. i I 203 6406 0.03 0.04 17 8 2.94 Shallow Pitting. i 204 6438 0.04 0.05 18 8 2.94 Shallow Line of Pits. i 205 6468 0.04 0.05 21 6 2.94 Line of Pits. 1 206 6499 0 0.05 18 7 2.90 Shallow Pitting. Lt. Deposits. i 207 6531 0.03 0.05 19 8 2.94 Shallow Pitting. i I 208 6562 0.04 0.05 18 7 2.94 Shallow Pitting. i 209 6593 0 0.05 18 4 2.92 Shallow Pitting. Lt. Deposits. ■ 210 6624 0.06 0.04 17 6 2.92 Shallow Line of Pits. Lt. Deposits. 2 211 6656 0.04 0.04 17 4 2.93 Shallow Line of Pits. Lt. Deposits. ■ I 211.1 6687 0.04 0.03 11 2 2.91 Pup Lt Deposits. 211.2 6697 0 0 0 0 2.90 GLM 3 (Latch e 10:00) 211.3 6703 0 0.15 61 7 2.93 Pup Isolated Pitting. 1 212 6714 0.07 0.25 100 11 2.94 Hole! I 212.1 6746 0 0.06 23 3 2.93 Pup Isolated Pitting. Lt. Deposits. 212.2 6752 0 0 0 0 2.94 Baker PBR Sheared 212.3 6764 0 0 0 0 3.96 Baker FHL HYD Single String Packer 213 6775 0.03 0.15 58 10 2.92 Line Corrosion. Lt. Deposits. 214 6807 0.06 0.15 60 9 2.92 Line Corrosion. Lt. Deposits. I 215 6838 0.04 0.14 55 8 2.94 Line Corrosion. 216 6869 0.07 0.17 65 7 2.92 Line Corrosion. Lt. Deposits. IL 217 6901 0.09 0.18 70 7 2.92 Line Corrosion. Lt. Deposits. 218 6932 0.05 0.14 54 11 2.93 Line Corrosion. Lt. Deposits. I 219 6962 0.05 0.16 63 7 2.91 Line Corrosion. Lt. Deposits. �■ 220 6993 0.12 0.12 48 7 2.93 Line Corrosion. Lt. Deposits. 1s2 221 7024 0.11 0.13 52 6 2.91 Line Corrosion. Lt. Deposits. ■■ 222 7056 0.13 0.15 59 6 2.93 Line Corrosion. Lt. Deposits. ■■ I 223 7086 0.08 0.24 93 6 2.92 Possible Hole! Lt. Deposits. �■ 224 7117 0 0.14 56 6 2.91 Line Corrosion. Lt. Deposits. 1 225 7148 0.12 0.22 86 7 2.89 Possible Hole! Lt. Deposits. - Mil 226 7179 0.03 0.18 71 7 2.92 Line Corrosion. Lt. Deposits. I 227 7211 0 0.47 100 7 2.91 Hole! Lt. Deposits. �■ II. 228 7241 0.06 0.17 65 4 2.91 Line Corrosion. Lt Deposits. ■■ 229 7273 0.07 0.34 100 7 2.92 Hole! Lt. Deposits. t s 230 7305 0.09 0.51 100 6 2.92 Multiple Holes! Lt. Deposits. 231 7336 0.03 0.13 50 7 2.90 Line Corrosion. Lt. Deposits. >t I 232 7368 0.06 0.13 51 6 2.90 Line Corrosion. Lt. Deposits. a { I_ - 233 7397 0.08 0.16 65 7 2.89 Line Corrosion. Lt. Deposits. I Penetration BoBody dy I Page 5 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE8RDMOD Well: 3M -13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 23, 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 234 7428 0 0.39 100 9 2.77 Hole! Deposits. 235 7459 0.08 0.43 100 12 2.89 Multiple Holes! Lt. Deposits. 236 7491 0.13 0.38 100 16 2.92 Multiple Holes! Lt. Deposits. ! 237 7522 0.08 0.17 66 7 2.91 Line Corrosion. Lt. Deposits. 238 7553 0.09 0.27 100 10 2.90 Hole! Lt. Deposits. I 239 7585 0.06 0.46 100 13 2.92 Multiple Holes! Lt. Deposits. 240 7616 0.10 0.11 43 6 2.91 Line Corrosion. Lt. Deposits. 241 7647 0.07 0.15 57 7 2.91 Corrosion. Lt. Deposits. 242 7678 0.07 0.19 76 6 2.89 Line Corrosion. Lt. Deposits. I 243 7710 0.12 0.33 100 4 2.89 Multiple Holes! Lt. Deposits. 244 7740 0.07 0.34 100 11 2.92 Multiple Holes! Lt. Deposits. 245 7772 0.07 0.21 84 6 2.90 Line Corrosion. Lt. Deposits. L 246 7803 0.08 0.41 100 8 2.91 Hole! Lt. Deposits. I 247 7834 0.08 0.29 100 8 2.93 Hole! Lt. Deposits. 248 7866 0.11 0.25 96 9 2.93 Probable Hole! Lt. Deposits. 249 7897 0.04 0.23 91 11 2.91 Possible Hole! Lt. Deposits. It 250 7927 0.18 0.17 67 10 2.95 Corrosion. 251 7958 0.10 0.18 71 9 2.95 Line Corrosion. 252 7989 0.11 0.16 63 8 2.92 Line Corrosion. Lt. Deposits. 253 8021 0.15 0.18 70 8 2.93 Line Corrosion. Lt. Deposits. L 254 8052 0.17 0.22 88 10 2.92 Possible Hole! Lt. Deposits. M 255 8084 0.06 0.16 64 8 2.93 Line Corrosion. Lt. Deposits. I 256 8115 0.10 0.21 82 11 2.93 Line Corrosion. Lt. Deposits. 257 8147 0.11 0.16 65 7 2.90 Line Corrosion. Lt. Deposits. 258 8178 0.09 0.14 54 7 2.92 Line Corrosion. Lt. Deposits. L 259 8209 0.05 0.15 59 8 2.90 Line Corrosion. Lt. Deposits. r_ I 260 8240 0.05 0.15 58 7 2.92 Line Corrosion. Lt. Deposits. 261 8271 0.12 0.20 78 9 2.90 Line Corrosion. Lt. Deposits. L 262 8302 0.06 0.22 85 12 2.92 Line Corrosion. Lt. Deposits. 263 8334 0.10 0.16 62 9 2.93 Line Corrosion. Lt. Deposits. I 264 8365 0.10 0.17 67 9 2.93 Line Corrosion. Lt. Deposits. 265 8396 0.08 0.14 57 11 2.91 Line Corrosion. Lt. Deposits. 266 8427 0.04 0.16 61 7 2.92 Line Corrosion. Lt. Deposits. L 267 8458 0.07 0.17 67 7 2.88 Line Corrosion. Lt. De..sits. no 268 8488 0.08 0.14 57 9 2.92 Line Corrosion. Lt. Deposits. - 1 ■•• I 269 8517 0.05 0.15 60 8 2.92 Line Corrosion. Lt. Deposits. mom 270 8549 0.07 0.14 55 6 2.91 Line Corrosion. Lt. Deposits. in 271 8580 0.06 0.11 44 7 2.91 Line Corrosion. Lt. Deposits. 272 8612 0 0.17 66 6 2.92 Line Corrosion. Lt. Deposits. I 273 8643 0.03 0.10 40 4 2.90 Line Corrosion. Lt. Deposits. i� 274 8674 0 0.12 48 6 2.91 Line Corrosion. Lt. Deposits. u 275 8705 0.03 0.10 40 5 2.91 Line Corrosion. Lt. Deposits. mom 276 8737 0 0.12 49 4 2.88 Line Corrosion. Lt. Deposits. ■N I 277 8768 0.03 0.07 27 2 2.90 Line Corrosion. Lt. Deposits. woo 8797 0.06 0.07 28 4 2.92 Line Corrosion. Lt. Deposits. ■o 279 8828 0.04 0.07 26 4 2.90 Line Corrosion. Lt Deposits. ■■ 280 8859 0.05 0.08 31 2 2.89 Line Corrosion. Lt. Deposits. 281 8889 0.04 0.05 19 3 2.86 Shallow Line Corrosion. Lt. Deposits. I 282 8921 0.05 0.06 22 2 2.85 Line Corrosion. Lt. Deposits. 283 8952 0.14 0.07 26 4 2.85 Line Corrosion. Lt. Deposits. I Metal Loss Body Page 6 Penetration I I ' • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE8RDMOD Well: 3M -13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 23, 2011 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 1 283.1 8983 0 0.03 12 0 2.90 Pup Shallow Pitting. Lt. Deposits. 283.2 8992 0 0 0 0 3.96 Baker Premier Packer with TCII Connection Penetration Body Metal Loss Body I I I I Page 7 I I I • • I PDS Report Cross Sections I Well: 3M -13 Kuparuk Survey Date: April 23, 2011 Field: Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE8RDMOD Analyst: C. Lucasan 1 i i I Cross Section for Joint 230 at depth 7328.379 ft Tool speed = 52 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 94% Tool deviation = 46° / \ \ / \ 1 II I i - - - - - - 7 \\■ 1 I Ir i \ ---Y I Finger = 2 Penetration = 0.511, ins Multiple Holes 0.51 ins = 100% Wall Penetration HIGH SIDE = UP I I I I I I • • I PDS Report Cross Sections I Well: 3M -13 Survey Date: April 23, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 EUE8RDMOD Analyst: C. Lucasan I I Cross Section for Joint 227 at depth 7239.769 ft Tool speed = 54 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 93% /--- Tool deviation = 48° I ,/ \ 1 I \ I I * -....•■• I Finger = 19 Penetration = 0.46 ins Hole 0.47 ins = 100% Wall Penetration HIGH SIDE = UP I I I I I I • • I JJ ,,. PDS Report Cross Sections I Well: 3M -13 Survey Date: Tool Type: April 23, 2011 Field: Kuparuk UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 EUE8RDMOD Analyst: C. Lucasan I I Cross Section for Joint 236 at depth 7518.639 ft Tool speed = 55 Nominal ID = 2.992 I Nominal OD = 3.5 ��.�..,,,�_ Remaining wall area = 84% Tool deviation = 49° / /! I 1 1 i ,/ \ 1 i I - ) I I ♦ , \ , I Finger = 14 Penetration = 0.147 ins Multiple Holes 16% Cross - sectional Wall Loss HIGH SIDE = UP I I I I I I KUP ConocoPhillips ttributes rD 3M -13 � .I....:..: Wellbore APW WI Field Name Well Status I•gle&MD ND (m( Act Btm (NCB) Lanoaoftiapc 500292172000 KUPARUK RIVER UNIT PROD 57.42 2,800.00 9,734.0 Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date ' -- well conga - 13 3/21/2011 7 55 27 AM SSSV: Nipple 250 12/25/2009 Last WO: 5!22/2005 41.81 5/31/1987 Schematic - 13 31 Actual Depth 11 B) End Date Amotation Last Mod ... End Date Last Tag: SLM 9.110.0 3/12/2011 Rev Reason, GLV C/O Imosbor 3/21/2011 Casing Strings Casing Description String 0... String ID ... Top (NCB) Set Depth (f... Set Depth (ND) ... String Wt... ring ... String Top Thrd HANGER. 29 CONDUCTOR 16 15.062 38.0 115.0 115.0 62.58 I-1-40 WELDED I CaSURFsing Desat ACE 9 on String 0... String ID ... Top (IKE) Set Depth (t.. Set Depth (TVD) ... String Wt... String _. String Top Thrd 5/8 8.921 3 4,886.8 3,416.0 36.00 J BTC Ca sing Description String 0... String ID ... Top ptiCB 7 0 ) Set Depth (L.. Set Depth (WO)... String Wt... String... String Top Thud PRODUCTION 7 6.151 15.0 9,689.1 6,506.6 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (MB) Set Depth n... Set Depth (ND) ... String Wt... String ... String Top Thrd I Completion TUBING 3 1/2 2992 26.0 9,017.0 6,025.0 9.30 L-80 EUE8rdMOD Details Top Depth (ND) Top Ind Nowt- CONOl1CTOR, Top (11 B ( ) B) n Item Description Comment ID OM 38 -115 26.0 26.0 0.01 HANGER FMC TUBING HANGER 3.500 I NIPPLE, 488 488.5 488.5 1.26 NIPPLE CAMCO LANDING NIPPLE 2.875 6,751.4 4,500.2 50.75 PBR BAKER PBR - SHEARED 2.940 6,764.8 4,508.7 50.72 PACKER BAKER FHL HYD SINGLE STRING PACKER FOR 7" CSG LEAK 3.960 GAS LIFT. 1 _ 8,987.4 6,004.2 45.18 PACKER BAKER PREMIER PACKER WITH TCII CONNECTION 2.875 3,769 I 9,009.7 6,019.8 45.25 NIPPLE CAMCO DS NIPPLE 2.812 I 9,016.7 6,024.8 45.28 WLEG WIRELINE ENTRY GUIDE 2.992 Tubing Description String 0... String ID ... Top (11 B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thal TUBING FISH 1998 5.62 9,124.0 9,205.6 6,157.7 Completion Details I 1 Top Depth SURFACE, \ (ND) Top Ind 374,887 - Top (D(g) Mee (1 Item Description Comment Nona... ID pin 9,124.0 6,100.5 45.52 SEAL ASS/ CENTRILIFT GST3 4B HL PFS PARTIAL TANDEM SEAL SECTION 0.000 9,137.6 6,109.9 45.40 ESP MOTOR CENTRILIFT 304 HP KMH 229/81 SERIES 562 MOTOR 0.000 cns u FT w /CENTRALIZER 5 923 9,181.4 6,140.6 45.03 PACKER BAKER SAB-3 PERMANENT PACKER w /K22 ANCHOR SEAL 3.000 i ASSEMBLY 9,188.2 6,145.3 44.97 XO Reducing CROSSOVER REDUCING 3.5 "x2.875" 2.875 - -- 9,195.8 6,150.8 44.91 NIPPLE CAMCO NIPPLE NO GO 2.250 GAS - IF I 6,69' 9,204.8 6,157.1 44.83 SOS BAKER SHEAR OUT SUB 0.005 I Perforations & Slots Dens Top (WD) Btm (WD) Dens Top MKS) ( ) ( 6 ) (0KB) Zone Date (se... type Comment PER. 6.751 I 9,269.0 9,283.0 6,202.9 6,212.9 C-4, A -3, 3M -13 8/29/1991 6.0 APERF 2 1/8" EnerJet; 0 deg ph PACKER.6,765 E 9,283.0 9,303.0 6,212.9 6,227.6 A -2, 3M -13 8/29/1991 6.0 APERF 21/8" EnerJet; 0 deg ph i 9,308.0 9,332.0 6,231.2 6,248.3 A -2, 3M -13 8/29/1991 6.0 RPERF 2 1/8" EnerJet; 0 deg ph T:1- 9,320.0 9,323.0 6,239.7 6,241.9 A -2, 3M -13 8/17/1987 1.0 IPERF 4" Csg Gun; 120 deg ph 9,338.0 9,380.0 6,252.6 6,282.7 A -1, 3M -13 8/29/1991 6.0 RPERF 2 1/8" EnerJet; 0 deg ph PACKER 6967 t- v 9,340_0 9,379.0 6,254.0 6,282.0 A -1, 3M -13 8/17/1987 1.0 IPERF 4" Csg Gun; 120 deg ph I r Notes: General & Safety End Date Annotation NIPPLE, 9,010 1/5/1995 NOTE: WAIVERED WELL: IAx OA COMMUNICATION 6/20/1997 NOTE: NORDIC 2 WORKOVER #1 wLEG. 9.017 6/23/1998 NOTE: NORDIC 2 WORKOVER #2 I SEAL ASSV, 5/18(2005 NOTE: 7° CASING LEAK @ 8635' - 8658' 5/22/2005 NOTE: CTD WORKOVER #3 9,124 ESP MOTOR, 7/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 9,138 ' PACKER. 9.181 I. og NIPPLE 9,196 r�P, I SOS. 9206 111 ' APERF, 9,259 -9,283 APERF, 9,283 -9,303 Mandrel Details RPERF, Top Depth Top Port I 8.3085332 (ND) Ind OD Valve Latch ace 1RO Run IPERF, 9,3204,323 Stn Top(MCB) MCP l9 Make Model lM) Sery Type TYPe On) (Pell Run Date Com -. 1 3,769.3 2,787.8 55.19 CAMCO KBUG -M 1 GAS LIFT GLV BK 0.156 1,249.0 3/6/2008 2 5,922.8 4,000.8 55.41 CAMCO KBUG -M 1 GAS LIFT GLV BK 0.188 1,278.0 3/6/2008 RPERF, 3 6,697.3 4,466.2 51.20 CAMCO KBUG -M 1 GAS LIFT OV BK 0.250 0.0 3/20/2011 I 94385380 IPERF 9440-9379 I I ' PRODUCTION. 155.689 TD, 9,734 ~~il~~~rr~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~-_, ATTN: Beth ~%~i,. bA~~~ ` ! ~ ~" ,s: `~ ~, ~,~ NO, 4914 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7ih Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 10/14/08 • Well Job # Log Description Date BL Color CD ~) 1 L-23 12097405 SBHP SURVEY / 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - J[. O p L 09/10/08 1 1 3G-25X 12080437 LDL ~ - 3 Ll (0 09/21/08 1 1 2C-04 3M-13 12100444 12096541 INJECTION PROFILE C ( LDL - (~L. ( (~ 09/14/08 09/10/08 1 1 1 1 2Z-13A 12100446 LDL ab(o- i 7 0 '3U 3 09/15/08 1 1 1 F-O6 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - r 5-0- 09/22/08 1 1 1C-111 12100451 INJECTION PROFILE "t U ~j J 09/20/08 1 1 30-15 12100452 LDL - ~ 5Q 09/2f/OS 1 1 iC-117 12100453 INJECTION PROFILE o 09/23/08 1 1 iR-11 11966277 SBHP SURVEY 5 - (~ 09/25/08 1 1 iR-35 11966279 SBHP SURVEY ~ _ ~ 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE -- 09/30/08 1 1 1R-34 12080444 _ GLS ~jL - 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .= L ~~~/ 10/02/08 1 1 1 D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~r~ ( 10/06/08 1 1 1 H-19 12096548 INJECTION PROFILE L~ 10/03/08 1 1 16-16 12097426 GLS Cj _ -'~' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE 09/12/08 1 1 3K-103 12096550 USIT _. 10/06!08 1 1 2X-05 12096551 INJECTION PROFILE - ~~ 10/07/08 1 1 18-04 12096552 INJECTION PROFILE -- ~ 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ + 10/09/08 1 1 i B-16 12096554 PRODUCTION PROFILE q C .r 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ('~t~ ~ 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~} `~' '~~../ i, '.,/ 3M -13 (187 -040) SCP Report • • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, A ugust 05, 200 5:24 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 3M -13 (187 -040) SCP Report Attachments: 3M -13 TIO.jpg; 3M- 13.pdf Jim and Tom, Kuparuk ga lifted prod ucer 3M -13 (187 -040) is SI and showing signs of TAA communic The IA is rp essur above li� ft gas p ressure. Since most CPF3 wells are SI a TIFL was not completed. However, we are assuming it would fail and will follow up with slickline to troubleshoot the GLV's and repai the leak if pos sible. The current TWO pressure are 62/1700/1550. The well was added to the weekly SCP report and is already on the master SCP report for IAxOA communication. Attached is a 90 day TIO plot and schematic. «3M -13 TIO.jpg>> «3M- 13.pdf>> Please contact me at your convenience if you have questions or comments. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 r A (IC�ti Cell (907) 943 -1687 12/10/2009 dwalralouo G G G G LD G ° CD co N G G is : 00 G ci i 00 O i G u CO CO mo o o Q CD 00 ° LL m o M O 6 LLJ O_ CL o O o o G G G G M CL ( .0 7r C O 00 CD co c.0 � G G �+ Q O I$d KRU 3M -13 ConocoPhIllips Alaska, Inc. 3M -13 API: 500292172000 Well T e: PROD Angle TS: 44 de 9267 TUBING SSSV Type: NIPPLE Ong Completion: 5/31/1987 Angle ft TD: 43 de 9734 (0 -9017, Annular Fluid: Last W /O: 5/22/2005 Rev Reason: GLV C/O OD:3.500, Reference Lo : Ref Lo Date: Last Update: 3/28/2008 ID:2.992) Last Tag: : 9116' TD: 9734 ftKB Last Tag Date: 10/1712006 Max Hole Angle: 57 deg ft 2800 Casing String - ALL STRINGS- Description Size To Bottom I TVD Wt Grade I hread CONDUCTOR 16.000 0 115 1 115 62.58 1 H -40 SURF CASING 9.625 0 4887 3416 36.00 J -55 PROD CASING 7.000 0 9689 1 6507 1 26.0 1 J -55 Tubing String - TUBING Size Top Bottom I TVD I Wt I Grade Thread IIII 3.500 0 9017 1 6025 1 9.30 1 L -80 I EUE8rd Tubina String - OLD COMPLETIONS Size I To Bottom TVD I Wt I Grade Thread 2.875 9159 9206 6158 6.50 J -55 EUE ABM Perforations Summary Interval TVD Zone Status Ft JSPFJ Date Type Comment 9269- 9303 6203-6227 C -4,A -3 34 6 1 8/29/1991 APERF 2 1/8" EnerJet; 0 deg ph 9308-9320 6231 -6240 A -2 12 6 1 8/29/1991 RPERF 2 1/8" EnerJet 0 deci ph 9320-9323 6240-6242 A -2 3 7 8/29/1991 RPERF 2 1/8" EnerJet; 0 deo ph 9323-9332 6242-6248 A -2 9 6 8/29/1991 RPERF 2 1/8" EnerJet 0 deg ph 9338-9340 6252-6254 A -1 2 6 8/29/1991 RPERF 2 1/8" EnerJet 0 deg ph 9340-9379 6254-6282 A -1 39 7 8/29/1991 RPERF 2 1/8" EnerJet 0 deg ph 9379-9380 1 6282-6283 A -1 1 6 8/29/1991 RPERF 2 1/8" EnerJet 0 de ph Gas Lift Mandrels/Valves St :6697 D TVD Man Mfr Man Type V Mfr V Type VOID Latch Port TRO Date Run VIV Cmnt 1 769 2788 CAMCO KBUG -M GLV 1.0 BK 0.156 1249 3/6/2008 2 923 4001 CAMCO KBUG -M GLV 1.0 BK 0.188 1278 3/6/2008 3 4466 CAMCO KBUG -M OV 1.0 BK 0.250 0 3/7/2008 Other (Pluci equip., etc. - COMPLETION R 9010 TVD T e Descri tion ID 26 HANGER FMC TUBING HANGER 5/22/05 2.992 488 NIP CAMCO LANDING NIPPLE 5/22/05 2.875 4500 PBR BAKER PBR - SHEARED 5/22/05 2.940 4509 PACKER BAKER 'FHL' HYD SINGLE STRING PACKER 5/22/2005 3.960 6004 PACKER BAKER PREMIER PACKER WITH TCII CONNECTION 5/22/2005 2.875 6020 NIP CAMCO DS NIPPLE 2.812 6025 WLEG WIRELINE ENTRY GUIDE 5/22/2005 2.992 Other lu s equip., etc. - OLD COMPLETION FISH #2 POST 5/2212005 WORKOVER De th TVD Type Description ID 9141 6112 SEAL Centrilift'GST3 4B HL PFS' Tandem Seal Section 0.000 9155 6122 MOTOR Centrilift '304 HP KMH 2290/81' Series 562 Motor w /motor lead extension cable. 0.000 Motor has a 6" centralizer threaded to base. Other s e ui . etc. - OLD COMPLETION FISH #1 POST 5/20/1998 WORKOVER Depth TVD Type Descri tion ID 9182 6141 PKR Baker'SAB -3' Packer w /'K -22' Anchor Seal Ass 3.000 9186 6144 NIP Camco'D' Ni le No -Go 2.250 9205 6157 SOS Baker 2.441 9206 6158 TTL 2.441 General Notes Date I Note 1/5/1995 1 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 5/18/2005 1 NOTE: 7" CASING LEAK @ 8635'- 8658' 5/22/2005 1 NOTE: CTD WORKOVER SEAL (9141 -9155, OD:2.441) kup-1;p Sep i.lP PROD p f 2 �� CASING �' "" C '; J �, I S `" / f �t (0 -9689, �� OD:7.000, /gyp Wt:26.00) q P�G� CSG 4-` r— TUBING (9159 -9206, OD:2.875, ID:2.441) 1L ",:ul r�L lit ` Eric NIP ) (9186 -9187, { OD:2.875) C�- C'1'7ti� /�� Cyr 49 4 Perf (9269 -9283) Perf — - (9283 -9303) - I 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 63' . . \\/ED STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing 0 Ope rat. ShutdownD Stimulate Q Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development Q Stratigraphic 0 Time Exten$ion:." Re-enter Suspended Well 5. Permit to Drill Number: 187-040/ . 6. API Number: 50-029-21720-00 Exploratory 0 Service 0 9. Well Name and Number: 3M-13 . 8. Property Designation: ADL 25512; ALK 2553 11. Present Well Condition Summary: Tubing (size, grade, and measured depth) 3.5" /2-7/8", L-80 / J-55, 9017' /9206' MD. Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING Perforation depth: 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool measured 9734' feet true vertical 6539' feet measured 9105' feet true vertical 6087' feet Length Size MD 115' 16" 115' 4824' 9-518" 4887' 9626' 7" 9689' Plugs (measured) Junk (measured) 9032' TVD Burst Collapse 115' 3416' *8~Q7' Vd/' ,,-,. ._!..! ,-, '" ,t~Ji.. ',i - ',.1 ,"J!'-dþ'V,l ,..... ",,,.,).. t¡ (. Measured depth: 9269'-9303', 9308'-9332', 9338'-9380' true vertical depth: 6203'-6227',6231'-6248',6252'-6283' BH 2 ) 2006 Packers & SSSV (type & measured depth) Baker 'FHL', Baker Premier pkr= 6765', 8987' Cameo landing nipple @ 488' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9115' 11 bbls of 12% HCI Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 365 1092 901 150 Subsequent to operation 487 . 1482 1102 153 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development Q 'Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilQ' GasD WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Form 10-404 Revised 04/2004 Contact Printed Name Signature Howard Gober @ 263-4220 Howard Gober Wells Group Engineer Date n114/exo Title Phone Pre a' b haron All u Dr ke 263-4612 OR\G\NAL t- o. \,\ I'd , -Db II../~~ ~t(~MnIY . 3M-13 Well Events Summary . DATE Summary 10/21/06 Spot 11 bbls of 12% Hcl acid on top of fish @ 9115' CTMD. Once @ surface, squeezed acid into perfs by injecting 5 bbl incr~ments @ .5 bpm wI 30 minute hesitation times between pumping. (Established injection rate of 2300 psi @ .5 bpm). . . ConocoPhillips Alaska, Inc. KRU 3M-13 '~ TU81NG (0-9017, 00:3.500, 10:20992) 3M-13 Well Tvoe: PROD Oria ComDletion: 5/31/1987 Last W/O: 5/22/2005 Ret Loo Date: TD: 9734 ftKB Max Hole Anole: 57~2800 TaD Bottom o 115 o 4887 o 9689 I ~TVD I wt I 030 TVD wt 6158 I 6050 Status Ft SPF Date 34 6 8/29/1991 12 6 8/29/1991 3 7 8/29/1991 9 6 8/29/1991 2 6 8/29/1991 39 7 8/29/1991 1 6 8/29/1991 V Mfr V Type V OD Latch Annie f1'/) TS: 44 den f1'/) 9267 Annie f1'/) TD: 43 deo !If¡ 9734 Rev Reason: TAG FILL Last Uodate: 10/12/2006 SEAL (9032-9046, 00:2.441) MOTOR (9046-9050, 00:20441) API: 500292172000 SSSV TVDe: NIPPLE Annular Fluid: Reference Loo: Last Tao: 9105 Last E;äate: 10/10/2006 Description Size CONDUCTOR 160000 SURF CASING 90625 PROD CASING 7.000 Tubing String - TUBING . Size Top I Bottom 30500 0 I 9017 Tubina Strina - OLD COMPLETIO Size TaD I Bottom 2.875 9159 I 9206 Perforations SummarY Interval TVD Zone 9269 - 9303 6203 - 6227 C-4,A-3 9308 - 9320 6231 - 6240 A-2 9320 - 9323 6240 - 6242 A-2 9323 - 9332 6242 - 6248 A-2 9338 - 9340 6252 - 6254 A-1 9340 - 9379 6254 - 6282 A-1 9379 - 9380 6282 - 6283 A-1 Gas Lift MandrelslValves St MD TVD Man Man Type Mfr 1 3769 2788 CAMCO KBUG-M 2 5923 4001 CAMCO KBUG-M 3 6697 4466 CAMCO KBUG-M other rDluas, eQUiD., et DeDth TVD TVDe 26 26 HANGER FMC TUBING HANGER 5/22/05 488 488 NIP CAMCO LANDING NIPPLE 5/22/05 6751 4500 PBR BAKER PBR - SHEARED 5/22/05 6765 4509 PACKER BAKER 'FHL' HYD SINGLE STRING PACKER 5/22/2005 8987 6004 PACKER BAKER PREMIER PACKER WITH TCII CONNECTION 5/22/2005 9010 6020 NIP CAMCO DS NIPPLE 9017 6025 WLEG WIRELlNE ENTRY GUIDE 5/22/2005 other :Dluas, eauiD., ete-l - OLD COMPLETION FISH #2 (POST 5/2212005 WORKOVER) Depth TVD Tvpe DescriDtion 9032 6036 SEAL Centrilift 'GST3 4B HL PFS' Tandem Seal Section 9046 6045 MOTOR Centrilift '304 HP KMH 2290/81' Series 562 Motor w/motor lead extension cableo Motor has a 6" centralizer threaded to base. other :Dluas, equiD., etc.) - OLD COMPLETION FISH #1 (POST 5/20/1998 WORKOVER) Depth TVD Tvpe DescriDtion 9182 6141 PKR Baker 'SAB-3' Packerw/ 'K-22' Anchor Seal Assy TVD 115 3416 6507 wt 62058 36.00 26.00 Grade H-40 J-55 J-55 Thread I I I Grade I Thread I L-80 EUE8rd - I Grade I Thread I J-55 FIIF ABM TVDe Comment APERF 21/8" EnerJet· 0 dea Dh RPERF 21/8" EnerJel' 0 deg ph RPERF 2 1/8" EnerJet; 0 dea Dh RPERF 2 1/8" EnerJel' 0 dea Dh RPERF 21/8" EnerJel' 0 dea Dh RPERF 21/8" EnerJel' 0 deg ph RPERF 21/8" EnerJel' 0 dea Dh Port TRO Date Run Vlv Cmnt LRY GLV GLV OV DescriDtion 100 100 100 SBK-2C 00156 SBK-2C 00188 BK n IRR 1300 1332 o 9/2/2005 9/2/2005 9/2/2005 ID 2.992 20875 20940 30960 20875 20812 20992 ID 0.000 0.000 ID 3.000 9186 6144 NIP Camco 'D' Nioole No-Go 9205 6157 SOS Baker 9206 6158 TTL \!almêfál Notd Date Note 1/5/1995 WAIVERED WELL: IA x OA COMMUNICATION 5/18/2005 7" CASING LEAK @ 8635' - 8658' 5/22/2005 CTD WORKOVER 2.250 2.441 2.441 TUSING (9159-9206, 00:20875, 10:20441) Perf (9269-9283) Perf (9283-9303) - - = = - - = = - - STATE OF ALASKA ) ALASKA .JL AND GAS CONSERVATION COlvd\l1lSSION REPORT OF SUNDRY WELL OPERATIONSHJN 1 L,t 2005 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate 0 Other iii Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well a Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 63' 8. Property Designation: ADL 025512 4. Current Well Class: iii Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 187-040 6. API Number: 50-029-21720-00-00 9. Well Name and Number: Kuparuk 3M-13 10. Field / Pool(s): Kuparuk River Unit / Kuparuk River Pool 11. Present well condition summary Total depth: measured 9734 feet true vertical 6539 feet Plugs (measured) None Effective depth: measured 9032 feet Junk (measured) 9032 true vertical 6036 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 115' 115' Surface 4887' 9-5/8" 4887' 3416' 3520 2020 Intermediate Production 9689' 7" 9689' 6507' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 9269' - 9380' 6203' - 6283' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCAI\1NED JUN 1 £; 2005 3-1/2",9.3# & L-80 2-7/8",6.5# J-55 Baker 'SAB-3' packer w/ K-22 Anchor Seal Assy; Baker Premier Packer; Baker 'FHL' Hyd Single String Packer; Camco Landing Nipple Surface to 9017' & 9159' - 9206' 9182'; 8987'; 6765'; 489' Treatment description including volumes used and final pressure: RBDMS BFl JUN ] 5 2005 13. Oil-Bbl Prior to well operation: 330 Subsequent to operation: 295 14. Attachments: 0 Copies of Logs and Surveys run iii Daily Report of Well Operations iii Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure 930 658 1233 505 Tubinq Pressure 132 165 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: iii Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 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: Contact Howard Gober, 263-4220 305-065 Printed Name Terrie Hubble Signature -1 Q/If\i..e . ~ ~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone Date r:Jo(¡ 41 óS Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 n R I h I í\1 A I ) ) Well: Field: API: Permit: Kuparuk 3M-13, Rig Workover Kuparuk River Unit 50-029-21720-00-00 187 -040 Accept: Spud: Release: Rig: 04/30/05 N/A OS/22/05 Nordic #2 PRE-RIG WORK 02/16/05 TAGGED AT 8833' SLM W/ IMPRESSION BLOCK (FACE OF IMPRESSION BLOCK INDICATES FILL). 