The URL can be used to link to this page

Home My WebLink About185-262 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2H-11 50-103-20052-00 185261_2H-11_SCMT Post-BiSN_22Aug2023 185261_2H-11_SCMT Pre-BiSN_27Jul2023 2H-12 50-103-20053-00 185262_2H-12_PPROF_01Jun2023 2H-17 50-103-20329-00 200019_2H-17_IPROF_01Jul2023 2K-07 50-103-20107-00 189071_2K-07_RBP_17Apr2023 2M-20 50-103-20169-00 192048_2M-20_LDL_30Mar2022 2M-29 50-103-20183-00 192097_2M-29_Patch_30Dec2022 2N-310 50-103-20549-00 207090_2N-310_CIBP_16Jul2023 2N-316 50-103-20342-00 200090_2N-316_EVO RPB_23Mar2023 200090_2N-316_LDL Caliper_02Sept2022 2N-329 50-103-20257-00 198067_2N-329_PLUG-LDL_03Mar2023 198067_2N-329_RST_31Dec2022 2T-14 50-103-20061-00 186044_2T-14_Patch_11Jun2022 2U-12 50-029-21304-00 185041_2U-12_LDL_06Aug2023 7of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38372 T38373 T38374 T38375 T38376 T38377 T38378 T38379 T383780 T38381 T38382 2/29/2024 2H-12 50-103-20053-00 185262_2H-12_PPROF_01Jun2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:56:50 -09'00' RECE STATE OF ALASKA 1V ALIIIL OIL AND GAS CONSERVATION COMMON JUL 2 7 2016 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r', Plug Perforations r Fracture Stimulate r Pull Tubing r , Gown r Performed: Suspend r', Perforate F Other Stimulate r Alter Casing r Change Approved Program r', Plug for Redrill r Perforate New Pool r Repair Well f- Re-enter Susp Well r i- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F ' Exploratory E 185-262 3.Address: 6.API Number: Stratigraphic E Service r P.O. Box 100360,Anchorage,Alaska 99510 50-103-20053-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25587 KRU 2H-12 9.Logs(List logs 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 6840 feet Plugs(measured) None true vertical 6237 feet Junk(measured) None Effective Depth measured 6786 feet Packer(measured) 6415,6565 true vertical 6198 feet (true vertical) 5930,6041 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2706 9 5/8 2741 2741 PRODUCTION 6802 7 6834 6232 Perforation depth: Measured depth: 6515-6535,6589-6598,6614-6625,6654-6684 True Vertical Depth: 6004-6019,6058-6065,6076-6084,6105-6127 SCANNED J tN 3 02017; Tubing(size,grade,MD,and TVD) 3.5,J-55,6582 MD,6053 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER HB RETRIEVABLE PACKER @ 6415 MD and 5930 TVD PACKER-BAKER 1B PERMANENT PACKER W/5'SBE @ 6565 MD and 6041 ND SAFETY VLV-CAMCO TRDP-4A SAFETY VALVE @ 1787 MD and 1787 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 6589-6598 Treatment descriptions including volumes used and final pressure: Perforated Interval w/2" Millenium2 SDP 6SPF 60 DEG PHASING 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 81 601 1180 1175 210 Subsequent to operation 65 90 1208 1210 210 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service E Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas [ WDSPL r Printed and Electronic Fracture Stimulation Data IT GSTOR IT WINJ IT WAG r GINJ IT SUSP IT SPLUG 1'- 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Sydney Autry Caa,265-6813 Email Svdnev.Autryca conocophillips.com Printed Name Sydney Autry Title Assoc. Petroleum Engineer Signature1. 11?2 265-6813 Date --'j_ !�� /)to T! L Form 10-404 Revised 5/2015�/ �� g 3l /`J' RBDMS Li. AUG 1 2016 Submit Original Only • • 2H- 12 DTTMS JOBTYP SUMMARYOPS 3/19/16 PERFORATIONS TAG @ 6644' SLM. DRIFT W/2"x 21' DUMMY GUN TO 6644' SLM. READY FOR E-LINE. 3/22/16 PERFORATIONS PERFORATE INTERVAL 6589'-6598'. CORRELATED TO CBL DATED 11- 18-1985. JOB COMPLETE. 3/22/16 PERFORATIONS PRE E-LINE FREEZE PROTECT. PUMP 20 BBLS DSL DOWN TBG, 23 BBLS METHANOL DOWN FL. (JOB COMPLETE) 7/15/16 ANNCOMM (WC) : MIT-OA(PASSED)TO 1800 PSI. 7/18/16 ANNCOMM (WC) : TIFL PASSED. • KUP PD 2H-12 ConocoPhillips S Well Attribut Max Angle I TD Alaska Inc, Wellbore API/UWI Field Name Wellbore Status !noir) MD(ftKB) Act Btm(ftKB) Cartoca`Yluliips 501032005300 KUPARUK RIVER UNIT PROD 1 45.28 6,800.00 6,840.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date • 20-12,7/27/2016 1x.30;30 AM SSSV:TRDP 85 11/22/2015 Last WO: 1/13/1993 39.61 11/100985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date . .Last Tag:SLM 6,644.0 3/19/2016 Rev Reason:H2S UPDATE pproven 7/21/2016 HANGER;31.5 II 1'® Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WI/Len(I...Grade Top Thread 1I CONDUCTOR 16 15.062 36.0 114.0 114.0 62.50 H-40 WELDED I■ i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WhLen(I...Grade 'Top Thread • I ..SURFACE 95/8 8.921 35.5 2,741.0 2,741.0 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 31.5 6,833.6 6,232.4 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top IRKS) Set Depth(ft.. Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 1 3 1/2I 2.9921 31.51 6,581.6] 6, 053.01 99.301 J- 55 (Top -"Vic-CONDUCTOR,36.0-114.0 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl I') Item Des Com (in) 31.5 31.5 0.11 HANGER FMC GEN III TUBING HANGER 3.500 SAFETY VLV;1,787.4 f ®.' 1,787.4 1,787.3 0.27 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 2.813 il 6,401.5 5,919.7 41.19 PBR BAKER PBR w/10'STROKE 3.000 6,415.2 5,930.0 41.34 PACKER BAKER HB RETRIEVABLE PACKER 2.890 If GAS LIFT;2,357.7 6,547.8 6,028.4 42.94 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE w/NO GO PROFILE, 2.750 CLOSED 6/4/2004 6,562.3 6,039.0 43.15 XO Reducing CROSSOVER 3.5 x 2.875,6.5,J-55,ID 2.441,ABM-EUE 2.875 6,562.7 6,039.3 43.15 LOCATOR BAKER GBH-22 LOCATOR SEAL ASSEMBLY w/ 2.406 MULESHOE BTM SURFACE;355-2,741.0-+ 6,564.8 6,040.8 43.18 PACKER BAKER 1B PERMANENT PACKER w/5'SBE 3.250 6,575.0 6,048.3 43.33 NIPPLE CAMCO D NIPPLE 2.250 GAS LIFT;3,987.5 1 - 6,580.7 6,052.3 43.41 SOS BAKER SHEAR OUT SUB,3500 PSI SHEAR,ELMD TTL 3.015 6576'during SWS SBHP on 06/30/2008 GAS LIFT;5,301.0 0 Perforations&Slots Shot Dns rL■■ Top(ND) Btm(TVD) (shots/ GAS LIFT;5,899.1 ' '� - Top(ftKB) Btm(1KB) (ftKB) (ftKB) Zone Date ft) Type Com la 6,515.0 6,535.0 6,004.3 6,019.0 C-4,2H-12 12/12/1985 12.0'IPERF 120 deg.Ph;5"HyperJet II 1 6,589.0 6,598.0 6,058.4 6,064.9 A-5,2H-12 3/22/2016 6.0'APERF PERFORATE GAS LIFT;6,349.6 INTERVAL 6589'-6598' "� WITH 2"MILLENIUM2 SDP 6SPF 60 DEG 11 PHASING 6,614.0 6,625.0 6,076.5 6,084.4 A-4,2H-12 3/18/1986 4.0 APERF Zero deg.Ph;2 1/8" Tornado Link PBR;6,401.5111 6,654.0 6,684.0 6,105.2 6,126.7 A-3,2H-12 •12/12/1985 4.0'IPERF 90 deg.Ph;4"HyperJet II PACKER;6,415.2 •a.a Mandrel Inserts IIISt ah on Top)ND) Valve Latch Port Size TRO Run GAS LIFT;6,463.1 . N Top(ftKB( (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,357.7 2,357.6 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,240.0 7/21/2011 .I. 111111LEZIMMINIZEINIUMMIEZNIMEMILSIMMIIEZIEEZEIMI= 5,301.0 5,059.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,291.07/21/2011 CAMCO KBUG 1 GAS LIFT GLV BK 0.18817/21/2011 ::1 • OV RK 0.250 117/17/2012 IPERF;6,515.08,535.0_ CAMCO '•• DMY RK 0.000 11 2/8/1998 Close End Date Annotation SLEEVE C;6,547.8 1/20/2004 • • ••COMMUNICATION LOCATOR;6,562 7 10/27/20n • •1 1,,,,P 7/12/2012 NOTE:"'"'TUBING SET DEPTH/COMPONENT DEPTHS ARE WLM*** PACKER,6,564.8 i,■A, NIPPLE;8,575.0 ISOS;6,580.7Alt APERF;6,589.06,598.0 . I APERF;6,814.08,625.0-. IPERF;6,654.06,684.0 PRODUCTION;31.56,833.6 RECEIVED • • MAY 06 2016 21 1209 GC:AO WELL LOG TRANSMITTAL#903201990 Cy To: Alaska Oil and Gas Conservation Comm. May 4, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 .BENDER � �J1. K.BENDER RE: Perforating Record: 2H-12 Run Date: 3/22/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2H-12 _ _ .....�.._ Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20053-00 Perforating Record(Field Print) S _ 1 color log 50-103-20053-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / / �� v / `E:lt'""( \LkO)91 111 41) AS-24,z, WELL LOG TRANSMITTAL €.?) To: Alaska Oil and Gas Conservation Comm. December 7, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 2016 RE: Production Profile: 2H-12 Run Date: 11/20/2011 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 2H-12 Digital Data in LAS format,Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20053-00 Production Profile Log 1 Color Log 50-103-20053-00 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: all--c) ‘i Signed: 04$14416 6004 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. ! ~ 5-2 ~-~ Well History File Identifier Organization (done) //~ Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds [] Other To~^, PAGES= C/0' "O~ES: Project Proofing LOWELL By: Date: PROOFED BY: E~EVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si PAGES: ~ 0 (at the time of scanning) SCANNED BY: BEVERLY BREN VINCE~MARIA LOWELL RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL PAGES: DATE: /s/ Quality Checked {done) RevlNOTScanned.wpd • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 2H-12 Run Date: 6/9/2010 June 25, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2H-12 Digital Data in LAS format, Digital Log Image file 50-103-20053-00 1 CD Rom PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RE'TURIVING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3 ~ ~'~ rafael.barreto@ , o ;_ ,, ~. ~. :, ~~,~! ~~~ Date: `' " ~~. ~ 1~~-~a ~~ 1 ~~a~ Signed: ~-- 09/15/08 ~~ ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,., •.r ~..~ ~.~~, ~ .. N0.4871 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 1 C-172A 11978478 PRODUCTION PROFILE ~- 08/19/08 1 1 iC-172A 12080429 GLS/FBHP 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY - 08/20/08 1 1 3C-17 11996657 SCMT C.7(5 - /(n ~} /L/ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY ~aOSS-Q'~~ f'~G1~/~' 08/27/08 1 1 2U-06 12080428 LDL _p( - 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE l '=-p 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31/08 1 1 2D-07 11975790 INJECTION PROFILE - f~ f Q 09/07/08 1 1 2H-09 11975788 PRODUCTION PROFILE (p 09/05/08 1 1 iC-174 12096539 INJECTION PROFILE - D 09/07/08 1 1 2H-12 12096540 PRODUCTION PROFILE ~ 09/09/08 1 1 30-01 11975792 LDL ~-O 09/09/08 1 1 3F-10 11975789 LDL ( 09/06/08 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. ;~ • 2H-12 (PTD 185-262) Report of ~ed TIFL ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, September 16, 2008 7:58 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); NSK Problem Well Supv; Gauer, Jenn L; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK Subject: 2H-12 (PTD 185-262) Report of Failed TIFL Attachments: 2H-12 Wellbore Schematic.pdf; 2H-12 TIO Plot.ppt Tom, ,/ Kuparuk gas lifted producer 2H-12 (PTD 185-262) failed a diagnostic TIFL on 09/15/08 and has been added to the weekly SCP report. The well is also waivered for IAxOA commun-- ic~ion which requires a passing TIFL to continue producing. The TIO prior to the test was 240/1300/1300. A leaking GLV is suspected so slickline will troubleshoot the GLV's and repair if possible. Attached is a 90 day TIO plot and a Wellbore schematic. «2H-12 Wellbore Schematic.pdf» «2H-12 TIO Plot.ppt» `~ Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~,~~} ry 1-r 5: ~~ 12/10/2009 IAP 140Q 1200 100 800 a 600 400 200 0 OAP T/VO Plot - 2H-12 200 150 i a E as 100 Y 0 s V 50 0 01-Jul-08 01-Aug-08 01-Sep-D8 Date !~~ ~~ ConocoP~iiltps Alaska, lnc. KRU 2H-12 2H'-72 5 00 ll T W PROD An le TS: 42 de 6514 API: 50103200 3 e: e SSSV T e : TRDP Ori Com letion: 11/10/1985 An le TD: 45 de 6840 SSSV Annular Fluid: Last W/O: 1/13/1993 Rev Reason: TAG, Confirm Leak (na7-17e8, OD 3 500 f { Reference Lo : Ref Lo Date: Last U date: 10/6/2004 : . ) J Last Ta : 6680 TD: 6840 ftK6 Last Ta Date : 9/23/2004 Max Hole An le: 45 de 6840 Lif G Casin Strin' - dLL STRINGS t ~~ as andrel/valve ~} Descri tion Size To Bottom TVD Wt Grade Thread 1 '" _ CONDUCTOR 16.000 0 114 114 62.50 H-40 (z35a-2359, ~ SUR. CASING 9.625 0 2741 2741 36.00 J-55 PROD. CASING 7.000 0 6834 6233 26.00 J-55 Gas Lift ~ Fubin Strin -TUBING andrel/valve ~~ ~~ Size To Bottom TVD Wt Grade Thread z 3.500 0 6562 6039 9.30 J-55 ABM-EUE (3988-3989, 2,875 6562 6582 6053 6.50 J-55 ABM-EUE Perforations Summa Gas Litt Interval TVD Zone Status Ft SPF Date T e Comment andrel/Valve ~~ ~ 1 12/12/1985 IPERF Ph' 5" H erJet II 120 de 6515 - 6535 6004 - 6019 C-4 20 2 . 3 6614 - 6625 6076 - 6084 A-4 11 4 3/18/1986 APERF Zero deg. Ph; 2 1/8" Tornado (5301-5302, Link 6654 - 6684 6105 - 6127 A-3 30 4 12/12/1985 IPERF 90 de . Ph' 4" H erJet II Gas Lift ~~ ~ GasLift MandrelslValves andrel/Valve ~• - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv 4 (sass-5sao Cmnt , 1 2358 2358 Camco KBUG GLV 1.0 BK 0.125 1258 6/4/2004 Lif G 2 3988 3972 Camco KBUG GLV 1.0 BK 0.156 1297 2/7/1998 as t andrel/Valve ~? ~~ ^ 3 5301 5059 Camco KBUG GLV 1.0 BK 0.188 1332 2/7/1998 5 p' 4 5899 5531 Camco KBUG GLV 1.0 BK 0.188 1325 2/7/1998 (s35o-6351, 5 6350 5881 Camco MMG-2 OV 1.5 RK 0.156 0 2/6/1998 Production MandrelsNalves St MD TVD Man Mfr Man T e V Mfr V Type V OD Latch Port TRO Date Run Viv PBR (sao2-6ao3, yp Cmnt OD:3.5o0) - - 6 6463 5966 Camco NMG DMY 1.5 RK 0.000 0 2/8/1998 Closed Other lu s e ui .etc. -JEWELRY De th TVD T e Descri tion ID PKR 1787 1787 SSSV Camco TRDP-4A 2.813 (6415-6416, 6402 5920 PBR Baker w/ 10' Stroke 3.000 OD:6.151) 6415 5930 PKR Baker'HB' Retr. 2.890 6548 6028 SLEEVE-C Shifted Camco CB-1 Slidin Sleeve w/ NO GO Profile C Sand CLOSED 6/4/2004 2.750 6563 6039 PBR Baker'GBH-22' Locator Seal Ass w/ Muleshoe Btm 2.406 ~ 6565 6041 PKR Baker'1-B' 3.250 ~" ' ' 2 250 6575 6048 NIP Ni le NO GO Camco D . 