02/17/05 OBTAINED SBHP OF 3740 PSI AND BHT OF 1510 FAT 8940' RKB AND MADE GRADIENT STOP AT 8840' RKB. ()2/22/05 MITOA - PASSED, POT-IC - PASSED, PPPOT-IC - PASSED, FUNCTION TEST LDS'S. 04/20/05 TAGGED FILL IN TUBING AT 8950' RKB (80' OVER TOP OF THE ESP PUMP AND 13' BELOW THE LAST MANDREL). PULLED CV FROM STA # 5 AT 8937 RKB, PULLED OGLV FROM STA # 3 AT 5596' RKB, AND PULLED LGLV FROM STA # 2 AT 3544' RKB (ALL VALVES SCALED UP). 04/21/05 SET DGLV'S IN STA # 2 AT 3544' RKB AND STA # 3 AT 5596' RKB. RAN IMPRESSION BLOCK AND TAGGED FILL TO CONFIRM DGLV'S IN PLACE. PERFORMED SBHPS AT 8940' RKB (3465 PSI AT 149 DEG) AND 8840' RKB (3434 PSI). 04/24/05 POT & PPPOT-T -PASSED. 04/26/05 ATTEMPTED TO PLUG PERFS WITH CALCIUM CARBONATE PILLS FOR UPCOMING RIG WORKOVER. PUMPED 2 PILLS, 10 BBLS EACH, 600# OF CALCIUM CARBONATE PER PILL. NO PRESSURE RESPONSE SEEN. LEFT WELL DISPLACED, WILL RETURN AFTER REVIEW OF OPTIONS WITH ENGINEERING STAFF. 04/28/05 PUMPED 2 CALCIUM CARBONATE PILLS (10 BBLS EACH) ATTEMPTING TO PLUG OFF PERFS. DID NOT SEE ANY PRESSURE INDICATIONS THAT PERFS PLUGGED OFF. DISPLACED WELL WITH DIESEL AND LEFT SHUT-IN. INJECTIVITY TEST: LEAK OFF RATE OF 1.7 BBLS OVER 1 HOUR. FORMATION PRESSURED UP AS IT LOST 50# OVER FIRST 10MIN, 50# OVER 17 MIN, FOLLOWED BY 20#'S LOST OVER 15 MINS. 04/29/05 PUMPED HOT SW (160 F), 30 BBLS LUBRICANT, 350 BBLS (120 F) 11.5 PPG BRINE DOWN THE TUBING CIRCUL TING RETURNS OUT THE IA. FINAL PRESSURES T/IA/OA = 250/450/825. FINAL SAMPLE WAS 11.3 PPG CLEAN BRINE. TBG HELD WHEN BLED TO 0 PSI, ALTHOUGH IA PRESSURE WAS 25 - 50# WITH GAS/HYDROCARBONS TO SURFACE. RETURNED TO PUMP 148 BBLS 11.5# HEAVY BRINE TAKING RETURNS TO THE TIGER TANK FOR RECYCLE. INITIAL SAMPLES CONTAINED 10.5 PPG BRINE WITH COPIOUS AMOUNTS OF GAS. SAMPLES BEGAN TO WEIGHT UP AND GAS DIMINISHED WITH 90 BBLS AWAY. ') ) BP AMERICA Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-13 3M-13 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/30/2005 Rig Release: 5/22/2005 Rig Number: Spud Date: 4/30/2005 End: 5/22/2005 4/30/2005 00:00 - 02:00 2.00 MOB P PRE 02:00 - 02:45 0.75 MOB P PRE 02:45 - 04:00 1.25 MOB P PRE 04:00 - 06:00 2.00 MOB P PRE 06:00 - 06:30 0.50 MOB P PRE 06:30 - 08:45 2.25 MOB P PRE 08:45 - 10:30 1.75 MOB P PRE 10:30 - 10:45 0.25 MOB P PRE 10:45 - 11 :00 0.25 MOB P PRE 11 :00 - 12:30 1.50 MOB P PRE 12:30 - 14:00 1.50 MOB P PRE 14:00 - 14:20 0.33 RIGU P PRE 14:20 - 16:00 1.67 RIGU P PRE 16:00 - 18:00 2.00 RIGU P PRE 18:00 - 19:30 1.50 RIGU P PRE 19:30 - 21 :00 1.50 RIGU P PRE 21 :00 - 21 :43 0.72 RIGU P PRE 21 :43 - 00:00 2.28 RIGU P PRE 5/1/2005 00:00 - 00: 15 0.25 BOPSUPP PRE 00:15 - 02:00 1.75 BOPSUPP PRE 02:00 - 02:40 0.67 BOPSUR P PRE 02:40 - 04:30 1.83 BOPSUP P PRE 04:30 - 06:00 1.50 BOPSUPP PRE 06:00 - 10:30 4.50 BOPSUPP PRE 10:30 - 11: 15 0.75 BOPSUPP PRE 11:15 -13:30 2.25 BOPSURP PRE 13:30 - 14:30 1.00 BOPSUF N RREP PRE 14:30 - 18:00 18:00 - 23:15 3.50 BOPSUR P 5.25 BOPSUR P PRE PRE Description of Operations Continued from 3H-26 DIMS entries. Continued rig down on 3H-26, and prepare to move off well. Pre move safety meeting, and prespud meeting for 3M-13. Move rig off of well 3H-26, and stage at the entrance to the pad. Move rig off of 3H pad heading to 3M pad in Kuparuk. Stop at intersection of spine road and 31 pad access road for crew change, and to remove 3 posts that are blocking the rig from entering 31 pad. Resume move to 3M pad. Nordic 2 arrived at 3M pad. Prep pad, spot herculite and drip pans, etc. PJSM prior to moving over well. Move over well 3M-13. Spot timbers under rig to level rig prior to setting down. RIG ACCEPTED AT 1100 hrs 4/30/2005 Set down rig, slide in cuttings box, make up hardline to tiger tank to rig. Safety meeting prior to performing crane lifts to bring ESP cable spooler to rig floor. Lift ESP spooler to rig floor. Continue with crane lifts, simultaniously bleeding down T, lA, OA. Initial pressures IA=250, OA=650 psi. RU to pull BPV, pull BPV, Pia = 100 psi Pt = 0 psi RU to circulate KWF in well. RD kill and ckoke lines off 7/16" BOP's and install on tree. PT surface line to 3000 psi OK. Lined out to circulated down tubing Circulated 11.7ppg at 1.00 to 3.75 bpm. Circulated 370 bbls and SO to monitor well Monitor well, still flowing 1/2'" stream up the annulus Circulated well at 3.5 bpm. Vp 500 bbl SO and monited well, well dead NO circulating lines and install TWC in hanger. Checked pressure on hanger. Painted strip on tree. NO tree and set in cellar. removed TWC sleeve and a-rings from heat trace and ESP penetrator. Screwed in 2-7/8" EUE 8rd PJ to check treads. Made 9-1/2 turns to torque. IA is pressure up slightly due to gas in ESP cable. < 50 psi at 0530 hrs NU 7-1/16" 5k BOP's Continue NU BOP stack. Body test stack, found leaking seal under annular. Suck down stack with chugger pump, and change out seal ring. Body test passed ok. Begin BOP test. Small leak on riser that we will repair after the BOP test. Witness of BOP test performed by BP Co Rep, Greg Sarber. Witness by the AOGCC waived by Chuck Scheave. Blind Shear rams failed to test. Chugger out stack. Change out blind ram horse shoe rubbers that were worn out. Resume test. Continue with BOP test. Blinds tested fine after replacement. Try to check pressure under TWC with dry rod. Can screw into TWC but torques up 2 turns (need 3) RU lubricator to Pull Printed: 5/23/2005 1 :37:54 PM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-13 3M-13 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/30/2005 Rig Release: 5/22/2005 Rig Number: Spud Date: 4/30/2005 End: 5/22/2005 Code NPT Phase 5/1/2005 18:00 - 23:15 5.25 BOPSUPP PRE TWC. Unable to screw-in to hanger with Lopsa Apsa and 2-7/8" crossover. Reconfigure lubricator to place 3-1/2" 8rd above annular. Screwed into hanger 10 turns. RU spaceout stem and lubricator RIH with retrieving tool and backed out TWC, lAp = 0 psi Pulled TWC, well on slight vac. Pulled lubricator OOH and backed off 3-1/2" tubing above annular. Screwed into collar and backed off from hanger. Pulled out of hole 23: 15 - 00:00 0.75 BOPSURP PRE LD FMC tools and loaded out 5/2/2005 00:00 - 00:30 0.50 BOPSURP PRE Finish loading out FMC tools 00:30 - 02:35 2.08 PULL P DECOMP RU to pull completion. Screwed into hanger 8 turns, torqued up. Backed of LDS, bleedd annulus down to 0 psi 02:35 - 02:45 0.17 PULL P DECOMP PU on string, pulled out of hanger at 70k. PU 3 ft, PU wt is at 90k. Doesn't act like its free. Slacked off to 70k, shut annular and set slips. RU to cir bottoms up. 02:45 - 04:30 1.75 PULL P DECOMP Circulated wellbore longway at 2.5 -3.0 bpm at 476/750 psi. Vt= 53 bbl Va = 273 bblDensity = 11.7/11.6 ppg 04:30 - 06:00 1.50 PULL P DECOMP PU on tubing to 100k. no movement, stacked off, no movement in either direction. Working tubing while cir at 2.5 bpm. Working tubing between 100k and 50 k. Called SLS Pipe recover to FP tubing and jet cut tubing and ESP cable. 06:00 - 08:30 2.50 PULL P DECOMP Confirm SWS is bringing the proper equipment. Notify town engineer of situation and plan forward. Wait on Schlumberger to arrive at location. 08:30 - 08:45 0.25 PULL P DECOMP Continue to circulate while we discuss with town the plan forward. While waiting for Schlumberger we will add MI EMI-920 mud lub to the system to try to reduce pipe friction. The material is thick and cold and will take time to add to the system. 08:45 - 09:00 0.25 PULL N DPRB DECOMP Driller noticed a 138 bbl pit gain. Notify the Company man, and shut in the well. 09:00 - 09:50 0.83 PULL N DPRB DECOMP Hold safety meeting on rig floor. Initial SI P on standpipe is 0 psi (5000 psi gauge). 220 psi on CSG. Discuss situation. Check fluid density in pits. Pit 2 = 11.39 ppg, Pit 3 = 11.25 ppg, Pit 4 = 11.13 ppg, Pit 5 = 11.18 ppg. We were pumping out of pit 5, taking returns to pit 2. Rig up SWS electric transducer to DPP. DPP=176 psi, IAP=305 psi. 09:50 - 10:45 0.92 PULL N DPRB DECOMP Call Mike Mooney and Howard Gober of CPAI. Call Lowell Crane of BP. Call AOGCC, Chuck Scheave. Appraise them of the situation. Make Kill plan. Initial SIDPP=95 psi. with 11.25 ppg fluid in tubing. Calculated KWF=11.55 ppg. Weight up pits to 11.6+ PPG. Tubing vol=52 bbls (1550 strokes), Backside vol=262 bbls (7860 strokes), Round trip vol = 314 bbls (9410 strokes). 10:45 - 11: 15 0.50 PULL N DPRB DECOMP Hold PJSM to discuss well kill. Plan to kill the well using the drillers method, taking gas cut returns to the tiger tank. 1100 psi on Annular hydraulic pressure. Pipe rams are just above tubing hanger. Probably can't close pipe rams. Plan is to use annular only. If it starts to leak, we will strip the tubing hanger back down on seat, close the pipe rams, and run in the LDS. 11 :15 - 12:30 1.25 PULL IN tDPRB DECOMP Notify pad operator of taking gas returns to tiger tank. Try to line up to Triflo choke. DPP gauge is not working. Fix gauge. Printed: 5/23/2005 1 :37:54 PM BP Operations Summary Report Legal Well Name: 3M-13 Common Well Name: 3M-13 Spud Date: 4/30/2005 Event Name: WORKOVER Start: 4/30/2005 End: 5/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 5/22/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/2/2005 12:30 - 12:45 0.25 PULL N DPRB DECOMP On line with 11.6 ppg brine. 470 PVT, Tiger tank base volume = 15 bbls. Assign 1 hand to watch tiger tank. Catch tank levels every 15 minutes. 12:45 - 13:00 0.25 PULL N DPRB DECOMP CSP=450 psi, DPP=304 psi, pit vol=450 bbls, pumping at 1 bpm. 13:00 - 13:15 0.25 PULL N DPRB DECOMP CSP=450 psi, DPP=300 psi, Gained 22 bbls in tiger tank. Note fresh water tank on rig 105 bbls at 06:00, 105 bbls at 09:00. Also note, Playback of PVT data shows kick started at 05:30 this AM. 13:15 - 13:30 0.25 PULL N DPRB DECOMP CSP=460 psi, DPP=260 psi, PVT=430 bbls, +27 bbls gain in TT in last 15 minutes 13:30 - 13:45 0.25 PULL N DPRB DECOMP CSP=520 psi, DPP=300 psi, PVT =418 bbls, +24 bbls gain in TT in last 15 minutes. 13:45 - 13:50 0.08 PULL N DPRB DECOMP CSP=500 psi, DPP=300 psi, PVT=407 bbls, +14 bbls gain in TT in last 15 minutes. 13:50 - 14:00 0.17 PULL N DPRB DECOMP CSP=500 psi. Increase pump rate to 2.0 bpm. New DPP=425 psi. Note - Checked with CPF3, no injectors opened up, or rates increased in past 12 hours. BHP should be the same as last pressure survey. 14:00 - 14:15 0.25 PULL N DPRB DECOMP CSP=560 psi, DPP=440 psi, PVT =387 bbls, Strokes=3400, +11 bbls in TT. 14:15 - 14:30 0.25 PULL N DPRB DECOMP CSP=608 psi, DPP=483 psi, PVT =363 bbls, STR=4368, + 17 bbls in TT. 14:30 - 14:45 0.25 PULL N DPRB DECOMP CSP=626 psi, DPP=550 psi, PVT=343 bbls, STR=5288, +25 bbls in TT. 14:45 - 15:00 0.25 PULL N DPRB DECOMP CSP=650 psi, DPP=500 psi, PVT =326 bbls, STR=6205, +20 bbls in TT. 15:00 - 15:15 0.25 PULL N DPRB DECOMP CSP=660 psi, DPP=550 psi, PVT=301 bbls, STR=7134, +26 bbls in TT. Caught a sample of returns, got 10.6 ppg, gas cut sample. 15:15 - 15:30 0.25 PULL N DPRB DECOMP CSP=505 psi, DPP=440 psi, PVT=281 bbls, STR=81 00, +9 bbls in TT. 15:30 - 15:45 0.25 PULL N DPRB DECOMP CSP=470 psi, DPP=430 psi, PVT=258 bbls, STR=9051, +19 bbls in TT 15:45 - 16:00 0.25 PULL N DPRB DECOMP CSP=505 psi, DPP=480 psi, PVT=240 bbls, STR=9702, +19 bbls in TT. 16:00 - 16:15 0.25 PULL N DPRB DECOMP CSP=417 psi, DPP=400 psi, PVT=226 bbls, STR=10760, +18 bbls in TT. Total returns = 238 bbls since start of pumping. 16:15 - 16:30 0.25 PULL N DPRB DECOMP CSP=480 psi, DPP=440 psi, PVT =200 bbls, STR=11823, +23 bbls in TT. 16:30 - 16:45 0.25 PULL N DPRB DECOMP CSP=322 psi, DPP=380 psi, PVT=172 bbls, STR=12510, +19 bbls in TT, 280 bbls total. Bottoms up is 262 bbls, return sample density is 11.1 ppg, continue to circulate. 16:45 - 16:50 0.08 PULL N DPRB DECOMP CSP=500 psi, DPP=540 psi, PVT=152 bbls, STR=13380, +23 bbls in TT. Catch a sample of returns it is 11.4 heavy. Pumped 323 bbls out of pits based on PVT, got 303 bbls in tiger tank. 16:50 - 17:15 0.42 PULL P DECOMP Circulating back into the pits thru the gas buster. PVT =146 bbls. DPP=90 psi, CSP=99 psi. Clean returns at 11.4+. 17:15 - 21 :30 4.25 PULL ( DECOMP Circulating out of pit 5, PVT now 154 bbls. Took another pit Printed: 5/23/2005 1 :37:54 PM BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-13 3M-13 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/30/2005 Rig Release: 5/22/2005 Rig Number: Spud Date: 4/30/2005 End: 5/22/2005 5/2/2005 17:15 - 21 :30 4.25 PULL P DECOMP gain of 7 bbls. SI returns. Casing pressure is 84 psi, Tubing pressure is 0 psi. Monitor tubing and casing pressure. No change. No pressure on tubing. Could be out of balance, u-tubing. Kick pumps back on. Circulate. Adding 4 drums EMI920 to system. Inc Qp to 2.5 bpm. Density = 11.8 / 11.8 gas cut to 11.25 ppg. Density increasing as we'll circulating. to 11.5 ppg. Added 12.00 ppg to pits Vp = 420 bbl. Lost efficiency with MP1 switch to MP 2 21 :30 - 23:00 1.50 PULL P DECOMP Circulating, adding EMI 920. Qp = 2.30/ 2.39 bpm Density = 11 .7 / 11 .7 ppg SD pump, monitor well, no flow, gas is percolating at surface. 23:00 - 23:30 0.50 PULL P DECOMP PU on string to 100k 5 times with no movement up of down 23:30 - 00:00 0.50 PULL P DECOMP Cit at 2.00 bpm and RU Schlumberger 5/3/2005 00:00 - 00:45 0.75 PULL P DECOMP Circulated at 2.5 bpm. Density = 11.8/11.8 ppg, no losses or gains 00:45 - 02:00 1.25 PULL P DECOMP PJSM with SLB, BP, Nordic on Pipe Recovery methods and hazards. 02:00 - 02:50 0.83 FISH P DECOMP SD pumps and RU SLB to run CCL log. 02:50 - 04: 15 1.42 FISH P DECOMP RIH with CCL and logged all 5 GLM. Found GLM #1 at 8,936ft and PBTD at 8,950ft. The PBTD at the bottom of the 8 ft PJ below the GLM. This would require the Chem cut to be on bottom and the anchor would be near the GLM pocket. Not good. Have to shoot 1/2 way on the 1st full joint above the GLM. POOH. 04: 15 - 06:00 1.75 FISH P DECOMP OOH, RD and LD CCL tool string, Change cable head and RU to run FP tool Waiting on 12 ft 350 Ton bails from Nordic Rig 3. 06:00 - 07:50 1.83 EVAL P DECOMP RU Schlumberger E-line to run free point log. 07:50 - 09:45 1.92 EVAL P DECOMP RIH, run SWS free point log. 09:45 - 11 :30 1.75 EVAL N DFAL DECOMP Pipe confirmed free down to 6000'. SWS FP tool failed. POOH, swap tools and rerun below 6000'. 11 :30 - 16:00 4.50 EVAL P DECOMP Re log free point. Best indication is pipe free to 6093'. Only able to pull 93k# at surface due to J-55 pipe strength. 16:00 - 19:00 3.00 EVAL P DECOMP Discuss with town. Order EP Lube from Baroid. 19:00 - 20:00 1.00 EVAL P DECOMP RU to circulate well and add E-Lube 20:00 - 21 :30 1.50 EVAL P DECOMP Circ well at 2.5 bpm. Vp = 413 bbl, No losses or gains Addibg EP Lube to system with 1 % EMI 920 lube 21 :30 - 22:00 0.50 EVAL P DECOMP Wirth EPLube spotted, worked tubing from 50k to 100k, Nordics weight indicator failed. Unable to determine correct tensionl on sting. Called N1 and order their Totco Line Weight Indicator to determine the correct pull on fish. 22:00 - 00:00 2.00 EVAL N RREP DECOMP Circulate at 2.5 bpm and wait on replacement weight indicator Vp = 409 bbl 5/4/2005 00:00 - 00:15 0.25 EVAL P DECOMP RU Totco WI and confirmed string wt. Pulled 3 times to 100k and no movement. 00:15-01:00 0.75 EVAL P DECOMP RU eline with FP tool 01 :00 - 04:40 3.67 EVAL P DECOMP RIH and FT string. Checked FP from 65k to 95k @ D= 6124 ft 100% Free D= 7009 ft 60.6% Free D= 7498 ft 36% Free D = 7010 ft = 56% Free D = 6491ft (Below the GLM at 6390 ft) = 88.6 % Free D 6430 ft (Below GLM at 6390 ft) = 77.28% Free Free Printed: 5/23/2005 1 :37:54 PM ) ) Operations Summary Legal Well Name: 3M-13 Common Well Name: 3M-13 Spud Date: 4/30/2005 Event Name: WORKOVER Start: 4/30/2005 End: 5/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 5/22/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/4/2005 01 :00 - 04:40 3.67 EVAL P DECOMP D = 6314 ft ( 3 jts above GLM at 6390 = 100% Free Checked twice, the same Ran collar log from 6,500 ft to 6,200 ft to identify the collars above GLM There is LaSalle camps on every other collar to suface. The location of chem cut is 6,288 ft, 6 ft above a LaSalle Clamp and 3 jts above the GLM at 6,390 ft plus 6 ft stub. 192 jts out of 275 jts recoverable with 3 GLM removed with ESP cable. Estimated string wt = 51 k up minus drag POOH and LD FP tool. 04:40 - 05:00 0.33 EVAL P DECOMP RU and arm string shot 05:00 - 05:30 0.50 EVAL P DECOMP RIH with string shot to 6,290 ft (bottom of string shot) Fired 05:30 - 06:45 1.25 EVAL P DECOMP POOH with string shot. LD tools on rig floor. 06:45 - 07:00 0.25 EVAL P DECOMP Hold PJSM with crews to discuss handling chemical cutter & procedures. 07:00 - 07:30 0.50 EVAL P DECOMP MU chemical cutter for 2-7/8" tbg. 07:30 - 08:30 1.00 EVAL P ·DECOMP RIH. Get on depth with cutter. (6288'). Well began to flow up back side. 08:30 - 09:30 1.00 EVAL P DECOMP POOH with cutter tools. Stop periodically to circulate down tbg to keep hole full and prevent swabbing. Get off well. Gain 3 bbls fluid from IA while POOH. 09:30 - 13:00 3.50 KILL P DECOMP Discuss fluid handling plan with crews. Off load pits to make room to weight up to 12.0 ppg with fluid on location. Load 12.2 ppg brine from vac truck and mix with pit fluids. SITP: 0 psi, SICP: 29 psi. Continue to condition brine to bring weight up to 12.0 ppg. 13:00 - 15:30 2.50 KILL P DECOMP Criculate down tbg at 840 psi @ 3.0 bpm in/out. Hold 220 psi WHP with choke. Take rtns out to tiger tank, then bring back inside to weight up additional volume. 15:30 - 16:30 1.00 KILL P DECOMP Monitor well while weighting up remaining brine. Hold PJSM with SLB and rig crew. 16:30 - 18:30 2.00 FISH P DECOMP RU safety valve and pump in sub. MU SLB 2-7/8" chemical cutter. 18:30 - 19:30 1.00 FISH P DECOMP RIH and found restriction at 6,440 ft. Logged up for tie-in. Chem cut at 6,288 ft. String wt = 75k, lost 35 k when shot. POOH and RD Eline 19:30 - 22:00 2.50 FISH P DECOMP PU 10 ft, PUW = 50 k and circulated 230 bbl, BU - 190 bbls 22:00 - 0.00 FISH P DECOMP Pulled hanger through table. PU to 65k and ESP came apart and wt dropped off to 45k. Remove ESP and Heat trace probes. PUH LD landing jt, made up safety joint with floor valve. RU ESP sheave and hang in derrick. PUH laying down 2-7/8" completion. filling hole through trip tank every 10 jts = 2.00 bbl 5/5/2005 00:00 - 02:45 2.75 PULL P DECOMP LD ESP completion LD 61 jts and 1 GLM. 02:45 - 03:30 0.75 PULL P DECOMP Unload pipe shed of tubulars 03:30 - 06:30 3.00 PULL P DECOMP LD ESP Completion LD 108 jts at 05:30 hrs. Call for crane to remove ESP cable spooler. 06:30 - 07:30 1.00 PULL P DECOMP LD 121 jts. Remove same from pipe shed. 07:30 - 07:45 0.25 PULL P DECOMP Hold PJSM with crew and KRU crane operator to discuss lifting ESP spool from rig floor. 07:45 - 09:15 1.50 PULL P DECOMP Spot crane. Lift and remove full ESP cable spool from rig floor. Estimated weight was 14k#. Lift and spot empty ESP spool on rig floor. Printed: 5/23/2005 1 :37:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-13 3M-13 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/30/2005 Rig Release: 5/22/2005 Rig Number: Spud Date: 4/30/2005 End: 5/22/2005 5/5/2005 09:15 - 13:30 4.25 PULL P DECOMP Continue to pull and LD 2-7/8" completion assy. 13:30 - 14:30 1.00 PULL P DECOMP At surface with cut joint. 25.8' cut joint recovered, clean, round chemical cut on tbg. 15.1' of ESP cable extending below cut, including +/-4' section of stretched 1 distorted cable armor at btm end of cable. All clamps recovered intact. Estimate ESP cable parted at or below shallowest clamp on tbg remaining in hole. There maybe up to 60' to 65' of loose cable below fish top and/ or next clamp in hole. 14:30 - 15:30 1.00 PULL P DECOMP Continue to remove recovered tbg from pipe shed and clean up rig floor. 15:30 - 00:00 8.50 FISH P DECOMP Load pipe shed with 300 jts of 3-1/2" PH6 work string. Drift and strap same. 5/6/2005 00:00 - 06:00 6.00 FISH P DECOMP Load pipe shed with 3-1/2" 12.95#/ft P110 PH6 Tubing The connection are dirty and will be required to be clean before making up. There is a lot of scale inside the tube, will have to be delt with while picking up. 06:00 - 06:30 0.50 FISH P DECOMP Hold PJSM with day crew to discuss MU fishing BHA and· picking up work string. 06:30 - 08:00 1..50 FISH P DECOMP MU 5-1/2" overshot assembly BHA. 08:00 - 10:30 2.50 FISH P DECOMP Run in hole with overshot on PH6 pipe, picking up singles. 40 jts in the hole as of 10:30. 10:30 - 12:30 2.00 FISH P DECOMP Continue to pick up PH6 singles. 12:30 - 13:15 0.75 FISH P DECOMP 85 jts in hole. RU to circulate to clear pipe. Well stable. 12.0 ppg in and out. 13:15 - 17:15 4.00 FISH P DECOMP Continue to pick up PH6 singles. 191 jts as of 1715 hrs. 17:15 - 18:30 1.25 FISH P DECOMP Ru and circulate well to clear PH6. 18:30 - 19:30 1.00 FISH P DECOMP PU DP to jt 201 and tag TOF at 6298' DPM. Space out with two pups. Work over TOF and engage 19:30 - 20:30 1.00 FISH P DECOMP Work pipe in stages from 53k neutral to 30k dn and 140k up and fish is not moving. Circulate at 2.0/240 while working pipe (no jars in string). After about 20 cycles and at 140k, had instantaneous wt loss back to 50k. PUH 15' and found fish moved freely at 65k (should be most of it) 20:30 - 21 :30 1.00 FISH P DECOMP CBU 4.3/630 with 300 bbls and had 3 bblloss 21 :30 - 22:00 0.50 FISH P DECOMP LD circ head and two pup jts. Change to shorter bails 22:00 - 00:00 2.00 FISH P DECOMP POOH standing back DP with minor drag on first 5 stds. Found connections very tite-used tongs to break out 5/7/2005 00:00 - 03:20 3.33 FISH P DECOMP Continue POOH w/ fish. OS swallowed top of stub to within 2' of top of clamp 03:20 - 03:50 0.50 FISH P DECOMP LD fishing tools 03:50 - 04:20 0.50 PULL P DECOMP RU tubing tools. Splice cable 04:20 - 09:30 5.17 PULL P DECOMP Wt of fish is 10k. Resume LD used tubing while spooling cable. A lot of scale on tbg exterior. Use dog collar on each joint. Note three holes in at approximately 7485' or jt #170. Holes appear to be from external corrosion. Will recover and save this section of tbg. 64 jts of 2-7/8" recovered. This leaves 14 jts, GLM, 2 jts, then ESP pump assembly. Tbg parted 1.5' above a collar with a LaSalle clamp. The pipe wall is corroded and the fish stub has an id of 2.435'. 32' of ESP cable is above top of fish. Top of fish: 8492' ELMD. 09:30 - 11 :00 1.50 PULL P DECOMP Unload tbg from pipe shed. Discuss plan forward with town. 11 :00 - 12:00 1.00 FISH P DECOMP MU rope spear assembly BHA 12:00 - 20:30 8.50 FISH P DECOMP RIH with spear on PH6 out of derrick. Clean pipe threads I Printed: 5/23/2005 1 :37:54 PM ) ) Operations Summary Legal Well Name: 3M-13 Common Well Name: 3M-13 Spud Date: 4/30/2005 Event Name: WORKOVER Start: 4/30/2005 End: 5/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 5/22/2005 Rig Name: NORDIC 2 Rig Number: From..; To NPT Phase Description 6f Operations 5/7/2005 12:00 - 20:30 8.50 FISH P DECOMP before make up. 20:30 - 22:30 2.00 FISH P DECOMP Pick up 71 singles while performing extensive thread cleaning and rattleing 22:30 - 22:45 0.25 FISH P DECOMP MU circ head on jt 270 22:45 - 23:45 1.00 FISH P DECOMP Circ 3.0/550 66k up, 44k dn RIH while rotate string using hand slips looking for TOF. PU jt 271 and find TOF @ 8469' DPM. PUH w/ 72k and lost wt back to 66k after 5'. Assume we got some cable 23:45 - 00:00 0.25 FISH P DECOMP CBU 4.0/620 5/8/2005 00:00 - 01 :00 1.00 FISH P DECOMP CBU 4.0/630 w/ no loss 01 :00 - 01: 15 0.25 FISH P DECOMP LD circ equipment and first jt 01 :15 - 02:00 0.75 FISH P DECOMP Start PUH with first stand and dragging up to 100k, then wt broke back to 66k. Swabbing bad, having to pull slow-wet string too. Pull 3 stds 02:00 - 03:45 1.75 FISH P DECOMP RU to circ. Start pumping with pump #2 lined up thru 'out' MM thru closed annular. Getting only 1/2 return rate, but determine that it is pump related. Swap to pump #1 3.0/380 while repair pump #2 (find a valve stuck from EP lube). CBU 3.0/380 wI no loss, constant density and no debris noted over shaker. RD pump equipment 03:45 - 06:00 2.25 FISH P DECOMP Resume TOH wI no swabbing and dry pipe 06:00 - 11 :00 5.00 FISH P DECOMP Crew change. Continue to POOH dry. 95 stands as of 0900. 11 :00 - 12:00 1.00 FISH P DECOMP At surface. Stand back BHA. No recovery of ESP cable. 12:00 - 14:30 2.50 BOPSUF P DECOMP Install 2nd set of variable rams in lower cavity of upper double gate rams (3-1/2" x 2-3/8") 14:30 - 00:00 9.50 BOPSUPP DECOMP Weekly test of BOP equipment. Test witness waived by J. Crisp. Perform extensive greasing of valves 2 hrs NPT 5/9/2005 00:00 - 00:30 0.50 BOPSUPP DECOMP Fin BOPE test 00:30 - 01 :30 1.00 FISH P DECOMP Load fishing tools to floor 01 :30 - 03:00 1.50 FISH P DECOMP MU fishing BHA #3 (new spear, jars and DC's to fish ESP cable) 03:00 - 07:00 4.00 FISH P DECOMP TIH wI DP. 76 stands in hole as of 0700. Brine flowing back through DP. Suspect out of balance. 07:00 - 07:45 0.75 FISH P DECOMP Circulate bottoms up the long way. 872 psi pump pressure at 5 bpm inlout. 07:45 - 09:45 2.00 FISH P DECOMP Continue to RIH. Pipe displacement slowly increasing above calculated. At 123 stds in hole, "extra" 10 bbls gained in pits. 09:45 - 12:00 2.25 KILL P DECOMP Shut in well and RU to circulate. Monitor out density (11.8+ to 11.9+). Weight up rtns to 12.0 ppg while circulating at 570 psi @ 3.0 bpm. Circulate 310 bbls. 12.0 in/out. 12:00 - 12:15 0.25 KILL P DECOMP Shut down pump. Open well. Monitor for flow. Well stable. 12:15 - 14:30 2.25 FISH P DECOMP Continue to RIH. Begin to PU singles when close to fish. 60k# up, 40 k# dn wt. Take wt at 8472', three feet deeper than previous run. Set 5k# dn. Set slips. Rotate pipe 6 turns and release. Work pipe. Repeat this process approx ten times. Eventually showed high rotary torque, and making no additional footage. PU and see 5-8k# overpull, then 60k# up wt. 14:30 - 15:45 1.25 FISH P DECOMP Circulate btms up. 15:45 - 23:00 7.25 FISH P DECOMP POOH with rope spear assembly. Well stable. Note several wt bobbles, may indicate wire fish. Swabbing at normal pulling speed, so slow trip OOH Printed: 5/23/2005 1 :37:54 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-13 3M-13 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/30/2005 Rig Release: 5/22/2005 Rig Number: Spud Date: 4/30/2005 End: 5/22/2005 Code DECOMP Stand back BHA. Recovered approx 10' of ESP cable which was wound around the top 1/3 of spear. The end at the bottom had parted at a kink in the line at a Y in the spear (indicating there was more attached at one time) Discuss plan ahead-still have 22' of ESP cable above top of tubing. Clean up spear and floor tools MU same spear and BHA (BHA #4) on one stand of DP CDL (50') TIH w/ DP TL mtg and crew change. Continue to RIH with rope spear on PH6. MU singles from 8420'. Circulate while RIH. Tag fish I take weight at 8472'. Set dn 5k#. Rotate 6 turns. Repeat this process unitl worked down to 8483'. Cannot make additional ftg, and possibly getting close to top of tbg fish. PU. 6k# overpull, then 3k# drag while PUH. Circulate btms up. Monitor returns out weight closely. 1180 psi @ 4.5 bpm. LD singles. POOH slowly to avoid swabbing. Monitor hole fill closely. Recovered 14' of ESP cable. This leaves aprroximately 8' in hole. Discuss options with town crew. Decide to proceed with 5-7/8" OD x 4-3/4" ID washover shoe wI internal catch wires and 1 jt of washpipe. With this attempt to washover remaining ESP cable and cut cable clamp and ESP cable below tbg collar clearing the way for follow-up overshot run. Review plan forward with crews. LD BHA #4. Install wear bushing. PU BHA #5 RIH Continue RIH with washover assembly to 8363'. PJSM review procedure for M/U kelly. Pick up swivel and make up kelly and pressure test RIH w/3 stds and LD a single. MU kelly Start circ 3.0/500 86k up, 58k dn, 70k rot @ 35 rpm/200 amps. Wash down to TOF and tag at 8482' DPM (8492' ELMD) Burnover TOF slowly. Pump pressure slowly increased due to ESP cable working its way into washover pipe so reduced rate to 2.0 bpm. Recover small pieces of cable rubber and wires over shaker 8486' 2k wob, 35 rpm/200 amps 2.0/800 Pump second hi vis sweep (20 bbl). Slow progress, so assume this is the clamp/collar 8486.2' 4k wob, 55 rpm/225 amps 2.0/1030 Pick up to check paramenters 2.0/275, start 20 bbl sweep. A few more pickups and made 5' of progress to 8491'. Continue milling f/ 8491' to 8493' 2.0bpm and varying pump pressures 550-950psi. Higher pressures would also hydraulic string wt off fish. Made several repeated passes over this area without further progress. DECOMP Continued milling f/8493' wo pump and almost imediately started making progess. String torqued up several times. 5/9/2005 23:00 - 00:00 1.00 FISH P 5/1 0/2005 00:00 - 00:45 0.75 FISH P DECOMP 00:45 - 01 :45 1.00 FISH P DECOMP 01 :45 - 03:00 1.25 FISH P DECOMP 03:00 - 06:00 3.00 FISH P DECOMP 06:00 - 08:00 2.00 FISH P DECOMP 08:00 - 09:30 1.50 FISH P DECOMP 09:30 - 10:45 1.25 FISH P DECOMP 10:45 - 18:30 7.75 FISH P DECOMP 18:30 - 19:00 0.50 FISH P DECOMP 19:00 - 20:30 1.50 FISH P DECOMP 20:30 - 20:40 0.17 FISH P DECOMP 20:40-21:15 0.58 FISH P DECOMP 21:15-23:00 1.75 FISH P DECOMP 23:00 - 00:00 1.00 FISH P DECOMP 5/11/2005 00:00 - 04:30 4.50 FISH DECOMP 04:30 - 04:45 0.25 FISH DECOMP 04:45 - 11 :00 6.25 FISH DECOMP 11 :00 - 11 :30 0.50 FISH DECOMP 11:30-12:15 0.75 FISH DECOMP 12:15 - 15:00 2.75 FISH DECOMP 15:00 - 16:30 1.50 FISH DECOMP 16:30 - 18:00 1.50 FISH DECOMP 18:00 - 21 :00 3.00 FISH DECOMP 21 :00 - 23:45 2.75 FISH I I I Printed: 5/23/2005 1 :37:54 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Operations Summary Report 3M-13 3M-13 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/30/2005 Rig Release: 5/22/2005 Rig Number: Spud Date: 4/30/2005 End: 5/22/2005 5/11/2005 21 :00 - 23:45 2.75 FISH DECaMP Started charge pump only on hole to move minimal fluids past mill. Milled over LaSalle clamp at 8494' and cleaned out to 8500.3'. Reciprocated from 8500' to above stub 4 times and was clean both directions 23:45 - 00:00 0.25 FISH DECaMP Circulate. Break off kelly. Drop ball rod and open Circ Sub. 5/12/2005 00:00 - 01 :50 1.83 FISH P DECaMP Circulate several hi-vis pills at 5-6bpm. 01 :50 - 05:45 3.92 FISH P DECaMP TOH. 05:45 - 06:20 0.58 FISH P DECOMP Stand back collars 06:20 - 08:15 1.92 FISH P DECaMP LD fishing BHA. Found small pieces of rubber, wire and production solids in boot baskets. Shoe was worn smooth on bottom, but had good cutrite inside. Wire catchers were very frayed/missing and mashed against inside surface. Found 2-1/2' packed wad of ESP cable 13.5' above shoe in washpipe with clear indention mark of top of tubing stub 08:15 - 08:30 0.25 FISH P DECOMP Safety mtg re: MU BHA 08:30 - 09:30 1.00 FISH P DECOMP MU overshot fishing BHA/drift w/ 2.40" (BHA #6) 09:30 - 14:30 5.00 FISH P DECaMP RIH w/ DP 14:30 - 15:40 1.17 FISH P DECaMP Unintentionally latched fish while planning to just tag. Rotate to right and release. Space out with a 17' pup below one full joint and with a 6' pup at surface. RU circ head 15:40 - 16:45 1.08 FISH P DECaMP CBU above TOF 4.1/800 12.0 ppg thruout. Meanwhile MI RU Halliburton slickline and bring tools to floor. Slack off and reset overshot and pull 10k to verify' 16:45 - 17:00 0.25 FISH P DECaMP Safety mtg re: RU slickliners 17:00 - 18:00 1.00 FISH P DECaMP RU Halliburton slickline to TIW valve in DP with XO to pump-in sub and WL BOP's. RU WL sheaves 18:00 - 00:00 6.00 FISH P DECaMP RIH w/ 2-1/4" tapered drift. Tagged at 8494' (top of tbg stub) unable to work through. POH. RIH w/ 2.30" LIB. Impressions revealed some junk on top of tbg. RIH w/ pump bailer. Recovered small amount of scale. 5/13/2005 00:00 - 02:10 2.17 FISH P DECOMP Make 2nd run with pump bailer same results recovered small amount of scale. No marks on end of mule shoe. RIH with 3 prong spear without any junk recovery. RD slickline. 02: 10 - 06:00 3.83 FISH P DECaMP Circulate at 2bpm 4-700 psi holding 1 Ok over string wt. of 70k for 40 min. Work pipe between 40k-100k for 30min pump pressure varying 400-1900psi. Circ at 2bpm 2075psi for 20min. increase 3bpm 21 OOpsi getting scale and sand back. CBU and continue working pipe. 06:00 - 07:45 1.75 FISH P DECaMP Continue to circ 3.0 @ 1600 psi and work pipe every 30 min to 30k over w/ no movement and no additional solids recovered 07:45 - 10:30 2.75 FISH P DECaMP Circ at 2.0/700 psi, then 1.0/150 psi while discuss w/ Asset various options Meanwhile, fin RDMO slickline unit 10:30 - 11 :45 1.25 FISH P DECaMP Decision made to terminate fishing soon, but maximize recovery of remainer of tubing Increase max pull to 65k over string wt while circ at 2-3 bpm. Perform approximately 30 cycles between max up and down wts w/ various techniques including pump off. It's obvious that the OS packoff is washed out and there is absolutely no stretch in fish. We will have a better chance if circ'ing thru fish while I DECaMP jarring at fish 11 :45 - 12:00 0.25 FISH P Prep to release from OS and notice well is flowing from FL. Assume slight imbalance Printed: 5/23/2005 1 :37:54 PM ) ) Page 10 of 15 BP AMERICA Operations Summary Report Legal Well Name: 3M-13 Common Well Name: 3M-13 Spud Date: 4/30/2005 Event Name: WORKOVER Start: 4/30/2005 End: 5/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 5/22/2005 Rig Name: NORDIC 2 Rig Number: Hö LJrs Task Code NPT 5/13/2005 12:00 - 13:30 1.50 FISH P DECOMP CBU+ w/ 300 bbls @ 4.2/1300 and measure 12.1 minus ppg 13:30 - 13:50 0.33 FISH P DECOMP Release from OS by turning to right. LD 6' pup, full jt and 17' pup 13:50 - 14:20 0.50 KILL P DECOMP Monitor FL and had a pencil stream. DP flowing a pencil stream. Discuss. CPF-3 has not added any injectors so must have loosened something up downhole 14:20 - 17:30 3.17 KILL P DECOMP Circulate thru 'out' MM (annular closed) 2.0/220 while weight up to 12.3 ppg using pit 4 and 5 17:30 - 18:00 0.50 KILL P DECOMP Circ and condition to even out system to 12.3 ppg (satuation point) 18:30 - 19:35 1.08 KILL N RREP DECOMP Repair air regulators on drillers console. 19:35 - 20:00 0.42 KILL P DECOMP Circulate at 6bpm to even out mud system ppg. 20:00 - 23:30 3.50 FISH P DECOMP TOH 23:30 - 00:00 0.50 FISH P DECOMP L/D BHA #6 5/14/2005 00:00 - 01 :30 1.50 FISH P DECOMP PU BHA #7 01 :30 - 04:45 3.25 FISH P DECOMP TIH 04:45 - 05:30 0.75 FISH N RREP .DECOMP Boot on riser is leaking. Blowdown riser and replace boot. 05;30 - 07:20 1.83 FISH P DECOMP Continue to TIH. 07:20 - 07:45 0.42 FISH P DECOMP PU kelly and wash over fish to 8498.5' ELMD. Engage 20' in on kelly 82k up, 60k dn 07:45 - 09:15 1.50 FISH P DECOMP Circ 2.0/270 for 15 min then work pipe to 20k over and bump down in attempt to loosen up debris while circ 09:15 - 12:15 3.00 FISH P DECOMP Begin lite jar action up at 20k over while continue to circ 2.0/280 and bump down occasionally. Gradually increase overpulls. First btms up 12.0 ppg with 12.2+ ppg in 12:15 - 13:15 1.00 FISH P DECaMP Work pipe from 50k over while circ at 2.0/230 with occasional bump down. No movement, very tite 13:15 - 14:35 1.33 FISH P DECOMP At 165k, or 83k over, jars hit. Slacked off and lost 2' of hole. PUH dragging at 150k while jars went off. Stop w/ tool joint at RT. CBU 4.1/1220 w/ 300 bbls 14:35 - 15:45 1.17 FISH P DECOMP Getting sand, scale, crude and production solids back. Incr rate 5.2/1800. Move pipe in several 15' cycles and appears to move clean at 130k, but some packing off on down stroke. Mix and pump a viscous 40 bbl pill 15:45 - 18:00 2.25 FISH P DECOMP Displace pill w/ one pump 3.0/750 while work on oiler for pump #2. Resume pumping wi 2 pumps at 4.0/1025. Plugged shaker screens w/ solids from pill and went overboard to cuttings tank. Recip pipe occasionally and string wts and circ pressure are coming down with circ'ing and moving pipe. Circ until returns were clean (of solids). Circulating at 4bpm 875psi. Brine wt down to 12.1 ppg. 18:00 - 19:30 1.50 FISH P DECOMP Circulate and increase brine wt to 12.2+ppg. 19:30 - 00:00 4.50 FISH P DECOMP (string up wt w/kelly & wolfish 87k) UD 4 jts with kelly. Up wt 90-135k. Rathole kelly. Pull4stds w/overpulls. Pulling easily 7 stds out at 82k w/occassional overpulls. Pulling clean after 9 stds out. 5/15/2005 00:00 - 02: 15 2.25 FISH P DECOMP Continue TOH to DC's. Well burped from tbg 1 gal. Stabbed TIW. 02:15 - 02:45 0.50 FISH P DECaMP Rig up and circulate well 15min. Monitor well dead. Circulate another 15min. RD circ line. 02:45 - 03: 15 0.50 FISH P DECOMP Monitor well with TIW stabbed while RU to setback DC's and handle fishing tools. MU another TIW valve for 2-7/8" fish if needed and dress air slips for 2-7/8" tbg. Printed: 5/23/2005 1 :37:54 PM ) ) Legal Well Name: 3M-13 Common Well Name: 3M-13 Spud Date: 4/30/2005 Event Name: WORKOVER Start: 4/30/2005 End: 5/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 5/22/2005 Rig Name: NORDIC 2 Rig Number: Task COdé NPT Phasé 5/15/2005 03:15 - 04:15 1.00 FISH P DECOMP Stand back DC's LID fishing tools. Breakout overshot from fish. Weight indicates the complete fish is on. Only 6" of tbg above collar. Below collar is pitted with holes. Lucky! Replace collar. PU on 1 st jt tbg and ESP cable was twisted around in knot 12' below collar (where we earlier stopped milling). Again lucky break! Fish: 14jts 2-7/8" tbg, 1 GLM, 2jt tbg, ESP motor 04:15 - 06:15 2.00 FISH P DECOMP LID 13 jt of tubing while cutting ESP cable in full jt lengths (due to kelly and DP in the way of using spooler) 06: 15 - 06:30 0.25 FISH P DECOMP Safety mtg re: trapped pressure/BHA LD 06:30 - 10:00 3.50 FISH P DECOMP Pull full jt and GLM wI lower pup above table. Didn't need to hot tap-corroded thru at btm of pup and oozing fluid/solids. LD same using mousehole after removing solids. Hot tap two full jts and could only remove solids from top one. LD pump which had very deep external pitting. LD 4.30' of top seal assy (tandem) to motor which was corrodedleroded to expose seals. Fine threads to the lower part of the top seal assy had pulled out due to thread corrosion. Left approx 3' of lower part of top seal section, the 6.5' lower seal section and the 23' Series 562 motor in the hole (OD varies from 5.125" to 6.0") wI flat cable. Can't overshot due to OD's and have only a 2" ID and 3-1/2" depth to spear (which is also blocked by a 1/2" OD rod) 10:00 - 13:30 3.50 FISH P DECOMP Discuss wI Asset. Decide to forego additional fishing based on low probability of recovery. Will proceed with completion Meanwhile fin LD fish, fishing tools and load out. Test BOPE choke manifold. NORM test used completion 13:30 - 15:30 2.00 FISH P DECOMP RIH wI DC's. POOH LDDC's and load out 15:30 - 16:00 0.50 BOPSUF P DECOMP Pull wear bushing/set test plug 16:00 - 18:45 2.75 BOPSUPP DECOMP Weekly BOPE test. Witness waived by AOGCC 18:45 - 19:00 0.25 RIGD P DECOMP Halt testing BOP's. Conduct PJSM with crews and crane operator to discuss steps in dismantling ESP spooler and removal from rig floor. 19:00 - 22:30 3.50 BOPSUPP DECOMP RD Baker ESP spooler and remove from rig. Same time finish up testing BOP equipment. Pull test plug. Lost both O-ring seals off of test plug. Filled stack and retreived 2/3rds of one of them. Circulate hole from kill line but couldn't see the remainder of seals. 22:30 - 23:30 1.00 EVAL P OTHCMP Cut and slip 50' drilling line 23:30 - 23:45 0.25 EVAL P OTHCMP PJSM review BHA handling and TIH procedures. Monitoring well for correct displacement. 23:45 - 00:00 0.25 EVAL P OTHCMP P/U BHA #8. Check for seals again. 5/16/2005 00:00 - 01 :50 1.83 EVAL P OTHCMP TIH wI BOT test packer. Stopped at 1850'. Work pipe but no help. 01 :50 - 03:20 1.50 EVAL N DPRB OTHCMP TOH. Found 12" of ESP cable armor wrapped in packer. Packer also thickly covered with heavy oil sludge. Clean-up packer with steam. Sent back to shop for inspection. 03:20 - 04:15 0.92 EVAL N DPRB OTHCMP Wait for tools. 04:15 - 07:15 3.00 EVAL N DPRB OTHCMP P/U casing scraper and RIH wI 35 stds w/ no wt loss 07:15 - 08:10 0.92 EVAL N DPRB OTHCMP Park at 2192' and reverse btms up 2.65/120 until clean 08:10 - 09:15 1.08 EVAL N DPRB OTHCMP RIH wI 35 stds wI wt loss at 4243', PUH, clean 09:15 - 10:30 1.25 EVAL N DPRB OTHCMP Park at 4378' and reverse btms up 2.5/170 until clean 10:30 - 11 :30 1.00 EVAL N DPRB OTHCMP RIH w/35 stds w/ no wt loss 11 :30 - 13:30 2.00 EVAL N DPRB OTHCMP Park at 6562' and reverse btms up 2.55/260 until clean Printed: 5/23/2005 1 :37:54 PM ) ) RIH wI 28 stds wI no wt loss Park at 8312' and reverse btms up 2.5/310 until clean RIH wI 20 singles wI no wt loss until last jt and was mushy Park at 8936' and reverse btms up 2.55/370 PVT 228 RIH to 8998'. Mushy on last 6' in. Reverse circ but pressures exceding 500psi. PU 20' and start over. Still had to clear the long way for 112 bbl. Reverse make connections and working down slowly to 9000'. Returns showing abundant sand. At 9000' running into well packed fill. DPRB OTHCMP Work pipe down in stages to 9014' and finally packing off drill string. Work pipe and clear. Try again with same results. Clear string. Need to do something different or could possibly pack-off string and result in a wet trip. Call town and review problem. In agreement to call 9014' good enough for now and proceed with testing casing. TOH Steam clean scraper and UD. Clean rig floor. Prep to run BOT test packer. MU BOT RBP on BOTtest packer RIH wI DP while checking torque on middle connections (test packer sets to left) Park at 800'. Close upper VBR's. Ensure DP is full. Pressure test 7" casing against fill on bottom Time Bbls Test P Final Test P Duration (min) 0815 0.5 500 345 5 0825 0.8 620 465 5 0836 1.1 885 767 10 0848 1 .4 1 040 970 5 0855 1.7 1220 980 5 Broke down around 1200 psi-no injectivity, just slow bleed off Recheck surface lines, ok. Bleed off press, open rams OTHCMP Resume TIH wI RBP and test packer to find leak. Set down, overpull @ 2328'. Rotate 2 turns to right and RIH, clean OTHCMP Resume TIH OTHCMP Set RBP at 8999 ft. PU 30 ft and closed Variables. PT annulus to 500 psi, ok, 1000 psi, bleed off and was unable to get 1200 psi. In 5 min pressure bleed down to 750 psi. Set test pkr at 8958' and tested between BP and pkr to 1500psi - held good. Release pkr and retest annulus and bleed down as before. Setback kelly. TOH 10 stds. PU kelly set pkr at 8312' test void between pkr/BP not holding. Test annulus to 1450psi bleed down to 1400psi in 15min. Considering this a good test. Setback kelly. RIH 5 stds to 8626'. Test void - failed RIH to following depths and test void: 8651' test failed. Seeing communications to annulus. 8688' test failed. Same communications. 8718' test failed. Same communications. Pulled 4stds to 8501'. Test annulus held at 1525 psi. MU singles and test as follows: 8532' test annulus to 1525 psi 8563' test annulus to 1525 psi 8604' test annulus to 1530 psi Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-13 3M-13 WORKOVER NORDIC CALISTA NORDIC 2 Date Frorn .. To Ho u rs Task Code ··NPT Phase 5/16/2005 13:30-14:15 0.75 EVAL N DPRB OTHCMP 14:15 - 16:30 2.25 EVAL N DPRB OTHCMP 16:30 - 17:00 0.50 EVAL N DPRB OTHCMP 17:00 - 18:00 1.00 EVAL N DPRB OTHCMP 18:00 - 18:30 0.50 EV AL N DPRB OTHCMP 18:30 - 22:30 4.00 EVAL N DPRB OTHCMP 22:30 - 00:00 1.50 EVAL N 5/17/2005 00:00 - 00:30 0.50 EVAL N DPRB OTHCMP 00:30 - 05:00 4.50 EVAL N DPRB OTHCMP 05:00 - 06:00 1.00 EVAL N DPRB OTHCMP 06:00 - 07:00 1.00 EVAL P OTHCMP 07:00 - 08:10 1.17 EVAL P OTHCMP 08:10 - 09:20 1.17 EVAL P OTHCMP 09:20 - 11 :00 1.67 EVAL P 11 :00 - 16:00 16:00 - 18:30 5.00 EV AL P 2.50 EV AL P 18:30 - 19:30 1.00 EVAL P OTHCMP 19:30 - 21 :00 1.50 EVAL P OTHCMP 21 :00 - 00:00 3.00 EVAL P OTHCMP Start: 4/30/2005 Rig Release: 5/22/2005 Rig Number: Spud Date: 4/30/2005 End: 5/22/2005 Description of Operations Printed: 5/23/2005 1 :37:54 PM ') ) BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-13 3M-13 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/30/2005 Rig Release: 5/22/2005 Rig Number: Spud Date: 4/30/2005 End: 5/22/2005 Code OTHCMP Continue test casing. 