6581 6052 SOS Baker 2.441 6582 6053 TTL 2.441 Pert 6535 6515 General NOteS ) ( - Date Note 1 /20/2004 WAIVERED WELL: IA x OA COMMUNICATION 9/2312004 CONFIRMED'C' SAND LEAK AT BOTTOM OF PACKER @6417' SLEEVE-C (s5as-s5as ~ 'C' SAND MANDREL 6463' ALSO LEAKING , OD:4.312) L PBR (6563-6564, OD:2.875) PKR (6565-6566, O D:6.151) NIP ' (6575-6576, OD:2.875) TUBING ~ (6562-6582, OD:2.875, I D:2.441) Perf (6614-6625) Pert (6654-6684) /7 r~?.J /- ~ ',~ r .~ ~ r,~~_._ ___ .~- vim, ii~~11111YGI-f~l- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~~~ JUL 2 ~ 2008 Log Description NO. 4775 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE j 06/24/08 1 1 1L-20A 10215099 PRODUCTION PROFILE ~(Jt,J '~ 06/26/08 1 1 1 G-05 12080389 LDL (p 06/27/08 1 1 36-10 12061714 INJECTION PROFILE T - t / ~ 06/27/08 1 1 2L-327 12061715 SBHP SURVEY 1~5 06/28/08 1 1 1J-109 12080390 SBHP SURVEY / ( 06/28/08 1 1 2N-323 12061716 SBHP SURVEY ~ '~-_- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY ~ -- 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY - j 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY ~(- ~~ 06/29/08 1 1 iG-09 12080401 INJECTION PROFILE () -' 1 /~ ~ 07/05/08 1 1 2H-05 12080396 SBHP SURVEY ~°° .-e- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY _ ~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY / 06/30/08 1 1 1D-07 12080398 SBHP SURVEY - .j 07/02/08 1 1 2N-341 12061720 SBHP SURVEY 06/30/08 1 1 3C-15 11982441 USIT - (~ / (~ 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `a - (p 07/08/08 1 1 i L-19 12061724 PRODUCTION PROFILE J p ~-b 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ~ 07/09/08 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. • 4 , ConocoPhillips Alaska P.O. BOX 100360. ANCHORAGE, ALASKA 99510-0360 May 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7tt' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ MAY 2 0 2008 5 r ~(~ a- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids. were filled•with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with. the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped April 3 2008 and the corrosion inhibitor/sealant was pumped on April 20th and 30`h of 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, 4 Perry Kle ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska-Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry ®perations (10-404) Date Kuparuk Field 5/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-01 184-115 25' S" 3.25 23" ~ 4/3/2008 1.7 .4/20/2008 26-02 184-122 30' 5" 0.5 20" 4/3/2008 4.3 4/20/2008 2B-03A .203-009 4' 0.5 33" 4/3/2008 10.2 4/20/2008 26-04 184-120 30' ~ 4 28:' 4/3/2008. 6.4 4/20/2008 2B-06 184-022- 26' 5 19" 4/3/2008 8.5 4/20/2008 2B-09 184-027 74' , 10.5 32" 4/3/2008 11.1 4/20/2008 2B-10 184-029' 74' ~ 10.5 33" 4/3/2008 17 4/20/2008 2B-11 184-035 50' - 7.5 29" 4/3/2008 6 4/20/2008 2B-12 184-038 6' 1 29" 4/3/2008 6 4/20!2008 2H-01 184-077 SF n/a SF n/a 2.5 4/30/2008 2H-02 184-073 SF n/a SF n/a 2 4/30/2008 2H-03 184-070 SF n/a SF n/a 4 4/30/2008 2H-04 184-055 SF n/a SF n/a 2 4/30/2008 2H-08 185-171 2' 6" n/a 2' 6" n/a 25 4/30/2008 2H-10 185-260 SF n/a SF n/a Z 4/30/2008 2H-11 185-261 SF n/a SF n/a 2.5 4/30/2008 2H-12 185-262 SF n/a SF n/a ~ 2.5 4/30/2008 2H-13 184-096 2" n/a 2" n/a 2 4/30/2008 2H-14 184-095 SF n/a SF n/a 2 4!30/2008 02/21/06 Schlumberger NO. 3691 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth "~"',l,¡ ? "'~^ '" F'EB f') 2. . ;-l1o~ r- [.. f-\J;JV Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n:l ~W:.. -,,,ìI~. v\J!ìUIH:>5101' ?,;icOOr¢~e Field: Kuparuk Well Color CD Job # Log Description Date BL 1 B-17 Iq4 - 045" 11216283 SBHP SURVEY 02/18/06 1 1 E-36 /98-.2/3 11216282 SBHP SURVEY 02/18/06 1 3H-07 /ß7-n7Q 11217023 LDL 02/11/06 1 3H-07 " /, 11166757 STATIC SURVEY 01/20/06 1 2A-09 ¡f:J/n-!íJ1 11154126 PRODUCTION PROFILE 02/09/06 1 1A-10 /B/- lid) 11213710 INJECTION PROFILE 02/08/06 1 2M-14 ¡q;; - Dlo, 11154127 INJECTION PROFILE 02/10/06 1 1 E-05 l.s::n- ()ó¡ 11166747 PRODUCTION PROFILE WIDEFT 12/25/05 1 2H-12 /PlS-:Jfl 11154128 PRODUCTION PROFILE W/DEFT 02/11/06 1 1 C-21 11154131 PRODUCTION PROFILE W/DEFT/GHOST 02/14/06 1 3G-18 /qtJ- / /)5' 11154129 PRODUCTION PROFILE WIDEFT 02/12/06 1 1 E-119 11217025 INJECTION PROFILE 02/13/06 1 2U-13 /B4-c?J{p 11166753 PRODUCTION PROFILE 01/14/06 1 1Y-09 18~-~ 11213128 INJECTION PROFILE 02/06/06 1 1 E-1 05 11162832 MEMORY INJECTION PROFILE 01/28/06 1 2C-08 1'83 -()C)5 11141255 INJECTION PROFILE 01/28/06 1 2C-02 /p,;.- rR!!J 11213129 INJECTION PROFILE 02/07/06 1 1C-25 ¡qq-C>3/ 11144074 GLS 02/02/06 1 2C-14 1M - '" fO 11166759 PRODUCTION PROFILE 01/25/06 1 2C-10 1!3-f-~ t 11144067 PRODUCTION PROFILE 01/26/06 1 1A-18ICJo-)Z5 ,::1, 11144070 PRODUCTION PROFILE 01/29/06 1 2C-01 /~-(;8? 11213709 INJECTION PROFILE 02/07/06 1 10-32 6200-173 11141252 LEAK DETECTION LOG 01/25/06 1 2C-12 /F54-~ 11141260 PRODUCTION PROFILE 02/02/06 1 2C-15 /84 - :;).6~ 11141254 PRODUCTION PROFILE 01/27/06 1 1J-154 N/A PRODUCTION LOG WITRACTOR 02/05/06 1 1 E-1 04 11217024 INJECTION PROFILE 02/12/06 1 e e Please sign and return one copy of this transmittal to Beth at the above address or fax to'(907) 561-8317. Thank you. ~~ ) ) ~~!Æ~! : F !Æ~!Æ~~~~, AIfASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR November 26,2004 333 W. ¡m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (90, 7", )""2",,,,7,,6, -"""7,,54,, ,,= lA""""2,,, , " ", ~"", . \f(j¥,,'plY Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") received a well safety valve system (SVS) test report from ConocoPhillips at Kuparuk River Unit 2H pad ("KRU 2H") dated November 1 0, 2004. Attached is a copy of the SVS Test Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission policy, "as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure thresho ld. Effective November 10, 2004 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2H must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, cf~ 'ß~RnC; James B. Regg ~ II Petroleum Inspection Supervisor Attachment SCANNEr) .Jt\N 112005 ") l ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ConocoPhillips Operator Rep: Noble - AES AOGCC Rep: Waived Submitted By: Brad Gathman FieldlUnitlPad: KRU 2H Separator psi: LPS Date: 11/10/2004 ,'<'WellDatil:' .:,,"::-.~ ~':.~,""',' W ell Permit Separ Number Number PSI 2H-01 1840770 2H -02 1840730 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 2H-06 1851690 96 2H-07 1851700 96 2H-08 1851710 96 2H-09 1852590 96 2H-10 1852600 96 2H-11 1852610 I 96 2H-12 1852620 96 2H-13 1840960 2H-14 1840950 2H-15 1840860 2H-16 1840870 2H-17 2000190 Wells: 96 HPS :",: ':' Pilots<:t.,';::...':'::'';,;::',' ,SSV SSSV Test/Retest/SflJO,te We!l;"Typ(!~;:' Set LIP Test Test Test Date Tested and or PSI Trip Code Code Code Passed Retest or SI 96 70 50 P P 70 65 P P 70 70 P P 70 50 P P 70 55 P P 70 50 P 4 70 55 P P 70 60 P 4 70 50 P P Oil, WAG, GINJ, GAS, CYCLE, SI WAG WAG WAG WAG OIL OIL OIL OIL OIL 11/11/2004 OIL OIL 11/11/2004 OIL WAG OIL WAG WAG WAG 9 Components: 18 F ai/ures: 2 11.11o/B 90 Day Remarks: Failure Rate: 2H-10 & 12 serviced and passed re-test Pad to be re-tested in 90 days RJF 09/19/02 Page 1 of 1 SVS KRU 2H 11-10-04.xls Schlumberger NO. 3231 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1 0/06/04 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Rocf-IJ$( J 1E-119 10884033 SCMT 10/04/04 / 90 - t) :3 if /1 L-09 10802915 PRODUCTION PROFILE W/DEFT 07/26/04 1 /Y5- t):;f j2V-14 10884026 PRODUCTION PROFILE W/DEFT 09/27/04 1 / 8~- I~ I 2K-02 10884027 PRODUCTION PROFILE W/DEFT 09/28/04 1 / q~ - (ifdJ 3J-17 10884031 PRODUCTION PROFILE 10/02/04 1 /~5- :2.23 3A-07 10884030 INJECTION PROFILE 10/01/04 1 /80 -{)S7 J 1E-04 10884023 INJECTION PROFILE 09/24/04 1 1 E-11 10884024 INJECTION PROFILE 09/25/04 1 /?~ - °5¡ J 2H-12 10884022 PRODUCTION PROFILE 09/23/04 1 / ~5 - ~ fR-z.. Q" tNED: /1 -k~ Kuparuk .-/ Color CD ~' SCANNED NOV 0 5 2004 DATE: ~~( Please sign and retur 0 e copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM TO' THRU' State of AlaSka Alaska Oil and Gas ConserVation Commission Julie Huesser, /~,~'~ Commissioner Tom Maunder, P. I. Supervisor DATE: December 2, 2000 FROM: Chuck Scheve; SUBJECT: Safety,Valve Tests Petroleum InspeCtor Kuparuk River Unit~ 2H Pad Saturday, December 2,-2000i I traveled to the KuParUk River Field and witnessed the semi annual safety valve system testing on 12H Pad.. ~ As the attached AOGCC Safety Valve SYstem Test Report indicates ! witnesSed the testing of 9 wells and 18 components with four failUres observed. The low pressure pilots on wells 2H-5,2H-6 and 2H-12 tripped well below the required set point and the surface safety valve on well 2H-12 failed to pressure test. The three failed pilots were adjusted and retested at the time of this test. The failed ValVe will be repaired and retested by the operator. The 22.2% failure rate will require, a retest of this PadS Safety Valve SyStem in 90 days rather than the n°rmal~Ott~day cycle. - ~ Earnie Barndt conducted the testing today he demonstrated good test prOcedUre and was a pleasure to work with · · Summary: I witnessed the semi annual SVS testing at 2H Pad in the KuParuk River Field. KRU 2H Pad, 9 wells, 18 components, 4 failures 22% failure rate Attachment: SVS KRU 2H Pad 12-2-00 cS X Unclassified Confidential (Unclassified if doc. RemOved) SVS KRU 2H Pad 12'2-00 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Emie Bamdt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: ,.Kupamk / KRU / 2H Pad Separator psi: LPS 96 HPS 12/2/00 Well Permit Separ Set L/P Test Test Test Date - Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 2H-01 1840770 ' · 2H-02 1840730 · 2H-03 1840700 2H-04 1840550 · 2H-05 1851680 96 70 20 3 P - 12/2/00 OIL 2H-06 1851690 96 70 10 3 P 12/2/00 · ' OIL 2H-07 1851700 96 70~ 60 P P i OIL 2H-08 1851710 96 70! 60P P OIL 2H-09 1852590 96 70 50 P P ' ' -OIL , 2H- 10 1852600 96 70 50 ' P P OIL 2H-11 1852610 96 70 50 P P . ' OIL 2H-12 1852620 96 ' 70 10 3 4 remarks 2H- 13 1840960 ' 2H-14 1840950 96 70 60 'P P OIL 2H- 15 1840860 2H-16 1840870 2H- 17 2000190 . . . . Wells: 9 Components: 18 Failures: 4 Failure Rate: 22.0% ~]90 my three failed pilots repaired and retested, failed SSV to be repaired and retested by op Pad on 90 day test cycle Remarks: 12/4/00 Page 1 of 1 SVS KRU 2H Pad 12-2-00 CS.xls ARCO Alaska, In( Post Office----~..~-~~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 27, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive' Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~<~-~qq 2A-13 Stimulate ES- zu~.--- 2H- 12Stimulate ~:}--~ 2K-14 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering t ECEIVED s EP 2 9 993 Alaska Oil & Gas Cons. Commissio,', Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMiboION REPORT OF SUNDRY WELL OPERATIONS ""/CD,,. 1. Operations Performed: Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska. Inc. Exploratory _ RKB 1.;30, PAD ~5" 3. Address P. O. Box 100360, Anchorage, AK 99510 Stratigraphic Service 4. Location of well at surface 170' FNL, 714' FEL, SEC. 35, TLLN, R8E, UM At top of productive interval 1315' FSL, 1267' FEL, SEC. 26, TLLN, R8E, UM At effective depth 1505' FSL, 1263' FEL, SEC. 26, TLLN, R8E, UM At total depth 1544' FSL, 1262' FEL, SEC. 26, TLLN, R8E, UM 12. Present well condition summary Total Depth: measured 6840' feet true vertical 6236' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2H-12 9. Permit number/approval number 85-262 (Qgrlserv Order No. 261~ 10. APl number 5o-103-20053 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 6 7 8 6' feet true vertical 6198' feet Junk (measured) Casing Length Structural 9 0' Conductor Surface 2 7 1 0' Intermediate Production 6 8 3 4' Liner Perforation depth: measured 6515'-6535', true vertical 6004'-6019', Tubing (size, grade, and measured depth) Size 16" Cemented 9 5/8" 700 SX CS III 300 SX CS II 3O0 SX CLASS G & 175 SX CS I 6614'-6625', 6654'-6684' 6076'-6084', 6105'-6126' 3 1/2", J-55/L-80 9.3# TBG & 2 7/8" 6.5# J-55 (TAIL) @ 6582' Packers and SSSV (type and measured depth) Measured depth 114' 2741 ' 6834' True vertical depth 114' 2741 ' R E D SE P 2 9 1993 Alaska 0il & (~as ~;uns. u,,,,m~sst Anchorage BAKER HB RETR PKR @ 6415', BAKER '1B' PERM PKR @6561' (E-LINE MEAS), CAMCO TRDP-4A SSSV @1787"MD 13. Stimulation or cement squeeze summary Intervals treated (measured) A3, A4 Sand 6614'-6684' MD Treatment description including volumes used and final pressure 36,000 lbs of 12/18 LWD in formation, final pressure 7400 psi 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 100 .,/1-000 500 1500 255 1500~' 2200 30 1500 225 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service Signed17. I her~~rtify~l ~'~-that i~~)regoing,,,.~ · ~is true and correctTitle tOseniorthe beStEngineerOf my knowledge. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc~. g~ Subsidiary of Atlantic Richfield Company IFIELD - DISTRICT- STATE OPERATION AT REPORT TiME WELL SERVICE REPORT WELL .,ONTRACTOR ,, , REMARKS 070O FoR c,~5a~e /~33 Z.~'P · 7t ~'.6, '-ltZO PS[ ~ C~RE 156~ ESoP .?o FG ~/35PSi F~3H N~ K~G~ 2~ 5P~ 57.8 ~ 57~ PS; Ft~ 17q3 /StP RECEIVED SEP 2 ~ i99~ Alaska Oil & Gas Cons. L;ommi~ssut, ' ' [~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport ITM 'F Chill Factor. F Visibility mile, I Wind Vel. STATE OF ALASKA ALASKA OIL AND ~ GON,SEBVA~ GOMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Pull tubing 2. Name of Operator Operation Shutdown__ Stimulate m x Alter casing Repair well 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service ARGO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 170 FNL, 714' FEL, SEC 35, T11N, R8E, UM At top of productive interval 1315' FSL, 1267' FEL, SEC 26, T11N, R8E, UM At effective depth 1505' FSL, 1263' FEL, SEC 26, T11N, R8E, UM At total depth 1544' FSLr 1262' FELt SEC 26r T11Nr R8E~ UM 12. Present well condition summary Total Depth: measured 6840' true vertical 6236' Plugging __ Perforate _ X Other 6. Datum elevation (DF or KB) feet feet Plugs (measured) RKB 130'. pAD g0' 7. Unit or Property name Kuparuk River Unit 8. Well number 2H-12 9. 'Permit number/approval number 85-262fConserv Order No. 10. APl number 50-103-20053 11. Field/Poo~ Kuparuk River Oil Pool 261}. Effective depth: measured 6786' feet true vertical 6198' feet Junk (measured) Casing Length Size Cemented Structural 90' 1 6 ' Conductor Surface 2710' 9-5/8' 700 SX CS III Intermediate & 300 SX CS II- Production 6834' 7 ' 300 SX CLASS G & 175 SX CS I Uner Perforation depth: measured 6515'-6535', 6614'-6625', 6654'-6684' MD true vertical 6004'-6019', 6076'-6084', 6105'-6126' TVD Tubing (size, grade, and measured depth) 3-1/2' J-55/L-80 9.3# TBG & 2-7/8' 6.5# J-55 (TAIL) ~ 6582' Packers and SSSV (type and measured depth) Measured depth 114' 2741' 6834' True vertical depth 114' 2741' 6233' FEB I ! ":* Anchorage BAKER HB RETR PKR @ 6415',BAKER'1B' PERM PKR @ 6561' (E-line meas), CAMCO TRDP-4A SSSV @ 1787' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Dai_ly Averaae Production or Iniection Data OiI-Bbl _~.-~_-_~AVlc~ Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 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 that the foregoing is true and correct to the best of my knowledge. Signed ~ Form 10-404 Rev 05/17/89 Title Area Drilling Engineer Service Date SUBMIT IN DUPUCATE ARCO ALASKA INC. "-~ DAILY OPERATIONS'~ PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2H-12 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-103-20053 ACCEPT: 01/06/93 03:30 SPUD: RELEASE: 01/15/93 12:00 OPERATION: DRLG RIG: WO/C RIG: NORDIC 1 01/07/93 (1) TD: 6840 PB: 6786 CONT TO KILL WILL MW:ll.4 NaCl/Br RELEASE RIG F/2M-07 AND MOVE TO 2H-12. ACCEPT RIG @ 15:30 HRS 01/06/93. LEVEL RIG, PULL FMC ANN VR PLUG(UNABLE TO REMVE), LOAD SW IN RIG. NU OUTSIDE VALVE ON 7" CSG VALVE, BLEED OUT VR PLUG. RU KILL LINES TO WELLHEAD, SITP=1550 PSI. SICP=ll00 PSI. BULLHEAD TBG VOLUME SEA WATER, SITP=800 PSI SICP=ll50 PSI. FILL PITS W/160 BBL BRINE, COND TO 11.4 PPG, BULLHEAD 45 BBLS, CIRC 96 BBLS 11.4 BRINE, TBG ON VACUMM, DIESEL IN ANN RETURNS, SICP=250 PSI. CONT CIRC 31 BBLS 11.4 BRINE IN ANN RETURNS. SITP=0 PSI, SICP=100 PSI. SET BPV. ND TREE. NU BOPE & FLOWLINE. C/O PIPE RAMS, PULL BPV, WELL FLOWING AFTER PULLING BPV, FLUID & GAS BLEEDING BACK THRU MUD PMP. REMOVE ROCKS F/DISCHARGE VALVES ON PMP. TRANSFER BRINE F/TIGER TANK TO PITS, SITP=350 PSI SICP=500 PSI. WELL : 2H-12 OPERATION: RIG : NORDIC 1 PAGE: 2 01/08/93 (2) TD: 6840 PB: 6786 01/09/93 (3) TD: 6840 PB: 6786 POOH & STAND BACK 2-7/8" MW:10.6 NaCl/Br CONT TO MONITOR WELL PRESS; SITP=350 PSI, SICP=500 PSI. ATTEMPT TO REKILL WELL. BULLHEAD 50 BBLS 11.4 BRINE DN TBG @ 3 BPM; FINAL SITP=0 PSI, SICP=350 PSI. CIRC BRINE DN TBG TAKING RETURNS F/ANN TO UPRIGHT STORAGE TANK. BOTH TBG & ANN ON VACUUM; TOO STRONG TO CONT. PRESS ON ANN AFFECTED TBS READING WHEN CALC KILL WT FLUID & WT OF BRINE IS TOO HIGH. REKILL WELL W/SEAWATER. ATTEMPT TO CIRC SEAWATER DN ANN & UP TBG, SAW 2000 PSI @ .5 BPM, ONLY GOT AWAY 14 BBL. BULLHEAD 50 BBL SEAWATER DOWN TBG & MONITOR PRES. FINAL SITP=725 PSI, SICP=200 PSI. KILL WT FLUID CALC TO BE 10.6 PPG. WATER BACK BRINE. BULLHEAD 48 BBL 10.6 PPG BRINE DN TBG. FINAL SITP=O PSI ON VAC. SET TEST PLUG. TEST BLIND & PIPE RAMS, ANN, HCR, CHOKE & KILL LINE VALVES, & FLOOR VALVES TO 3000 PSI. TEST ACCUM SYSTEM-OK. WITNESSING OF BOP TEST WAIVED BY AOGCC REP LOU GRIMALDI. PULL TEST PLUG. MU LANDING JT. WELL STILL DEAD. PULL HGR TO FLOOR & CLOSE ANN. UP WT=38K W/20K DRAG ONCE OUT OF PBR. ATTEMPT TO CIRC BRINE OUT ANN W/10.6+ PPG. PMP 100 BBL, LOSE 36 BBL, SOME SEAWATER BUT MOSTLY 11.4 PPG BRINE RETURNS. SHUT DN TO CHECK PMP SCREENS & SUCTION LINES F/JUNK AS PMP HAS BEEN HAMMERING DURING CIRC. BRING BRINE INTO PITS & COND. CONT TO CIRC DN TBG, BUT BEGIN RECEIVING CLEAN 10.6 PPG RETURNS; APPARENTLY CIRC THROUGH TBG LEAK INSTEAD OF OUT SEALS. ATTEMPT TO CIRC DN ANN & UP TBS; PMP 110 BBL 10.6+ BRINE, LOSE 47 BBL W/O SEEING ANYTHING BUT 10.6 RETURNS; ASSUME STILL CIRC THROUGH LEAK. MONITOR TBG & ANN, WELL DEAD. TBG ON SLIGHT VAC, SICP=0 PSI. LD LANDING JT & HGR. POOH, STANDING BACK 2-7/8" TBG & REMOVING SSSV CL. NO EXCESS DRAG. RIH W/4.5 GRAPPLE MW:10.6 NaCl/Br SERVICE RIG, CHECK CROWN. INSPECT DRILLING LINE. CONT POOH & STAND BACK 2-7/8" TBG TO 3567' LD JEWLELRY. RIH W/ 2-7/8" TBG. 30 SS C-LINE BANDS RECOVERED. STRAP 2 JTS 3-1/2" TBG & MU W/XO TO 2-7/8". RIH TO TOP OF PBR. RU CIRC HEAD. CIRC 10.5 PPG BRINE DN TBG F/ SURF TO SURF @ 3 BPM & 400 PSI, LOST 9 BBL. SAW + 60 BBLS OF 10.0 TO 11.1 PG FLUID DURING CIRC. STING INTO PBR EASY. RU HLS. RIH W/I-Ii/16" TBG PUNCH, COULD NOT GET PAST 5512'. POOH & MU WT BARS & SPANGS. RIH, STILL COULD NOT GET PAST 5512'. VERY SOLID OBSTRUCTION, TOOL NOT STICKING. POOH. RD HLS, RU FLOOR EQUIP. LD 3-1/2" TBG. POOH & LD 2-7/8" TBG & JEWELRY. TEST TBG & JEWELRY FOR NORM, ALL OK. LOAD PIPE SHED W/3-1/2" DP & 12 4-3/4" DC. STRAP & TALLY. CHANGE OUT PIPE RAMS F/2-7/8" TO 3-1/2", TEST TO 3000 PSI. SET WEAR BUSHING. PU FISHING ASSY ~1 & RIH ON 3-1/2" DP. WELL : 2H-12 OPERATION: RIG : NORDIC PAGE: 3 01/10/93 ( 4) TD: 6840 PB: 6786 01/11/93 (5) TD: 6840 PB: 6786 RIH W/SECOND CHEM CUTTER MW:10.6 NaCl/Br SERV RIG. CHECK CROWN. CONT RIH W/4-1/2" GRAPPLE ON 3-1/2" DP TO TOP OF PBR. CIRC WELL SURF TO SURF W/10.5 PPG BRINE @ 3 BPM & 550 PSI. MONITOR WELL F/30 MIN & CHECK HOLE FILL, LOST 2 BBL. LATCH PBR W/GRAPPLE. RU HLS. RIH & FIRE 1-11/16" 4 SPF TBG PUNCH F/6566'-6567'. POOH. RIH W/I-ii/16" CHEMICAL CUTTER & FIRE @ 6552', COULDN'T SEE FIRING OF HEAD VERY WELL. DP UP WT @ 90K, DOWN WT @ 73K. BEGIN POOH & BECOME STUCK @ 6516'. WORK LINE, ATTEMPT TO PMP DOWN ON TOOL STRING W/O SUCCESS. UNABLE TO SHEAR OFF ROPE SOCKET. WAIT ON KINLEY CUTTER F/OIIS. DROP CUTTER @ 0040 HRS & CUT LINE. POOH W/LINE, APPEARS THAT MOST IF NOT ALL LINE RECOVERED. REHEAD LINE. RIH W/WT BARS, CCL, & SPANGS, TAG FISH @ 6516'. POOH TO MU SECOND 1-11/16" CHEMICAL CUTTER STRING. WILL CUT IN FULL JT ABOVE BLAST RINGS. POOH & ATTEMPT TO PULL PKR. DECIDED AGAINST WL FISHING F/KINLEY & FIRST CHEMICAL CUTTER AS TOOL STRING SEEMED FIRMLY STUCK, BELIEVE CAN RETRIEVE TOOLS W/BLAST RING JT. CBU AFTER WASH OVER B RINGS MW:10.6 NaCl/Br RIH W/ SECOND CHEM CUTTER & SHOOT @ 6504' IN FULL JT ABOVE BLAST RING. POOH & RD HLS. PU ON PKR, PULL & JAR LOOSE @ 160 K. CIRC OUT GAS THROUGH CHOKE, 1.5-2 BPM, 450 PSI. SAW VERY LITTLE GAS COME BACK. MONITOR WELL FOR PRESS & FLOW, NO GAS. POOH W/PKR. WORK ACROSS CASG COLLARS TO TRY & BREAK DOWN RUBBER ELEMENTS. POOH SLOW TO PREVENT SWABBING. LD PKR, 2 1-1/2 "GLMS, 3 FULL JTS 2-7/8" TBG & 12.95' TBG STUB. TOP OF STUB IN HOLE @ 6488' NORDIC RKB. SOME EROSION ON BTM GLM & TBG STUB, CORROSION ON TBG & GLMS. PACKER ELEMENTS IN FAIRLY GOOD SHAPE. RERUN WEAR RING. MU 5" ID WASH PIPE(5-3/4" OD) FOR RUNNING OVER BLAST RINGS. RIH TO TOP OF DRILL COLLARS. SLIP & CUT 50' DRILL LINE. RIH W/WASH PIPE ON 3-1/2" DP TO TOP OF FISH. PU KELLY. TEST LOWER & UPPER KELLY COCK VALVES TO 3000 PSI. WASH OVER FISH F/6488'-6540' NORDIC RKB. CIRC & WORK PIPE A LITTLE TO GET ANY SAND MOVING. LITTLE SIGN OF FILL WHEN WASHING OVER, VERY SOFT IF ANY PRESENT. PU WASH PIPE UNTIL OFF FISH. CBU @ 2.5 BPM & 400 PSI. ROTATE & RECIP WHILE CIRC. LITTLE SAND ACROSS SHAKERS. WELL : 2H-12 OPERATION: RIG : NORDIC 1 PAGE: 4 01/12/93 (6) TD: 6840 PB: 6786 01/13/93 (7) TD: 6840 PB: 6786 01/14/93 ( 8) TD: 6840 PB: 6786 BAIL SND F/TOP OF FISH W/WL @5 MW:10.6 NaCl/Br CONT CIRC WHILE SERVICE RIG, BLOW DOWN & STAND BACK KELLY, RU TO POOH, POOH W/WASHOVER PIPE, CLEAN PIT #1 WHILE POOH, STAND BACK DCS, LD FISHING BHA ~2, MU FISHING BHA #3 (GRAPPLE F/2-7/8" TBG), RIH 0N'3-1/2" DP TO 6465', UP WT 90K DN WT 70K, FL F/0600-1200 = 18 BBL, TAGGED TOP OF TBG STUB @ 6488', WORK GRAPPLE OVER FISH, PULL 10K OVER STRING WT, COULD NOT PICK UP FISH (17' TBG STUB, BLAST RING JT, 2' STUB IF FIRST CHEMICAL CUT TOOK). WAIT ON WIRELINE TO FISH OUT STUCK CHEMICAL CUTTER TOOL STRING & KINLEY CUTTER, RU OTIS, FL F/1200-1800 = 13 BBL, RIH W/ GRAPPLE, COULD NOT LATCH, POOH & RUN IN W/LIB, SHOWED FINE SAND ON TOP OF FISH. RIH W/1-1/2"XS' PUMP BAILER W/MS (FLAPPER CHECK), MADE 6 RUNS @ 06:00, COMING BACK W/FULL TO PARTIAL LOADS OF SAND. WORKED DOWN TO 6500 & SEEING SIGNS OF FISH, RUNNING IN W/CENTERING SKIRT ON BAILER TO DETERMINE IF ON TOP OF FISH. FL F/1800-0600 = 18 BBLS POH W/DCS MW:10.6 NaCl/Br POOH W/BAILER @ 06:40 AND RECOVERED FULL LOAD. MADE 6 MORE BAILER RUNS UNTIL MADE CONTACT W/CUTTER, ALL TRIPS CAME BACK W/FULL LOADS. RIH W/1.82" LIB TO 6509', RECEIVED GOOD IMPRINT ON BLOCK. RIH W/WL & FISHING TOOL, RECOVER KINLEY CUTTER, RIH W/ 1.82" LIB, RIH W/ WL & 1.75" BAILER W/MULE SHOE, RETURN W/BAILER EMPTY, RIH W/DOWN DRIVER BAILER, RETURN W/SMALL PIECE OF METAL SLIP, RIH W/WL & 1.75" BLIND BOX TO 6511', TRY TO PUSH FISH DH TO RATHOLE W/O SUCCESS, RIH W/LIB, TOP OF TBG PATCH @ 6511' SL, RIH W/10' 1.5" TOOL STRING TO 6521', FISH MUST HAVE WENT DOWN HOLE WHILE BAILING SAND. RIH W/1.75" TBG BRUSH ON 1.5" TOOL STRING TO 6600', DID NOT TAG OBSTRUCTIONS, CHEMICAL CUTTER IS IN RATHOLE, RD OTIS, RU HLS, RIH W/I-II/16" CHEMICAL CUTTER, CUT TBG IN 4' PUP BELOW BLAST JT @ 6538.5, POH RD HLS, DID NOT GET COMPLETE CUT, WORK PIPE GENTLY 10K ABOVE WT WHILE CIRC, PIPE CAME FREE, CONT TO CIRC, POH W/3-1/2" DP LOAD PIPE SHED W/3-1/2" TBG MW:10.6 NaCl/Br SERV RIG. CHECK CROWN-O MATIC. POOH W/FISH, FISH CONSISTS OF ALL REMAINING JEWLELRY DOWN TO PERM PKR. BREAK FISH DOWN. LD TRI-STATE TOOLS. TALLY & STRAP BHA ~4. RIH W/6-1/8" BIT, BHA, & 3-1/2" DP FOR CLEANOUT RUN TO PKR. TAGGED PKR @ 6554'. CIRC WELL @ 2 BPM & 50 PSI. POOH & LD OIL JARS, BUMP SUB, XO & BIT. MU SEAL ASSY, & XO. RIH W/BHA ~5 & 3-1/2" DP FOR DUMMY RUN ON PKR. STING INTO PKR TO VERIFY SEAL. POH. LD 3-1/2" DP & DC'S. RD. LD EQUIP. PULL WEARBUSHING. WELL : 2H-12 OPERATION: RIG : NORDIC 1 PAGE: 5 01/15/93 (9) TD: 6840 PB: 6786 PREP TO ND BOP MW:10.6 NaCl/Br SERV RIG. HOLD SAFETY MEETING. LOAD PIPE SHED W/3-1/2" TBG, DRIFT & TALLY SAME. INSTALL BLAST RINGS ON BLAST RING JT. RIH W/3-1/2" COMPLETION STRING: 3-1/2, 9.3# J-55 TBG & JEWELRY. MU CAMCO SSSV, MU "C" LINE & TEST LINE TO 5000 PSI F/10 MIN. CONT TO RIH W/3-1/2" TBG. INSTALL SS BANDS ON EVERY OTHER JT. TOTAL 29 BANDS. SPACE OUT W/2-10' & 1-4' PUP. MU FMC TBG HGR, ATTACH 'C' LINE TO TBG HGR & TEST TO 5000 PSI F/10 MIN. DRAIN BOP'S. LAND TBG & RILDS. RU CAMCO SL. RIH & SET CA-2 PLUG IN 'D' NIPPLE. POH. PRESSS TBG TO 2500 PSI TO SET PKR. SHEAR PBR 22K ABOVE WT. RELAND TBG. RILDS. TEST SSSV TO 1000 PSI. TEST ANN TO 2500 PSI. TEST TBG TO 3500 PSI. RU CAMCO. RIH. POH W/EQUALIZING PRONG. RIH. POH W/PLUG. RD CAMCO. LD LJT. SET BPV. 01/16/93 (10) TD: 6840 PB: 6786 RIG RELEASED MW:10.6 NaC1/Br ND BOP, NU TREE, TEST PACK-OFF & FLANGE @ 5000 PSI. PULL BPV & INSTALL TEST PLUG. TEST TREE @ 250 PSI & 5000 PSI. PULL TEST PLUG & RU LINES TO DISPLACE WELL. DISPLACE ANN W/12 BBLS DIESEL, BULLHEAD 4 BBLS DIESEL DOWN TBG @ 1 BPM & 1600 PSI. RD LINES & SECURE WELL. SITP=0, SICP=0. CLEAN PITS & FLUSH ALL LINES W/SW. MOVE OFF WELL. CLEAN AROUND LOCATION. RIG RELEASED @ 1200 HRS 01/15/93. SIGNATURE: DATE: STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION ~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate ~ Plugging Perforate Repair well X Pull tubing Other 2. Name of Operator ARCO Alaska. IRc. 3. Address P. 4, O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 70' FNL, 714' FEL, Sec. 35, T11N, R8E, UM At top of productive interval 1315' FSL, 1267' FEL, Sec. 26, T11N, R8E, UM At effective depth 1315' FSL, 1267' FEL, Sec. 26, T11N, R8E, UM At total depth 1544' FSL~ 1262' FEL~ Sec. 26, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) 130' RKB 7, Unit or Property name Kuparuk River Unit 8. Well number 2H-12 9. Permit number/approval number 85-262 10. APl number 5o-103-20053 11. Field/Pool Kuparuk River Oil Pool feet 6 8 4 0' feet Plugs (measured) 6236' feet Effective depth' measured 6 7 8 6' feet Junk (measured) true vertical 6200' feet None Casing Length Size Cemented Measured depth Structural Conductor 82.5' I 6" 250 Sx AS I 1 1 4' Surface 2709.5' 9 5/8" 700 Sx CS III & 2741' Intermediate 300 Sx CS II Production 6802.5' 7" 300 Sx Class "G" & 6834' Liner 175 Sx CS I Perforation depth: measured 6654'-6684' MD (4 JSPF 90 degree phasing), 6515'-6536' MD (12 SPF true vertical 6105'-6127', 6004-6020' TVD Tubing (size, grade, and measured depth) 2 7/8", J-55, 6.5 lb/fi, 6578' MD Packers and SSSV (type and measured depth) Brown lB ~ 6561'~ Brown HB ~ 6365'~ Baker FVL@ 1797' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth 114' 2741 ' 6233' 120 degree phasing) ECEIVED DEC 1 I 1990 A/aska .0il ~ (~as ~J0ns. 60mmisslu~ Anchorage Repaired Well as follows: On 8/18/90, ran and set Merla tubing patch from 6529'-6545' MD (ID=1.873") to isolate the A Sand. 14. Reoresentative Daily Average Production or In!ection Data Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X OiI-Bbl Gas-Mcr Water-Bbl Casing Press Tubing Press 31 5 394 797 1 1 6 0 173 3 4 2 366 0 1 2 0 0 250 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. Si~ned~~_-/~. ~ Title: ..OPERATIONSENGINEER Form 10-404 Rev 06/15/88 Date~, ~./ //~ SUBMIT IN DUPLICATE A'RCO Alaska, Inc. ", ~ $~bsidlary of Atlantic Richfield Coml~ny '..,~ ~NT~CTOR WELL SERVICE REPORT 'OPERATION AT REPORT TIME JO,5 //50 1530 P.,, D E,C' Z3OD$?.gHL ',EC iVED .