8604' test annulus to 1500psi 8635' test annulus to 1540psi 8656' test failed f/1550psi to 1200psi in 5 min Based on test results calling top of leak in 7" somewhere between 8635' - 8656' OTHCMP TOH Notified SWS for USIT log. May be late in arriving. Conflict with Doyon #14. SWS sent our truck to them because of a mechanical problem with the truck they were using. LD Packer, recovered element, LD same. RU to run USIT log with Schlumberger Housekeeping while waiting on SLB Eline, behine Nabors 4ES rig move SLB Eline arrived at 1200 hrs, RU to run US IT log from 8,980 ft to 5,500 ft PJSM on Eline HZARDS RU SLB USIT tool in shooting nipple and lubricator RIH USIT tool Logging up from 8,970 ft at 1,500 fph. Log to 5450'. No indications of holes. RD loggers. PJSM: review TIH hazards, trip sheets. PU RBP retrieving tool and RIH RIH to 8933' PU kelly. Circ above RBP. Close annular and test 7" csg 1 last time. SICP 1250psi bleed down to 725psi in 5min. MU single stab on RBP and unseat. CBU Stand back kelly. TOH LD BOT RBP and load out. PU Rev Cir basket BHA and make up RIH Tagged at 9,019 ft RKB with 143 std plus 22 ft. Stood stand back and make up kelly Circulate BU Loaded 2 jts in pipe shed, 292 good jts in pipe shed Qp = 4 bpm Pp = 1263 psi Va - 237 bbl Pumped 230 bbl's, dropped 7/8" ball and pumped on seat Increased Qp = 5.0 bpm at 1700 psi Mixed up 35 bbl pill of 12.3 ppg brine and 1 drum SafeSurf W solvent to pump around to clean up DP on final circulation OTHCMP Washing to bottom at Qp = 5bpm and Pp= 1589 psi Cleanout to 9032'. With 5k WOB unable to go further. Grind on bottom for 15 min without progress. OTHCMP Pump 35 bbl pill of 12.3 ppg brine w/ 1 drum SafeSurf solvent followed by normal brine around to surface. OTHCMP TOH LDDP OTHCMP UD drill pipe. OTHCMP UD and clean BHA RUNCMP PJSM on LD kelly and shuck. LD same and store outside 5/18/2005 00:00 - 02:30 2.50 EV AL P 02:30 - 07: 15 4.75 EVAL P 07:15 - 08:00 0.75 EVAL P OTHCMP 08:00 - 12:00 4.00 EVAL N WAIT OTHCMP 12:00 - 14:45 2.75 EVAL P OTHCMP 14:45 - 16:30 1.75 EVAL P OTHCMP 16:30 - 21 :15 4.75 EVAL P OTHCMP 21:15-21:25 0.17 EVAL P OTHCMP 21 :25 - 00:00 2.58 EVAL P OTHCMP 5/19/2005 00:00 - 02:30 2.50 EV AL P OTHCMP 02:30 - 03:00 0.50 EVAL P OTHCMP 03:00 - 04:25 1.42 EVAL P OTHCMP 04:25 - 09:00 4.58 EVAL P OTHCMP 09:00 - 10:45 1.75 CONDHLP OTHCMP 10:45 - 15:15 4.50 CONDHLP OTHCMP 15:15 - 16:45 1.50 CONDHL P OTHCMP 16:45 - 18:45 2.00 CONDHL P 18:45 - 20:00 1.25 CONDHL P 20:00 - 00:00 4.00 CONDHL P 5/20/2005 00:00 - 05:00 5.00 CONDHL P 05:00 - 06:00 1.00 CONDHL P 06:00 - 10:00 4.00 RUNCOr 10:00 - 19:30 9.50 RUNCOrvP RUNCMP Loading pipe shed with 3-1/2" 9.3#/ft L-80 tubing Drifting the last47 jts and hanger wI PJ's to 2.92" and Printed: 5/23/2005 1 :37:54 PM ) ) BP AMERICA Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-13 3M-13 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/30/2005 Rig Release: 5/22/2005 Rig Number: Spud Date: 4/30/2005 End: 5/22/2005 5/20/2005 10:00 - 19:30 9.50 RUNCOMP RUNCMP everything else will be drift 2.875" 19:30 - 19:45 0.25 RUNCOMP RUNCMP PJSM review harzards and tally for running 3-1/2" completion string. 19:45 - 00:00 4.25 RUNCOMP RUNCMP Run 3-1/2" L-80 9.3# EUE 8rd AB Mod completion string. 5/21/2005 00:00 - 00:00 24.00 RUNCOMP RUNCMP Continue running 3-1/2" completion tbg. 06:00 - 06:45 0.75 RUNCOMP RUNCMP Crew change and rig service 06:45 - 10:00 3.25 RUNCOMP RUNCMP Continue running 3-1/2" completion tbg. RIH to 9017 ft, RU to cir 10:00 - 12:20 2.33 RUNCOMP RUNCMP Unable to rev cir, Pa increased to 1300 psi, SD. released P and RU to cir down tubing. Cir down tubing at 1.6 bpm and 250 psi.Mixing brine / corrosion inhibitor 12:20 - 13:30 1.17 RUNCOMP RUNCMP Dropped ball / rod,waited 20 minutes. Pressured up to 1,200 psi and FHL packer set. Increased pressure to 2,000 psi and the Seal Assy sheared from PBR. Lost string wtr, Released tubing pressure and recovered string wt. The shear release force was 25k instead of 40k. FHL packer set with 15k set down wt. Marked tubing and PU out of PBR. LD 1 jts (285) of . tubing. Well out of fluid balance. Stabbed floor valve. 13:30 - 16:00 2.50 RUNCOMP RUNCMP Circulating well. Pumped 40 bbl12.3ppg brine down tubing, SD well balanced. Pulled 2 jts, PU 3 space out PJ, 1 full joint and hanger. RIH and landed tubing, RILDS. PT surface lines to 4500 psi OK. Pressure up on Premier Packer to 4500 psi and set. 16:00 - 18:00 2.00 RUNCOMP RUNCMP RU to PT and shear valve in GLM #3 at 6,697 ft. Pressured up again to 4,500 psi on Preimer Packer and decreased to 2,500 psi. Charted for 15 minutes. OK. Released tubing pressure to 1,500 psi and increased IA pressure to 2,500 psi, charted for 15 min. Released P on tubing and GLM # 3 sheared and communicated 18:00 - 19:00 1.00 RUNCOMP RUNCMP Crew change and remove landing jt and installed BPV 19:00 - 22:00 3.00 BOPSUPP POST RD BOP riser. RU SWS Coil Otis lubricator. Empty and do a quick clean on mud tanks. Take on 290 bbls of 140 deg water mix wI 1 drum of Safe-Surf W 22:00 - 23:00 1.00 BOPSURP POST Pressure test 7" Otis lubricator. Failed. Same time circulate and clean mud tanks of oily sludge. 23:00 - 00:00 1.00 BOPSURN POST Replace o-ring on 1 st section. Retest failed. 5/22/2005 00:00 - 01 :30 1.50 BOPSURN POST Replace o-ring a second time- failed. Replace scarred lower lubricator section just above annular. Retest ok 01 :30 - 03:00 1.50 RIGD N POST Stab 2" coil to injector. 03:00 - 04: 15 1.25 RIGD N POST MU nozzle. Stab injector to well. Close blind rams. PT lubricatorlinjector to 2000psi. Same time RU N2 truck. 04:15 - 04:30 0.25 RIGD N POST PJSM review N2 blowdown procedures. 04:30 - 05:30 1.00 RIGD N POST Blowdown diesel from reel and same time jet inside of BOP stack to remove sludge and fishing debris 05:30 - 06:00 0.50 RIGD N POST RD N2 and setback injector. 06:00 - 15:00 9.00 RIGD N POST Pulled CT back to reel house. Pull doors on BOP, inspect. BOP body completly full of EP Lube and CaCo cleaned. Pulled suctions and filters on MP1 & 2 and they were full of EP-Iube. Install CTD BOP rams and function test. ND BOPs and make 7.00 I WHSUR N ready to install tree 15:00 - 22:00 POST Clean hanger, Jack rig up to place tree adaptor in cellar. Install on tree and NU same. Damaged seals. ND replace seals. With I Printed: 5/23/2005 1 :37:54 PM ') ) BP AMERICA Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-13 3M-13 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/30/2005 Rig Release: 5/22/2005 Rig Number: Spud Date: 4/30/2005 End: 5/22/2005 Code NPT 5/22/2005 15:00 - 22:00 7.00 WHSUR N POST lubricator pull BPV. Set test plug. Test tree to 5000psi. Pull test plug set BPV. Install tree cap and test to 5000psi. Released rig at 2200hrs 5-22-2005 Printed: 5/23/2005 1 :37:54 PM ) ) Well: Field: API: Permit: Kuparuk 3M-13, Rig Workover Kuparuk River Unit 50-029-21720-00-00 187 -040 Accept: Spud: Release: Rig: 04/30/05 N/A OS/22/05 Nordic #2 POST RIG WORK OS/27/05 PULLED DCR AT 6697' RKB. DISPLACED BRINE W/ 200 BBL DSL. SET DV AT 6697' AND MIT'D lA, GOOD. PULLED BALL & ROD AT 8988' WLM, PULLED DV AT 6697'. OS/28/05 PULLED DVS 5923' AND 3769' RKB. SET GLVS AT 3769' AND 5923' RKB, OV AT 6697' RKB. ATTEMPTED PULL RHC PLUG BODY, ENCOUNTERED THICK MUD/FILL - 33' ABOVE LOCK. OS/29/05 BAILED MUD / FILL FROM 8955' TO 8993' WLM. TURNED WELL OVER TO OPNS. TO UNLOAD THRU RHC BODY. 05/30/05 ATTEMPTED PULL RHC PLUG, ENCOUNTERED FILL. 05/31/05 ATTEMPT TO CLEAN DOWN TO RHC PLUG. TUBING PRESSURED UP. IA PRESSURED UP. TUBING X IA LEAK. REPLACED OV AND GLVS WITH DV'S. TESTED IA TO 1900 PSI. SEEMED TO BE HOLDING AT 1610 PSI BUT TEST INCONCLUSIVE. DSO WILL MONITOR IA PRESSURE OVERNIGHT. . 06/01/05 MADE MUL TPLE BAILER RUNS. RECOVERED SMALL AMOUNT OF GRIT SUSPENDED IN THICK FLUID. FOUND METAL MARKS ON LAST 1.75" DD BAILER RUN. IA IS HOLDING STEADY REGARDLESS OF CHANGE IN TUBING PRESSURE (0 PSI TO 2000 PSI). 06/02105 BAIL FILL OFF RHC PLUG. 06/03/05 PULLED RHC PLUG BODY. PULLED DV'S. SET LGLV'S 3769' AND 5923' RKB. SET OGLV 6697' RKB. PRESSURE UP ON TUBING TO VERIFY THAT GL DESIGN IS SET. TEST GOOD. READY FOR PRODUCTION. ) ) KRU 3M-13 ¡.·...ç·Ø:ñ~Ç·9F'b.Ullipl5,·..·,,'~.ø,~~'ijç'· 3M-13 TUBING (0-9017, OD:3.500, ID:2.992) SEAL (9032-9046, OD:2.441 ) MOTOR (9046-9050, OD:2.441) TUBING (9159-9206, OD:2.875. ID:2.441) Perf (9269-9283) Perf (9283-9303) 1111[i ~ 1']11111 .. .. ~ I·i"""'" ,...... ..., .; ',' ::,': l,: .:\: 1'0,' .',:' ~ ' .~,:":~,: \~ r .:h):II':':'('::': i'r>""".,/,'I:":-;' 'i,:,'",,,",,j ,'"',',1,,,,1 API: 500292172000 SSSV Type: NIPPLE Well Type: PROD Orlg 5/31/1987 Completion: Last W/O: 5/22/2005 Ref Log Date: TD: 9734 ftKB Max Hole 57 deg @ 2800 Angle: Angle (â) TS: 44 deg (â) 9267 Angle @ TD: 43 deg @ 9734 Annular Fluid: Reference Log: Last Tag: 9004 Last Tag Date: 6/3/2000 Rev Reason: WORKOVER Last Update: 5/26/2005 Casina Strina - ALL STRINGS Description Size CONDUCTOR 16.000 SURF CASING 9.625 PROD CASING 7.000 TubinQ Strina - TUBING Size I Top I Bottom 3.500 0 9017 TubinQ StrinQ - OLD COMPLETIONS Size I Top I Bottom 2.875 9159 9206 Perforations Summary Interval TVD 9269 - 9303 6203 - 6227 9308 - 9320 6231 - 6240 9320 - 9323 6240 - 6242 9323 - 9332 6242 - 6248 9338 - 9340 6252 - 6254 9340 - 9379 6254 - 6282 9379 - 9380 6282 - 6283 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 1 3769 2788 CAMCO KBUG-M 2 5923 4001 CAMCO KBUG-M 3 6697 4466 CAMCO KBUG-M 1. Sheared Other 'pluas( equip., etc.) - JEWELRY Depth TVD Type Description ID 26 26 HANGER FMC TUBING HANGER 5/22/05 2.992 488 488 NIP CAMCO LANDING NIPPLE 5/22/05 2.875 6751 4500 PBR BAKER PBR - SHEARED 5/22/05 2.940 6765 4509 PACKER BAKER 'FHL' HYD SINGLE STRING PACKER 5/22/2005 3.960 8987 6004 PACKER BAKER PREMIER PACKER WITH TCII CONNECTION 5/22/2005 2.875 9010 6020 NIP CAMCO DS NIPPLE w/RHC PLUG/BALL 5/22/2005 2.812 9017 6025 WLEG WIRELlNE ENTRY GUIDE 5/22/2005 2.992 Other ~pluQs, equip., etc.) - OLD COMPLETION FISH #2 (POST 5/22/2005 WORKOVER) Depth TVD Type Description 9032 6036 SEAL Centrlllft 'GST3 4B HL PFS' Tandem Seal Section 9046 6045 MOTOR Centrlllft '304 HP KMH 2290/81' Series 562 Motor w/motor lead extension cable. Motor has a 6" centralizer threaded to base. Other ~pluas, equip., etc.) - OLD COMPLETION FISH #1 (POST 5/20/1998 WORKOVER) Depth TVD Type Description 9182 6141 PKR Baker'SAB-3' Packer w/'K-22' Anchor Seal Assy Top o o o Bottom 115 4887 9689 TVD 115 3416 6507 Grade H-40 J-55 J-55 Wt 62.58 36.00 26.00 Thread TVD 6025 Wt 9.30 Grade L-80 Thread EUE8rd TVD 6158 Wt 6.50 Grade J-55 Thread EUE ABM Zone C-4,A-3 A-2 A-2 A-2 A-1 A-1 A-1 Status Ft SPF Date Type Comment 34 6 8/29/1991 APERF 21/8" EnerJet; 0 deg ph 12 6 8/29/1991 RPERF 2 1/8" EnerJet; 0 deg ph 3 7 8/29/1991 RPERF 21/8" EnerJet; 0 deg ph 9 6 8/29/1991 RPERF 21/8" EnerJet; 0 den ph 2 6 8/29/1991 RPERF 21/8" EnerJet; 0 deg ph 39 7 8/29/1991 RPERF 21/8" EnerJet; 0 deg ph 1 6 8/29/1991 RPERF 2 1/8" EnerJet; 0 deg ph DMY DMY DMY Date Run o 5/22/2005 o 5/22/2005 o 5/22/2005 (1) Vlv Cmnt 1.0 SBK-2C 0.000 1.0 SBK-2C 0.000 1.0 DKC 0.000 ID 0.000 0.000 ID 3.000 9186 6144 NIP Cameo 'D' Nipple No-Go 9205 6157 SOS Baker 9206 6158 TTL General Notes Date Note 1/5/1995 WAIVERED WELL: IA x OA COMMUNICATION 6/21/1998 A Sands are open. 8/31/2001 PACKERLESS COMPLETION: FLOW TO SURFACE WELL 2/30/200~ WAIVERED WELL: T x IA COMMUNICATION, PACKERLESS COMPLETION 5/22/2005 CTD WORKOVER 2.250 2.441 2.441 ) 5]Z7jD6 lessons learned I Action Plan > When delegating a task. realize that you are transferring a responsibility and ensure that the designee is trained and capable of performing the task. > No elements of safety system are to be disabled. Refresher training on Rig data acquisition systems to be done. > An MOC form will be initiated for changes to critical parameter ranges in the rig acquisition systems. ~ Kick drills to be unannounced - manually trip pit levels to gauge reaction and elapsed time. );> Review option for auto-reset of a disabled alarm with software designer. ~ Communicate incident with North Slope via Incident Alert and safety meetings on other rigs. SCANNED JUN 1. 6 2005 SchlulDberger RE: [Fwd: FW: 3M-13 USIT] e e Subject: RE: [Fwd: FW: 3M-13 USIT] From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Tue, 31 May 2005 16:06:25 -0800 To: Thomas Maunder <tom_ ma4ndêr@admin;state~~. us> . cc: "Mooney, M" <M.Moo~ËY@êÖnocophilIips.cotli~~NSK Problem Well Supv <n 1617@conocophilliþs~com>, "Dethlefs, Jerry C" <Jeþy.CDethlefs@conocophil1ips.corri>. Tom, The results of 3M-13 RWO has increased our concern about corrosion in these completions. The timing for pulling a similar completion in well 3J-I0 has been moved by 3 months to get another data point. We've done as much as can be done with gas lift to minimize the dead leg. Tarn packerless ESPs are treated with biocide/corrosion inhibitor every month down the IA. This program may be expanded to other packerless ESP wells. Marie McConnell Problem Well Supervisor 659-7224 \Y'::>\\ \0 ~"\ '-> ~" ~(L\\S ~'\"<é. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, May 23, 2005 7:04 AM To: NSK Problem Well Supv Subject: Re: [Fwd: FW: 3M-13 USIT] Marie, Thanks for the information and compliment. As you note, it looks like the potential problem area for wells such as 3M-13 is that interval between the lift point and the fluid entry point. I don't know all the tubing/IA hydraulics or possible entry points, but it would seem to be prudent to attempt to minimize the length of the "dead leg" or if that is not possible to see if it is possible to spot some sort of inhibited fluid in the dead leg. I would suspect that there are "dead legs" on the other wells with broken ESPs similar to 3M-13. I'll bet this is a topic for discussion around your shop. Please keep me advised what you all might determine. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: ~tANNE[ ¡~OV 0 ~ 2005 Tom, The rig's pressure testing work identified the IA leak between 8635' and 8656'. The gas lift was entering the tbg thru the orifice GLV set at 5596'. This depth was as deep as possible with our limited gas lift header pressure of only 1400 psi. The production was entering the tbg thru a CV in the bottom GLM at 8937'. It appears that the corrosion occurred in the dead leg between the gas and fluid interface. Lifting as deep as possible is the right approach since the leak is well below the surface casing shoe and the new completion's packer can be set above the damage with out a reduction in gas lift effic~ency. If I remember correctly, it was your suggestion to lift these wells as deep as possible, thanks for the good idea! Marie McConnell Problem Well Supervisor ~~~ ~'\'tJ'o- ~ ~.l \ ~O ~'1'n 10f2 10/4/2005 8:47 AM RE: [Fwd: FW: 3M-13 USIT] e e 659-7224 -----Original Message----- From: Thomas Maunder [!!I~~_~_o: to'!l-n:!..~under@admin. state. ak. us] Sent: Friday, May 20, 2005 7:30 AM To: NSK Problem Well Supv Subject: [Fwd: FW: 3M-13 USIT] Jerry, et al: I am sure you are aware that a workover is underway (has been for a while) on 3M-13. This was one of those failed ESPs that was operated on GL. Here is the USIT I received from Howard Gober. As the workover has proceeded they did a casing test and do have a casing leak. If I remember, somewhere between about 9000' and 8500'. I remember some discussions regarding how deep to GL on these wells and it was determined to lift from as deep as possible to minimize the amount of casing "in fluid". I would be interested in your assessment of the USIT especially with regard to where the GL was entering. Thanks, Tom Maunder, PE AOGCC -------- Original Message -------- Subject: FW: 3M-13 USIT Date: Thu, 19 May 2005 15:29:08 -0800 From: Gober, Howard <Howard.Gober@conocophillips.com> To: tom maunder@admin.state.ak.us ._~---_._-_._.- Tom, When you have a minute, I would like to discuss our completion. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com -----Original Message----- *From:* Feketi, Michael R [mailto:FeketiMR@bp.com] *Sent:* Wednesday, May 18, 2005 7:48 PM *To:* Go~er, Howard *Subject:* 3M-13 USIT 20f2 10/4/2005 8:47 AM ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparukl KRUI 3M 05127/05 Hughes - HES \~1'Dl{O Packer Depth Pretest Initial 15 Min. 30 Min. Well 3M-13 Type Inj N/A TV.D. 4509 Tubing 600 600 600 600 Interval I P.T.D. 1870400 Type Test P T est psi 1500 Casing 600 2500 2500 2500 P/F P Notes: Initi'al produeer"MITIApost ,RWO OA = 50, 60, 60, 60 Well Type Inj TV.D. Tubing Interval P.TD. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.TD. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Test Details: SC/-\NNED JUN 1 4 2005 TYPE I NJ codes F = Fresh Water Inj G = Gas I nj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) MIT Report Form Revised: 05/19/02 MITP KRU 3M-13 05-27-05.xls 6/9/2005 ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report S u bm it to: J¡I.n...r.~g9.@ªf1m.lr.U?1ªtf¿.~ª!$.JJ.§ ªºfaç.~~...QnJ~iJ.1~!!:L.º-ª-Y.@.fJ~i}.n¡fL~~tª.~ê.:ªtSd2 .t~X¿.tt..Hª9.k~~Ll~.tºjLl@ªf1m.ln:§.1ªtfUà!$.~~.§ Rig No.: 2 DATE: 5/15/05 Rig Phone: 659-4398 Rig Fax: 659-4356 Op. Phone: 659-4393 Op. Fax: 659-4356 E-Mail ~.u.ª~1yy.çÀrJ.qn.m:f:H~~~.1~!º¡11!J.§.b~[@.tm:.G~!J PTD # 187-040 11/09/04 Contractor: Nordic Rig Rep.: Mckeirnan / Igtanloc Operator: BPX Rep.: Sevcik / Feketi Well Name: 3M-13 Operation: Drlg: Test: Initial: Test Pressure: Rams: 250/4000 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P Well Sign Dr!. Rig Hazard Sec. BOP STACK: Quantity Size/Type Stripper 1 Annular Preventer 1 7 1/16" #1 Rams 1 Blind / Shear #2 Rams 1 2 3/8" X 3.5" #3 Rams 1 2 3/8" X 3.5" #4 Rams 1 #5 Rams N/A Choke Ln. Valves 1 3 1/8" HCR Valves 2 3 1/8" Kill Line Valves 1 3 1/8" Check Valve 0 N/A CHOKE MANIFOLD: Quantity Test Result No. Valves 14 FP Manual Chokes 1 P Hydraulic Chokes 1 P ) Workover: XXX Weekly: XXX Annular: 250/4000 TEST DATA Test Result P P P Test Result NT P P P P NT NA P FP P NA Explor. : Bi-Weekly Valves: 250/4000 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly NT Lower Kelly NT Ball Type 1 P Inside BOP 1 P MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Visual P P P P P Alarm P P P P P Quantity Test Result I nside Reel valves NT ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2900 P Pressure After Closure 2200 P 200 psi Attained 15 sec P Full Pressure Attained 1 min 30sec P Blind Switch Covers: All stations Y Nitgn. Bottles (avg): 4@ 2050 Test Results Number of Failures: º Test Time: 4.5 Hours Components tested 27 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: .uI.n...r~~g9.@ªf1fIÜn&1ªtfu~XJJ.§ Remarks: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector YES 24 HOUR NOTICE GIVEN XXX NO Date 5/14/05 Time Test start 1600 Finish Coil Tubing BFL 11/09/04 SCANNED MAY 2. G 200~j Waived By Jeff Jones 14:30 Witness Dave Lancaster 2030 Nordic 2 BOP 5-15-05p.xls ) ) 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report S u bm it to: .un1...r.~g9.@ªf1fx}.tn:§.1ªJ&~ª!$.~~.§ ªºfaç.~~...QLU~iJJ~!ª...þ..ª-y.@.ft\i}Jl¡Ll:.~~tª.~ê.:ªß:.~2 .t~.Q.tL.Hª9.k~~Ll§.tºjLl@ªf1fIÜn:§.1ªtfLª!$.~hI.§ Contractor: Nordic Rig No.: 2 DATE: 5/11/05 Rig Rep.: Mckeirnan-Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sevcik / Feketi E-Mail ~.~m~1iAf.çÀrJ.n.n.m:gj~~~.1~!º¡11!J.§.b~~[@.~111:XJ~!J Well Name: 3M-13 PTD # 187-040 Operation: Drlg: Test: Initial: Test Pressure: Rams: 250/4000 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P Workover: XXX Weekly: XXX Annular: 250/4000 TEST DATA Test Result P P P Explor.: Bi-Weekly Valves: 250/4000 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type Inside BOP Well Sign Dr!. Rig Hazard Sec. BOP STACK: Quantity Size/Type Test Result Stripper Annular Preventer #1 Rams #2 Rams #3 Rams #4 Rams #5 Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve CHOKE MANIFOLD: Quantity Test Result No. Valves Manual Chokes Hydraulic Chokes MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Visual P P P P P Alarm P P P P P Quantity Test Result Inside Reel valves NT ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure P Pressure After Closure P 200 psi Attained P Full Pressure Attained P Blind Switch Covers: All stations Y Nitgn. Bottles (avg): Test Results Number of Failures: º Test Time: .5 Hours Components tested ~ Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: .U!.n...mg9.@ªf1m.tLU?1ªJ&~ª!$.~~.§ Remarks: 24 HOUR NOTICE GIVEN YES NO XXX Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector Date Time Test start Finish Coil Tubing BFL 11/09/04 SCJ~N\\iED r·..1Þ'/ 2. f; 20 O!~ Waived By Witness Tyler Mcconnell Nordic 2 BOP 5-11-05 valve test.xls . :~ TlfÆA IT íŒ:~ íñlllf: C ì', ltlll,r""'I.\U '[ dJp¡' _u ~ ~ r ) fÆ'':"ð' ¡"l /;1i";1ð' \ :r:¡:::;-.~, '\'~ ~: 1,1,/7/ ":1,\ , , Ill' ',' \\ ~,(WI I ,,' ! I~' '''' ¡:i \ \ 'II~ /;1\\1 ,r 'I I I ',U\ " !: IJlj rÌJ i :,~ Lr1J AIfA~1iA. OIL AND GAS CONSERVATION COMMISSION Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska Re: Kuparuk 3M-13 Sundry Number: 305-065 Dear Mr. Gober: I / ./ / I I J ) FRANK H. MURKOWSKI, GOVERNOR 333 w. -¡m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ot\'(J /'"", \C{¿ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed fonn. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior unless rehearing has been requested. DATED thisØ day of March, 2005 Ene!. ~r"Æ~~i~'eD\ M 1\ r1 1 ff" ~DD~ \)}'\.f~"\nn ' /in; .('. \J r- , ,,,,j .// / ( ~ ) ) ConocJPhillips Alaska RECEIVED MAt< 0 7 2005 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 3, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 3M-13. 3M-13 was worked over in June of 1998 to install electric submersible pump (ESP) equipment. The ESP equipment ran until October of 1998 when the pump failed. ConocoPhillips submitted a Sundry for this well in September of 2003. The intent of the Sundry was to document AOGCC approval of variance from 20 ACC 25.200 (d) since the well was on gas lift without an isolating packer. Sundry Number 303-281 was approved on October 3, 2003. The purpose of the proposed workover will be to pull the ESP completion and run a standard gas lift completion with isolating packer. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, ~ Howard B. Gober Wells Engineer CPAI Drilling and Wells OR\G\NAL hrç 3!R" I. C r ~ STATE OF ALASKA ) ~:REè~I\1EDK' ALASKA OIL AND GAS CONSERVATION COMMISSION , 'S/'1 APPLICATION FOR SUNDRY APPROVAL MAR 072005 20 MC 25.280 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development 0 Stratigraphic D Perforation Depth MD (ft): 9269'-9303',9308'-9332',9338'-9380' Packers and SSSV Type: pkr= BAKER 'SAB-3' PACKER W/'K-22' ANCHOR SEAL ASSY no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name r i¡;}i:3J~ Gober Signature /IPiT~ Perforation Depth TVD (ft): 6203'-6227', 6231'-6248', 6252'-6283' Packers and SSSV MD (ft) pkr= 9182' no SSSV 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D ) Abandon D Alter casing D Change approved program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 63' Suspend D Repair well 0 Pull Tubing 0 1. Type of Request: 8. Property Designation: ADL 25512, ALK 2553 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 9734' 6539' 9004' Length Size Casing CONDUCTOR SURF CASING 115' 4824' 16" 9-5/8" PROD CASING 9626' 7" March 16, 2005 Date: Alaska atl & G~t Coni. Comm¡$~inn Perforate D waivÄnCh~ge Annular Disp. D Stimulate D Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill ~ber: 187-040 " 6. API Number: J 50-029-21720-00 9. Well Name and Number: 3M-13 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6016' MD Exploratory D Service D TVD Burst Collapse 115' 4887' 115' 9689' 3416' 6507' Tubing Size: 2-7/8" Tubing Grade: J-55 Tubing MD (ft): 9206' Service D Plugged D WINJ D Abandoned 0 WDSPL D Contact: Title: Howard Gober @ 263-4220 Wells Engineer Date 3/=¡-/O5 Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .- j r- 3(?~ -þ~ Plug Integrity D BOP Test .~ Mechanical Integrity Test D Location Clearance D Other: ," \ ~ \""-"~\\;)<;, <.. \ ~ ~~\ \>~S '3>-.) "" .,} 5 ~\ ~ \. ~~\:.t. ,\\.!~ SUbSeqUen~r~ ~ 0 R ¡ G \ N A L RBDMS BFl MAR 0 9 20~ j (~ ~I BY ORDER OF .,~. rø~' V ~ Approved ~: ¡ COMMISSIONER THE COMMISSION Date: <.7: ,a ~ \.-.-/ Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Sub t in Duplicate ') ) Kuparuk 3M-13 General Workover Procedure Pre-riQ Work 1. 10 days before Rig Workover, RU Slickline Unit. Pull GlV at 3544' and OV at 5596'. Install DV's in both pockets. Pull CV at 8937' leaving an open pocket 2. Pump CaC03 pill to limit fluid loss to perfs 3. Set BPV. 4. Prepare location for Workover Rig. GeneralWorkover Procedure 1. MIRU Workover Rig. 2. Kill well by pumping heated seawater followed by 12.4 ppg brine. 3. ND Tree, MU Test plug, NU BOPE. 4. Test the BOPE to 4000 psi. 5. Pull Test plug. 6. Pull tbg hanger. 7. RU spools for ESP cable. Pull tbg & ESP Motor. 8. MU packer and gas lift mandrels on new 3-1/2" tubing. Set packer. Pressure test IA to 1500 psi. 9. Shear PBR. Space out. land tubing hanger. RllDS. Set BPV. 10. ND BOPE. NU Tree. Pull BPV. Set test plug. Test tree. Pull test plug. 11. Freeze protect with diesel to +/- 2000' TVD. 12. Set BPV. RDMO workover rig. Post-RiQ Work: 1. Pull BPV. 2. RU Slickline. Pull ball and rod. Run gas lift valves. 3. RU CTU. Clean out CaC03. 4. Return to production. i . Current Completion .... II1II... ~ ~ ~' ~ ~ ) . . ~ II1II... ) ) 3M-13 Proposed Workover 9-5/8" Csg 2.875" Tbg 5 KBMM-2 GLMS 2.25" Camco D-Nipple ESP, Seal, & Motor Original Baker SAB Packer with KBH-22 anchor Original 2.25" Camco D-Nipple 7" Csg Proposed 2005 Completion ~ ~ II1II... ~,'M' -,-,~.~ ~L"- \ ~ ) . ~ 2.875" D Nipple +/- 500' 3.5" Tbg 5 KBUG GLMS FHL Packer/PBR 2.812" DS Nipple Poor boy overshot RE: FW: 3M-13 Workover--187-040 ) ) Subject: RE: FW: 3M-13 Workover--187-040 From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Fri, 18 Feb 2005 08:49:29 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Gober, Howard" <Howard.Gober@conocophillips.com>, NSK Problem Well Supv <n 161 7@conocophillips.com> Tom, You are correct, after the workover this well will be a noramally equipped Kuparuk well with gas lift mandrels in the tubing string and a packer isolating the production zone from the IA. There is one additional failed ESP Kuparuk well, 3J-10, that I am aware of, that we are reviewing for a similar workover this year. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Friday, February 18, 2005 8:36 AM To: NSK Problem Well Supv Cc: Gober, Howard Subject: Re: FW: 3M-13 Workover--187-040 Howard and MJ, I have looked at the file. When I do my work on a sundry, I do not necessarily repeat all the items given in the accompanying letter. It is my expectation that what is planned/proposed in the letter will be done. I would not expect that some sort of operation would be proposed in a document submitted to the Commission without knowledge and buy off of "management" and that by proposing certain work there is a commitment to do it. In this case, your proposal to not run the inspection log is acceptable. As presently equipped the flow directions of the produced fluids and gas lift are not different from most other wells at Kuparuk. The exception is that 3M-13 does not have a packer. Unless there was some indication otherwise, a casing inspection log would not be required on a normally equipped Kuparuk well. You do plan to conduct a pressure test which is prudent and in compliance with the Sustained Casing Pressure Conservation Order. It also appears that a normal completion is planned rather than replacing the ESP. Is that correct?? Is there a plan as other failed ESPs are removed to run traditional completions?? Please call or message with comments/questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: SCANNED FEB 1 8 2005 Tom, 10f3 2/18/2005 9:22 AM RE: FW: 3M-13 Workover--187-040 ) ConocoPhillips requests clarification on the proposed Sundry requirements on 3M-13 (Sundry # 303-281, pro 187-040). Please read the attached email and let me know if it outlined plan is acceptable. ) MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Origi na I Message----- From: Gober, Howard Sent: Thursday, February 17, 2005 5:06 PM To: NSK Problem Well Supv Cc: Ennis, J J Subject: 3M-13 Workover MJ, In June of 1998 a workover was performed on 3M-13 (PTD 187-040) to convert the well from gas lift to ESP. The ESP failed in August of 2001. Since that time the well has been producing on gas lift with the ESP equipment still in the hole. There is not a packer on the current tubing string. On September 14, 2003 Jerry Dethlefs submitted an Application for Sundry Approval to the AOGCC. The purpose of the Sundry was to document with the AOGCC that 3M-13 was producing. without a packer in the well. Jerry stated in his letter that whenever the well was worked over, a casing inspection log would be run. The Sundry was approved by the AOGCC on October 3¡2003(Sundry #303-281). The approval letter and the approved Sundry do not contain any mention of the casing inspection log. We are planning a workover for 3M-13 beginning on or about April 1, 2005. As part of the planning, I would like a clarification on the casing inspection log. In lieu of the log, we would like to pressure test the 7" casing. This would be performed after the new completion is stabbed into the production packer. This packer was not recovered during the 1998 workover. If the casing pressure tests, there will be no further tests. If the casing does not pressure test, we will do the following: a Run retrievable packer and bridge plug. Identify the interval that is leaking. a If the production packer is leaking, a stack packer will be run and the well completed. a If there is a casing leak up hole, we will run a casing inspection log to identify the extent of the problem. a The casing leak will be isolated with an expandable patch or 5-1/2" casing will be run from the production packer to surface. The appropriate fix will be determined once we have all the data in hand. We feel that the pressure test will prove that we have competent casing. If the risk pays out, we will be able to use the money earmarked for a casing inspection log on another workover Please let me know if you have any questions, or if you need further information. Thanks, 2of3 2/18/20059:22 AM RE: FW: 3M-13 Workover--187-040 ) ') Howard Gober Well Supervisor ConocoPhillips Alaska, Inc. 907 -263-4220 Office 907-240-5515 Cell Howard. Gober@coDPcophil!ip?com 3 of3 2/18/2005 9:22 AM ALASKA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERIVOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Wells Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 Re: KRU Kuparuk Pool. Wells Equipped with Electric Submersible Pumps (ESPs) KRU 2C 09 184-221 303-274 ESP failed flowing well KRU 2C 16 184-202 303-275 ESP failed flowing well KRU 3B 13 185-023 303-276 ESP failed gas lifted well KRU 3A 01 185-186 303-277 ESP failed gas lifted well KRU 3B 14 185-024 303-278 ESP failed gas lifted well KRU 3H 04 187-076 303-279 ESP operating KRU 3J 10 185-250 303-280 ESP failed gas lifted well KRU 3M 13 187-040 303-281 ESP failed gas lifted well KRU 3M 14 187-051 303-282 ESP operating Dear Mr. Dethlefs: You recently submitted Sundry Notices (Form 403) for the above nine (9) wells. Each sundry requested an exception to Commission regulation 20 AAC 25.200(d) where wells caPable of unassisted flow are required to be equipped with tubing and a packer. It has been determined from examination of Commission records that the installation of ESPs in the wells was approved either by a Commission letter to ARCO Alaska (dated November 1 l, 1996) or individual sundry notices for some of the wells. No further exception is necessary. As shown in the table listing, two (2) of the pumped wells have operating pumps, five (5) of the wells have failed pumps and are being gas lifted and two (2) of the failed pump wells are flowing. After examination of the sundry applications and the Commission well files, we have determined the following actions with regard to those Kuparuk Pool wells equipped with ESPs: 1. Until the ESPs fail, 3H-04 and 3H-16 should be allowed to continue production with no restrictions. . The sundries for wells 3M-14, 3M-13, 3J-10, 3A-01 and 3B-13 are approved for a 2-year period. Production entry into the tubing should remain at the deepest mandrel as presently configured. 3. In order to remain in production, the tubing entry configuration of wells 2C-09 and 2C~ 16 should be changed to be similar to the other failed ESP wells with the fluid entry Jerry Dethlefs Problem Wells Supervisor October 2, 2003 Page 2 of 2 nominally at the deepest gas lift mandrel. With the fluid entry changed, the sundries are approved for 2 years. 4. You should submit form 404 to document the completion of the work on 2C-09 and 2C- 16. Please contact Tom Maunder at 793-1250 with any questions. Sincerely, Randy Ruedrich Commissioner STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing Change approved program Suspend [--] Operation Shutdown r-'] Perforate Repair well ~] Plug Perforations ~ Stimulate Pull Tubing [~ Perforate New Pool [~ r--] Variance ~-~ ~] Time Extension ~ Re-enter Suspended Well ~ Annular Disp. Other 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development __ [] Exploratory Stratigraphic E~ Service 5. Permit to Drill Number: 187-040 50-029-21720-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 63' 3M-13 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Total depth MD (ft): 9734' Total Depth TVD (ft): PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): 6249' MD TVD 115' 115' 4887' 3416' 6505' Effective Depth MD (ft): 6539' 9335' Casing Length Size CONDUCTOR 115' 16" S U R F CAS IN G 4824' 9-5/8" PROD CASING 9626' 7" 9689' Perforation Depth MD (ft): Perforation Depth TVD (ft): 9269'-9303', 9308'-9332', 9338'-9380' 6202'-6226', 6230'-6247', 6251'-6282' Junk (measured): Burst Collapse Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8" J-55 9207' Packers and SSSV Type: pkr= BAKER 'SAB-3' PACKER W/'K-22' ANCHOR SEAL ASSYr~: no SSSV 12. Attachments: Description Summary of Proposal r'~ Detailed Operations Program [~] BOP Sketch [--] 14. Estimated Date for Commencing Operations: Immediately 16. Verbal Approval: Date: Packers and SSSV MD (ft) pkr= 9182' no SSSV 13. Well Class after proposed work: Exploratory r-~ Development ~-~ 15. Well Status after proposed work: Oil [-~ Gas [~] WAG [] GINJ r-~ Plugged D WINJ [-"] Service Abandoned [- WDSPL [] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~1'1~/Dethlefs ~ Signature , ~,,,//~ C Commission Use Only Contact: Jerry Dethlefs, 659-7043 Title: Problem Well Supervisor Phone 659-7043 Date ~/~ Conditions of approval: Notify Commission so that a representative may witness ISundry Number: Plug Integrity [] BOP Test ~ Mechanical Integrity Test Location Clearance Other: C.~eN~--"~{ (~_.~f~,[.-¢C.~.~ ~,f~/,..-O~..~% ~ ~~~~ ~ ~~~ RECEIVED SEP 6 2883 Subsequent Form Required: ~~ .~ ~ ~ ~,', ~ ~ Alaska Oil & Gas Cons. Commission Approvod by: ~OMMISSIO~E~ BY O~Dfi~ OF { IHfi GOMMISSIO~ Dato: - ORIGINAL SUBMIT IN DUPUCATE 0-403 OCT ]. 20 9 ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 3M-13 (PTD 1870400) September 11, 2003 This application for Sundry approval for well 3M-13 (PTD 1870400) is to document that the AOGCC and ConocoPhillips concur the well may be produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. Well 3M-13 was originally completed in May 19.8.7_as a gas lifted producer. The well was re- completed with an ESP in June 1998. The well produced via ESP until October 1998, at which time the pump faile-dl The AOGCC was notified of the pump failure on August 31~ 2001. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gaslift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is s~ (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing through a gaslift mandrel at 8937'measured depth. From that point produced fluids flow up the tubing and out the wellhead to production facilities. Gaslift is maintained on the well through gaslift valves at 3544' and 5596' to keep annular fluids to the lowest possible depth. The well is equipped with a wellhead Safety Valve'~-ystem as per regulations. Recent well test data shows the following results: DS WL LENGTH CHK FTP FTT OIL WATER/%WC \FLUID GAS GOR GLR RATE PRES 3M 13 19:00 176 126 95 274 594 [ 68 /868 140 511 457 256 ~ 1077 3M 13 18:00 176 122 97 239 591 I 71 { 830 184 771 566 285 / 967 3M 13 18:00 176 114 100 269 692 / 72 1961 205 763 512 287 ~ 969 3M 13 18:00 176 114 100 336 811 ~ 65 )947 208 620 523 287 ~ 969 3M 13 17:20 176 133 96 231 594 ~825 168 727 532 271 ~ As per this request, ConocoPhillips intends to produce 3M-13 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. GConocoPhillips Alaska, Inc, TUBING ~ (O9084, 0D:2.875, ID:2.441) Gas VlandrelNalvE 2 (3544-3546, 0[:):4.742) Gas Lift VlandrelJalvE 3 (5596-5598, OD:4.742) Gas Lift VlandrelNalvE 5 (8937-8939, 0D:4.742) NIP (9016-9017, 0D:2.875) PUMP (9030-9069, OD:ZOO0) SEAL (90699084, 0D:2.441) PKR (9182-9183, 0D:6.151) NIP (91969197, 0D:2.875) (9269-9283) Perf (9283-9303) KRU 3M-13 3M-13 APl:1500292172000 SSSV Type:I NONE Annular Fluid:I Reference Log:I Last Tag:19004 Last Tag Date:] 6/3/2000 Casing String - ALL STRINGS Description Well Type: PROD °rigls/31/1987 C°mpleti°n:l Last WlO:1612011997 Ref Log Date:I TD:19734 ftKB Max Hole Angle:157 deg (~ 2800 Size I Angle (~ TS:144 deg (~ 9267 Angle @ TD:I43 deg @ 9734 I Rev Reason:IWAIVERED I FTS WELL Last Update:J5/25/2003 Top 0 Boffom CONDUCTOR 16.000 115 115 SURF CASING 9.625 0 4887 3416 PROD CASING 7.000 0 9689 6507 TVD Wt Grade Thread 162.581H-40I 136.001 J-55 I 126.001 J-55 I Tubing String - TUBING Size I Top I Bottom TVD Wt Grade , Thread 2.875 I I0 9084 6072 6.50 J-55 I EUE ABM 2.875 9158 9207 6159 6.50 J-55 I EUE ABM PerfOrations Summary Interval TVD 9269-9303 6203-6227 9308-9320 6231-6240 9320-9323 6240-6242 9323-9332 6242-6248 9338-9340 6252-6254 9340-9379 6254-6282 9379-9380 6282-6283 Zone Status Ft SPF Date I Type I Comment C-4,A-3 34 I 6 8/29/19911APERFI21/8"EnerJet;0degph A-2 I 12 I 6 8/29/1991 I RPERFI2 1/8" EnerJet;0deg ph A-2 I I 3 I 7 18/29/1991 I RPERFI2 1/8" EnerJet; 0 deg ph A-2 I I9 I6 18/29/19911RPERF121/8''EnerJet;0degph A-1 I I 2 I 6 18/29/19911RPERFI2 1/8"EnerJet; 0 deg ph A-1 I I 39 I7 18/29/1991I RPERFI2 1/8"EnerJet; 0 deg ph A-1 I I 1 I 6 18/29/1991 I RPERFI2 1/8" EnerJet; 0 deg ph stI MD I TVD I Man I Man I V Mfr I V Type Iv OD I Latchl Port I TROI Date I vlv Mfr Type Run 1 I 951 951CamcoI KBMM2 I I DMY I 1'0 I BK I0'000 I1 10/31/199~cmnt 2135441 266°1camc°1 KBMM2 I I GLV I 1.0 I BK 10.188 11316~1/26/1998~ 3155961 38151Camc°1 KBMM2 I IOV I1.0 IBE10.2501 0 /6/4/2000/ 4163911 42751Camc°1 KBMM2 I IDMYI1.0 IBK10.0001 0 /6/4/2000/ 5 189371 59691 CamcoI KBMM2 I I CV I 1.0 I BE 10.0001 0 /6/4/2000| Other (plugsp equip, etc;~ - JEWELRY Depth I TVD Type Description ID 9016 I 6024 I NIP Camco 'D' No-Go Landing Nipple 2.250 9030 I 6034 I PUMP Centrilift Model '20 GCNPSH/44GC3500/82GC2900', Series 513 Triple 0.000 I I Taper pump w/bolt-on intake & discharge heads. 9069 I 6061 I SEAL Centrilift 'GST3 4B HL PFS' Tandem Seal Section 0.000 9084 I 6072 I MOTOR Centrilift'304 HP KMH 2290/81' Series 562 Motorw/motor lead extension 0.000 I I cable. Motor has a 6" centralizer threaded to base. 9182161411 PKR Baker 'SAB-3' Packer w/'K-22' Anchor Seal Assy 3.000 I I 9196 I 6151 I NIP Camco'D' Nipple No-Go 2.250 9205 I 6157 I SOS Baker 2.441 9206 16158 I TTL 2.441 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 973' FNL, 1607' FEL, Sec.25, T13N, R8E, UM At top of productive interval 1072' FSL, 4485' FEL, Sec.19, T13N, R9E, UM At effective depth At total depth 1191' FSL, 4786' FWL, Sec.19, T13N, R9E, UM Perforate _ Other_X 5. Type of Well: Development _X Explorato~__ Stratigraphic_ Service__ (asp's 506261, 6016527) (asp's 508609, 6018575) (asp's 512651, 6018699) 6. Datum elevation (DF or KB feet) RKB 63 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3M-13 9. Permit number / approval number 187-040 10. APl number 50-029-21720 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURF CASING 4824' PROD CASING 9626' 9734 feet Plugs (measured) 6539 feet 9004 feet Junk (measured) 6016 feet Tagged Fill (6/3/00) @ 9004' MD. Size Cemented Measured Depth True vertical Depth 16" 200 Sx CS II 115' 115' 9-5/8" 1700 Sx CS III & 400 G 4887' 3416' 7" 350 Sx G & 175 Sx AS I 9689' 6506' Perforation depth: measured 9269 - 9303'; 9308 - 9332'; 9338 - 9380' true vertical 6203 - 6227'; 6231 - 6248'; 6252 - 6283' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, J-55, Tubing @ 0 - 9084' MD; Old 2-7/8", 6.5#, J-55, Tubing @ 9158 - 9207' MD. Packers & SSSV (type & measured depth) Baker 'SAB-3' Packer w/'K-22' Anchor Seal Assy @ 9182' MD. Otis 'X' Nipple w/Selective Profile @ 523' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 348 Subsequent to operation 432 Representative Daily Average Production orlnjection Data Gas-Mm W~er-Bbl 186 743 180 832 Casing Pressure Tubing Pressure 161 214 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .._X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed / t~, _. ,~,/_/,]~;(_,.,../%, Title: RECEIVED Form 10-404 Rev 06/15/88 · ~An o 7 tVl t."i!~. /_. Alaska 0il & Gas Cons. Commissior,, Anchorage Date ~/~ Prepared by John Peirce 265-6471 SUBMIT IN DUPLICATE~ 3M-13 CEMENT OUTER ANNULUS DESCRIPTION OF WORK COMPLETED 6/3/00: RIH & tagged fill at 9004' MD. 6/7/00: MIRU. RIH w/high pressure hose 50' down the 9-5/8 x 16" annulus, then pumped 9.4 bbls of 12 ppg Litecrete cement into the annulus. RD. Returned the well to production w/gas lift & obtained a valid well test. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 8, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3M-13 (Permit No. 87-40/398-107) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the report of Sundry Well Operations to cover any changes made to the completion during the recent workover operations on KRU 3M-13. If there are any questions, please call 265-1319. Sincerely, Mark A. Chambers Drilling Engineer Kuparuk Drill Site Development MAC/skad RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Pull tubing Stimulate_ Plugging__ Perforate Alter casing __ Repair well __ Other X Install ESP completion 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 973' FNL, 1607' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1072' FSL, 4485' FEL, Sec. 19, T13N, R9E, UM At effective depth 1157' FSL, 4699' FWL, Sec. 19, T13N, R9E, UM At total depth 1191' FSL, 4786' FWL, Sec. 19, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 5. Type of Well: Development X Exploratory __ Stratigraphic _ Service Effective depth: measured true vertical 9734' feet Plugs (measured) 6538' feet 9335' feet Junk (measured) 6249' feet 6. Datum elevation (DF or KB) Rig RKB 32' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-13 9. Permit number/approval number 87-40/398-107 10. APl number ! '7 &O 11. Field/Pool Kuparuk River ORIGINAL Casing Length Structural Conductor 80' Surface 4852' Intermediate Production 9654' Liner Size Cemented 16" 200 sx CS II 9-5/8" 1700 sx CS III & 400 sx Class G 7" 350 sx Class G & 175 sx AS I Measured depth 115' 4887' 9689' True vertical depth 115' 3416' 6505' Perforation depth: measured 9269'-9303',9308'-9332',9338'-9380' true vertical 6202'-6226', 6230'-6247', 6251'-6282' Tubing (size, grade, and measured depth) 2.875", 6.5#, J-55 @ 9206' Packers and SSSV (type and measured depth) Baker SAB-3 perm pkr @ 9182' 13. Stimulation or cement squeeze summary RECEIVED jul 1 Intervals treated (measured) Treatment description including volumes used and final pressure Naska Oil & Ga9 Cons. CommlS~ion Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Repod of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,/~,.,X J ~ Title Drilling Engineer Form 10-~'~74-Rev 05/17/89 Date SUBMIT IN DUPLICATE Date: 7/7/98 ARCO ALASKA INC. Page: 1 WELL SUMMARY REPORT REMEDIAL AND COMPLETION OPERATIONS WELL:3M-13 RIG:NORDIC WI: 0% SECURITY:0 WELL_ID: 999201 TYPE: INSTALL ESP COMPLETION AFC: 999201 STATE:ALASKA API NUMBER: 50-029-21270-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:06/17/98 FINAL: 06/17/98 (C1) TD: 9575' PB: 0' R/U hard line to tree MW: 8.6 SW SUPV:BP Move rig from 3K-34 to 3M-13. Accept rig at 2200 hrs. 6/17/98. 06/18/98 (C2) TD: 9575' PB: 0' Nippling down tree MW: 0.0 BRINE SUPV:BP Pull VR plug and BPV (BPV gave trouble - hanging up in SSV). Work on leaking 7" annulus valve. Displace well to brine to kill well. Well taking fluid. Circulate well to 9.8+ ppg brine. Fluid losses stopped. 06/19/98 (C3) TD: 9575' PB: 0' O6/2O/98 (C4) TD: 9575' PB: 0' 06/21/98 (C5) TD: 9575' PB: 0' 06/22/98 (C6) TD: 9575' PB: 0' 06/23/98 (C7) TD: 9575' PB: 0' POOH w/2-7/8" completion MW: 9.9 BRINE SUPV:BP Monitor well, decreasing flow. N/D tree. N/U BOPE and test. Bleed well, attempt to stabilize, flowing from annulus. Circulate well to brine. Well stable. POOH w/2-7/8" tubing. Bit/scraper on bottom, ci MW:10.0 BRINE SUPV:BP Continue POOH w/2-7/8" completion. RIH w/bit and scraper. Well flowing w/bit @ 7600'. Circulate brine around. Still flowing. Weight up to 10.0+ ppg and circulate. Running completion MW:10.0 BRINE SUPV:BP Continue circulating 10.0+ ppg brine around to kill well. Well stable. Continue RIH with bit and scraper on 3.5" drillpipe. Tag cut-off tbg stub at 9147'. Run ESP completion Prep rig for move to 3M-2 MW: 0.0 DOILW SUPV:BP Continue RIH w/2-7/8" ESP completion assembly. N/D BOP stack. N/U tree and test tree to 250/5000 psi. Release rig @ 0930 hrs. 6 MW: 0.0 SUPV: DLW RDMO. Release rig @ 0930 hrs. 6/23/98. Move rig. RECEIYE, I) " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown __ Re-enter suspended well _ r~mm~,,~ Alter casing _ Repair well _ Plugging __ Time extension _ Stimulate _ Change approved program _ Pull tubing X__ Variance _ Perforate __ Other ~ Install ESP 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 973' FNL, 1607' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1072' FSL, 4485' FEL, Sec. 19, T13N, R9E, UM At effective depth 1157' FSL, 4699' FWL, Sec. 19, T13N, R9E, UM At total depth 1191' FSL, 4786' FWL, Sec. 19, T13N, R9E, UM 5. Type of Well: Development Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 63' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-13 9. Permit number 87-40 10. APl number 50-029-21270 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured 9734' (approx) true vertical 6538' feet feet Plugs (measured) None Effective depth: measured 9598' (approx) true vertical 6439' feet Junk (measured) feet Casing Length Size Structural Conductor 80' 16" Surface 4852' 9.625" Intermediate Production 9654' 7" Liner Cemented Measured depth True vertical depth 200 sx CS II 115' 115' 1700 sx CS III 4887' 3416' & 400 sx Class G 350 sx Class G & 9689' 6505' 175 sx AS I Perforation depth: measured 9269'-9303', 9308'-9332', 9338'-9380' true vertical 6202'-6226', 6230'-6247', 6251'- 6282' Tubing (size, grade, and measured depth) 2.875", J-55 tbg @ 9206' Packers and SSSV (type and measured depth) Baker SAB-3 perm. pkr @ 9182' ORIGINAL 13. Attachments Description summary of proposal X Contact William Isaacson at 263-4622 with any questions_. Detailed operation program __ BOP sketch _ 14. Estimated date for commencing operation May 15, 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas_ Service Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~, ~. ~ Title Kuparuk Drilling Team Leader FOR COMMISSION USE ONLY Plug integrity_ BOP Test ~ Location clearance cOTM I Mechanical Integrity Test_ Subsequent'form require 10- ~ ~ ~ ~"~'~" -,~ ~'~- ~ ~.