©, r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knot81 Signed ARCO Alaska, Inc. ' ,Subsldlaryof Atlantic Richfield Company ,.cr)I~TRACTOR R~-MARKS i FIELD- DISTRICT. STATE OPERATION AT REP,~T TIME WELL SERVICE REPORT . · o 330 ls-'oo 0/~/Y' tv",.. L L /oo~6Lr 3~'?o ~6rO Z-dJ o..T /~-.z C/,z) /0~¢3,c c" Oil & Gas CO.n.S. Coium/sslorl Anchorage [-i CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ STATE OF ALASKA A "L~.~J~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALE 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X~ Pull tubing _ Variance _ Perforate _ Other 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 170' FNL, 714' FEL, Sec. 35, T11N, RSE. UM At top of productive interval 1315' FSL, 1267' FEL, Sec. 26, T11N, RSE, UM At effective depth 1315' FSL, 1267' FEL, Sec.26, T11N, RSE, UM At total depth 1544' FSL, 1262' FEL, Sec. 26, T11N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production measured true vertical Length 82.5' 2709.5' 6802.5' 6840' feet Plugs (measured) 6 2 3 6' feet 678 6' feet Junk (measured) 6 2 0 0' feet None Size Cemented 1 6" 250 Sx AS I 9 5/8" 700 Sx CS III & 300 Sx CS II 7" 300 Sx Class G 175 Sx CS I 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit 8. Well number 2H-12 feet 9. Permit number 85-262 10. APl number 5o-103-20053 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured de~h True ve~ical depth 114' 114' 2741' 2741' 6834' 6233' measured 6515'-6536' (C Sand) 12 SPF 120 degree phasing 6654'-6684' (A Sand) 4 SPF 90 degree phasing true vertical 6004'-6020', 6105'-6127' Liner Perforation depth: Tubing (size, grade, and measured depth 2 7/8" J-55 EUE, 6.5 lb/fi, set @ 6578' Packers and SSSV (type and measured depth) Packers: BROWN HB 6365', BROWN lB 6561'~ Baker FVL ~ 1797' 13. Attachments Description summary of proposal _ Refrac A Sand with 27,940 lbs of 16/20 mesh carbolite. Date approved 14. Estimated date for commencing operation December, 1989 16. If proposal was verbally approved RPCEIVED Detailed operation program X.~ BOP sketch _ (Procedure and Wellbore schematic attached). 15. Status of well classification as: Oil ~ Gas __ Service Name of approver Suspended Date 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~~ ~ /~f~f~.x.x~~ Title Sr. Operations Engineer FOR COMMISSION USE ONLY Approved by the order of the Commission Form 10-403 Rev 5/03/89 IIAppr°val No~ Date //-",~ '~ SUBMIT IN TRIPLICATE Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test m Location clearance__ Mechanical Integrity Test Subsequent form require 10-~-~-'~ -- -.vect Ool3¥ ~Retu~neu 0p.,cqN^L SIGNED BY ~ ~n ~ n~,~.!iF fi. SMITH er Kuparuk Well 2H-12 'A' Sand Re-Fracture Procedure Cost Tracking AFE #K80666 1. MIRU Slickline unit. Tag bottom. . . . . . . . Pull CV's at 6400', 6471', and 6543'. Run DV's at 6400', 6471', and 6543'. RDMO slickline unit. If less than 50 feet of rathole is discovered during the pre-frac Wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. Perform A Sand only production test followed by an Automatic Echometer PBU. MIRU Slickline unit. Pull GLV's at 2271', 3570', 4689', 5501' and 6310'. Run DV's at 2271', 3570', 4689' and 5501'. Circulate 2 7/8" tubing and 7" annulus with 9.8 ppg brine with a diesel cap. Set DV in GLM at 6310'. Note that DV's are set in GLM's at 4284', 5098' and 5935'. Set standing valve in Camco 'D' nipple at 6571' MD-RKB. Pressure test the tubing. Pull standing valve. RDMO Slickline unit. RU fracture equipment. Install "Tree Saver". Pressure up 7' annulus to 3500 Psi. Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After the fracture stimulation, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. Pump the 100 Bbl pre-pad at 18 BPM. Shut down and determine the ISIP. The A Sand was perforated with 120 shots, 4 spf, at 90 degree phasing with a Casing Gun and with 44 shots, 4 spf through tubing. Pump fracture treatment per the attached schedule. Record the 2, 5, 10, and 15 minute pressures following the ISlP. Expected wellhead treating pressure: WHTPE = 4400 psig Fracture Gradient = 0.73 psi/ft (6080' TVD) Frac Fluid Gradient = 0.35 psi/fi Tubing Friction = 320 psi/1000 ft @ 18 BPM (6578' MD) * If excessive treating pressures are experienced, try reducing the rate in small increments adjusting additive rates as appropriate. With 9.6 ppg brine on the backside, the maximum recommended treating pressure is 6400 psi based on analysis of tubing strength and PBR type. Maximum pressure during the initial fracture treatment was 5600 psi. 8. Rig down fracture stimulation equipment. Follow attached flowback schedule. KUPARUK WELL 2H-12 A 8AND FRACTURE PUMP SCHEDULE 11/8189 STAGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PFDPPANT PFIOPPANT WT DIRTY VOM.ME HIT PERFS OESCR,IPT[~ BBLS ,BPM PPG DESCRIPTION LBS STG/CUM BBLS 1 GD PRE-PAD 100.0 18 0 - - 0 100 / 100 40 ............................................. SHUT DOWN FOR ISlP, FLOW METER CALIBRATION ................................................ 2 G~PAD 160.0 18 0 - - 0 160 I 260 140 3 GD w/2 PPG 4.6 18 2 16/20 M C~,RBO-LITE 386 5 I 265 300 4 GD wi4 PPG 8.5 18 4 16/20 M CARBO-LITE 1428 1 0 I 275 305 5 GDw/6PPG 11.9 18 6 16/20 M CARBO-LITE 2989 15 / 290 315 6 GD w/7 PPG 15.3 18 7 16/20 M CARBO-LITE 4494 20 I 310 330 7 GD w/8 PPG 18.5 18 8 16/20 M CARBO-LITE 6210 25 I 335 350 8 GD wi10 PPG 13.9 18 10 16/20 M CARBO-LITE 5830 20 I 355 375 9 GD w112 PPG 13.1 18 12 16/20 M CARBO-LITE 6593 20 I 375 395 10 SLICK DIESEL FLUSH 38.0,,+SV 18 0 . TOTAL SLICK DIESEL - 38.0 +SV TOTAL GELLED DIESEL- 345.7 BBLS TOTAL FLUID - 383.7 27,931 LBS NOTES: The table above represents total job volume. Stages 1 and 2 are Gelled Diesel with 40 Ib./1000 gal silica flour and enough breaker for an 8 hour break. Stages 3 through g are Gelled Diesel with enough breaker for an 8 hour break and WITHOUT silica flour. Stage 10 should Include a volume adjustment for surface equipment between the wellhead and the densitometer and an 8 hour breaker. Stages 3 through 10 are scheduled to pump at 18 BPM to limit height growth. However, an increase in treating prmur® may warren a decrease In rate or early flush. The Job is Intentionally underflushed by 2 Bbl. The blender tub ~hould be by~ .at flush. All fluids should be maintelned at 90+ degrees F on the ~urfece. The A Sand was perforated with approximately 164 shots (4 apl). KUPARUK WELL 2H-12 APl #: SPUD DATE: 501032005300 10/30/85 ADL LEASE: 25587 COMPLETION DATE: 12/13/85 PERMIT #: WORKOVER SURFACE LOCATION: 170'FNL,714'FEL,SEC35,T11N,R8E TOP OF KUPARUK: 1315'FSL,1267'FEL, SEC26,T11N,R8E TD LOCATION: 1544'FSL,1262'FEL,SEC26,T11N,R8E All depths are MD-RKB to top of equipment unless otherwise noted ORIGINAL RKB: 130 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 62.5~ H-40 114 9.625" 36# J-55 2741 7" 26# J-55 6834 2.875 6.5 J-55 EUE 6578 LINER DETAILS SIZE WEIGHT GRADE TOP TUBING SPOOL: 31.5 WELLTYPE: PRODUCER BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV BAKER FVL 2.313 1797 SBR BROWN PBR 2.5 6352 PKR BROWN HB 6365 PKR BROWN lB 6561 NOC-~ CAMCO 'D' NIPPLE 225 6571 SHROUT BROWN 6577 STN 1 2 3 4 5 6 7 8 9 10 11 INTERVAL 6515-6535 6614-6625 6654-6684 DATE: PAD ELEVATION: 95 GAS LIFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2271 CAMCO KBMG 1.0" 3570 CAMCO KBMG 1.0" 4284 CAMCO KBMG 1.0" 4689 CAMCO KBMG 1.0" 5098 CAMCO KBMG 1.0" 5501 CAMCO KBMG 1.0" 5935 CAMCO KBMG 1.0' 6310 MCMURRY HUGHES FMHO 1.5" 6400 MCMURRY HUGHES FMHO 1.5' 6471 MCMURRY HUGHESFMHO 1.5" 6543 MCMURRY HUGHES FMHO 1.5" PERFORATION DATA ZONE FT SPF PHASE C 20 12 120 A 11 4 A 30 4 90 85-262 PORT SIZE .1563 .1563 DV .1875 DV · 1875 DV .1875 FO FO FO COMMENTS MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLEANGLE: 45 deg HOLE ANGLETHRU KUP: 43 deg LAST TAG DATE: 11/27/87 RATHOLE: ~,'7o~ ft FISH/OBSTRUCTION: PBTD: PBTDSS: DEPTH 3400 6786 6O68 REVISION DATE: 06/05/88 REASON: OPEN C SAND SUNDRY NOTICE - WELL 2H-12 NO BOP'S WILL BE UTILIZED DURING THIS PROCEDURE. BOTTOM HOLE PRESSURE (6200' SS) = 3230 PSI NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. ~---.- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIO 1. Type of Request: Operation Shutdown __ Stimulate , · Plugging Perforate _ Pull tubing Alter casing Repair well Pull tubing .. Other X 2. Name of Operator ARCO Alaska, Inc, 3. Address P. 4. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 70' FNL, 714' FEL, Sec. 35, T11N, R8E, UM At top of productive interval 1315' FSL, 1267' FEL, Sec. 26, T11N, R8E, UM At effective depth 1315' FSL, 1267' FEL, Sec. 26, T11N, R8E, UM At total depth 1544' FSL, 1262' FEL, Sec. 26, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 6840' feet Plugs (measured) 6236' feet 6. Datum elevation (DF or KB) 130' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number,~ 2H-12 / 9. Permit numb, er/~oproval n_umber 85-262 //~'"" 10. APl number 5o-103-20053 11. Field/Pool Kuparuk River Oil Pool Effective depth' measured 6 7 8 6' feet Junk (measured) true vertical 6198' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 2.5' 1 6" 250 Sx AS I 1 1 4' I 1 4' Surface 2709.5' 9 5/8" 700 Sx CS III & 2741' 2741' Intermediate 300 Sx CS I! Production 6802.5' 7" 300 Sx Class "G" & 6834' 6233' Liner 175 Sx CS I Perforation depth: measured 6654'-6684' MD (4 JSPF 90 degree phasing), 6515'-6536' MD (12 SPF true vertical 6105'-6127', 6004-6020' TVD Tubing (size, grade, and measured depth) 2 7/8", J~55, 6589' MD Packers and SSSV (type and measured depth) Brown lB @ 6561'~ Brown HB @ 6365', Baker FVL@ 1797' 13. Stimulation or cement squeeze summary C Sand SOC Treatment for Barium Scale= Intervals treated (measured) 6515'-6535' Treatment description including volumes used and final pressure 10 bbls sea water, 42.6 bbls diesel/musol(6.1%), 94 bbls *SOC pill, 118 bbls sea water, flush with 38 bbls diesel. Final pressure 2000psi. *SOC pill consisted of 3025 gal sea water, 415 gal 7.5% HCI, 4 drums SOC-2~ 6 drums Chemlink s-256, 6 drums CaCI2. 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FormSigned 1 (~-4~04~R~ /'~06,15/88 ,i~ ~,f.4.,~ tie SR. OPERATIONS ENGINEER 120 degree phasing) RECEIVED :JUN 2 Nask~ 0il & Gas ,dons. uomrnlss~u,~ Anchorage ~eoresentative Daily Average Production or Iniection Data -~,~iI-Bbl Gas-Mcf Water-Bbl Casing Press Tubing Press~ ~ 612 880 126 750 145 ~719 948 116 780 135 --I16. Status of well classification as: ! Oil X Gas Suspended ~ Service SUBMI~ IN DUPLICATE ARCOAlaska, v Subsidiary of Atlantic Richfield Compan-~/'-~ WELL IPBDT '3NTRACTOR REMARKS IFIELD - DISTRICT- STATE OPERATIO~N~AT~REPORT TIME WELL SERVICE REPORT I I £.g$- ~? IfeO --/?.~-_¢ ~JUN 2 2 ~ooo Alaska Oil & Gas Cons.n~omm~ss~,On' A~chorag~ Fl CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp' I Ch"' Fact°r I Visibmty IWindVe".eport °F °F miles '"~----- STATE OF ALASKA "-~' ~ ~ ~;, ~ i'~ ~" ~ ~ L ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~'~_.~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ 2. Name of Operator 15. Type of Well: Development ~( ARCO Ala,$ka, In(;. Exploratory __ 3. Address Stratigraphic __ P. O. Box 100360, Anchorage, AK 99510 Service __ 4. Location of well at surface 1216' FNL, 170' FNL, 714' FEL, Sec. 35, T11N, R8E, UM At top of productive interval 1315' FSL, 1267' FEL, Sec. 26, T11N, R8E, UM At effective depth 1315' FSL, 1267' FEL, Sec. 26, TllN, R8E, UM At total depth 1544' FSL, 1262' FEL, Sec. 26, T11N, R8E, UM 12. Present well condition summary Total Depth' measured true vertical 6840 feet Plugs (measured) 6236 feet _ Re-enter suspended well _ Time extension Stimulate Variance _ Perforate _ Other 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2H-12 9. Permit number 85-262 10. APl number 5o-1 03-20053 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 6786 feet Junk (measured) 6 2 0 0 feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 82.5' 1 6" 2709.5' 9 5/8" 6802.5 7" Cemented Measured depth True vertical depth measured 6654'-6684' 4 SPF 6515'~6536' 12 SPF true vertical 13. C Sand SOC treatment (scale). ' - '-'~ :--~ -~..~-- .-~---~- 14. Estimated date for commencing operation May 20, 1988 16. If proposal was verbally approved 250 Sx AS I 1 14' 1 14' 700 Sx CS III & 2741 2741' 300 Sx CS II 300 Sx Class (3 6834' 6233' 175 Sx CS I RECEIVED @0 degree phasing 120 degree phasing MA~ 2 6 ]989 6105 -6127, 6004-6020 TVD Tubing (size, grade, and measured depth 2 7/8" J-55 set at 6589' Packers and SSSV (type and measured depth) Brown lB ~ 6561'~ Brown HB @ 6365'~ Baker FVI @ 1797' Attachments Description summary of proposal X Detailed operation program ~ ~= . _ ~ -. ~-' '. 15. Status of well classification as: Oil X Gas & Gas cons. commissi01~ Anchorage BOP sketch Suspended Name of approver Date approved Service 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require Approved by the order of the Commission ORIGINAL SIGNED BY LONNiE C. SM!TI't 10-/~/¢ Approved Copy ?/eturned Commissioner IlAppr°val No~.~ Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE SUNDRY NOTICE - WELL 2H-12 Pump a C Sand SOC Scale Inhibitor Squeeze NO BOP'S WILL BE UTILIZED DURING THIS PROCEDURE. The treatment will be pumped through a surface manifold. C SAND PRESSURE (6200' SS) = 3230 PSI (1/29/88 SWHP/FL) NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. Messrs. Sioan and Jackson May 3, 1989 Page 2 SOC TREATMENT PROCEDURE WELL 2H-12 5/3/89 CC: 230DS28HL 1. MIRU slickline unit. 2. Set standing valve in D nipple at 6571' RKB. 3. RDMO slickline. ,1 Mix SOC pill in the following order: 1. 3025 gallons sea water (72 Bbl) 2. 415 gallons 7.5% HCL (9.9 Bbl) NO CORROSION INHIBITORS 3. 220 gallons SOC-2 (4 Drums) 4. 330 gallons Chemlink S-256 (6 Drums) Once the pill is mixed, agitate to ensure complete mixing before sampling pH. Monitor pH of pill, adding additional SOC-2 chemical to lower pH below 2.5, if necessary. Once the above are mixed, add the following-: 5. 330 gallons 30% CaCI2 (6 Drums) 6. MIRU pump equipment . Spear ahead of SOC pill with 10 Bbls seawater followed by 40 Bbls diesel containing 2 drums of Chemlink SA-8660. Follow spear with pre-mixed SOC pill pumping at a rate of 2 to 4 BPM. 8. Displace pill with 118 Bbls of seawater to push the SOC pill out into the formation. . 10. 11. 12. Follow water overflush with 38 Bbis diesel to displace tubing. RDMO pump equipment. = Shut-in well for 36 hours to allow chemicals to soak. MIRU slickline and recover standing valve. RDMO slickline. RECEIVED MAY 2 6 ]989 Nask~ 0il & (~as Cons. Commission1 Bring well back on production at 500 BPD. Open well fully and turn on gas/~h~ first day. Leave gas lift scale inhibitor off to allow SOC residuals to be measured. 1 3. Sampling for residuals will be coordinated by the Kuparuk Corrosion group. 3 2 1. 5000 PSI ?" WELLHE,a~ GONN[CIOR FLANGE 2. 5000 PSI WIRELIN[ RAIDS (VARIABLE $12£) ,1. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW IUB£ PACK-OFF RECEIVED MAY 2 6 ]989 .. Al~ka Oil & Gas Cons. Com,~lissiott Anchorage HIRELINE BOP .EOUIPMEN! STATE OF ALASKA ALA'~,<..A'OIL AND GAS CONSERVATION COIV,~.~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360: Anchorage: AK 99510 4. Location of well at surface 170' FNL, 714' FEL, Sec .35, TllN, R8E, UM At top of productive interval 1315' FSL, 1267' FEL, Sec.26, T11N, R8E, UM At effective depth 1506' FSL, 1266' FEL, Sec. 26, T11N, R8E, UM At total depth 1544' FSL, 1262' FEL, Sec.26, T11N, R8E, UM 5. Datum elevation (DF or KB) RKB 130' 6. Unit or Property name Kunaruk Riv~:r Ilnit-. 7. Well number 2H-12 8. Approval number 9. APl number 5O-- 103-20053 10. Pool Kuparuk River 0il Pool Feet 11. Present well condition summary Total depth: measured 6840 true vertical 6236 feet feet Plugs (measured) None Effective depth: measured 6786 feet true vertical 6198 feet Junk (measured) None Casing Structural Conductor Surface Production XXXL>~i~&-XXXXX Perforation depth: Length Size Cemented Measured depth 82' 16" 200SX CS-II 114' MD 2709' 9-5/8" 700SX CS-III 2741' MD & 300SX CS-II 6802' 7" measured 300SX Class G 6834' MD & 175SX CS-I 6654'-6684' MD, 6515'-6535' MD, 6614'-6625' MD True Vertical depth 114' TVD 2741' TVD 6234' TVD true vertical 6105'-6126' TVD, 6004'-6019' TVD, 6095'-6105' TVD Tubing (size, grade and measured depth) 2-7/8", J-55 EVE @ 6589' MD Packers and SSSV (type and measured depth) Baker FVL SSSV 8 1797'/Brown HB pkr @ 6365'/Brown lB pkr. @ 6561' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 380 4161 0 1000 458 130 0 1000 Tubing Pressure 130 110 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~..~//~/¢~, .~ 2/h~ ¢"~'r~¥"~'¢?~S' Form 10-404 Rev. i~-1-85 Title Sr. Operations Engineer Submit in Duplicate A'RCO Alaska, In¢~~ Subsidiaw of Atlantic Richfield Company WELL ' ":~NTRACTOR REMARKS IPB~,T.7 WELL SERVICE REPORT IFIELD - DISTRICT - STATE IOPERATION AT REPORT TIME ' iq3 o R u( iz~o - Pi'r- ~op ., L.,,,k . //' 1986 -_ ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report °F i "F [ miles ! }Signed~. knotsi STATE OF ALASKA ~ ALASKA O'TE AND GAS CONSERVATION COi~IlSSION Y-~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well l OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-262 3. Address 8. APl Number P. 0. Box 100:360, Anchorage, AK 99510-0:360 50- 10:3-2005:3 4. Location of well at surface 9. Unit or Lease Name 170' FNL, 714' FEL, Sec.:35, TllN, RSE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1:315' FSL, 1267' FEL, Sec.26, TllN, R8E, UM 2H-12 At Total Depth 11. Field and Pool 1544' FSL, 1262' FEL, Sec.26, T11N, R8E, UH Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 1:30' RKBI ADL 25587 ALK 267:3 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116' No' of Completions 10/:30/85 11/07/85 11/10/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 6840 'MD ,62:36 'TVD 6786'MD,6198'TVD YES E~x NO [] 1808 feetMD 1500' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 114' 24" Conductor report not y~t received. 9-5/8" :36.0# J-55 Surf 2741' 12-1/4" 700 sx CS I I I & :300 sx CS I I 7" 26.0# J-55 Surf 68:34' 8-1/2" :300 sx Class G & 175 st CS 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) 6654' - 6684' w/4 spf, 90° phasing 2-7/8" 6589' 6:376' & 6572' 6515' - 6535' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached AddEndum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "Ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneR CEIVED APRO 1986 Ala~ ~ii & Gas Cons. ConlfriissJori Anchorage. Form 10-407 * NOTE: Tubing was run and wel 1 perforated 12/1:3/85. GRU13/WC18 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. J' 30.. · . , . GEOLOGIC MARKERs FORMATION T'ESTS · . 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 6513' 6002' N/A Base Kuparuk C 6537' 6020' '' Top Kuparuk A 6578' 6050' Base Kuparuk A 6776' 6191' i:~ ~ · ~::: . . . :-, . · .. 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) ., -- 32. i hereby certify that the foregoing is true and correct to the best of my knowledge ~ Associate' Engineer Signed ~ Title Date 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.). ~-~'~ -~ ~, ~ i .", '"',. ': :" Item 2~3! '~t~a~hed supplemental records for this well should show the details of any mul'tiple stage cement- ing and th,e. location of. the cementing tool. .~i. . '.-i :' Item 27' Method of O, perati.o.n' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jeb±ioh,~(3 ~is '1 nj~c~io.~n;'S'hutin~ Other-explain. .~,~ Item 28: If no cores taken, indicate "none". ',. Form 10-407 ADDENDUM WELL: 12/02/85 1/12/86 2H-12 Rn GR/CCL/CET/gage ring f/6782'-5500'. Rn GCT gyro f/6782'-surf. Frac Kuparuk "A" sand perfs 6654'-6684' in 3 stages per 12/27/85 procedure using gelled diesel, Musol & 20/40 sand. Press'd ann to 1510 psi w/diesel. Tst lns to 7000 psi; OK. Pmp'd 20 bbls 5% Inflo 40 Musol, followed by 40 bbls cln diesel on 1/11/86. Stage 1: 22 bbls gelled diesel @ 5/5.6 BPM w/press of 3360'-2890 psi. Stage 2: 23.7 bbls gelled diesel w/6 ppg 20/40 mesh sand @ 12 BPM w/max press of 4280 psi. Stage 3: 38 bbls gelled diesel flush @ 19.6 BPM w/final press of 4900 psi. Underflushed by 3 bbls. Pmp'd 4088# 20/40, 6 ppg sand in formation leaving 593# 20/40, 6 ppg sand in 7". Load to recover 78.5 bbls of diesel. Job complete @ 1730 hrs, 2/12/86. Drilling S~perintendent / Date ARCO Alaska. Inc. : - ~-- · Post Office i=~rx 100360 Ancl~orage. Alaska 99510-0360 Telephone 907 276 1215 RETUP~N TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 03-11-86 ~."T~%NSMI~ ~ 5595 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Schl/ CET or CBL's/ One * of each ~lQ-12 01-21-85 Run .%1 3536-6934 A-8 11-02-85 Run #1 6986-8362 D-13 12-17-84 Run #1 5425-7488 ~2D- 14 17-12-84 Run #1 6288-8136 ~2H- 11 11-28-85 Run .%1 4850-6642 ~2H-12 11-28-85 Run #1 5500-6776 ~W-15 02-02-85 Run #1 6500-8096 ~3A-4 11-03-85 Run #1 6792-8329 ~ ~'~3F-4 11-12-85 Run #1 4770-6734 '~F- 7 11-14-85 Run #1 4950-7876 PLEASE NOTE: These logs were received from the vender today 03-11-86. Receipt Acknowledged: ~?' Stat~6f ~'AK*b 1/se ::'~?:.!~ Vault*~fi~ NSK Clerk*bl Cons. Commission ARCO Alaska. Inc. ,s I Suos,O~'lr¥ ot AllanticRichhelcIComl:)an~ STATE OF ALASKA ALASKA OJ'"~AN D GAS CONSERVATION COi~llSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IZ~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc 85-262 3. Address 8. APl Number P. 0. Box 100360, Anchorage, Alaska 99510 50- 103-2CE63 4. Location of Well SURFACE LCr. ATION: 170' FNL, 714' FEL, SEC. 35, T11N, R8E, LM 5. Elevation in feet (indicate KB, DF, etc.) 130' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25587, ALK 2673 9. Unit or Lease Name kIJPARUK RIVER UNIT 10. Well Number 2H-12 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER 0IL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate} Perforate ~ Alter Casing [] Perforations ~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made ,~, Other Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" Sand be perforated for production. Procedures call for the well to be perforatc< through tubing with 4 SPF. · Proposed Interval (MD)' 6614 - 6625 ANTICIPATED START DATE: March 10, 1986 RECEIVED MAR 0 5 1986 _.. ,", ,-, ! ~ Al,,oX,, 0il & Gas Cons, Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Kuparuk Signed _~0_.~_..-_~ Z'~ /<~~~~ Ti,,e Sr. Operal;ions Engr. The space below fo~ommission use Conditions of Approval, if any: Approved by ¢ ~.p~roved Copy Returruj~i /o / By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 ARCO Alaska, Inc. Post Office Bo~"~'00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 6, 1986 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2H-12 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for 2H-12. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU13/L66 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO.._jllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I-~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-262 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20053 4. Location of well at surface 9. Unit or Lease Name 170' FNL, 714' FEL, Sec.35, T11N, R8E, UN . .~-~, Kuparuk River Unit AT~ONS At Top Producing Interval I ~/E~,/~I~) I~ 10. Well Number 1315' FSL, 1267' FEL, Sec.26, T11N, RSE, UNj ~.~ 2H-12 Surf At Total Depth }i .. ~7 !'-'-r-/~- I 11. Field and Pool 1544' FSL, 1262' FEL, See.26, T11N, R8E, UN ~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 130' RKBI ADL 25587 ALK 2673 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 10/30/85 11/07/85 11/10/85*I N/A feet MSL 1 17. Total Depth (MD+T~D) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6840 'MD ,6236 'TVD 6786 'MD ,6198 'TVD YES [~gX NO []I 1808 feet MD 1500' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Sur.f 114' 24" Conductor report not ~/~t received. 9-5/8" 36.0# J-55 Surf 2741' 12-1/4" 700 sx CS Ill & 300 sx CS II 7" 26.0# J-55 Surf 6834' 8-1/2" 300 sx Class G & 175 s~ CS 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) 6654' - 6684' w/4 spf, 90° phasing 2-7/8" 6589' 6376' & 6572' 6515' - 6535' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 'TEST PERIOD Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 * NOTE: Tubing was run and wel 1 perforated 12/13/85. GRU13/WC02 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' '" "'~': ' GEOLOGIC MARKERS ' ' ~ ' : -'! "~ .... -'::":'-; .... -":"i~O'R~I~,TI'~3N NAME Include intervai tested, pressure data, all fluids recovered and gravi[y, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. : Top Kuparuk C 6513' 6002' N/A Base Kuparuk C 6537' 6020' Top Kuparuk A 6578' 6050' Base Kuparuk A 6776' 6191' I 31. LIST OF AT:FACHMENTS , Well History (completion details)~ Gyroscopic Survey (2 copies) '32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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'ln- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO OIl'and Gas Company Well History- Initial Report - Dally Preoare and submit the "lnlUiI RlpOl~" on the firat Wedneaday after a well ia spudded or worl<over operatlonl ere at&r~ed. Dally worl< prior to SPudding should he summarized-on the form giving inclusive dates only. Olstrict Alaska Field ICounty. parish or borough North Slope Borough ILeas, or Unit ADL 25587 ITitle Completion State Alaska Kuparuk River Au~, or W.O. no. AFEA~0073 Roii'N ~4. AP1 50-103-20053 IWell no. 2H-12 O~rltor A~CO Alaska, Inc. Spudd~ ~ W.O. ~g~ Complet~ 12/9/85 I"°u' Date end depth el of 8:00 I.m:... 