~'~'~'" ~' Approved by the order of the Commission ;)avid W. Johnston Commissioner Date ~'""~-~)" Y Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE KRU 3M-13 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH with wireline. Dummy off all GLM's. 2. RU E-line unit and RIH with chemical cutter. Cut tubing in middle of full joint immediately above permanent packer. 3. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 10.6 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH standing back 2-7/8" tubing, lay down all jewelry. 5. PU DP and RIH with bit and scraper. Circulate hole clean immediately above tubing cut. POOH standing back DP. . RIH w/Electric Submersible Pump completion on 2-7/8" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge, through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 7. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 5.0 days Expected Case: 6.0 days Upper Limit: 8.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running ESP completion WSI 04/17/98 3M-13 Proposed Completion K. 2-7/8" 5M FMC Gert IV Eccentric tubing hanger with 'BIW' penetrators for ESP cable (100 amp) and downhole gauge conductor wire. 2-7/8" L-80 tubing pup on bottom. Round #2 power cable with tech wire in double armor wrap J. Rerun 2-7/8" J-55 EUE 8rd Mod IPC tbg to surface. Space-out 2-7/8" x 1" Camco 'KBMM' mandrels w/ DV's as follows: GLM# MD-RKB 2 TBD 3 TBD 4 TBD 5 TBD NOTE: Install LaSalle cable protectors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM should be made up with an 8' pup below and a LaSalle cable protector placed on cplg below pup. LaSalle ESP Cable Protectors spaced out as procedure ~ Cable splice from flat to round cable adjacent to 10' ~ pup above pump I. 2-7/8" X 1" Camco 'KBMM' mandrel with DCK-2T-1 dump kill valve (pinned for 3500 psi tubing to casing differential). H. Pup jt, 2-7/8" x 8' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg between 8' pup and full jt. G. 1 jt Rerun 2-7/8" J-55 EUE 8rd Mod IPC tubing with LaSalle cable protector on cplg below joint. F. 1 jt of Rerun 2-7/8" J-55 EUE 8rd Mod IPC tubing with annulus sensing Baker 'Sentry' gauge clamped to OD of tubing. Conductor Wire for gauge will be run to surface with-in the 2nd Armor wrap of ESP cable. E. 2-7/8" Camco 'D' landing nipple with 2.25" No-Go profile. Standing Valve to be set as nipple is made-up. D. Pup jt, 2-7/8" x 4' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. LaSalle Protectolizers at each flange of ESP assembly C. Centrilift '20 GCNPSH/44GC3500/82GC2900' Series 513 Triple Taper Pump with bolt-on intake and bolt-on discharge head. 2-7/8" x 10' L-80 handling pup on top. B. Centrilift 'GST3 4B HL PFS' Tandem Seal Section. A. Centrilift '304 HP KMH 2290/81' Series 562 Motor with Motor Lead Extension Cable. Motor has a 6" centralizer threaded into base. Bottom of motor set at +/-9115' MD RKB. C Sand Perfs A Sand Perfs 7" 26# @ 9689' ~ PBTD @ 9575' 3-1/2" x 7" Baker 'SAB-3' permanent production packer left in hole. Top of 2-7/8" tubing cut-off joint at 9165' MD. 9269'-9283' 9283'-9303' 9308'-9332' 9338'-9380' WSI 3/31/98 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 973' FNL, 1607' FEL, Sec. 25, T13N, At top of productive interval 1072' FSL, 795' FEL, Sec. 19, T13N, At effective depth 1157' FSL, 579' FEL, Sec. 19, T13N, At total depth 1191' FSL, 494' FEL, Sec. 19, T13N, 12. Present well condition summary Total Depth: measured true vertical 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service R8E, UM R9E, UM R9E, UM 6. Datum elevation (DF or KB) RKB 63 7. unit or Property name Kuparuk River Unit 8. Well number 3M-13 9. Permit number/approval number 87-40 10. APl number 50-029-21720-00 11. Field/Pool Kuparuk River Field/Oil Pool R9E, UM 9734 feet 6538 feet Plugs (measured) None feet Effective depth: measured 9 5 9 8 true vertical 6439 feet Junk (measured) None feet Casing Le n gth Structural Conductor 8 0' Surface 4 8 5 0' Intermediate Production 9656' Liner Perforation depth: measured 9269'-9283', true vertical 6202'-6212', Size 16" 9-5/8" 7" Cemented Measured depth True vertical depth 200 Sx CS II 1 I 5' I 1 5' 1700 Sx CS III & 4887' 341 6' 400 Sx Class G 350 Sx Class G & 9 6 8 9' 6 5 0 5' 175 Sx AS I 9283'-9303', 6212'-6226', 9308'-9332', 6229'-6247', 9338'-9380' 6251'-6282' Tubing (size, grade, and measured depth) 2-7/8", 6.5#/ft., J-55 @ 9206' Packers and SSSV (type and measured depth) Packer: Baker SAB-3 @ 9181'; SSSV: None, nipple @ 523' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sand on 6/27/97. Intervals treated (measured)ORIGINAL 9283'-9303', 9308'-9332', 9338'-9380' Treatment description including volumes used and final pressure Pumped 229.3 Mlbs of 20/40, 12/18, and 10/14 ceramic proppant into formation, fp was 6610 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 468 259 653 1325 200 . Subsequent to operation 662 390 950 1329 211 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas .. . Suspended Service 17. S.i~lned//~ ~j Form' 10-404 Revt~/88 I hereby certify that the foregoing is true and correct to the best of my knowledge. ~-~r '~", ~-.-~.-~ ~ Title Wells Superintendent Date SUBMIT IN DU~LIG^TE~L~ ARCO Alaska, Inc. KUPARUK RIVER UNIT '~ WELL SERVICE REPORT '~ Kl(3U-13(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-13 FRAC, FRAC SUPPORT 0513971509.2 DATE DAILY WORK UNIT NUMBER 06/27/97; PUMP "A" SANDS RE-FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 4 (~ Yes' O NoI (~ Yes O No DS-YOKUM JOHNS FIELD AFC,~ CC_,~ DAILY COST ACCUM COST Signe/d~ ,~ (,"-') y ESTIMATE KD1862 230DS36ML $1 38,400 $158,235 ~--7'-_~,~ ~~ ~. Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer And I Final Outbr'Ann 1 181 PSI 800 PSI 600 PSI 1000 PSII 0 PSII 0 PSI DALLY SUMMARY PUMPED 'A' SANDS RE-FRAC , WITH 229,300# PROPPANT TO 13# PPA 12/18 PROP. TO PERFS. FLUSHED TO PERFS , LEAVING 1000# PROPPANT IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LI'I-I'LE RED SERV. AND APC EQUIP. 07:55 HELD JOB SITE SAFETY MEETING 08:03 PRESSURE TEST SURFACE LINE TO 9500 PSI. 08:13 INITIAL WHP 118'.~ ~'~:~ ?r,:~F:iT ~',~JI¥iPlNG BREAKDOWN TO 23 BPM AND 8858 PSI. PUMP 1PPA SCCc/~-i ,~v~'i'iq 20'~i 'i# 20/40 PROP. 15 BPM AND 8850 PSI. 08:19 08:21 PUMP CONDITION STAGE 15 BPM AND6450 PSI, TOTAL 83 BBLS. 08:26 PUMP 2PPA SCOUR WITH 3860# 20/40 PROP. 15 BPM AND 6546 PSI. 08:29 PUMP FLUSH WITH 50 # GEL AND SEAWATER 08:38 SHUT DOWN FOR ISIP 2431 PSI AND PUMPED PULSE TESTS. 09:28 PUMPED DATA FRAC AND FLUSHED 09:46 SHUT DOWN FOR ISIP AND CLOSURE CALCULATION. 10:39 PUMPED 465 BBLS PAD 5TO 15 BPM 6514 PSI. 11:17 PUMPED 2PPA STAGE 11,579# 15 BPM AND 6506 PSI. 11:29 PUMPED 211,251# 12/18 PROP. 6 TO 13 PPA, CUT PROP AND RAMPED TO 13 PPA, 20,000 # PROP SHORT, TREATING PRESSURE INCREASING RAPIDLY. 12:35 FLUSHED COMPLETELY TO PERFS., AND SHUTDOWN. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $839.00 APC $6,700.00 $10,900.00 DOWELL $130,000.00 $130,000.00 HALLIBURTON $0.00 $10,266.00 LI~-FLE RED $1,700.00 $6,230.00 ,, TOTAL FIELD ESTIMATE $138,400.00 $158,235.00 ARCO Alaska, Inc. -~ ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1997 Mr. ~David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORIGINAL Subject: 3M- 13 (Permit No. 87-40) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent workover operations on KRU 3M-13. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSldskad ,Gas Cons. ...,,,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~"MMISSION 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. 87-40 '3. Addres~ ............. 8.'APl Numbe( P. O. Box 100360, Anchorage, Alaska 99510 50-029-21720 973' FNL 1607' FEL Sec. 25 T13N R8E UM f'~~ ;.~~; ! Kuparuk River Unit At top of productive lnterval i EAT~ ' [ ~ [ i10 Well Number 1072' FSL, 4485' FEL, Sec. 19, T13N, RgE, UM i ' ' ;~! ' 3M~13 At tot,al depth , 'i .... };}}Tr~.i~-~,E-~ I&!F&~; 11. Field and P°ol- 1191 FSL, 4786 FWL, Sec. 19, T13N, RDE, UM ~ Kuparuk River i~. Eievati0,n in feet (indic-ate KB~-DF~ etC.) 16. Lea¢'e~~T~r~ and Serial No. RKB 63 I ADL 25512, ALK 2553 12. Date Spudded 113. DatoT.D. Reached ll4. DateOomp.,Susp.,orAband.ll5. Water depth, ifoffshore il6. No. of Com¢ietions 5/23/87 5/28/87 6/20/97 .. . t ....... N/A MSLI TWO 17. Total Depth (MD+TVD)i 18. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV Set[j2.1. ThickneSs'of Permafrost 973_4 ...... _6538______Fll .......... 95_9__8. ....... 643_9 .... FT!l i-lYes [~No ]~ ............ N!._A_____M__D../ 1650, (Approx.) 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD CAS'lNG ....... S E.iLi:.i~iG DEPTH HOLE ........ _S_!zE ..... ._V~.__._?_E__R F~: .......... .G____F~,.___DE_ ............ T__0__P_ ..... B__0___TTOM ....... SIZE ..... CEME_N__T. ING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf. 115' 24" 200 sx CS II 9.625" 36.0# J-55 Surf. 4887' 12.25" i1700 sx CS III & 400 sx Class G 7" 26.0# J-55 Surf. 9689' 8.5" 350 sx Class G & 175 sx AS I ................................... 24. PerfOrations OPen to Production (MD+TVD of Top and Bottom 25. TUBING REcoRD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 9206' 9182' MD TVD MD TVD ............................................................................................... 9320'-9323' 6238'-6241' 26. A----~iD, FRACTURE, OEMENT SQUEEZE, ETC. 9340'-9379' 6253'-6281 ........ 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production ........ iMethod of Operation (Flowingi"gas lift', etc.) .............. L1 .................. J ............................ -: ................................. Date of Test -Iours Tested !PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S~ZE i GAs-O~L RATIO i TEST PERIOD ' '~-10WT'ub[ng Casing PreSsureCAI-CULATED · O~L-BBL GAS-McF WATER-BBL OiL (~-I~-(/ITY--,~-P-i (-(~0Rl~i .............................. Press. 24-Hour RATE 28; ....... CCRE D A:I:'A ...................... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or wat~ ~~q~o~~ JUL 1 8 1997 :crT 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic M ark,,..,~ 30. ~ Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Annulus left open - Freeze protected well with diesel. 3i. LiSt of ~ttaChments ........... Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is ~rue--~.-nd C~-rre~::t--~O-fl~--~-est -~--~y, k~-~v~i~d-~-e- .......................................................................................... Signed 1.~'~' J~. ~.~.,_.....-- Title ~""~t~.~.t.~.,,,~ ~'~'-~l~& Date ............... P-~epare~ By Name/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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 only 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'. Form 10-407 Rev. 07-01-80 Date: 7/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3M-13 RIG:NORDIC WELL ID: 998787 TYPE: AFC:--998787 AFC EST/UL:$ 305M/ 455M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:06/04/97 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21720-00 06/04/97 (C1) TD: 9734' PB: 9599' SUPV:RLM DAILY:$ 06/05/97 (C2) TD: 9734' PB: 9599' SUPV:RLM DAILY:$ 06/06/97 (C3) TD: 9734' PB: 9599' SUPV:RLM DAILY:$ 06/07/97 (C4) TD: 9734' PB: 9599' S UP V: RLM DAILY: $ 06/08/97 (C5) TD: 9734' PB: 9599' SUPV:RLM DAILY: $ 06/09/97 (C6) TD: 9734' PB: 9599' S UP V: RLM DAILY:$ ND NU MW:ll.3 BRINE Move rig from 3M-11 to 3M-13. Accept rig at 01:30 6/4/97. Held prejob safety meeting. Change well over to seawater. Weight up brine from 10.9 to 11.3 ppg. Kill well with 11.3 ppg brine. Shut in well. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 PULL TUBING MW:ll.3 BRINE Weight up mud to 11.3 ppg. Pumped salt pill followed by brine. Well dead. ND tree, NU BOPE. Test BOPE to 300/3500 psi. Tested all mud manifold valves to 300/3500 psi. Test choke manifold and surface valves. Had 10 psi/minute leak in manifold. No visible leaks. Ail confined spaces where choke lines penetrated were inspected. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 CIRCULATE ABOVE FISH MW: 0.0 Pull tubing hanger to floor. CBU. No gas or oil cut on bottoms up. POOH with 2-7/8" tubing. RIH with fishing BHA. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 RUN IN WITH OVERSHOT MW:ll.3 BRINE Test kelly valves to 300/3500 psi. CBU. Work over fish. POOH. RIH w/washover shoe. Wash over fish. Had small bridge at top of fish. Pumped 2 hi vis sweeps on top of packer. Had formation sand and scale returns. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 CIRCULATE MW:ll.3 BRINE Spot pill on top of packer. Wash to top of fish. Engaged tof at 9299' Fish had fallen 41' while making trip. Jar on fish. Fish started working down hole when recocking jars. Get off fish due to lack of working room with kelly. Circulate to clean hole. No major sand or metal to surface. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 RUN SLICK LINE MW:ll.5 BRINE Mix pill, monitor well and POOH. Hole taking incorrect fill, slight flow. Brine cut from 11.3 to 10.8 ppg on bottoms up. Had a small amount of gas, mostly water cut. Increase weight to 11.5 ppg. POOH. Pre-job safety meeting. RIH w/2-7/8" tubing to 9270' 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 Date: 7/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 06/10/97 (C7) TD: 9734' PB: 9599' SUPV:DEB DAILY:$ 06/11/97 (C8) TD: 9734' PB: 9599' SUPV: DEB DAILY:$ 06/12/97 (C9) TD: 9734' PB: 9599' SUPV: DEB DAILY: $ 06/13/97 (C10) TD: 9734' PB: 9599' SUPV:DEB DAILY:$ 06/14/97 (Cll) TD: 9734' PB: 9599' SUPV: DLW DAILY: $ 06/15/97 (C12) TD: 9734' PB: 9599' SUPV:DLW DAILY:$ 06/16/97 (C13) TD: 9734' PB: 9599' SUPV:DLW DAILY:$ 06/17/97 (C14) TD: 9734' PB: 9599' SUPV:DLW DAILY:$ RUNNING BAILER ON SLICKLI MW:ll.5 BRINE CBU. Work OEJ barrel over slick stick to 9311'. Well flowing. Circulate around. No water or gas cut at bottoms up. Run bailer and gauge ring, recover some frac sand. Run retrieving tool for standing valve, did not recover standing valve. Make several bailer runs, recovering frac sand in each bailer run. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 POH WITH 2-7/8" TUBING MW:ll.5 BRINE Several bailer runs, recovering frac sand. Run GS retrieving tool, no recovery. Run 1-3/4" bailer, sticky, bailer full of frac sand. Tagging same spot @ 9312'. Run retrieving tool, no recovery. Run 2-1/4" LIB, no marks except sand. Sand fill staying at top of packer, not making any progress cleaning out tailpipe. RD slickline. Circulate. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 RIH WITH FTA %6 MW:ll.5 BRINE Set test plug. Test BOPE to 250/3500 psi. RIH with FTA to 9277' CBU. Wash down over fish to 9298'. Attempt to catch fish. POH with FTA %5. 0 CUM:$ 0 ETD:$ 0 EFC:$ BURNING OVER PKR @ 9323' MW:ll.5 BRINE RIH w/fishing BHA %6. Work over top of fish @ 9294' . Unable to circulate work and jar on packer assy. POOH. RIH w/ BHA %7 on 3.5" DP. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 BURNING ON SLIPS OF PKR @ MW:ll.5 BRINE Burn over 7" x 2-7/8" CAMCO PKR from 9318' to 9321' POOH. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 POOH MW:ll.6 BRINE Pick up kelly and work over slick-stick start burning over 7" x 2-7/8" Camco packer 9321' to 9326' Packer moved down hole 5'. Work over fish top of slick-stick @ 9308' and down to 9318' Packed off unable to circulate. Fish came free. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 TIH W/OVERSHOT MW:ll.6 BRINE Continue to POOH w/fish. Recovered slick-stick + 2' of packer. Held safety meeting. P/U kelly and work over top of packer @ 9318' and down to 9325'. Try to burn over, fish turning made no hole. Pump dry job. POOH. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 C/O FRACSAND & JUNK F/934 MW:ll.5 BRINE RIH with short catch overshot dressed w/2-7/8" grapple. Work over top of packer @ 9320' Pull 195K packer moving up hole. Swabbing and dragging 20 to 40K. Continue to POOH fish dragging. Quit swabbing but not taking the right amount of mud. Recovered total packer assy. L/D fish. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 Date: 7/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 06/18/97 (C15) TD: 9734' PB: 9599' SUPV:DLW DAILY:$ PULL AND LAY DOWN 3.5" DP MW:ll.5 BRINE Clean out from 9345' to 9580'. Circulate, hole continues to make frac sand. Set Baker 7" storm packer 40' below rig floor. N/D BOPE and test to 5000 psi. N/U BOPE. Test BOPE to 250/3500 psi. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 06/19/97 (C16) TD: 9734' PB: 9599' SUPV:DLW DAILY:$ RUN COMPLETION MW:ll.5 BRINE Continue to circulate @ 9575'. POOH slow hanging up on junk to 9257'. Circulate til hole clean on frac sand. Rerun 2-7/8" tubing completion w/jewelry. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 06/20/97 (C17) TD: 9734' PB: 9599' SUPV:DLW DAILY:$ RELEASE RIG MW: 0.0 BRINE Land tubing. Set Baker packer. N/D BOPE. N/U tree. Test tree to 250/5000 psi. Release rig @ 1430 hrs. 6/20/97. 0 CUM:$ 0 ETD:$ 0 EFC:$ End of WellSummary for We11:998787 STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed' Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well O t h e r 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 973' FNL, 1607' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1072' FSL, 4485' FWL, Sec. 19, T13N, R8E, UM At effective depth 1157' FSL, 4699' FWL, Sec. 19, T13N, R9E, UM At total depth 1191' FSL, 4786' FWL, Sec. 19, T13N, R9E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 12. Present well condition summary Total Depth: measured true vertical 9734' feet 6538' feet 6. Datum elevation (DF or KB) 63 RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number ;~M-1;~ 9. Permit number/approval number 87-40 10. APl number 5o-025-21720 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 9 5 9 8' true vertical 6439' feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4850' 9 5/8" 9689' 7" measured 9269'-9303', true vertical 6196'-6228', Cemented 200 sx CS II 1700 sx AS III & 400 sx Class G 350 sx Class G & 175 sx AS I 9308'-9332', 6231'-6248', 9338'-9380' 6252'-6283' Tubing (size, grade, and measured depth) 2-7/8", J-55 tbg w tail @ 9181' Packers and SSSV (type and measured depth) HRP-I-SP pkr ~ 9150' & TRDP-1A-SSA SSSV @.179.81 13. Stimulation or cement squeeze summary See attached well report Intervals treated (measured) See attached well report Measured depth 115' 4887' True vertical depth 115' 3416' 9689' 6505' Treatment description including volumes used and final pressure See attached well report 14. Regresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 5 8 5 638 -0- 1180 145 Subsequent to operation 21 5 2 '---~' 1242 -0- 15. Attachments ~16. Status of well classification as: Copies of Logs and Surveys run -- I Water Injector Daily Report of Well Operations X Oil ....X.. Gas Suspended 17. I hereby certify thai the foregoing is true and correct to the best of my knowledge. 12OO 169 Service Si~lned C' ('~}' ~ --orm 10-404 Rev 09/12/90 Title Operations Engineer Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Rlcl~fi®ld Company WELL " PBDT ~TRACTOR REMARKS tFIELD - DISTRICT- STATE ~., ~ mR.~K. I~',,,/~ '~.. OPERATION AT REPORT TIME WELL SERVICE REPORT IDAYS l DATE I ? Illj '~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. I Chill Factor J Visibility !Wind Vol. Report i *FI OF Stgn~l STATE OF ALASKA AL-A~SKA OIL AND GAS CONSERVATION COMM~iON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service RaE, UM R9E, UM R9E, UM Location of well at surface 973' FNL, 1607' FEL, Sec. 25, T13N, RaE, UM At top of productive interval 1072' FSL, 4485' FWL, Sec. 19, T13N, At effective depth 1157' FSL, 4699' FWL, Sec. 19, T13N, At total depth 1191' FSL, 4786' FWL, Sec. 19, T13N, 12. Present well condition summary Total Depth' measured 9734' true vertical 6538' feet feet 6. Datum elevation (DF or KB) 63 RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-13 9. Permit number/approval number 87-40 10. APl number 5o-029-21720 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool Plugs (measured) None Effective depth' measured 9 5 9 8' true vertical 6439' feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 1 6 '° 200 sx CS II 4850' 9 5/8" 1700 sx AS III & 400 sx Class G 9689' 7" 350sxClassG& 175 sx AS I measured 9259'-9303', 9308'-9332', 9338'-9380' true vertical 6196'-6228', 6231'-6248', 6252'-6283' Tubing (size, grade, and measured depth) 2-7/8", J-55 tbg w tail @ 9181' Packers and SSSV (type and measured depth) HRP-I-SP pkr @ 9150' & TRDP-1A-SSA SSSV @ 1798' 13. Stimulation or cement squeeze summary See attached well report Intervals treated (measured) See attached well report Measured depth 115' 4887' True vertical depth 115' 3416' 9689' 6505' RECEIVED $ E P 1 2 · ~l~it~ ~li ~ ~g~ ~UiI~, ~Uiltiilig¢~v'' Anchorage Treatment description including volumes used and final pressure See attached well report 14. Pressure Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1 5 2 6 581 -0- 1230 1 5 8 5 638 -0- 1180 Tubing 135 145 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby_certify that the foregoing is true and correct to the best of my knowledge. Signed ~~'~. ~ Tit, e Senior Operations Engineer Form 10-404 Rev 09/12/90 Date ~ '''~'~ *''?/ SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subs~chary of Atlantic Richhetd Company WELL SERVICE REPORT :FIELD- DISTRICT-~TATE ', ,~. ,6. /Z ~ [DAYS ~ DATE / ; ~-~e,~- ~/ /o lOZG ..q' oo 7/0 Alaska 0il & Gas Cons. Commissim't ~CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~/~ /(~) 'Ancr~orage _~/eather Temp. Chill Factor ; Visibility :Wind Vel. Signed ARCO Alaska, Inc. Date: November 4, 1988. Transmittal #: 7343 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Q-05 1Y-16 3K-06 31-02 2H-08 2D-06 3H-18 3M-13 Kuparuk Fluid Ku3aruk Fluid Ku3aruk Fluid Ku 3aruk Fluid Ku:3aruk Fluid Ku3aruk Fluid Ku 3aruk Fluid Ku~3aruk Fluid Level Report I 0 - 2 5 - 8 8 Casing Level Report 1 0 - 2 5 - 8 8 Casing Level Report 1 0 - 2 5 - 8 8 Casing Level Report 1 0 - 2 2 - 8 8 Tubing Level Report I 0 - 3 0 - 8 8 Casing Level Report I 0 - 3 0 - 8 8 Casing Level Report 1 0 - 3 0 - 8 8 Casing Level Report 1 0 - 3 0 - 8 8 Casing Receipt Acknowledge '<~~~-- ate: DISTRIBUTION: D&M State of Alaska Mobil Chevron Unocal SAPC . ORIGINAL · STATE OF ALASKA ALASK"~' OIL AND GAS CONSERVATION'~'O~'MISSION 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. 