12/to/8~. 12/12/85 12/13/86 Complete record for each day reported rARCO w.I. Prior statue if 56.24% a W.O. 2030 hrs. 7'~ @ 6834' t0.8 PP8 NaCl/NaBr Accept ri~ @ 2030 hfs, 12/9/85. BOPE. RU Schl f/perf'g & RIM. NDCbg adapter. Cst:. 7" @ 6834' 6786' PBTD, RIH w/coiled tbg 10.9 ppg NaCl/NaBr Perf w/4" gun, 4 SPF, 90° phasing f/6654'-6669" & 6669'-6684'. Perf w/5" gun, 12 SPF, 120° phasing f/6515'-6535'. Make gage ring/JB rn to 6500'. RIH, set pkr @ 6561'., well flowing. RU to kill well. RIH w/coiled tbg. 7" @ 6834' 6786' PBTD, C&C hole 10.9 ppg NaC1/NaBr RIH w/coiled tbg, circ, kill well w/10.8+ ppg brine. Monitor well, POH. RIH, PU 2-7/8" opened ended tbg, C&C @ 6394'. 7" @ 6834' 6786' PBTD, Displ'g well to diesel 6.9 ppg diesel Observe well, C&C hole to 10.9 ppg brine, POOH. RIH w/207 jts, 2-7/8", 6.5#, J-55 8RD EUE + 1 jr, 2-7/8" BTC tbg w/SSSV @ 1808', HB pkr @ 6376', lB pkr @ 6573', "D" Nipple @ 6583' Tailpipe @ 6589'. Space out & lnd tbg. Set HB pkr, tst tbg, shear off PBR. Tst ann & pkr. Tst SSSV. Set BPV. ND BOPE, NU &tst tree. Displ'g well to diesel. The above is correct Signature For form preparation ~ld distribution, see Procedures Manual, Section 10, Drilling, Pages 88 and 87. Drilling Superintendent . _ ARCO Oil and Gas Company Daily Wel~istory- Final Report IrletruclJons: 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 "F(nal Report" form may be used for reporting the entire operation it space is available. District J County or Parish Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ~Title AFE A[0073 Roll'N #4 Operator ARCO Alaska, Inc. North Slope Borough ADL 25587 Completion API 50-103-20053 A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Complete 12/9/85 Date and depth Complete record for each day reported as of 8:00 a.m. 7" @ 6834' 6786' PBTD, RE 6.9 ppg diesel Fin displ well to diesel. RR @ 1300 hfs, 12/13/85. 12/14/85 12116185 Accounting JState I otal number of wells (active or inactive) on this~ DSt center prior to plugging and bandonment of this well our ' ~ Prior status if a W.O. 2030 hrs. cost center code Alaska no. 2H-12 Tst tbg & orifice vlv; OK. Sec BPV. Old TD Released rig 1300 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing New TD tPB Depth 6786' PBTD Date IKind of rig 12/13/85 Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effegtive date' corrected The above la correct Signature I Date [Title I For form prel~aration and d~tribution, see Procedures Manual, Seclion 10. Drilling, Pages 86 and 87. Drilling Superintendent GCT I)IRECTI[)NAI, E;URVE¥ C U,q T,q :~ F R LI$1'ING . ' . .,;~ ;, .!, , ' . '-.~ ,., .~::. , '9'"~'~t',,~,~. ;'~';:AcP~"P;..r ,, METHODS OF COaPUTATION TOOh LOCATION INTERPOhATtON VER'I'I CAb SECTION KoPARIJK ALASKA ,~IJRVEY PATE; 28 NOV 85 TANGENTIAL- averaged LINEAR,' tIL)RIZ, DIST, PROJECT~' deviation and TARGET ; f,t f,, azlmutll ARCO ALASKA, INC. UPARUK NORTH SLOPE,ALASKA ' . 3';~..' ' r.. CUMPUTATION.upA~E I,: 17-DEC-PS '"' "'i "? :',r'.. : TRUE 5UO-$EA CUUHS~ IEAS~R£D VERTICAl, VERTICAt, D~VI~TIDN AZIMUTH DEPTH D£P~H D~PTH D~G MIN D~(;MIN PAGE DA'rE OF SURVEYI 28 NOV 85 Kg~bJ BUSHI~G gbEVATIUNI OOoo O0 400,00 500.00 oo , ,00 0,00 100,00 200,00 300,00 400,00 499,99 599,99 699,99 ~99,99 899.99 ,,, 130.00 FT INTERPOLATED VALUES FOR'..EVEN 100 FEE'~ LJF MEASUREO DEPTH ,,. VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTiDN SEVERITY NDRI'n/$OU'fH EAST/WEST DIST, AZIMUTB F~ET DEG/1OO FEE'~ : FE~T FE~T DEG 0,00 0,00 N 0,00 0,07 0.82 0.19 N 0,29 -0,31 0,11 0,00 S 0,81 -0.65 0,23 0.23 S 1,15 -0~51 0 13 0,0~ S 1,21 -0.22 0~37 0,3'1N 1.49 -0.26 0,60 o,5u N 1,91 0.11 0.35 0.85 N 1,87 0,39 0,38 1.30 N 2,15 0.07 0,53 1,0~ N 2.43 '130,00. O, 0 '30,00 0 20 70~00 0 17 170.00 0 9 270,00 0 14 369,9g 0 21 469,99 0 10 569.99 0 16 6~9,99 0 j8 '16q,99 0 3 N' .'.O.',O'.g ....... .. 0,00, t000.00 999.99 869,99 0 10 ~½~'00 1099.99 969,99 0 25 .00 1199.99 1069.99. 0 .~t.) 1 ~00,00 1299 9U 1109,9~ 0 22 1400.00 1399:98 !269.98 O 21 I00,00 14 98 1369,98 0 27 00.00 15~ 97 1,69.97 0 31 · , 1669,97 0 16 1~00.00 1899,97 1'169'~97 0 8~9,97 0 t'~ 2069,96. 0 2U 0 2O u 21 0 21 0 19 0 O ~9 0 45 85 54 E 59 58 E S 62 21E 040£ 66 57 E N 27 8 g 6 32 W 78 34 E 20 53 W N 66 18 W 0.13 0,23 1.00 ~ 2,12 ~ 21 52 E -0.13 0,17 0.'14 i~ 2,18 $ 2 37 W -0.88 0.39 O.oJ ~.~ 2.41 5 14 43 ~ -1,54 0 12 0,'1'1S 2,20 S 53 24 E -2.06 0:05 1.25 S 2,42 $ 38 ~ f -2.68 0,61 1,o9 S 2.95 S 20 14 VI -3.39 0,23 2.~8 S 2.90 S 49 51 W '3,84 0,3'1 3.11 S 2,54 S 40 1.8 E -4.11 0,25 3.41 S 2,54 S 03 52 W '4,46 0,32 3,71 5 2,'11 "4.23 0,46 -3.79 0,27 '3.73 0,37 '4.13 0.18 '4.59 0.09 "1.86 0,1.3 '4.82 0,26 '5.t5 0,50 -5,42 1,00 -5.71 0.05 -5.g8 0.27 '6,31 0,26 -7,06 0.55 -7.89 0.~5 -8,54 1.42 '6.47 5,22 3.89 5,15 23.09 4,32 48.37 3.03 77,05 4,22 3,56 S. 2.48 g 3,02 5 2,62 E 2,7; $ 3,09 g 2.99 S 3,61 E 3.2'7 S 4,16 g 3.]'1 $ 4,63 E J,14 S 5,08 g 3.43 S 5,25 g 3,~u S ..>.5~ 4.56' S ],.~ E 5 33 S ,~..~ei.~ E 9.51 S ,W 8,3! $ 3 25 W 1,52 N 6 57 W 19~78 N ~2,b4 42.]5 ,~ 24,26 W VO.'13 N A0,45 W 0,00 N O 0 E 0 35 N 56 47 E 0 81 ~ 89 50 E 1 17 S 78 31 g I 21 S 87 19 ( 1 54 N 76 12 . 1,98 N 75 28 ~ 2,O6 N 64 47 E 2,§1 N 5B 53 E 2,65 t{ 66 26 E 2,34 ii 64 44 E 2,30 i{ 71 6 E 2,41 N 89 20 g 2;33 S 70 46 E 2~ 72 S 62 42 E 3,40 S 60 11 E 3,81 S 49 26 E 4,01 $ 39 18 E 4,25 S 36 42 E 4,59. S 3b 12 E 4,34 S 34 48 E 4,00 S 40 57 E 4,15 S 48 10 g 4.69 S 50 22 E 5,29 S 51 53 { 5,72 5 53 58 5,9'1 $ 58 13 ~ 6.27 S 56 51 E 6 30 S 52 54 E 6:02 S 40 45 E 6. O1 S 27 38 E 6~36 S 14 52 E 7,~3 S 6 35 g 8,42 S I 38 E 9,54 S 4 20 W 8,92 $ 2I 22 W 6,75 N 76 56 W 23,48 N 32 34 W 48.80 N 29 48 W 78,03 ' N 31 13 W oO i 69'96 69 i ,''. ,', 26 , i:. 69i92 j 00,00 :~ 91 too.oo )500,00 ]499 84 ~]69:84 3~00,00 3599 26 3469.26 0%00 ]697 $90~,00 3889 ARCO AEASKR~ ~NC, 2H~2 KUPARUK NORTH SbDPE~AbA$~A iEASURED DEPTH INTERPObATED TRIJE SUB-SE VERTICAl, VERT1C DEPTH DEPT 4000,00 J98J.19 3853. 4100.00 4074.60 ]944. 00,00 4164 20 4034, ~]00.00 4251:47 4121. 4400,00 4335.39 4205. 4500.00 4415.62 4285. ,00 4573.70 4443. ,00 4976,57 48't6, .~1~,00 505,.04 4928, .oo oo.oo 5600.00 52 o15 5165, 700,00 5373,8.4 5243, 800.00 5452,86 5322. 5900,00 55Jl,44 5401. 56~,3J 5479, 56 .Ol 5557. 5764,6U 5634, 5842,16 .5712 "~' 6106 : , t, COMPUTATION...DATE{. 17-DEC-H5 · ~:t,'.,~,,~,~,.. '"" ' ' 1 VAI~UES EOR.=~VEN lC)0 FgE'r , , VERTICAL DOGL SECTION SEVE FEET 6000,00 6100.00 b200,O0 6300.00 ~00,00 00,00 6600 O§ 6700 6840 0 A COURSE Al, DEVIATION AZIMUTH H bEG ~IN DEG 19 22 26 N 33. 31 60 255 r,{ 31, 33 20 27 51 ~ 26 59 47 30 47 N 24 36 39 35 9 N 22 5~ 02 37 39 N 2] 52 47 ~7 ~9 N 24 ! 70 37 43 N 24 2 06 37 20 N 24 2 85 36 33 ~ 24 6 34 .36 3 N 2q 27 ~ 78 ~5 5 N 24 59 w 57 35 t5 ~{ 25 2 ~ O4 ]6 3 N 21 49 W 75 37 53 N {7 47 ~ 59 37 58 N 18 3 W 15 30 18 N 19 27 w 84 J'l 50 ii 19 b0 h 86 37 42 N 19 27 w 44 j8 4~ ~ i'l 32 ~ 33 38 58 N 15 9 w O1 39 5 m 12 32 w 68 39 3 N 9 48 , 16 39 49 N 8 4'1 15 41 10 N 5 2 ~ ~1 42 t5 ~ ~) 4b ,~ 91 43 40 ,~ I J c; 5644 ,11 N 1 24 Fi 14 45 t~ h I 21 E 29 45 16 ~ 1 21 E 111,60 151.43 195.48 244.18 290'50 358.17 419.62 480,61 541,42 601.66 660.97 718.93 776.3~ U34.31 894~57 95b,92 1017.68 1079,34 1140.56 1202,28 1264,66 1327.00 1388.78 1450.44 15L3,1.8 1575.9,~ 1638.95 ].702.99 1767,94 179-t,01 O[~' MEASURED OEPTH EG RECI.'Ah{GUL, AR CUORD RITY ,"~ORTH/SJLIrH EA$]'/ 1 O0 {~ EET ' INATES HORIZ, DEPARTURE WES'f DIST, AZIMUTH FEET DEG 3,b0 95.90 iq 60,42 2,79 129.9o r~ 82,40 3 39 lbS,l'/ N 103 91 4:10 212.71 t~ 125:15 4.31 202,52 N 146.85 1.83 317.t2 N 1'10,50 1.05 373.40 N 195.58 0.20 429.20 ¢~ 220,39 O.4b 4~4.'1i a 245.19 0.55 539.81 ~ 209,75 1,,18 593.92 I~ 294,12 0.44 646.01 a 318.42 0.18 698.73 N 342,78 b,22 ';bl,Sb t'{ 306,64 0,50 80H.68 N 386,17 0,41 867,21 N 405 08 0.63 925,02 N 424:88 0,23 9U3,92 ~ 445,70 1,31 1041.54 N 466.55 1.51 11~0.19 N 486,i5 1,29 1160.3~ h 503,76 2.15 1221.47 N 519.00 l.Ob 12H3.31N 530,95 2,43 1345.6; N 541,27 2,7't 1410.1~ h 549,18 3,13 1476,59 h 552,64 l,O0 1.544.81 N 552,01 0,69 1614.55 N 550,50 O,OO 16bb,3/ N 548~78 0,n0 1713.79 N 548,11 113.35 t53,88 198,19 246,79 360.22 421,57 482,48 543,25 603,46 662,76 '120,'16 778,28 8J6,22 896,15 957,15 1018,66 1080 16 1141:26 1202,81 1265,01 1]27,16 1308,~1 1450.45 1513,34 1576,62 1640,47 1705.82 1772,4/ 1'799,30 N 32 12 W N 32 22 W N 31 ~17 a N 30 28 W N 29 13y' N 28 14 t N 2'/ 38 W N 27 10 W N 26 49 w N 26 33 W N 26 20 W N 26 7 W N 26 0 W N 25 31 W N 25 2 W N 24 39 W N 24 22 w N 24 7 ~ N 23 50 W N 23 28 W N 23 1 W ~ 22 28 W N 21 54 ~ N 21 16 / N 20 31l~. N 19 39 w N 16 49 W m 18 2 w N 17 44 w ARCO AbASKA, 1NC, 2H-12 KLIPARUK NORTH 5LOPE,AhAS~A C[JMPUTAT1 ON InI'ERPO6ATI~.:I) YAL, UE$ FOR TRUE 5U~-$LA IF. ASURED VERTICAl, VgRTICAL DEPTH DEPI'H L)I<P'I'H 0 O0 0,00 ']30,00 lO00~On 999.99 8i~9.99 2000.00 1999,9'1 IUb9.97 3000.00 2999,94 2869,94 4000,00 398],19 ]853,19 5000,00 4B13.34 bO00,O(.) bbOg,J3 54'19,]] 6840,00 623h,29 6106.29 COURSE DEVIATIOrl AZIMUTH DEG MiN PEG 0 0 N 0 U 0 10 ,~ 66 18 017 N 9 46 g O 46 $ 56 .1.4 22 26 N 33 ]l ,38 58 N 15 9 4.5 16 N 1 21 DAT£I. 17-DE:C-~5 , ,,' 1 PAGE DAli': L)F SURVEY: 28 NU'V d5 ~.i.,L,¥ BUSHING ELEVA'I'IUN: EVEN lOOO Fklgl' 0t" MEA$li VERTICAL DL1GL~(; RF:CTA SEC'r I [}l,: SEVERITY h(it~Ttt FEET bEG/1 O0 ~ ~: k r_:l) NGUbAR COORDINATES ttDRIZ, DEPARTURE /StJU'£11 EAST/wEST DIS'F, AZZ HUI'H ~'[' FEET F'EET DEG 0.00 0.13 -4.23 111.00 660 . 97 1264.b6 1794.01 0.00 0 0,23 1 O,4b 3 0,27 5 3,60 95 1..4~ 593 1.29 l.lbO 0,00 1113 .00 N 0,00 E 0,00 N 0 0 E ,00 N 2,12 E 2,34 N 64 44 E ,bo 5 2.48 E 4,34 S 34 48 £ .33 S 2.79 E 6,01 S 27 3B E .90 N b0,42 ~ 113,35 N 32 12 ~. .92 N 294,12 ~ 662,76 N 26 20 ,3U N 503,76 W 1265,01 N 23 2~ .79 N 5.t8,11 W 1799,30 N 17 44 w ARCO AbASKA~ ~NC. 2tt-12 KUPARUK NORTH SLOPE,ALASKA TRUE SUB-SEA qEASURED VERTICAl, V~:R'gICA[, DEPTH DEPTH D~P[H ,:~ 0,O0 0.00 30,00 30.00 tlg,O0 130.00 .dO 230.00 4 ,00 430,00 530,ol 630,01 6]0.00 730,01 730,00 830.01 83O.00 CUMPUTATION..,DATEt.;.17-OEC-B5 930,0t 930,00 ,02 1330:00 1430,02 1430,00 i530.02 1530.00 ,03 17t0o00 0~03 .[NTERPObATEO VALUES COURSE VER~ICA OEG MIN' DEG MIN FEET -130 O0 -100:00 0.00 tO0.O0 200,00 300.00 400,00 500.00 bO0.O0 700.00 0 0 .....N 0 17 O 19 S 0 16 0 5 0 17 N 0 19 0 1.2 0 19 0 17 S 100 f'EE~ O L DOGLEG N SEVERITY DCG/IO0 .0 ....0 E '0,00 0o00 13 23 E 0.00 0.36 71 1~ ~ -0.04 0,12 54 59 E -0.43 0.17 69 14 'E '0,69 0,6! 15 27 E -0.39 0.45 77 32 g -0.24 0,25 5 36 ~ -0.17 0.17 12 19 E 0,25 0,34 74 23 [': 0.33 800.00 0 1.2 S 59 58 w 900.00 0 ~ S 77 42 w 1000.00 0 23 S 2'7 59.E 1100,00 O 31 8 14 55 m 1200.00 0 18 S 2 16 ~ 1300,00 0 22 5 53 24 E 1400.00 0 31 S 7 ~1 E 1500,00 0 ]0 $ 22 U ~ 1600.00 O' lo S 50 41 w 1700,00 0 lO S 57 3 E 1930,00 lBO0,O0 2030,00 1900.00 2130,00 2000,00 2230.00 2100.00 ~gi; 2200.00 2300,00 2700 O0 i~:'~800 O0 3000 O0 3100 O0 3200 O0 '00 j30O,O0 O0 3400.0O ,18 36~0,00 3500,~§ , 6 3730,00 3600. ,42 3830.00 3700.o0 0.01 0.49 0.18 0,07 '0.34 O.Ob '1:12' ' 69 0,65 '2,23 0,23 -2.9,t r).76 '3,60 0,38 '3.87 0,4b -4,24 0,25 '4,44 0,50 '4.10 0,14 '3.09 0,71 -3.84 0,26 -4.26 9,14 -4,75 0,15 '4.80 0,14 -4.9t, 0.75 '5.22 0,8'1 '5.54 0,'t3 '5.78 0.26 -6.08 0,31 '6.44 1,42 '7,JO 0,46 -8.13 0,84 '8,5! 2,77 '4,~9 5.99 9,01 4,56 31.26 3,96 5~,b2 2,'18 RECT ~LJRT PAGE DAi'E [)F SURVEY: 28 NOV 85 KELLY 8U,5t-ilNG ELEVATION: El~Gl NEER: SARBER o °. 130.00 Fr EA UEPTH ANGUbA~ COORDINATES HUR1Z, tI/SC)llTH EAST/WE~'f DI,5'r, ~;E~ ' FEE'I' ~'E~'I' DEPARTURE AZIMU[H DEG 0,00 N 0,00 E 0,00 0.00 N 0,00 E 0,00 0.14 i~ 0,46 g 0,4U ().VB $ 0,94 E 0,94 0.20 S 1,20 g 1,2J O.OU N 1,22 E 1,2'2 0,42 N 1,67 ~ 1,72 0.60 N 1,92 E 2,01 1,04 ~ 1,87 g 2,14 1.3t) N 2,31 E 2,65 0.97 ~ 2,36 1.0~ N 2,06 0.55 .~ 2.27 (),24 S 2,3'~ 0.95 ,5 2,16 i.3u S 2,57 1.93 S 3,05 2,74 $ 2,80 3,18 S 2,45 3,50 $ 2,65 3,7t 3.40 2,8U 2.81 3,0'1 3.31 3.24 3.24 3,48 4,OU 2,59 2,52 2,70 3.2'~ 3,78 4,32 4,76 5,22 14 s o ss 8 75 $ 6''g 9,70 ,5 1,,96 ~ 6.41 S 4,13" 6.50 N 7,93' ~ 27,26 N ~5,95 W 51. [~ N 29,87. ~ 2,55 2.30 2.33 2,39 2,36 .i.91 3,61 4,~2 4,39 4,55 4,23 3,95 4,31 4,87 5.,18 5,'16 6,14 6:23 5,98 6,08 6,55 7~64 8,'15 9,78 7,63 10,26 31,59 59,22 N 0 0 g N 90 0 E n 72 39 E S 85 0 E 8 78 2(' h 75 57 g N 72 42 E N 61 2 E N 60 39 g N 67 36 g N 6J 24 g N 76 18 g S 84 12 g S 66 17 g '562 9 E 55'141 g $ 45 37 E S 37 40 E ,53'1 4 E S 34 4i E 8 36 32 E S 43 12 E S 0,9 17 E: S 50 57 [ $ 52 4L. S 55 44 E S 58 10 E S 56 46 E S 49 19 E 36 58 £ 23 43 E S 11 45 E 0 21 E 722, S 32 46 W 50 39 W m 30 20 W N 30 17 W ] ARCO AhASKA, INC. 2 NORTH Sb[)PF.,AhASKA MERSURED VERTICAl. DEPTH DEPTH 942.87 3930 DO 050.98 4030~00 4151,55 41]O,00 4275.1B 4230.O0 4~983,47 4330,00 4 I .24 44]0.00 4~44 78 4530,0U 4771~O2 ~630.00 489~,45 4730,00 5020.58 4830.o0 51~3.00 4930.00 5265.47 5030,00 5390 ,18 51.