87-40 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21720 4. Location of well at surface 9. Unit or Lease Name 973' FNL, 1607' FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1072' FSL, 4485' FEL, Sec.19, T13N, R9E, UM 3M-13 At Total Depth 11. Field and Pool 1191' FSL, 4786' FWL, Sec.19, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 63' ADL 25512 ALK 2553 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 05/23/87 05/28/87 09/22/87*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey [ 20. Depth where SSSV set I 21. Thickness of Permafrost 9734'MD, 6538'TVD 9598'MD, 6439'TVD YES ~I~ NO [] 1798' feet MD 1600' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, Gryo 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 200 sx CS II 9-5/8" 36.0# J-55 Surf 4887' 12-1/4" 1700 sx CS Iii & 400 s~ Class G 7" 26.0# J-55 Surf 9689' 8-1/2" 350 sx Class G & 175 s~ AS I 24. 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) 9320'-9323'MD 6238'-6241 'TVD 2-7/8" 9181 ' 9150' 9340'-9379'MD 6253'-6281 'TVD ~6. ACID, FRACTURE, CEMENT SOUEEZE, ETC~ Perforated w/4 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Adden(lum~ dated 9/28/87, for fracture d~,ta. 27. N/A PRODUCTION TEST , Date First Production Method of Operation (Flowing, gas lift, etc.) Date of-I:est Hours Tested PRODUCTION FOR OIL-BBL GAS-McF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE i~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~ ~,i,~ ~ .~,-,' ,~ *Note: Drilled RR 5/31/87. Well perforated & tubing run 8/18/87. Well fractured 9/:~,~Iz-&;~;~9 Wc~;/~~, :DAN I Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. , ' 30. ' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 9266' 6200' N/A Base Kuparuk C 9283' 6212' Top Kuparuk A 9283' 6212' Base Kuparuk A 9472' 6348' 31. LIST OF ATTACHMENTS Addendum (dated 9/28/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~/~/7~/~ .~ ~/.~(A~L~ Title Associ ate Engineer Date /0-/~-~ 7 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and 'log on all types of lands and leases in Alaska. Item 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 only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 6/23/87 8/02/87 9/22/87 3M-13 Arctic Pak well w/175 sx AS I & 60 bbls Arctic Pak. Rn CBL/CCL/GR; tl malfunctioned. Rn gyro to 9575'. Frac Kuparuk "A" sand perfs 9320-9323' & 9340'-9379' in ten stages per procedure dated 9/14/87 as follows: Stage 1: 100 bbls gelled diesel @ 10-20 BPM, 6426/5000/4900 psi Stage 2: 500 bbls gel diesel @ 20 BPM, 4800-4700 psi Stage 3: 30 bbls gel diesel, 2 ppg 20/40 sand @ 20 BPM, 4485 psi Stage 4: 50 bbls gel diesel, 4 ppg 20/40 sand @ 20 BPM, 4350-5100 psi Stage 5: 50 bbls gel diesel, 6 ppg 20/40 sand @ 20 BPM, 5500-5900 psi Stage 6: 50 bbls gel diesel, 7 ppg 20/40 sand @ 20 BPM, 6750-6500 psi Stage 7: 30 bbls gel diesel, 8 ppg 20/40 sand @ 20 BPM, 6750-6800 psi Stage 8: 30 bbls gel diesel, 9 ppg 20/40 sand @ 18 BPM, 6731-6770 psi Stage 9: 20 bbls gel diesel, 10 ppg 20/40 sand @ 18 BPM, 6639-7000 psi Stage 10:56.8 bbls gel diesel flush @ 20 BPM, 6829-5330 psi Fluid to Recover: Sand in Zone: Sand in Csg: 765 bbls 52,050~! (calculated) 5181! August 10, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70047 Well: 3M-13 Field: Kuparuk Survey Date: August 3, 1987~ Operator: T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry-Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 2 0 C! :200.,, 00 .1:3.7.,. 0..0. .................................. E! ................... 'R ................... S..... fZ..0..,. ?_,'.0......E .................................... 0.....D.5./. ................................. 0L,.1.5_ '._S .......................................... 0_..23_.E .......................................... O...1.7. :300 :'300 ,,. !:::, 0 . ..2;3-Z,....c!.0 ................................... O. ............ .1, 5 .... ;5.'; ..'::5:3..:::._,'.C~ . 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' :' .: ........... ======================================== ili:?~,: ;~;::. ,~:~.~.:::¥1::~z¥:!?x::::?.~.i,::::~:::~i:;ii~:.: ::ii~::.:' ?i:,4:. ~::: ~:~ :::~ :~i;i:.:~:~:::' ,: :: ~.: :. '.: .'.:~: , ,:' .~i .:. : ..~:>::.:,. d:, -- ARC:O ALAS.KA, !NC: ...... ...... --~ .-~ ~'-. - '-- -'-, I~ ,.:, M-i .-, ( .:, E L..,:. o. T 13 N .. R 0 ~.:.:E. ) ................................................................................................... CO MF.'.:U T A ]'...I.ON..-DA]'.E K':UF.'.AF.:U}L_FZZEI..D ............................................................................................ ALIGLJST[;.....,~.., ......... :I..:-2~Z ..................... ._.UDB NUMBER Ak::=BD-7r~047 .......~ "fT::LIE ....... ~ .... ~::::~:SUI::;:ED ..!JE!:;:T I CAL. fie F'"I' H Ii E:'. 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" ~--~ I;2' ~" · I.'4' -- ~ °~ "~I 7.-./04 ..... z./z,.L-:. (..)L.~ ._,z()t_) t)t) :1/',-, ,- W.-, ~ . ,1 71 7., F .... ... · . · .. . · · .... :....:.:::~. :..;~::m......~.....~. :..: .. ::.:....: :: ...... .... · - .n~.: . :.: ~ ~?..-.~? ~, · . ~" ~' :~ 'C~ '~* '. . · ~,~ ~ · "'~ -':?:~': :~.:: : '. :'.:'::. L'. , ,~t: ~i*:' :'...' .: · ~:,~¢ ~ .t~'~:h:¢~ ....... ' ~ 4 ~ ..~ ~"~ ~:~.: ~" ~"~ "~: ~:~'.~:.~': ~ ~:~; ~.: 'C:::~::: .~' .::." :~ .:.:.... · :'::: . ' .~:~:~:.,.:~'~,::.~.~:~;.~ . : . .. ~ ~" ~' '~·" t ? ~ " ~...~...~ ... ~ ~: .~:.. . ,~ ~ : . ~. ~ -:.. ~.~ .~::~.~, ~.,. ¢,.... ,:?~:~. ~.:~ ..x.~,.~: ~D~ ::::::::::::::::::::: ::':::..l:::: ..: .:..::..:::: . ...:. .: ............ ,..:::......u~: ....:.' ' ~.:r~ '.~.: .... .:.:. ,~ ,, ~ : : ,. ~ .:: ,... , .;. :.::... :..:~ :. :.: ~..: ~:..: .,.:. .... : ,..:~. ':' :.: . ' v.:v.: ...... :: ::::::":.::'::~:~-:~;:.::,~::*':~'"~" : ,~1 :/Y ~,4. A:-:.0~) .' 54o0,00'::.: .'::.:.~':....'1.76:Z., ~4" 'N. ':'' ...5~:~'~'::~ ~_~ .... ~._, 4 7 .~.~_~._,oc~. oo..:...: ....~..;:.. ~:.,:...:.::~:.:~ :DO0. ~,,:. E~ .. ~ .... ......=..:.:~4 ~:~4.~:..:~4~:~:*~:~:~~~:~:~:;~:~:~.~.:~:~:~:::~:~:~:~.~:.:?~.~::::,. .. ......ARC:FI At A::;k'A T NC: ............ .. . ?T :-~' T ~,: ~: ":"" ~'' ~' ....... ' :" :' ] .... -' ',.,,~'"' ~;~$~!~:~.~.:.' .............. ... ::.: :..... ................................................ ~TERPOLATED VALUES FOR ,EVEN_· 1OO ' · ' !~.::.::):fg,;~:~g :',":' '-> ag~:.'~ ': ....... . ...... -: [::[",, I. 1' [h':::lL ....... ] ~:]~tT I I_-:(:.~,1_ I::~E f::TANf]il I~Jl_[:::%l::;L ......... I"_.].!] I]I F( I] ]:_ N -AT'F~-; NIKI-TVFI .VFRT T_ I-:Al liEF'TH I,".~EF'TH NORTH/E:OLITH EAST/WEST D I FF~ERENCE CORRIECT I ON <': 0 00. 0 C) .1. '::?'.:.? ::!:. C) F-., N ~, .1. O0 ,, ()0 20:3 .1...1. :.:3 Iq 6.2!']. !'-!.....0 .Q ...................... 2£t,:_,..:Z ~, .::2,..'a._. _>J ........ ~, :3, "] 0 ,. 0 C) 2.1. ('-~ :3.3,'L:', N ,:'~., 4 0':::~ ,, 0 0 '21:2,'7 ,, '7'::) N MEASURED DEF'TH ............. TV[ ------~ .: ........ ::~ TM ::[ CKNE$$:. 141: TN MARKER .......... AD. .......................................................................................................................................................... .c,.EI ....... ..ca .......I.:L':Z ........F~.IL).::z t:' ................................... ,, , l ...-,~-.SPERBY-SUN · , , KUPARUK'F.IE~e · . 5M-tSISEC25:T13N ROSEi . · , AK-B~70047 ' TRUE NORTH· -1060. O0 --1000. O0 HOB I ZONTFtL PROJECTION ARCO ALASKA, INC. AUGUST 3, 1987 O. O0 tSOO. O0 SPERRY -SUN 5CRLE KUPRRUK FIELD 3H-i3(SEC25 T13N ROBE) RK -Bl~ -70047 :- 1 INCH TO 1500.00 /' 1500.0... : ,:;_': . ARCO ~L.-,RSKA, INC. :.~;'., · RUGUS T~.~:y 198"/.. ?..~ ). ,%:..~.. 3000.00 4500.00 I · . :.-'c ??_ . ;; I 600O.-O0 -~:-,.-; /': .J "' :'/ ' · ' ' 6588. t6 7500.00 I I / t500. O0 8000.00 4500.00 9734 6Q~O. O0 VERT I CFtL PROJECT I ON I 7500. OC ARCO Alaska, Posl Office dox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 15, 1987 Transmittal ~:6054 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3C-16 Kuparuk River Unit 'A' Sand 100598H' 8-26 thru30-87 2Z-1 Kuparuk River Unit 'A' Sand 100557H 8-31 thru9-2-87 3Q-2 Kuparuk River Unit PBU 100559H 8-25 thruS-29-87 3M-12 Kuparuk Well Pressure Report(Otis) Static A Sand 9-3-87 3M-13 Kuparuk %~11 Pressure Report(Otis) Static A Sand 8-28-87 3M-14 Kuparuk Well Pressure Report(Otis) Static A Sand 9-1-87 1Y-14 Kuparuk Well Pressure Report(Camco) C Sand 8-23-87 1Y-6 Kuparuk Well Pressure Report(Otis) 8-21-87 1Y-5 Kuparuk Well Pressure Report(Otis) Static C Sand 8-23-87 1Y-16 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-11 Kuparuk Well Pressure Report (Otis) Static 8-21-87 1Y-9 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-3 Kuparuk Well Pressure Report (Otis) Static C Sand 8-22-87 2X-14 Kuparuk Well Pressure Report (Otis) Static C Sand 7-18-87 2Z-1 Kuparuk Well Pressure Report (Otis) Static C Sand 7-2-87 2X-10 Kuparuk Well Pressure Report (Otis) C Sand 7-19-87 Receipt ~cknowledged: DISTRIBUTION: <ka 0il & Gas Cons. Commission Anchorage · D&M ,,~-,~State'of-Alaska BPAE Chevron Mobil SAPC ARCO Alaska, InC. Is a Subsidiary o! AllentlcRIchlleldCompany Unocal ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September I0, 1987 Transmittal #6051 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one s~gned copy of this transmittal. 3M-15 Cement Bond Log 8-3-87 5381-7397 3M-17 Cement Bond Log 8-5-87 6200-8564 3M-19 Cement Bond Log 8-10-87 6500-8794 3M-22 Cement Bond Log 8-12-87 7890-9598 3M-18 Cement Bond Log 8-21-87 7689-8410 3M-14 Cement Bond Log 8-2-87 4903-7108 3M-13 Cement Bond Log 8-3-87 7495-9559 3M-20 Cement BondL0g 9-1-87 8700-10687 3M-11 Cement Bond Log 8-1-87 5252-7802 3M-16 Cement Bond..Log 8-4-87 -7834 3M-lO Cement Bond Log 8-9-87 4700-7039 3M-12 Cement Bond Log(Coiled Tubing Conveyed) 8-12, 13-87 7403-10380 Receipt Acknowledged: DISTRIBUTION: NSK Dri~ State of Vault(film) ARCO Alaska, Inc, Is a Subsidiary of AllanticRIchfleldCompany STATE OF ALASKA ALA3r',,-, OIL AND GAS CONSERVATION COI~,,,',,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown i~ Stimulate [] Plugging [] Perforate J~ Pull tubing Alter Casing [] Other IX] COMPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 973' FNL, 1607' FEL, Sec.25, T13N, R8E, UN At top of productive interval 1072' FSL, 4485' FEL, Sec.19, T13N, RgE, UN At effective depth 1157' FSL, 4699' FWL, Sec.19, T13N, RgE, UN At total depth 1191' FSL~ 4786' FWL~ Sec.19, T13N~ RgE, UN 11. Present well condition summary Total depth: measured 9734 'ND true vertical 6538'TVD 5. Datum elevation (DF or KB) RKB 63 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-13 8. Approval number 7-441 9. APl number 50-- 029-21720 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet Feet Date Submit in Duplicate~ Effective depth: measured 9598 'MD true vertical 6439 'TVD feet Junk (measured) None feet Casing Length Size Conductor 80 ' 16" Surface 4850' 9-5/8" Producti on 9689 ' 7" Cemented Measured depth 200 sx CS II 115'MD 1700 sx CS III & 4887'MD 400 sx Class G 350 sx Class G & 9689'MD 175 sx AS i True Vertical depth 115 'TVD 3416 'TVD 6505 ' TVD Perforation depth: measured true vertical 9320'-9323'MD, 9340'-9379'MD 6238 '-6241'TVD, 6253 '-6281'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tubing w/tail ~ 9181' Packers and SSSV (type and measured depth) HRP-1-SP pkr ~ 9150' & TRDP-1A-SSA SSSV @ 1798' 12. Stimulation or cement squeeze summary RECEIVED Intervals treated (measured) Treatment description including volumes used and final pressure ~ ~D ]. 8 ],987 0il & Gas 13. Representative Daily Average Production or Iniection DataA!ask~ Anch0m_ge. N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Compl etlon Wel 1 Hi story) Daily Report of Well Operations I~ Copies of Logs and Surveys Run I~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ '~---~' ~'" ?Z Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW02/76 ARL;~, Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length o! time. On workovers when an official lest is not required upon completion, reporl completion and representative test data in blocks provided. The "Ftr~al Report" form may be used for reporting the entire operation if space is available. District ~County or Parish Alaska J North Slope Borough Field ~hease or Unit Kuparuk River I ADL 25512 Auth. or W.O. no. )Title AFE AK2131 I Completion I Accounting cost center code Slate Nordic ~'/1 API 50-029-21720 Operator IA.R.Co. W.I. rrota~ number of wells (acfive or inactive) on this, ARCO Alaska, Inc. J 56,24Z tc°st center prior to plugging and abandonment of this well Spudded or W.O. begun lDate Hour ]Prior status if a W.O. Complete I 8/17/87 0900 hrs. 8/]8/87 Date and depth as of 8:00 a.m. 8/19/87 Old TD Complete record for each day reported Alaska IWell no. 3M-13 7" @ 9689' 9598' PBTD, Setting pkr ]0.0 ppg NaCl/NaBr Accept..ri~ @ 0900 hrs, 8/17/87. ND tree, NU &tst BOPE. RU & perf 9340'-9379' & 9320'-9323' @ 4 SPF. Make GR rn to 9564'. RU & rn 2-7/8" compl. 7" @ 9689' 9598' PBTD, RR 6.8 ppg Diesel Rn 278 jts, 2-7/8", 6.5#, J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1798', HRP-1-SP Pkr @ 9150', TT @ 9181'. Tst tbg & ann to 2500 psi; OK. ND BOPE, NU &tst tree to 250/5000 psi. Displ well w/diesel. RR @ 1030 hfs, 8/18/87. RECEIVED S[.{P !S87 Alaska 0il & G~s Cons. C0m~l$ Anchorage Released rig 9598' PBTD I New TD I PB Depth Date JKind of rig 1030 hrs. 8/18/87 I Rotary Classifications (oil, gas, etc.) J Type completion (single, dual, etc.) Oil I Single Producing method I Official reservoir name(s} Flowing I Kuparuk Sands Potential test data Well no. :Date Reservoir I Producing Interval Oil or gas Tesl time IProduclion Oil on test Gas per day .... Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity ;Allowable Effective date Corrected .... The ~,~ t~ ~^~r~t Signature J Date ITitle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent AR3B-459-3-C INumberalt daily well history forms consecutively Page no. I as they are prepared for each well. I 1 I Dlvl~on of AIIsntlcRIchfleldCompen¥ ARCO Alaska, Inc. Post Offic/~- 120360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 Date: July 22, 1987 Transmittal # 6003 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 ~ransmitted herewith are the following items. Please acknowledge .receipt and returff one signed copy of this transmittal. 3M-15 OH Lis Tapes 6-19-87 #72365 3M-16 OH Lis Tapes 6-11-87 #72361 3M-13 OH Lis Tapes 5-28=87 #72348 3M-17 OH Lis Tapes 6-30-87 #72405 3M-18 OH Lis Tapes 6-24-87 #72375 3M-14 OH Lis Tapes 6-4-87 #72353 3M-12 OH Lis Tapes 5-21-87 #72329 Receipt Acknowledged: DISTRIBUTION: M. Stanford · ~;;State"of Alaska?~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA AL/-,_ .,A OIL AND GAS CONSERVATION COM~v~I~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well ~ Alter casing kT; Time extension ~ Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order ~ Perforate ~ Other 2. Name of Opera. tor ARCO AlasKa, Inc 3. Address P. 0. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 973' FNL, 1607' FEL, $ec.25, At top of productive interval 1291 ' FSL, 868' FEL, Sec.19, At effective depth T13N, R8E, UM T13N, R9E, UM (approx) 1281' FSL 4636' FWL, Sec 19, T13N, R9E, UM (approx) At total depth ' ' 1321' FSL, 4720' FWL, Sec.19, T13N, RgE~ UM (approx) 11. Present well condition summary Total depth: measured 9734 'MD feet Plugs (measured) true vertical 6540 ' TVD feet 5. Datum elevation (DF or KB) R KB 6 3 ' feet 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-13 8. Permit number R7 -/~(~ 9. APl number 50-- 029-21720 10. Pool Kuparuk River Oil Pool None Effective depth: measured 9598 ' HD true vertical 6441 ' TVD Casing Length Size Conductor 80 ' 1 6" Surface 4850 ' 9-5/8" Production 9689' 7" feet Junk (measured) feet None Cemented 200 sx CS II 1700 sx CS II I & 400 sx Class G 350 sx Class G Measured depth 115'MD 4887'MD 9689'MD Rue Verticaldepth 115'TVD 3416'TVD 6507'TVD Perforation depth: measured None true vertical None ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None RECEIVED ,Alaska 0il & Gas Cons. Co~,,missior~ Anchorage 12.Attachments WELL HISTORY Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ (/~~ .,~,fJ..L~.,, Title Ass ge ~ te Engineer Commission Use Only (Dani ~ ~A?/¢,1 approval Notify commission so representative may witness I Approval Conditions of No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by Date by order of · Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company "~' Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a, well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Fie~d Kuparuk River Auth. or W.O, no. AFE AK2131 Doyon 9 ICounty, parish or borough North Slope Borough Lease or Unit ADL 25512 ITitle Drill State Alaska Well no. 3M-13 API 50-029-21720 Operator ARCO Alaska, Inc. Spudded or W,O. begun Spudded J Date 5/23/87 I'°'r Date and depth as of 8:00 a.m. 5/24/87 thru 5/26/87 5/27/87 5/28/87 Complete record for each day reported 2130 hrs. ARCO W.I. Prior status if a W,O, 56.24% 16" @ 115' 4907', (4732'), ND diverter sys Wt. 9.4, PV 18, Y? 17, PH 9.0, WL 8.4, Sol 7 ~ccept rig @ 1800 hrs, 5/23/87. 'NU-diverter sys. .Spud well @ 2130 hrs, 5/23/87. Drl to & surv 12¼" hole to 4907', short trip, C&C, POOH. RU & rn 124 its, 9-5/8", 36#, J-55 BTC csg w/FC @ 4804', FS @ 4887'. Cmt w/IT00 sx CS III & 400 sx C1 "G" w/2% A-7 & 2 GHS D-6L. Displ w/wtr, bump plug. 614', 6.0°, N76.4E, 613.75 TVD, 9.51VS, 2.25N, 9.31E 1162', 24.0°, N78.1E, l139.09TVD, 155.72 VS, 30.99N, 154.72E 1915', 49.7°, N75.5E, 1737.4ATVD, 597.88 VS, 124.30N, 592.03E 2824', 57.6°, N73.1E, 2279.25TVD, 1323.84 VS, 315.79N, 1295.62E 3931', 55.2°, N69.6E, 2885.66TVD, 2248.09 VS, 588.75N, 2180.42E 4807', 56.7°, N70.6E, 3370.86TVD, 2977.40 VS, 849.19N, 2861.66E 9-5/8" @ 4887' 7190', (2283'), Drlg Wt. 9.2, PV 9, YP 3, PH 9.0, WL 8.4, Sol 6 NU BOPE & tst to 3000 psi. RIH w/BHA, tst csg to 2000 psi. DO FC, cmt, FS + 10' new hole. Chg to 8.5 ppg mud. Tst formation to 12.5 ppg EMW. Drl & surv 8½" hole to 7190'. 5383', 55.6°, N70.1E, 3691.70 TVD, 3455.70 VS, 1010.05N, 3312.17E 5952', 55.1°, N69.9E, 4015.21TVD, 3923.76 VS, 1170.14N, 3752.02E 6520', 51.4°, N67.SE, 4355.06 TVD, 4378.85 VS, 1334.35N, 4176.48E 7053'. 48.9°, N66.2E, 4696.60 TVD, 4787.69 VS, 1494.24N, 4553.15E 9-5/8" 9650', Wt. 10 Drl to 7620', 8188', 8749', 9287', @ 4887' (2460'), Drlg .0, PV 12, YP 6, PH 9.0, WL 4.0, Sol 11 9650'. 47.8°, N65.4E, 5073.42 TVD, 5210,54 VS, 1667.91, 4939.59 47.5°, N66.0E, 5456.06 TVD, 5629.45 VS, 1840.65, 5322.18 46.5°, N66.1E, 5838.66 TVD, 6039.05 VS, 2007.20, 5697.14 44.3°, 'N65.SE, 6216.42 TVD, 6421.43 VS, 2163.31, 6046.96 RECEIVED Alaska Oil & Gas Cons. Commissior~ Anchorage The above is correct For f~rrn'pre~ation ~'~(¥"distributionT'~ ' see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JTitle Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District lCounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25512 Auth. or W.O. no. ~Title AFE AK2131 J Drill Doyen 9 API 50-029-21720 Operator / A.R.Co. W.I. ~CO Alaska, Inc. ji 56.24% Spudded or W.O. begun Date Spudded 5 / 23/87 IAccounting cost center code state Alaska Date and depth as of 8:00 a.m. Old TD Released rig 5/29/87 5/30/87 thru 5/31/87 0300 hrs. Classifications (oil, gas, etc.) Oil Complete record for each day reported IWell no. 3M-13 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our II' I Prlor status If a W.O. / 2 3o I 9-5/8" @ 4887' _ 9734', (84'), TIH Wt. 10.0, PV 15, YP 6, PH 9.0, WL 4.4, Sol 11 Drl to 9734', short trip, C&C, spgg pill on btm, POOH. RU Schl, rn DIL/SFL/SP/SFL/GR/FDC/CAL f/9728'-8200'. Rn Fas; unable to get past 6950', RD Schl. TIH w/BHA. 7" @ 9689' 9734' TD, 9598' PBTD, (0'), RR Wt. 10.0, PV 20, YP 14, PH 8.5, WL 5.0, Sol 11 TIH, rm 9394'-9734', CBU, spot pill, POH. RU Schl, rn Fas f/9734'-4889', RD Schl. Make CO rn, POH, LD DP. RU & rn 224 jts, 7", 26#, J-55 BTC csg w/FC @ 9599', FS @ 9689', Mkr Jt. @ 9212'. Cmt w/100 sx 50/50 Pozz w/4% D-20, .2% D-46 & .5% D-65 & 250 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/10.0 ppg brine, did not bump plug. ND BOPE. NU & tst tree to 3000 psi. RR @ 0300 hfs, 5/31/87. JNewTD 9734' TD Oate 5/31/87 RECEIVED JUL t Alaska Oil & Gas Cons. Con, mission Ancr~orage 9598' PB~ Oepth Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data V~;II no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, sPa X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected _. The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle Drilling Supervisor ARCO Alaska, Inc. Posl Oflice Box 100360 Anchorage, Alaska 99510~0360 Telephone 907 276 1215 June 29, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. If Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure .].: .... ~') ~.:: 0il & Gas Cons. Comn]iss[~r~ Anchorarj~ ARCO Ab~ska, Inc. is a S[Jbsidiary of AtlanlicRichfie!dCompany ALL WELLS LOCATED IN SEC. 25, TI3N, R8E, UMIAT MERIDIAN. VICINITY MA~P SCALE I" NOTES: I. ALL COORDINATES ARE A.$J~. , ZONE 4. 2.ALL DISTANCES SHOWN ARE TRUE. ASPs 'X' LATITUDE 7'20.459 I o! I.:~ ,202.17 506,tZ6.1~9 6,225.10 506,136.41 16,248.21 506,145.91 ,271.24 506,155.5' ,294.28 506,165.0' ,317.42 506,174.6 6,016,340.48 506,184.1 6,016,363.49 506,193.5 506,205- I'~ 506,852.0; 506,9'41.5; · 2MILES $.ELEVATIONS ARE B.P.M.S.L. 4.REF. FIELD BOOK L67-3, PgL ?-rE; LI/-I, RT; LST-3,PSI - 53; 5.0.G.ELEVATIONS FROM F.R. BELL & ASSOCIATES. ~U~NTS ~R LHD ~ A~IATES. LONGITUDE Dist. EN.L. 59.43g 5g.157 '$8.316 14905 6' 506,251.07 70°; 506,260.13 700; 016,548.62 506,270.30 70°27',23'186 ,571.43 $06,2?9.77 70027.23-410 ,594.13 50~t289-40 70o27'23'639 ,617.99 506,299.05 1'0°27'23'868 6,016,641.02 506,308.76 7CP?..7~24.094 149056'$4'641 ~,/ c;/b , (,~7.~'~ 5c~,, :~ZT.,f-(,, 70'27' ~.~ o/b,/7~.~~ ~gb,//7. ~,~ 7~,Z7'/~/. /,;jcyb, 15~.77 .~ok,/~7.~J 7~27' /9.3~.J /,r/'?~'ST'DD. ~. z th Al. CRAIG L. SAVAGE 4538-S 1296 1273 1250 1204 1161 1156 1135 1112 I042 1019 996', 975 950~ 92T, 904, 23.1' 26.6' 83.2' ~6.6' 83.4 86.6 23.2~ 26-6~ 83. I, 25.0, 86.4' 2 1.7, 2 1.5 86.5 26.$ 20.9, 26.4, 80.9, 26.5, 20.9 26.5 20.8' 26.6' Dis t. F..E.L. 1741 1732 1715 1103 1694 1~84 161'5 1565' 1636 16 26 1617~ 1607 1598' t586'. 1576', 1569 1559' /5 ~*,~' /7~// / 7~ ' 858' 635 ' Z~>. ~' ZS. q' D/ z ' Z.v.,~' z5.7' / ~,I_~, z~.Q' z~.~ ' ARCO Alaska Inc. I HEREBY CERTIFY THAT I AM PROPERLY REGIS*IERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT A5 OF 3/8/87 D.S. 3M WELL CONDUCTOR AS-BUILT DWN BY: GLL CHK BY: AJR M_c~ ~_ 313 .d2 ARCO Alaska, Inc. Post Office?' 100360 Anchorage. ~oka 99510-0360 Telephone 907 276 1215 Date: June 5, 1987 Transmittal # 5993 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-13 3M-13 3M-13 3M-13 3M-13 3M-13 3M-13 3M-13 3M-13 3M-13 2" Dual Induction 5" Dual Induction 25" Dual Dipmeter 5" Porosity FDC 2" Raw Data FDC 5" Raw Data FDC 5" Dual Dipmeter Cyberlook 2" Porosity FDC · 1.2" Sam. Rate FDC 5-28-87 1800-9720 5-28-87 1800-9720 5-29-87 4889-9709 5-28-87 9050-9697 5-28-87 9050-9697 5-28-87 9050-9697 5-29-87 4889-9709 5-28-87 9150-9650 5-28-87 9050-9697 5-28-87 9050-9697 NSK Receipt Acknowledged: DISTRIBUTION: Drilling State(+ sepia) Date: Rathmell D &M Vault(film) L. Johnston(vendor pkg.) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany April 13, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3M-13 ARCO Alaska, Inc. Permit No. 87-40 Sur. Loc. 97-3'FNL, 1607'FEL, Sec. 25, T13N, RSE, UM. Btmhole Loc. 1405'FSL, 566'FEL, Sec. 19, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnifY you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~-~ t r~ly ~yo~-~f~ ~ / Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF THE CO}~4ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery r,~. , STATE OF ALASKA ALASKA ~._ AND GAS CONSERVATION CL,,,~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill~¢- Redrill EZ]I' lb. Type of well. Exploratory [] Stratigraphic Test [], Development Oil'.]?J~. Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone~']~_~Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 63' , PAD 26' feet Kuparuk River Field Kuparuk River Oil Pool i 3. Address 6. ~P.rop~e_rt,v, Desionation 'P.O. Box 100360 Anchorage, AK 99510-0360 AuL z.~.,~'~2 ~LK 2553 4. Location of well at surface 7. Unit or property Name 11. Type Bond lsee 2o AAC 25.0251 973'FNL, 1607'FEL, Sec.25, T13N, RDE, UM Kuparuk River Unit Statewide A.t tod of productive interval ~. Well number Number 129I'FNL- 868'FEL, Sec.19, T13N, R9E, UM 3M-13 ' #8088-26-27 At total depth 9. Approximate spud date Amount 1405'FSL, 566'FEL, Sec.19, T13N, R9E, UM 05/03/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depthIMD and TVD) property line 3M-1 2 9754 'MD 973'~ Surface feet 25' @ Surface feet 2560 6513'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure Isee 2o AAC 25.035 (e)(2)) Kickoff depth500 feet Maximum hole angle 53 0 Maximum surface 2032 psigAt total depth (TVD) 3109 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Ouantity of cement Hole Casing Weight Grade Coupling Length MD TVD' MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4' 9-5/8" 36.0# J-55 BTC 4580' 35' 35' 4615' 3433' 1200 sx AS Ill & HF-EI;W 340 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 9720' 34' 34' 9754' 6513' 200 sx Class G(minimum HF-EfW T0C 510' abov~ top of Kuparuk 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) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface~ i~ : Intermediate Production Liner .,. ,.~ , . Perforation depth· measured ....... : ' ' , ~., true vertical 20. Attachments Fili,n,g fee"~ Property plat [] BOP Sketch'~ Uiverter Sketch ~ Drilling program Drilling fluid progr,a,~m j2~k. Time vs depth plot [] Refraction analysis E~ Seabed report [] 20 AAC 25.050 requ/ irements/~;CL. 21. I hereby cert~ t,bt'at the foregoin/g is true and correct to the best of my knowledge · . ' - ' ., · Regional Drilling Engineer DateZ,j/._//,~,~ (~,,_,/.-~-u, /, Commission Use Only (JFB) PD2/21 Permit Number_. I APlnumber ,, 7,~_._~, IApprovaldate I See cover letter ¢ ;7 ~-/--O 50-- ¢ ~c¢ i o 0 4 / ]. 3 / 8 7 for other requirements Conditions of approval Samples required [] Yes ~No Mud Icg required E3 Yes ~t~'No Hydrogen sulfide measures [] Yes [] No DirectiOnal survey required ~ Yes E3 No Required wo~,-l~~~M; [] 10M; E~ 15M Other: by order of Approved by ~ ~', ~. v'/~/~,/~~ Commissioner the commission Date ! Form 10-401 Rev. 12-1-85 Subr~ 3ate J. , t J . . . I'1't rl,I 1,1-1 i l 1 I i j. i i 5-DEP=26~O-- J -ZONE. C 71 .ZO'N~ '~ .... 93 TVD=6332 WE! FI t_ . . t. o0o 25. r13N. . 'i Do t. I. . . I. N .69 12 . . , DE '~ :C O. TAROE : 2~ !MINE. , '' NORTHEAST. · . [ - ' 792' i FEL .... 1'40~' FSL. '$66"' ,_F'EL 3N.. RgE; '', S£C~., .'lg. '113N; '.R~iI, E 'i -- - ;'*: . . . ~ , ~850 1800 , ,I7,50 ~650 ~1600~. , ]550 ~1.500 ~ ~ ]450 ~ ~ . i : : , : .... t .' : . . . ',.'~; ~ :, ~ ,. · :, ,~ ,: ..... ~ , t,, : .... , ........... J ..... , ........~, ...... ., .... ................... : ............................... : ................... : ................. ........... _:oo ......... ................... ............................. ....... ..... .............. ' .... : ' '~'~ -- --~ -- -- ~4~ ..... ~ 1:29D ...... , ~l ........ I ': ............. i ~ ~ .......... ~ ' ', ~ +, , ..... ,~ ~ .................. , J ' ' ' ~ . ~ , ............ , .... ~ ..... ~ ..... ~:.~ ....... !. ..... ~ . ~ . · ~ .. J ...... ~''. ,~ ." ' · ~ ........ J .... : : "'t ........ ~ ' ~, ' ~ ............... I ....... : ' ' : ~ ' ..... : ~ ...... ~--~ ........................................................... t .............................. ' ........................... ~ ................................................... l ........................... ~ :' ';" "~ , ' '"I ...... J " '~ ................ : ' ':-,ix~ ....... : .......... ~ , ' J t ............... ....... ~'' · : ....... I · ' J' ' ~ ' ~ ......... ! ................ . . ~ ~ . . ~ ...... l __ _ _ -~ ~ , , , ....... ~ . · . ~ : - ~ _ ._ _ _ - . :~-t ..... : ....... ' '. J ~ I. . ~ , . } ............. I ...... ~ ............. t .~- - ~ .... : ' ............ .:.: .......... J ........ i I ~ ~nJ~ ........ j .. I ... :... ~...: ....... · ' · ] ........ t J z · ~ '~ ~ · . · , , · ' I ..... ~ ........... ·.. ~: . , . '., ....... ~ ................ ~ {, ..... ' . .X ........ ' ....... j ........ :~ ............ '' :' ~ ..... ~ .......... t ...... ~ ...... :~'~'~'%~845J ................ t .................. t' ' . · · ; ....... ~ . . ~ .... .. ; ~ ........ ~ j OUUT I .......... I ........ ~ .... , ........ J . . · 11S , · .... , - · . ..... x.. J .............. : ....... ~ . ..... ~ . .. i :!~ '1 j lei i{ .. : · J.- ~, i .... ........ ~ ..... '~ma~ - ~'~l .... t ...... j ' ' : :::: :::-h850 :"~800[::' h750~:': ar00 : a650 : h600 15SO~',':J1500["': 1450 ::': .,: .... : : ........ : ~ j- ~ J · ~ ....... KUPARUK RI VER UNIT 20" D IVERTER SCHEMATIC DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH T~O 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/lO" OUTLETS 10" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REHOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG I1-3-86 i i ' i~11 7 5 4 I3 ~11! ~ mi ~ II DIA(~ #1 13-b/~' 5OOOPSI RSRRA BCP STACK _ I. 16" - 2C)00 P~I TAI~<CO b"T~INI3 I-EAD 2. II · - 3000 PSI CASINO HE.a~ 3. II · - 3(XX) I:~I X 13-5/8" - 5000 P~I 8P~ SPOIL 4. 13--5/8" - 5000 PSI PIP~ 5. 13--5/8" - 5000 PSI DRILLINI3 SP(X]_ W/O4(:]<E AN) KILL 6. 13--,5/8= - 5000 PSI ~ RAM W/PIPE P, NaB ON TOP, 7, 13.-5/8" - 5(X)O PSI CAPACITY TEST 4~ 5~ 5 12. 13--5/8." BOP STACK TEST FILL BCP STAO( ~ Q-13(E I~N[F(1.D W[TH ARCI'ZC Q-EO( THAT ALL LCX3( D(3~ ~ IN ~I~EAD FLLLY RETRAC'I'~, ~.AT TEST PLUG ZN ~ WITH ~IN~ JT AN:) R~N IN L~ LI~E VALVES ~ TO BCP Sl'A(X, ALL ~ LP TO 250 PSI At~) HCLD FCR I0 NIIN, IN'- CREA~ PRESSURE TO 3(XX) PS] AI~D H~LD FCR I0 MZN. BLEED ~ TO 0 LZ~E VALV~.S. CLOSE TCP PZPE RAMS AN3 H~ VALVES CN KILL ~ O-ICKE LIliES, TEST TO 250 PS! ~ 3000 PS! AS IN STEP 4. C~NTIN.E TESTI~ ALL VALVES, LI~E~, A~ WITH A 2.50 P~! LON A~ ~ PS! HIGH. ~ A8 ~ A ~ ~O~ING PO~I~ SEAL CHC~<E~ CN.Y OF~ TC~ PIF~ RA~ A~ C1.0~ BOil'C~ PIP~ RA~. l'~ BOI'FCM PIP~ P,~ TO ~ PBX A~ ~000 P~I. FLUID. SET AU. YALVES IN CRILLING PO~ITICN. TEST STAN:PIPE VALVES, KELLY, KEllY COQ(~o DRILL PIPE S~ck"r'f VALVE, AN:) INSIDE ~ TO 250 PSI ~300 PSI. FOR~, SIGN, ~ SEN:) TO DRILLING ~F~RVI~. V~J~]<LY THE.~ FIJNCTICr~IJ.Y CPERATE BOP~ I n ir im i11 i ' I I .... 510084001 ~E' MAY 15, I.c · m Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. Lw~5 / ±h GENERAL DRILLING PROCEDUI~ KUPARUK RIVER FIELD DEVELOPMENT WELLS I. Mow&_ in rig. 2. Install' Tankco diverter system. 3. Drill 12~" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psiS. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8~" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide I00' between plug back total depth and bottom of Kuparuk sands. lO. Run and cement 7" casin$. Pressure test to 3500 psis. 11. Downsqueeze Arctic Pack and cement in 7" z 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. Il. Run cased hole logs. 15. Move tn workovar rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip ouc of hole standtn$ cubans back. 17. Perforate and run completion assembly, sec and cast packer. 18. Nipple down blow out preventer and install X~ms tree. 19. Change over to diesel. 20. Flow well co tanks. ShuC in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE _ :514AKER~ CLEANER STIR ,~--w, STIR ---w, STIR TYPICAL MUD SYSTEM SCHEMATIC LWK4 / ih CHECK LIST FOR NEW WEr.T. PERMITS ITEM APPRDVE DATE (1) Fee ~..~ ~- ~ .-~ 2 1. (2) Loc d~,,~ cf .~ ? --~ ;~ ...... (2 thru 8) (3) Admin me ( (9 thru 13) 10. . 13. (14 ~ 22) ('5) BOPE ~'4.~,"~'-~-~,? (23 tkru 28) (6) OTHER (29 thru 31) Company ! YES Is the permit fee attached .......................................... ~ , ,, Lease & Well NO Is well to be located in a defined pool ............................. Is well located proper distance from property liom .................. Is well located proper distance from other wells ...... Is sufficient undedicated acreage available in ~ ~i Is well to be deviated and is wellbore plat included Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval .needed ................................... Is the lease number appropriate ............. Does the well have a unique name ~'~~'.1..~. 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ ~ Will surface casing protect fresh water zones ....................... ~ Is enough cemmnt used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............ : IS old wellbore abandommmt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required .......................... - ............. IS the drilling fluid program schematic and list of equipment adequate/~f Are necessary diagrans and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~,~o psig .. Does the choke mmzifold comply w/AP1 RP-53 ~4ay 84) .................. Is the presence of H2S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. Geology: ttngineering: WWB ~ LCS f ~:~ BEW rev: 01/28/87 6.011 INITIAL GEOi UNIT DN/OFF POOL CLASS STATUS AREA NO. SHORE Additional R~rks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. No special'effort has been made to chronologically organize this category of information. TAPE, 'ATB :~7/06/1i~ mRI (;l~g : ~'S1A 'REVIOUS TAPE UNiT TYPC ClTE $lZ~ CODE 000 000 017 Ob5 00o 000 O0~ 065 o00 000 0o8 065 000 000 002 0~5 000 000 004 0~5 000 OOO 002 065 OOO 000 01~ 065 OOO 000 006 065 U~IT ~Y'PM CATt SIZE CODE 0 0 0 00 0 0 U 1 0 6 5 YPE FLd]U I $ C 0 S I T Y * ~') A, '1' ~ AvAI~ABb~: 9720' * UATA AVAiL, A~SI.,5: 9697' EPT FLU LD OIL 6 ~ '3 T L R F ~LI FDa4 ~H I R A T F NRA R Cab E ~¢ $ C H h t, GG 'fYPE. C(,A.5S F' r () 0 00 C' 0 [:i r, ~-'. :': 00 22 t> 0 I 0 0 " 120 44 V ;J 0 01 C 01 L,~ On ~3~ 21 0 0 GAPJ' O0 ~ 10 01 0 0 L, IC3 O0 35U 02 F :.' 00 890 0 [ 00 2 ~ 0 0 i ) 0 F U () 0 ~ 90 00 0 00 4. 20 01 0 :.1 0 0 0 C P 5 00 330 3 C f:' S :) 0 330 3 ,) 0 0 L, f..: 00 t, ] 5 6I Cu[:,~ (oc'rAh) ~ I 6~ OOO00UO0000000 4 1 68 OUO00000000OO0 4 t 68 O0000OO0000000 ~ l 68 O000000000OO00 q i ~8 ouO00000000000 4 I 6~ 00000000000000 4 ] ~ 00000000000000 4 I 6b O000OO00000OO0 q ! ~8 O0000OOUO00000 4 t ~ 00000000000000 q ~ 68 o0000000000000 4 t 68 00000000000000 ~ I b8 00000000000000 4 1 68 O00OO00~O00000 4 ! 6~ 00000000000000 ~ 1 68 00000000000000 4 ! 68 O0000000OO000O 4 I e8 0000000~000000 4 ~ ~8 uUO00000000000 4 i 6~ 00000000~00000 EPT gP T P HOB p~lr CM b PHI 'C N b ,P ~PHt 9743 500u -27 75O0 50 ~01 488 750O 9700,00 (,., 0 1 , 7617 49,8535 488,7500 9600. -1 2070 33 716 5000 -32 0090 5'10 -46 000<) 2 4219 35 4492 5KbU ,, o [.{ D F~: H ij i~'~ R A T S F b U 2,8185 -0.0151 090 00 "f E: N S DPHi 0,0376 3.0020 0,0009 103' 2500 3,59it~ 7620,0000 (;!, 0527 3, t 07 4 I L 0 G R DPH I 3420, 60, -§99, 7500 , 000 o G R 8 ~ 4640 C A L, i 5 9375 .~:~C N L 1925 2468 Ib~,i 2 0000 G R 8 ~ 9375 NCNL 1925 2500 T~]NS -999 4,225:1 Ib~: 7820,0000 GR 9,91.95 CAUI 3,2500 i,~ C ~i b -999,2500 Tt.Ci~S 2,8646 IbM 7680,0000 GR 1.3,5890 CAbl -999,2500 1;E~S 722~,0000 GR 3,2480 NCNb 7336 7500 2969 0000 2500 ,~052 ,7500 ,2109 ,250(:! 4,3272 82,1250 8,b172 330,0000 1~9 -99 8 227 9225 2500 8125 0000 2500 5,3426 2,1875 EPT P HOB PRI EP T P ,p }EPT :HOB {PHI )EPT iPHI )EPT ~P ipHI 9000 -19 500(> 2 371i 42 6758 471 7500 - 23,00 V 0 ~0,7715 88 () 0,0 (] .',.> 0 -24,, 2.4330 43.~477 576 ' b 0 u 0 ,,,,24. 2, 533. -20 7056 2 4941 36 6,21i 5(30 ' I, 3 2,502V $ F L U ~q R A T $ F b L~ '1RAT 0 R H. 0 'r ~: i:',, b SFbL) 7544. 1 3' 72.72. ! 96. O. 3. 3 1. la, V, ]. 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(;' 1 i7 0000 77 0e~25 0 O 59 I 3 5291{ 6608. 000") 1,51.43 3,b074 [bD [)PHi lbo TE~S OPaI 0 P H I 0 P H I -999. · 7228, 3. -999, 2~ 7664. 12, 3. '999, 7100, 14, 2, -999, 2 6828 19 '99g, 2~ 7008. 16, -999· 724B, 16. 3, '999, · 6768, !..8, 4, '999, 2o '"'999 6400, t9, 2500 1o32 t8~ 5237 45211 2500 4033 OOO0 5360 9]95 2500 7797 0000 0341 532]2 2500 1746 o000 3116 2852 2500 l 07 4 0 () 00 4299 2 500 914 '7 0000 3239 250 0 1146 Oouo 9972 5977 2500 90~9 0000 8027 0430 ~C~b CAbI I GR CALI t~ C ~"~ i,: CAbI C A I, I NCNk~ T E t~ S CAb I C A b I :Fga $ -999.25o0 2],3229 1i7,0625 9,7969 211~,0000 -999,2500 2,4422 90,9~75 9,1016 2328,0000 '999,2500 2.33~7 102,1250 8,7422 212~,0000 '999,2500 2 8194 102 ~375 8 7891 217~ :0000 -999.25P0 2,0504 112,8'150 9,2969 2005,0000 -999,25()0 2 1287 92 8750 9' 148~: 1S63 0000 -999 2500 i 9416 9~ 8750 9 32S 1 i982] 0000 -999 2500 2 1356 77:0625 9·101b 2039,0000 -999,2500 t,9007 110'8750 2000, gP"r 7 ]o0 P 36 O 0 ~'., 0 G ,q 9000 i' g i'...i $ ~p PHI 7200, 2,349 ~.~ b b 2,0000 i'~RAT ;P 'CNL, 7000 90UO 2 341~ 39 9~Ig 512,50t}0 )EPT 6900 0009 -0 U, 00 00 )gPT ;P (.MOB ~'P~I 6800 00~<, -27 7{}31 2 3613 624 5i}00 S F L ~P ~PHI. 2,3223 4~,2422 2.B76t ILO 9b,9]'15 O, 060 i, ~PH l 3..t543 R:qRA o. 0122 3.5723 6132.0000 GR t 395t 9 0161 6212 000~ ! L 0 g P, -999.25u'.) 'r El',S, 14,4175 -999,2500 T~$ 3,1.94& ~220,0~)00 12.760~ CALl 3.4434 ~C~[~ -999,25U0 'I~NS 3.4008 5228.0000 GR 1.2.9972 3,431b '999,2590 8132.0000 18.2055 3.3301. NCNL -999,25~0 T[5~S 3.510b 6212,0000 Ga i. 6,9034 CAUl 3,6%06 ~CNL -999'2500 T~NS 5940,0000 GA 18,6790 C~5I 3,6074 ~CNB 2.837~ lt~a 20.5729 CAb~ 0.00¢9 !~Ci~l~ -9'99.250o Tg~8 2,B61(~ IL~i 5584.0000 GR 19.8627 CAbI 3.b133 ~CNL -999.2500 99,3125 ~,2~91 90.9375 9,0938 210b,OOOO -999,2500 2,969~ 90,9375 9.1484 2172.0000 -999,2500 3,5410 110.t250 9 3281 2O56 0000 -999 2500 2.59!5 10~,0625 .5859 1849,0o00 -999,2500 U,O000 O,O000 -999.2b00 2,76t7 102.8125 2.1602 2316,0000 -999,2500 2,7965 10b,2500 2.1797 IEPT 5300,aUO0 SFbO l H 0 B 2,3 g 57 O i{ P, 0 ~P ~ ! 53,2227 ~i R A 't 'C~ 1., 65o,5000 TMt'iS )EPT 6200 ~P -33 ~HO~ 2 rC~L 718 000 g $ F [, d 5P -54 ~PMI 50 2 t? 51 b i< H ~:.~ 2,931~.] ILO 2,0605 93,4375 'lENS 3 ~ 654.3 RNR~ 5060,0000 924'5 ILO 1250 097 ] !.) P h ! 2363 4~88,0000 3.3077 I L 0 900625 fENS 'b'O464 OPt"lI 3 ~952, -'~99,2500 T~[a6 5520.0000 l '7. 2585 ~,7559 -999.250(; 3.3'190 ib~ 72,000 f) G .q 19.1525 CAbi '999,2500 T Et';' S 5360.0000 GP 19,5259 CAbI 3,B145 mCNL -999,2500 TEN~ ].7694 ibN 5060.0000 Gi~ i8.4422 CAbI 3,6426 NCNb -999,2500 liENS 3,4555 5140.0()00 18,5606 CALl 3,0977 NCNb -999,2500 TENS 3,4562 4888 0000 22 3485 3 4!4I -999,2500 GR CALl NCNL 7 .l[,a 4952':~852 CA[,I 22, 3,2852 !4CNb -999,2500 TENS 4,1609 4508,0000 3,9570 -999.2500 3 41Y7 gO 3125 2 179'1 2502 OOUO -999 2500 3.2804 92,8125 2.1797 2406,0000 '999,2500 3.7~33 2,1914 ~44,0000 ~999,2500 ~ 5088 9~ 4375 2428 0000 -999 2500 3 37~9 97 68'75 2 1836 2226 O00O -999 2500 3,3908 1.06,1250 2,1680 2414,0000 -999,2500 3 9265 90 0625 ~ 1875 2236 0000 -999 2500 1!2 1875 2 1719 2198 0000 -999 2500 94,1250 2,1602 2~40'0000 MOB 2. 2095 i>~<H P M ! ,,~ 7,9.~ g 2 !,~ ~ A i'~ C ~ i.., 54],0900 ~EPT 5300 ;P -27 'CNb ~PH I 'C N b ~EPT ;P ~PHI ;P ~PMI 'C~ L 63 b 7 a R A T 0000 T e] i,~ $ 6200 - 27 '! 5 60 $03,OOU(> ~ :R A T 601.5000 SF'LU DRHO T ~.~ N S D i< H 0 4900', 0009~ -37,7!~13 2,2324 51,~602 SFLLi 2 7349 94 9375 0 0532 I b D I () 6 000 0 72 u625 3 5703 I b D TE?~$ -999. 2500 4.40qo Ib~i .~408,0000 GR 24,5975 C~ol -999.2500 T!fh~8 3.3~74 4328.0000 23.0587 CALl 3.9551. ~CNb -999.2500 41~8,0000 GR 2].6506 CALl 3,9q92 !~CNb -9q~,2500 TENS 3.3413 4120.0000 20,3362 CALf -999.2500 TENS 4,0';34 ib~ 4!.04.0000 GR 22,2301 CALl 3,7813 NCNL -999.2500 TENS 2,709q 4010.0000 GR 22.7036 CALl 4,3477 NCNL -999,2500 TZaS 4,9471 3734.0000 2~.3608 3.4180 i~CNb -999,2500 TEN8 5,2153 lbN 3844,0000 GR 25,1894 CALI 3,0371. ~CNb -999.2500 TENS 5.0602 ib~i 3804,00OO GR 25.3078 C~LI 3.4102 NCNL -999,2500 q,2494 104,3125 2.1623 2260,0000 log 8125 2148 OOOO -999,2500 0,4487 98,18'15 2,1680 2.04~.0000 ~9 . 2500 3 94 9375 2 1641 2266 0000 -999,2500 4,0197 99,1875 2,2031 2194,0000 "999,2500 2,7045 q2,:0625 2,20'10 2188'0000 -999,2500 9~ 625 205~'0000 -999; 2500 5 0326 100 0000 2 2520 199~ 0000 -999 2500 5 032~ 72 0625 2 2670 I~8O O000 -999. -999 -999 -999 999. -999. -999, -999. -999. -999. -999~ -999. -999 . EPT 4500.00o0 SFLU -999 P - 999~250o (;:{ -999 HO~ '999,2500 o~dO -99~ PUl -999,2500 i',ii)A'l -999 EPT 4400.0000 8F'LU P -999,250o ~0~ -999,2500 DgHO PHI -999,2~:~) CNI, -999,2500 ""~ ~ R A Z 'EPT .p :~0~ ;PHi ;P -999 250o -999 2500 -999 2500 -999 2550 4000,0 J 0 ,.999,2500 - 999,2500 -999,25L'0 -999 -999 -999 -999 "999, -999 ~999 -999 -999 -999. -999, -Qqq -999 -999' '999, '999, -999. .o09 -999, -909 -999 -999 2500 25 (; t~ 25',<'0 250" 250t' 2500 2500 2500 2~;07, 250¢, 2500 25v0 250O 2500 250<> 2500 2500 2500 2500 ,,, 2 ~ 00 250 e 25 (> 0 2500 2500 25 0 2 b {? [!PHI 1. L 0 t; R. DPH i lhl.) ~NRA I 6 i) T'EN5 OPdl l' L, b P H I {,; R [<' P H I i) P ,q I -999.2500 tL~ -999.25U0 GR -999.2500 CAbI -999,2500 NCNb -999.2500 -999.250') -999.2500 -999.2500 7~.3750 '999,2500 [!.~ -999,2500 GE -999.2500 CAbl -999,2500 NCNL 44.3438 TE~S -999,2500 lhd '999,2500 GR -999.2509 CAhI -999,2500 NCNL 52,8437 I'~NS :999,2500 tu~ 999.2500 GR -999,.~500 CAb[ '9'99. 500 NCND 5~o3750 ~gN$ 999,2500 999. 2500 :999,250 -999,250('} 47. 5000 -999 2500 -999 250O -999 2500 -999 250{i) G~ NCNL -999,2500 -999,2500 - 9 9 9.2 5 0 0 A k, I r. -999,2500 !,,} "" h bt,,., 3700. UO00 -999 2500 -999 2500 -999 2509 -999 ~SPO 3764.0000 -999 2500 -999 250O -99~ 2500 -999 2500 3034 0000 -999,2500 -999,2500 -999,2500 -999,~500 3030,000 -999.2500 -999 2500 -999,2500 -999,2500 3500,0000 -999,2500 -999,2500 -999,2500 -999,2500 3494,~00t) -999 2500 '999 2500 '999 2500 '999 2500 ]430,0000 -999 2500 -999 2500 -999 2500 '999 2500 3]54'OO00 -999 2500 -~99 2500 -999 2500 -999 2500 3270 0000 -999 2500 -999 2500 -999 2500 -999 2500 ? -999.2bU:1 PHI -999. )EPT 35i30,0!)00 SFLU ;P -999,2500 GR ',1~'!0 B -999,2500 DRHO ~PHI -999.25C0 i~AT ~EPT 340O ;P -999 [HOB -999 ~P~I -999 "CNL -999 3300 -999 -999 -999 -999 }EPT ;P 250(.) 000{) SFLU 2500 'F K 3200. OOuO -5}99,2500 -999,25uu -999,250{i -999,2500 5FLiJ G~ 3 ! 00. (i~ 0 (3 () -999,25 (~'L1 ,,,999,2500 -999.250C' -999 -999 250;, -999 2509 -999,250~ -999 '999 2500 -999 2509 -999 250.? -9¢~9 2500 IbD R ~.! R A :999 2500 lbo -~q~,25U{) -999. 250O -999 2500 -999 2500 -999 2500 -999 25~)0 -999.25{)0 -999.250<) -999.2500 -999.2500 I bD D P ii I 63.593J T~;aS -999.2500 -~9g.2500 -999.2500 -999,25()q -999,25u9 1~ -999.250~) -999,2500 CAbI -999,2500 NCNb 29,7655 -999.2500 .tt,,~ -999.25on Gg -999,2500 CAb! -999,2500 NCab 52,7500 'fENS -999.2500 IbM -999.2500 GR -999,2500 CALl -999,2500 NCNb 3~,~503 T~NS -gg9.2500 Ib~i -999,2500 GR -999.2500 CAB.L -999.2500 qCmb 44,71B8 T~NS -999.2500 lI.,a -999,2500 GR -999,2500 cgbI -999.2500 ~CNL 27.1405 TE~iS -999,2500 -999,2509 -999,2500 CAbI -999,2500. . ~Ci~b 47,5938 lENS -999,2500 Ib~ -999.2500 Ga -999.2500 CAbI -999,25u0 NCNb 54.343~ T~:NS -999.2500 Ib~ -999,2500 GR -999',2500 CAgI -999.2500 i~CNb 3254,0000 :999,2500 99~,2500 -999,2500 -999,2500 3194,0000 -~99,2500 -999.2500 -999 25u0 -999:2500 31~0,0000 '999,2500 -999.2500 :999,250~ 999,2500 3014,0000 -999 2500 -999 2500 -999 2500 -999 2500 3030 0000 -999 2500 -999 2500 -99g 2500 -999 2500 2B74 0000 -999 2500 -999 2500 -999 2500 -999 2500 2800 0000 -]99. 2509 - 99[, 2S06 "999,~500 '999;Z500 2830; OOOO i999,22500 V99, 500 999,2500 -999,2500 2754,0000 -99~ 250O -99~ 2500 -999 2500 '999 2500 ~P '999, .. G.~ ,HOb '999'2500 NRA'f IpH I -999, ' C N b - 99 g, 250 o i' E'; ~'~ 8 )EPT )EPT ~P ~PHI 2300 -999 2500 -999 2500 -999 2500 -999 250o 220 O, 0 00 C -999,2500 -999,250b' -999.25CC. G;< -999,250C ILD -999,2500 F~ R~. -999,2590 GR -999.25~0 -999,2500 ~999, 500 GR -999 2500 -999 250Q -999 2500 -999 2500 -999 2500 -999 -9~9 2500 -999 2500 -999 250~ -999 2500 SPH I G R 41.0625 -999.2509 I6~! -999,25U0 CAhI -999.2500 NCNb 21.5409 TE~S -999.2500 -999,2500 GR -999.2500 CabI '999,2500 ~CNb :999,25f)0 lb~ 999,2500 dR -999.2500 CAUl -999,250n ~iCNb 54,0313 TE!~8 -999,2500 IbM -999,2500 -999,2500 CAbI '999.25()0 NCNL 33,5525 ~q' 250O .99, 999,2500 GR 999'2500 CALl -999'2500 t~CNL 41,0000 TENS -999 2500 IbM -999 2500 GR -999 2500 CAbi -999 2500 NCNb 35,0938 'rE~NS -999.2500 -999,2~t. GR -999,.2500 CALl '999,2500 NCNL 31,~4~7 TSNS -999,2500 -999,2500 GR -999,2500 -999,2500 41,0938 T~NS -999,2500 -999,2500 -999.2500 -999,2500 -999 2500 -99~ Z500 -999 2500 -999 2500 2584,0000 2500 '999'250,~ '999, . -999,2500 -999'2500 2600,00U0 -999.25U0 999,~500 999,2500 99~,25U0 2520,0000 999 2500 -999,2500 -999,2500 2~80,0000 -999 2500 -99~ 2500 -999 2500 -999 2500 2424 0000 -999,2500 -999,2500 -999,2500 ;999,2500 480,0000 -999,2500 -999,2500 -999,2500 -999.2500 2450,0000 -999,2500 -999 2500 -999 2500 -999 2500 -999,2500 -999,2500 -99~'Z500 -999,2500 -999.26¢0 )EPT 1745 ;P -999 t H 0 E; - 999 ~PHI -999 ~CNt, -999 5 0 t, 0 8 ¢ L J 2 5 0 0 G e 2 5 t~ 0 T g :'~ S '999.2500 '999.2500 -999.2500 I.bD -999 e 25(?!{) :999.2500 999. 250() GR -999 ~,500 -999 -,,999 2500 -999 2500 -999 2500 T~<N5 D P H I G~ ** . FILE ~ A iq, g CERSI:,ON )ATE; ~ILg TYFE : PREVIOUS FILE , -999,2500 IL~ -999.250~ GR -999.25U0 CAbl -999.2500 ~iCNL -999.2500 -999,25Uo -999.2500 CALl -999.2500 P~CNL 56,7500 'fgN$ -999,250() Ib~ -999.2500 6k -999.25t)0 CAbI -999.250(~ ~CNb 33.]125 TE~5 -999.25)0 GR -999.2500 CALl -999,2500 i~CN6 5~,3i25 'tgi~8 -999.2500 Ib~ -999.250u GR -999,2500 CAhl. -999.2500 NCN[, 43.~688 TE;~$ 226q.0000 -999 2500 -999,2LOt? -999.2500 2160.0000 999,2500 :999.2500 :999,2500 99~,2500 228~.00oU -999 2500 -999 2500 -99~ 25O0 -999 2500 2194 0000 -999 2500 -999 2500 -999 2500 -999 2500 2160,0000 -999,2500 -999.2500 :999, 500 2180,0000 ) A T I'~ ~,'~ SPEC I FiC tkT It)i',i ID ORDER ~ bOG 'I, YPE C:LAS8 ~qOD ~0, CODE (OCTAb) )EFT F';? O0 000 O0 0 0 4 I 68 00000000000000 972t .2988 I I . 221 ;EPT qTOO. 2 :~ 'PHI t3,4706 '~:PT 9000,29e ~:ET 9500,29~ ~PHI 13.1155 ~EPT 9400, (2) 9~ ~ P H 1 17, 21 )8;PT q3OU, 29~¢8 )EH l I 2. (~ t+2 )F, PT 9200,298 ~EFT 91t)O, ...... ;EPT 9000,29.~ )PHI' 14, 180 )~PT a 9'9 f~, ...... )pHI 1.3. bg9 ~* FILE TRAIbMR FILE i4A~4E SERVICE VERSIOM ~ DATE : FIbE T~ EE NE~T FILE; 93.4375 8, B !i 47 93.4375 9.0234 81,3750 8.5703 105,1250 91.b750 72.3750 8,07!,9 8.8797 192.1~75 l :t 1,8750 9,1719 9,1. 6<~1 ,002 EOF 2390.000') 2.42'17 72o8.0000 7032,0000 2,4336 7o32,0000 2.~59t 7248,0000 7204.0000 2,6680 7208.0000 2,6973 2.4160 6964"0000 2.~25~ OReO 0,1382 uRNO 0,114'1 t)¢aO 0,03t2 DR.O 0,10~9 O~HO o,oJ17 ORhO V,0547 O~H.O 0,1548 ORtiO -0,05~2 ~aaO 0,02~3 OR[lO 0,0596