~0,00 ,3g 5330,00 5771,07 5430,00 5898,15 5530.00 6026,58 5630,00 6155.34 57]0.00 6284,18 5B30,00 684 , COMPUT~TION,DATE~ I 7-DEC-U5 I,~'I'ERPOLATED VAL, UES FOR EVEN 100 FEET SUB-SEA COURSE VERTICAL DEVIATION AZIMtlTH UEP'I' n OkG MIN DEG 3800.U0 2O 28 N 390U.~{, 23 57 N ~O00.OU 26 39 s 4100.00 29 55 N 4200,00 34 52 N 4300.00 37 50 h ~40U,O0 37 33 a 4500.00 37 21 N O0,O0 36 34 ~ '/O0,O0 35 46 t~ IBO0.O0 35 5 N 4900,00 35 30 N 5000.0o 37 49 N 5100,00 38 4 N 5300,00 37 45 N 5400.00 J~ 42 i~ · 5500,00 38 59 ~ 560(1,00 3g 0 N 570U,00 39 32 i~ PAGE b ., OAI'E: OF SURVEY: 2~ NOV 85 , KEbb~ dU$tIING ELEVATIUN{ 13U,OO ENGINEERI SARBER OF SUB-SEA DEPTH 5BO0,O0 41 22 N 5900,00 43 3 N bO00,O0 44 38 N 6100,00 45 1.6 N 0106,29 45 10 N V£R'rICAb OOGbEG RECTANGULAR SECTION SEVERITY NORTiI/SU[I'fH F£E'I DEG/IOO FEEl' 34 32 ~ 91.22 J2 54 ~ 1~1.44 28 23 ~ 17'1.99 25 12 ~ 231.73 2] I ~ 294,80 23 59 ~ 369.37 2] 59 w 446,B7 24 2 W 523.88 24 5 ~ 599,55 24 35 W 67~.04 25 3 ~ 743.57 23 59 ~ 814.17. 1'1 4'1 ~ 888.56 IU 11 ~ 966,36 19 41 W 1045.t5 19 51 ~ 1122,8~ 1.7 .]4 ~ 1201.12 14 30 ~ 1281,25 10 43 W 1361.27 9 3 ~ 1440.59 4 26 W 1523,08 0 40 E 1607.64 I 21 g 1696,12 1, 2] E 17R8,19 I 21 E 1794.01 ,54 '18,6'1 ,6'/ 112.8J ,69 153.1~ .19 201.'11 ,'11 259.12 .(;7 327.56 .4U 398,3/ ,TH 468.74 ,5'1 537.8~ ,51 604.92 ,47 bbB.q/ ,~2 7]].05 .69 B02,93 ,95 8'77.10 ,h4 951.72 ,42 1024.~1 .53 1099,0~ ,33 11'10.5~ .97 1255,~2 EAST FEE D1NATES /WEST T 48,72 71.47 95,7'; 119.88 145,41 175,06 23a,04 268,88 299,13 HURIZ, DIST, ~ EET 328,86 358,70 3~4,33 408,33 434,13 450,55 485,79 508,05 526,01 539,'71 ,50 1420,51 N 550, .10 1510.7~ N 552, .71 1607,07 m 550, .00 1707,44 N 548, .':)O 1'113,'/9 N 548, 07 . 57 W 67 W 26 W 11 w DEPARTURE AZIMUTH OEG MIN 92,53 N 31 46 W 133,56 N 32 21 W 180.o~ ,~ 32 0 w 234.39 N 30 45 ~ 448,79 N 27 25 ', 525.~2 & ~6 55 w 6OI,35 N 2b 33 ~ 674.84 ~, 26 18 ~ 745,43 N 26 10 ~ 816,11 N 26 4 * 890,17 N 25 34 W 957,5~ N 24 57 W 1046,06 N 24 31 ~ 1123,b0 a 24 11 W 1201,66 a 23 50 , 1281,54 a 23 21 w 1361,35 N 22 43 w 1440,59 N 22 0 ~ 1523,30 1608,66 J69.~,80 79 . 30 1799,]0 ~ 21 10 w N 20 5 W ~ 18 54 W N 17 48 ~ N 17 44( ARCO ALASKa, iNC, NORTH ~EOPE~ALA~KA TOP BASE TOP BASE PBTD TD KUPARUK C KUPARUK C KUPARUK A KUPARUK A .,. COMPIJ'£ATIUN DA~EI I~'£ERPObATED VALUES ~.'i:,; .. ...... .; FOR. CliO,SEN HOR I Z ON S MEASURED DEPTH 6513,0U 6537.00 6570,00 6776,00 b78b,O0 6840.00 ..FROM KB 6002.43 b020.08 6049.9B 6191,25 OI9U,29 6236.29 ORIGIN= 170' SUb-SEA Kt';bL Y PAGE 6 JIF ~I.IRVEY| 28 NUV 85 BUSHING ELEVA'I'IUNI 130.00 FT ENGINEEE: SARBER' 714' F REC NO 5872,43 1485,33 N 552,7b 5890.~U 1501.59 N 552.65 5919,9H 1529,64 N 552,28 6051.25 1668,33 N 549,18 bObS.29 %675,43 N 549,0! 610h.29 [713,79 N 548,~1 ARCO ALASKA, 1NC. 2H-12 KUPARUK NORTH CUt~ PI, I T A'!' I ON [)Al'El BUSHING PAGE 7 - . , · 1~0,00 ~"I' TOP TOP t~ASE Pb'rt) TD ~ARKER KUPARIJK C KUPARUK C KUPARUK A F[.IPARIIK A aEASURED D~PTtl UgbU~ .~ 6b78,0U 6776.00 b7~6.00 FRON KB 6002.43 6O20. OB 6191 btgB.29 62.ib. 20 URI. t.,JN= l'lt)' FNL, 714' Fl,'. S U a..- S F..A NOB 5872.43 14 5890.0H 15 5919.98 15 o06t.25 16 0O08.29 16 6106.29 17 LIRFACE ~OCATION Al' b SEC 35~ '£11N RBE,UM Ai~GUbAR COOROJI';~Tg,5 85.3J N 552.75 01,59 N 552.b5 29,b4 N 552,28 68.]3 N 549.18 75.43 N 549.01 1].79 N 548,11 FINAL MEASURED D E P T H WFJbb t, UCA:I'ION A'I' I'D: bH40,O0 b236,29 6106,29 I'iURI ZUNTAL DEPART U Ri:': D I $ 'r A :',1C F: A Z 1 .'.% U 't H F E g '1,' L) g G i~ 1: N 1799,30 N t'i 44 GC.7' OIRECTI[.)NAL, SiJRVE'f C!JSTO~IFR b IS!'I r,~G FOR ARCD ALASKA, iNC. KuPARL!K i'.tOK£ti 6!,.~[IP~:,A.bASKA SURVEY g,&"r'E: 28 NCtV 85 METHODS OF CO~IPUTATION TOOL LOCATION: TANGENI'IAb- averaged deviation and azimutt~ INTERPOLATION: LINEAR VERTICAL SEC'I'IONI HU~IZ. DIS%, PROJECT~' lr,~'1'O A ~I'ARGg'[' AZI;qUI'H OF NO{RTH 22 DEG [8 ARCO ALASKA, INC. 2H-12 KUPARUK NORTH SLOPE,ALASKA COMPU TAT I DN ,:.I~A~.'E.I:: 17 -Dg£-85 .; "?' · TRUE SUB-SBA CUURSE iEASURED VERTICAL VERTICAL DEVIATIDN AZIMUTH DEPTH DEPTH DEPTH DEG MIN DE(;. MIN O0 100:00 -30,00 0 20 S 8~ 54 g .~00~00 200,00 70~00 o 17 S 59 58 E 300.00 300,00 170,00 0 9 S 62 21E oo.oo o..oo o.oo o . o 50O ,00 499,99 369,99 0 21 N 66 57 E ?0o .00 699.99 569.99 0 16 N 6 32 ~ 900 ,00 899.99 769,99 013 $ 20 53 W 1~00 00 1099,99 969,99 0 25 6 21 52 E !200 O0 11,99.99 1069.99 0 .,() $ 2 3'1 ~ 1300 O0 1299,9B 1109.9B' 0 22 ~ 14 43 W 1400 O0 1399.9~ 12 69.98 0 21 S 53 24 E 1600.00 15 : 1469'9 0 31 S 20 14 W PAGE DA'I'E OF SURVEY: 28 NOV 85 KELLY BUSH/aG EbEVATIUN{ '-,;..' :<'."...: ENGINEER: SARB~ INTERPOLATED VALUES FOR'EVEN 100 FE~ [if MEASURe!) DEPTH VERTICA6 DOGLEG RECTANGU6AR COORDINATES HORIZ, DEPARTURE SECTIDN SEVERITY N[)RT~/SOUTH EAST/WEST DIST, AZIMUTH FEET PEG/lO0 f'EEr ' FEET FEET DEG ~IN 0,O0 0,O0 0,O0 n 0,00 E 0,07 0.82 0.19 ~ 0,29 g '0,31 0,11 0,00 $ O,B1 E -0.65 0,23 0.2~ S 1,~5 E '0,51 0.13 O.Ob $ 1.21 E -0,22 0,37 0,3"1N 1.49 E -0.26 0,60 O,EU N 1.91 E 0.11 0.35 0.88 N 1.B7 E 0',39 0,38 1.3~ N 2,15 E 0.07 0,53 1,06 !~ 2.43 E O.t3 0.23 1.00 c{ 2,12 -0.13 0,17 0,7~ ~ 2,18 -U.88 0.39 ¢.).03 N 2.41 '1.54 0,12 0,'/7 $ 2,20 '2.06 0,05 1.25 S 2,42 '2.68 0.61 1,b9 S 2.95 '3.39 O,Y3 2,'~B $ 2,90 '3.B4 O,j7 ],11 $ 2,54 '4.ll 0.25 3.~1S 2,54 -4,46 0,32 3,71S 2,'11 '4.23 0.46 3.56 S 2.48 '3.79 0.27 3.02 S 2.62 -3.73 0,37 2,7'/ S 3,09 -4.13 ().18 2,99 S 3,61 -4,5~ 0,09 3.2'7 $ 4,16 '4.~6 0.13 3.37 S 4.63 s -5.15 0,50 3.43 S 5,25 -5,42 l,,.)O 3.~U -5.71 (.).05 4'56' S3~95: I 130.00 FT 0,00 N 0 0 g 0,35 m 56 47 E 0,81 S 89 50 £ 1,17 S 78 31 E 1'21 ~ 87 19 ? 1.54 N 76 12 1,9B N 75 28 ~ 2,06 N 64 47 E , 51 N 58 53 ,65 N 66 26 E 2 34 ~ 64 44 E 2 ]0 N 71 6 E 2 41 ~ 89 20 g 33 S 70 46 g 72 S 62 42 g 3 40 S 60 11 E 3 81 S 49 26 E 40l $ 39 lB E 4 25 S 36 42 g 4,59 S 3b 12 E 4,34 $ 34 48 g 4,00 S 40 57 E 4,15 S 48 10 g 4,69 S 50 22 g 5,29 S 5! 53 ~ 5,72 S 53 5B 5'97 S 58 13 6:27 S 56 51E 6,30 S 52 54 E 6,02 S 40 45 E OOiO0 999,97 1B69.:97 N 9 46 § 64 17 58 44 ~00~00 ~~~~ 2369,96 O 21 N 51 ]3 E ~ 00,00 .' ": .~,. 469,96 19 ~ bO 41 ..~'00,0'.,,:.'':~ ~~ "'': 2669,9b ~ 39 S 46 27 : oo.o :', ' 27 9. 5 45 5'7 .... ~ 46 $525614 .:.$~:'001003100.,00 '~~:::~26§;90::" ....... 169:~91 ~ 44 2'1 '~:$~001.00 3697~:.35 3567.35 ~ N '7.06 0,55 7,' -7.89 0,25 8,42 S -B.54 1.42 9.51 $ -6.47 5,22 8.31S 3,25 3.89 5,15 1,52 N 6,57 23,09 4,32 19,78 N 12,b4 48.37 3.03 42.35 i~ 24,26 77,05 4,22 bO,'/3 N &0,45 6,01 $ 27 38 E 6,36 $ 1452 E 7,33 S 6 35 g 8 42 S I 38 E 9 54 $ 4 20 W 8 92 $ 2! 22 ~ 6 75 N 76 56 W 23 48 N 32 34 ~ 48 80 N 29 48 ~ 78,03' N 3! 13 ~ ARCO ALASKA, INC, 2H-12 KUPARUK NORTH SbOPE~ALASKA COMPUTATION..DA~E,{ l?-bgC-~5 · TRUE 8OB-SE 4EAsuRED VERTICAL VMRTlC DEPTH DEPTH D~PT 4000,00 3983,19 ]853, 4100.00 4074.60 3944. 44~00,00 4164.20 4034, 00.00 4251.47 4121. 4400,00 4335.39 4205, 4500.00 4415.62 4285. 44~}0000. O0 4494,47 4364, ,00 4573,70 4443. 4~00,00 4653,0b 452~, 4900.00 4732...85 4602. 5000.00 4813.34 , O0 4976 5'/ .00 5137 75 ,oo oo. 600,00 52 ,15 5700,00 5373,~ 5800, O0 5452. .5900,00 5531 oo , 630 0 5R42 16 6840.b~ A COURSE V~RTICAL DOGLEG AL DEVIATION AZIMUTH SECTION SEVERITY 19 22 26 N 33 31 W 111,60 60 255 t.l 31. 33 ~ 151.43 20 27 51 a 26 59 w 195.48 47 30 47 N 24 36 w 244.18 39 35 9 N 22 5~ W 29B~50 62 37 39 N 2352 w 358.17 47 ~7 ~9 N 24 I w 419,62 70 37 43 ~ 24 2 W 480.61. 06 ]7 20 N 24 2 ~ 541.42 85 36 33 N 24 6 W 601.66 2,79 3,39 4,10 4.31 1..83 1,05 0,20 0,4b 0.55 1,48 0,44 ~,22 0.50 ,63 1,51 1,29 2.15 1,06 2.43 3,13 1,00 0.69 4683. 4764, 4928, 5007. 5086, 5165. 5401, 34 36 3 ~ 24 27 ~ 660.97 78 ~5 5 h 24 59 w 718.93 57 35 15 N 25 2 ~ 776.30 04 36 3 N 21 49 W 75 3'7 53 N 17 47 ~ 894d57 59 37 58 N 1~ 3 W 95b.92 15 30 18 N 1.9 27 W 1017.68 84 37 50 N 19 50 h 1079,34 86 37 42 N 19 27 W 1140.56 44 &8 43 a 17 32 W 1202,28 5479~ 5557. 5634, 5712. 5935. 6007. 60'lB, 6106, 33 38 58 N 15 9 w 1264,66 01 39 5 N 1.2 32 w 1327.00 68 39 3 a 9 48 , ~6 39 49 r; ~ 41 ~ 1450.4a 15 41 lO N 5 2 ~ 1513.t~ 91. 43 40 m I 3 ~, 1638.95 56 44 41 N t. 24 E 1702.99 14 45 lb N I 21 E 1'16'1,94 29 45 16 ~ 1 21 a PAGE 2 DA'YE OF SURYk¥: 28 NOV 85 E~bl.¥ ~USHImG ELEVATION: 130.00 E:i~GINEER: SARBE~ ~LASO REt_) DEPTH RECI'ANGUbAR COORDINATES HORIZ, DEPARTURE :'~ORTH/SJLI rH EAST/WEST DIST. AZIMUTH [' 5ET" FEET FEET DEG MIN 95.90 ia 60.42 129.9o N ~2,40 lbS,/'/ N 103.91 212.'71 a 125,15 202.52 N 146,~5 31"1.~2 N 1'10,50 373.4~ N 195.58 429.20 N 220,39 484.'1/ N 245,19 539.~I N 269,75 593.92 rl 294.12 64b. O1 N 318.42 69~.73 N 342,78 '/bl.Eb N 306,64 808.68 t~ 386,.17 867e21 N 405,0~ 925.82 N 424.88 9U3,92 N 445,70 1041,54 N 466,55 1100.19 N 486,15 1150.38 N 503,76 1221.47 N 519,00 12~3,31 N 530,95 1345.6l N 541'27 1410.1~ h 549,18 1476.59 a 552,64 1544.81 N 5~,~ 1614,55 N 5 , 16~5~3/ N .548~78 1713,79 N 548,11 113.35 N 32 12 153,88 N 32 22 w 198~19 N 3~ 37 246,79 N 30 28 W 300.80 360.22 N 28 14 421,57 N 27 38 W 482,48 N 27 10 W 543~25 a 2& 49 w 603,46 ~ 26 33 W 662,76 720,76 778,28 8~6 22 896 15 957 15 1018 66 1080 lb 1141 26 1202 81 1265,01 1327,16 1388,81 1450.45 151~:~4 157 62 1640,47 1705,82 1772,4; 1799,30 N 26 20 W N 26 7 W N 26 OW N 25 31 m N 25 2 W N 24 39 W N 24 22 w N 24 7 w N 23 50 w COMPUTATION DATE; 1,7-DE;C-85 PAGE 3 ARCO AbASKA~ INC. I,)AIt'; OF 8O~VLY: 28 NUV 85 2H-12 KUPARUK NORTH $~OPg,ALASKA I~O,OU YT Ii,~I.'gRPObATED VABi.,tg.S FOR I;;VEN 100o FP_.;gT OK ,~iSA$lJI'<r.:D DI~:p'I' TRUE SUB-SbA COURSE tEASURED VERTICAl, VERTICAL DEVIqTIO~ AZIMUTH VERTICAL DL}GbEG Rf:CTANGUbAR CUORD1NA'BES HURIZ, DEPARTURE SEC'I'IOr~ SEVERITY ~'~{.]~T~/SUU'flt EAST/WEST DIS'E, AZImUtH FEET bEG/100 ~ ~]~l.' FEET ~EET DEG ~I~ ,' 0.00 O,OO -130,bO 0 0 1000.00 999.99 869.99 0 10 2000.00 1999.~'1 1Bb9.g7 O 17 3000.00 2999.94 2869.94 0 46 4000.00 3983,19 ]853.19 22 26 5O 00.00 4813.34 46~3.3~ 36 3 bO00.O0 5b09,]3 54'19,33 .38 58 6840.00 6236.29 6106.29 45 16 N 0 O E 0.00 ~ 66 18 W 0.13 N 9 46 E -4.23 S 56 !4 ~ -5.q~ N 33 31 . lll,UO N 24 27 ~ 660,97 N 15 9 W 1264,~6 N 1 21 F 1794,01 0,00 0,23 0,27 3,60 1,29 0,00 0.00 N 0,00 E 0,00 N 0 O E 1,nV ~ 2.12 E 2,34 N 64 44 E 3.bo 5 2.48 E 4,3~ S ~4 48 E 5.33 S 2.79 E 6,0i S 27 38 £ 95.90 a 60,42 , 113,35 N 32 12 593.92 N 294.12 W 662,76 N 26 20 11~0.3~ ~ 503,76 w 1265,01 N 23 28 1~13,7~ ~ 54B,11 W 1799.30 N 17 ~4 W ARCO AbASKA, INC. 2H-12 KUPARUK NORTH SLOPE,AUABKA cuMpuTATION..i{;AT~.{. 17-PEC-B5 ~ ' .... "~" '<Y't'i: 1 PAGE [.)A£E [)F SURVEY: 28 NUV 85 KEbbY BUSHING E6EVATION: 150,00 .[N'£ERPLiL, ATED VAbUES FOR. EVEN 100 [EET U[" 5Ut~-SEA OEPTH TRUE SUB-SEA COURSE qEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEP'FH OEO MIN ' bEG MIN DEPTH N 14 27 E N 46 22 g S 72 55 E $ b5 3 g S 56 9 E N 40 43 E $ 41 1i E S 54 t7 ~ · ::~' 0,00 0,00 -130.00 0 0 30,00 30.00 -100'00 0 17 ~30,00 130,00 0.00 0 19 23O .00 230.00 100.00 0 16 · $30.00 330,00 200,00 0 5 430.00 430.00 300.00 0 17 530,Ol 530,00 400,00 0 19 6a ,.oo oo.oo o 7 o.oo oo.oo o o.oo ',oo.oo o g30,Ot 930.00 800.00 0 1.2 ?~I030,01 1030.0o 900.00 0 1130.01 1130,00 1000.00 0 23 :'1230,02 12.30.00 1100,00 0 31 1 330.02 1330.00 120o.00 0 18 4 o.oo , oo. o o 15 30.02 1530.00 1400.00 t) 31 .oo , oo.oo o' o ,: . 7oo,oo o 03 2030,00 1900,00 0 19 30~03 21'0'~00 2000,0o 0 19 ~30.04 22]0,00 2100.00 0 20 2200,00 0 21 2300,00 0 20 2400,00 2500.00 b O0,O0 0 7 700.00 0 48 ~800.00 0 46 ::~----: 9oo. OOooo.oo Oo 11t§ ~:12oo.oo o 45 100, O0 0 43 530 00 3400,00 · 3630,00 3500,~0 lO 14 3730.'00 3600. 0 4 31 3837~42 3830,00 3700.00 16 35 VERTICAL DOGDEG NEC'rANGUbAR COORDINATES HOR1Z, DEPARTURE SECTION SEVERITY .%L)RTH/SULITH EAST/WEST DIS'r, AZIMUTH FEET OEO/lO0 F'P;EIJ" FEE'r FEET DEG rain 0,00 0.00 O.OO N 0,00 E 0.00 0.36 0.00 N 0,00 E '0.04 0,12 0.14 m 0,46 E -0.43 0.17 (~.08 $ 0,94 E "0,69 0,61 0.20 S 1,20 E -0.39 0.45 0.08 N 1,22 E '0,24 0,25 0,42 N 1,67 ~ -O.l'/ 0.17 0.60 t~ 1,92 E 0.25 0,34 1.04 ~ 1,87 E 0.33 0.58 !.3u ~ 2,31 E 0.01 0.49 0.9'7 N 2,36 0,18 O,b7 l,OJ ~ 2,06 -0.34 0,06 O.b5 ,'~ 2.27 '1,12 0,40 0,24 S 2,37 -1.69 0.65 0.95 $ 2,16 '2,23 0.23 1.3~ S 2,57 -2.94 0.76 1,93 $ 3,05 -3,60 0,38 2.7~ $ 2,80 -3.87 0.4b 3.18 S 2,45 -4,24 0,25 3,50 S 2,65.E '4,44 0,50 3.7% S 2,59 '4.10 0,!4 3.40 8 2,52 '3,b9 0,71 2,80 S 2,70 '3.84 0.26 2.8I S 3.27 '4,26 U,14 .3,0'/ S $e78 -4.'75 0,15 3,)'1S 4,32 -4,BO 0,14 3.24 S 4,7b -4.9h !3.75 3.~q S 5,22 -5.54'5'22 0,0'.~3~1 4,0o3'4~ $8 ~,73 '5.78 0,26 4.78 S '~':":' -b.O8 0,31 5,5e S "6.44 1,42 6,41 S' '7,30 0,40 '/,bi S '6B g -8.13 O,B4 8,75 S' 06 '~.51 2.77 9,70 $ 1,26 -4, .~9 5,99 6,41 $ 4,13 9,01 '4,56 6,50 .~ 7,93' W 31.26 3.96 27,26 N 15,95 58.b2 2.'18 51. I.J N 29,87 0,00 N 0 0 E 0,00 N 90 0 E 0,48 N 72 39 E 0.94 S 85 0 E 1,2~ S 78 2 /' 1,2'2 N 8b 13t. 1,72 h 75 57 E 2.01 N 72 42 E 2,14 N 6! 2 E 2,65 N 60 39 E 2,55 N 67 36 E 2,30 N 63 24 E 2,33 N 76 18 E 2,39 S 84 12 E 2,36 S 66 17 E ,91 S 62 9 E ,61 S 5'1 41 E 3,92 S 45 37 E 4,02 S 37 40 E 4,39 S 37 4 E 4,55 $ 34 41 E 4,23 8 36 32 E 3,95 S 43 12 E 4,31 S 49 17 g 4,B7 5.48 S 52 4 5,'?b S 55 44 E 6,14 6,~5 S 5~ 46 E 6,23 S 49 19 E 5,98 S 36 58 E 6,08 S 23 43 E 6,55 S 11 45 E 7,64 $ 5 7 g 8,75 S 0 21 E 9,78 S 7 22 * 7,63 S 32 46 W 10,26 N 50 ~9 W 31.59 N 30 20 W 59,22 N 30 17 W CO~PUTAT.ION ARCO 2H-12 KUPARtlK NORTH Sb[)PE,AbASKA INI'ERPObA'rEI,~ VAbUES FOR EVEN MEASURED VERTICAL VMRTIC DEPTH DEPTH OEPT 100 e'ggT OF A COURSE v ER'rICAb AL OEVIATIOM AZIMUTH SECTION H bEG fllN OEG FIN FE.E'I 20 28 23 57 26 39 34 52 ~7 33 37 21 35 46 35 35 30 37 49 ~8 4 38 ~'7 45 38 42 38 59 3q 0 39 32 41 22 43 3 44 38 45 1.6 N 34 32 , 91.22 it J2 54 v~ 131.44 N 28 23 ~ 17'1,99 N 25 12 N 231.73 N 23 I ~ 294,80 N 23 59 ~ 369.37 N 23 59 W 446.87 M 24 2 W 523.8H ~ 24 5 , b99,55 it 24 35 ~ 673.04 25 3 w '/~3.57 23 59 ~ 814.17. 1'7 47 ~ 888.56 1U 11 ~ 966,36 19 41 W 19 51 W 1122,86 1.7 []4 ~ 1201.12 14 3~ ~ 1281,25 10 43 w 1361.27 9 3 ~ 1440.59 2b . 1523,0~ 40 g lb07,64 21 E 1696,12 21. E 17Rg.ln 21 E 1794.01. ,942.87 3930,00 3800.00 050.98 4030,00 3900.00 41bl 55 4130,00 4000.00 4275:18 4230.00 4100.00 I~93.47 4330,0t3 4200.00 18,24 4430.0U 4.~00. O0 4644,78 4530,00 4771.02 4630.00 4500.00 4896,45 4730,00 4bOO,O0 5020.58 4830.00 ~700.00 5143.0'0 q930.00 ~800.00 18 5130~00 5000,00 ~v. ,39 ~330,00 00,00 ~771,07 b430,00 §300,00 5898.15 5530.00 540{1.00 6~ ,34 5730,0U 5600,00 , 6030,00 59[)0.00 '..' '89 ~t O0 o.oo §§'oo SEVERITY OEG/IO0 3.54 '2,67 3.69 3.~9 4,41 1.07 0,4C} 0.78 O, 57 1.51 0.47 0.69 0,95 6.42 1.53 1,~3 1.97 2,15 2,50 2,10 0,71 0.00 (), 0 O PAGE b t) af~.: OF SURVIz;Y: 28 NOV 85 Kk, bbi ~USHING EbEYATLUN: 13u. OO FT ENGINEER: SARB£R RECTA~4GUbAR COORDINATES HORIZ. OEPARTUkg NORTH/SUtITH EAST/WEST DIST. AZIMUTH FEEt FEET ~EET OEG 'lB.6'; N 48,'72 W 92 53 N 31 46 W 112.83 N 71.47 ~ 135:56 N 32 21 W 153.1.~ h 95,77 w 180,b~ ~'~ 32 0 ~ 201.41 ~ 119.88 ~ 234.39 N 30 45 ~ 259.12 N 145,41 ~ 297,13 N 29 17(~, 327.56 iq 175.06 W 371,40 a 28 7 398.3/ N 206,bb W 448,79 N 27 25 468.74 ~ 238.04 W 525.72 ~ 26 55 w 537.8U 14 268,88 W 601,]5 N 26 33 W 604.92 ~ 2~9.13 '~ 674.84 ~ 26 18 W bbS.O/ ~ 328.86 a 745.43 N 26 10 ~ 733.05 N 358,70 W 81b,ll N 26 4 w 802.93 h 3~4,33 ~ 890,17 N 25 34 W 877.1~ N 408,33 ~ 967,54 N 24 57 W 95~.72 N 434,1~ ~ 1046,06 N 24 31 w 1099,08 N 485.79 w 1201,66 N 23 50 W lJ76.53 N 508,05 ~ 1281,54 N 23 21W 1~55.~ N 526,01W 1361.35 N 22 43 W 1335.~1N 539,71 W 1440,59 N 22 0 W 1420,51 N 550,07 ~ 1523,~0 1510.78 a 552,57 W 1608,66 N 20 5 1607,07 N 550,67 ~ ~698,80 N 18 54 W 1707.44 N 548.26 W1793.30 1'113.79 N 5~8,11 W 1799.]0 N ARCO AbASKA, i~C. 2H-12 KUPARUK NORTH SbOPE~AbASKA MARKER TOP KUPARUK C BASE KUPARLIK C TOP KUPARUK A BASE KUPARUK A ~BTD TD PAGE I)ATE [)F 8i. IRV~: 28 NUV B5 I~"SERPObATED VAbUES FOR CHOTEN HORIZONS HEASURED DEPTH 6513,00 6537.00 6578,00 6776,00 6840.0U SURFACE bOCATION Al' ECTANGULAR COORDI T FROM KB SUI~-$EA NOR'I'll/SOUTH EAST/WE~T 6002,43 b8'12,43 1485,33 N 552,7b 0020.08 5890,U8 1501,59 N 552,65 6049.9~ 5919.9~ 1529,64 , 552.~ 6191,25 6051.~5 ~668,33 N 549. b19U.29 bObS.29 1675.4~ N 549,01 6236.29 6106.29 13'71 79 N 548,11 ., ,,', 2H-12 KUPARUK NORTH COMPUTATION 1 *******~*~** $'IRAT.[GRAPHIC PAGE 130,00 FT TOP KUPARUK C BASE: KUPAR;JK C TOP KUPARUK A BASE ~LIPARIIK A PB~D TD ~4EASURgD DEPTH 6537.00 6578,0u 6776.00 6786,00 6~40,00 URIGIN: 17U' TVD FROM KB ~00~.~3 5872,43 6020.08 5890.0~ b049,98 5919.98 61.91.25 623~.2q 610;3.29 FNL, SUHF 114' FEI.,, RECTANG ACE ~OCATION AT S~C 35. TI1N. RSE,UM U~AR C.ORDINAT6SU SOUTH EAST/WE~T 1485,33 N 552,75 w t501,59 N 552,65 W X529,64 N 552,28 W /- 1668.33 N 549.18 w 16'75,43 N 549,01 W 1713.79 N 548,1! W FINAL MEASURED DEPTH Wgbb ~OCATION ']'~UE V [: i." TI C Al, i,)EPTH A T '1~ D: $ IIB -$ E A VERTICAL L)EP'r~ 6106,29 .= Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · o · ~IELL ~AHI~ ~ND NUMBER Reports and Materials to be received by: /~- -~./~ ~ Date Required Date Received Remarks ,, Completion Report y ~.~. Well .... History y Samples Mud Log Core Chips Cbr~ 'De,crlpt~on Registered Survey Inclination Survey Directional ~ - '" ... ,. , . .PI - ~.-- ;~.~ ~~_ , ~. ,~'. ~rtll 8tern ~est Report8 _ Production Test Reports Digitized Data . . Y~, L.FJ.04 ARCO Alaska, Inc. Post Office BrOnx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2H-12 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 2H-12. The bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is run. Also, I have not yet received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Si ncerely, Gruber Associate Engineer JG/tw GRU12/L156 Enclosure RECEIVED JA~,~ 0 2 ..... ' ~as~ 0il & ~t~ G~HS. Gommiss1~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany . ' , " STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO~..~i ISSION.. ~F(~r V}-[')r" -- 1. Status of Well Classification ofs rA v ,21986 OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Alaska 0il & Gas Cons. C0mmissi( 7. Permit Number Anchorage 2. Name of Operator ARCO Alaska, Inc. 85-262 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20053 4. Location of well at surface 9. Unit or Lease Name 170' FNL, 714' FEL, Sec.35, T11N, R8E, UH Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 2H-12 At Total Depth 11. Field and Pool To be submitted when gyro is received, Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 130' RKBI ADL 25587 ALK 2673 12. Da.te Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 10/30/85 11/07/85 11/10/85'J N/A feet MSL 1 17. Total Depth (M D+TV D) 6840 ' MD, 18. Plug Back Depth (MD+'I'VD) 6786 ' [4D YES19' Directional SurveYl_~X NO [] I20' Depth where sssv ,et1808 feet MD I21' Thickness °f PermafrOst1500' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cai, GR/CCL/CET/Cauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 114' 24" Conductor report not y.,t received. 9-5/8" $6.0# J-55 Surf 2741' 12-I/4" 700 sx CS Ill & 300 sx CS II 7" 26.0# J-55 Surf 6834' 8-1/2" 300 sx Class G & 175 s; CS 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) 6654' - 6684' w/4 spf, 90° phasing 2-7/8" 6589' 6376' & 6572' 6515' - 6535' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTsouEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~l~ 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 Form 10-407 * NOTE: Tubing was run and wel 1 perforated 12/13/85. TEHP3/WC32 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... ". GEoLoGIC MARKER~ ' "' ' ii. ;.'i~0'i~I:MZTi~'0N"~ESLrS'' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEASr' D. EPTH TRUE VERT. DEPTH 'GOR, and time of each phase. .: To be submitted w~ ;n gyro is rece~ fed. N/A 31. LIST OF ATTACHMENTS Well History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ (~'~ .)_~-/~ Title Associate Engineer Date' 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' I~dicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: ~l, ttached supplemental records ~or this well should show the details of any multiple stage cement- ing and th~ location of the cementing too. ? Item 2?:' 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 ARCO Oil and Gas Company Inltmctione: 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. JAN 0 2 ISS~ District Alaska Field Kuparuk River Auth. or W.O. no; Agg A[0073 ICounty, parish or borough North Slope Borough Lease ADL 25587 or Unit JTItle Dr/il ka 0il. & Gas Cons Commission ala~ ' iw~!,ora~e J 2H-12 Nabors 26E API 50-103-20053 O~tor rARCO w.I. ARCO Alaska, Inc. 56.24% . Spudded or W.O. begun: Io-e IHour lPr,or ,tatu, ,f e w.o. Spudded- 10/30/85 1230 hrs. Date and depth:: as of 8:00 a.m. 10/29/85 10/30/85 10/31/85 11/01/85 11/o2/85 thru 11/o4/85 11/o5/85 Complete record for each day reported 16" @ 110' MIRU. 16" @ 110' MIRU. NU diverter sys. 16" @ 114' 2500', (2386'), Drlg Wt. 9.0, PV 15, YP 17, PR 9.5, WL 11.4, Sol 5 Accept rig @ 0630 hfs, 10/30/85. NU diverter sys. 1230 hfs, 10/30/85. Drl 12¼" hole to 2500'. Spud well @ 9-5/8" @ 2741' 2755', (255'), NU BOPE Wt. 9.3, PV 21, YP 13 Drl to 2755', C&C, POH. RU & rn 69 its, 9-5/8", 36#, HF/ERW BTC csg to 2741'. Cmt w/700 sx CS III, followed by 300 sx CS II. Displ using rig pmp, bump plug. CIP @ 2315 hrs, 10/31/85. ND diverter sys. NU BOPE. 9-5/8" @ 2741' 5776', (3021'), Wt up mud to 10.4 ppg Wt up mud to 10.4 ppg Tst BOPE to 3500 psi. TIH to FC, tst csg to 2000 psi; OK. DO plugs, FC, cmt, FS + 10' new formation. Conduct formation tst to 12.5 ppg EMW. TIM, Navi-Drl to 5776', lost all rtns. Pmp 4 LCM pills; no rtns. Pull up hole 15 stds, break circ, lost pill. Pull up hole 17 stds to shoe, hole swabbing; break circ, min to good 'rtns. Gain in pit vol, SI & observe while bldg mud wt to 10.4 ppg. Total fluid lost = 1137 bbls. 3007', 1° S45.2W, 3007 TVD, - 1.0 VS, 1.9S, 1.gw 3543', 5.~°, N14.gw, 3542.5 TVD, 2.8 VS, 2.9S, 14.8W 3954', 20.7D, N32.gw, 3940.8 TVD, 98.7 VS, 84.7N, 53.9W 4332', 31.9°, N21.gW, 4279.3 TVD, 264.6 VS, 232.4N, 131.0W' 5458', 38.3°, N16.gW, 5183.9 TVD, 934.5 VS, 854.7N, 378.8W 9-5/8" @ 2741' 5776', (0'), Staging in Wt. 10.6, PV 11, YP 7, PH 8.5, WL 11, Sol 12 Circ 10.6 ppg mud; rtns 10.2 ppg-10.8 ppg; observe well, POH. TIH w/drlg assy to 2410', circ, stage in to 2879', 3353' & 3825', C&C mud each stage. The above is COf~,aOi Signature ~ /2M . For form preparation and see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate J Title /f-4-~5 Drilling Superintendent ARCO Oil and Gas Company,~,,'~' Daily Well History--Interim nstructions: This form is used during drilling or workover operations If testing coring or perforating, show formation name in describing work pe~,rr~. Number all drill stem tests sequential y. Attach descr pt on of a I cores Work perf .... d by Producing Section will be reported on "Interim" sheets u~l'~ f~'~'C [ I V E U completion. Report official or representative test on "Final" form. 1) Subm t "Inter m sheets when fil ed out but not less frequently than every 30 day~ Or ~ on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25587 Complete record for each day while drilling or workover in progress 11/o6/85 11/07/85 11/o8/85 & Ga~ Cu.~. Commission A]/~h~rage IWell no. 2H-12 9-5/8" @ 2741' 6096', (320'), Drlg Wt. 10.6, PV 14, YP 9, PH 9.0, WL 7.4, Sol 12 Fin staging in hole to 5047', single in to 5776' stable. Drl to 6096'. · wsh & rm; hole 9-5/8" @ 2741' 6830', (734'), Drlg Wt. 10.8· PV 18, YP 9, PH 9.0, WL 5.2, Sol 14 Drl to 6830'. Adjust mud wt to 10.8 ppg to control slow fluid lose. 9-5/8" @ 2741' 6840', (10'), Pmp LCM pill Wt. 11.0, PV 19, YP 8, PH 9.0, WL 5.4, Sol 15 Drl to 6840', 20 std short trip, C&C, POOH. RU Schl, log DIL/GR/SP/SFL f/6829'-2748', FDC/CNL f/6803'-6300' & 5800'-5500' & CAL f/6803'-2743'. RIH, rm to btm, lost full rtns. Build mud vol. Spot LCM pill #1 @ 5644'. M&P LCM pill #2. The above is correct Signature For form p~'~parati~n an~ dist~bution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle Drilling Superintendent ARCO Oil and GaS Company P,, F ~a~il~/~l History-Final Report Inslructions: 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 apprecial~.e.~l~tng~b oj~ti~,e~(~orkovers when an official test is not required up .... mpleti .... aport completion and representative test data in blocks provided. The ,'~F~l~el~OTft'~,~'orr~'3~ .... d for reporting the entire operation if space is available. IAccounting State cost center code Alaska IWell no. 2H-12 Naska 0il & Gas Cons. Commission District I County or Parish Anchorage Alaska I North Slope BOrough Field ~Lease or Unit Kuparuk River I ADL 25587 Auth. or W.O. no. ~Title AFE AK0073 I Drill Nabors 26E API 50-103-20053 cost center prior to plugging and I ARCO Alaska, Inc. 56.24~ abandonment of this well I Spudded or W.O. begun I Date Hour Prior status if a W.O. Spudded 10/30/85 1230 hrs. Date and depth as of 8:00 a.m. 11/o9/85 thru 11/10/85 Complete record for each day reported 7" @ 6834' 6840' TD, 6786' PBTD, RR 10.8 ppg NaC1/NaBr Spot 2nd LCM pill, observe well. Circ& balance mud & hole, POOH. RU & rn 7", 26#, J-55 BTC csg w/FS @ 6834', FC @ 6786'. Cmt w/300 sx C1 "G" w/l% DFP-19, .5% CD-31 & .3% A-2. Displ w/10.8 ppg brine, bump plug. CIP @ 0200 hrs, 11/10/85. ND BOPE, NU tbg head & lower tree. Tst pack-off to 3000 psi. R_~R @ 0830 hfs, 11/10/85. Old TD Released rig 0830 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data INew TD I PB Depth 6840' TD 6786' PBTD IDate JKind of rig 11/10/85 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production 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 above is correct Signature ~1~ ~~.~ For form preparation and distributi~In, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office B'~--,,Td0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC · ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-19- 85. TRANSMITTAL # 5473 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4/f G3-18-85 Run #1 4570.0-9471.0 ref# ' 70997 --;~d~~ ~2H-9/~ 12-02-85 Run #1 1800.0-8113.0 ref# 71048 ~2H-10 ~/ 11-23-85 Run #1 2856.0-7960.0 ref# 71002 '~2H-12 /, 11-07-85 Run #1 2743.0-6829.0 ref# 70947 2U-7// 03-19-85 Run #1 3594.5-8179.5 ref# 7095~~/~~_/~ ~2V-16/! 06-03-85 Run #1 2973.0-7168.0 ref# 70952-f~-~p~7~ ~3A-10H 11-09-85 Run #1 3179.0-7014.0 ref# 70960 ~3A-11w, 11-16-85 Run #1 3208.0-7330.0 ref# 70989 3A-12;/ 11-23-85 Run #1 3797.0-8006.0 ref# 71003 '~3A-13;/ 12-01-85 ~un #1 1800.0-7597.0 ref# 71047 ~3A-14'/ 12-09-85 Run #1 0144.5-7818.0 ref# 71073 '3C-9 07-10-85 Run #1 3920.0-8332.5 re f# __ 70996 -- r~_~_~4~ ~7-~ 3F-8~! 11-09-85 Run #lA2 0115.0-7040.0 ref# 70994 3F-9/~ 11-17-85 Run #1 3410.0-7770.0 ref# 70990 3F-10u 11-27-85 Run #1 1800.0-6631.0 ref# 71037 3F-11~ 12-05-85 Run #1 0148.0-8618.5 ref# 71061 3J-9.x/ 11-24-85 Run #lA2 0~91.0-6789.0 ref# 71034 3J-10-~ 12-08-85 Run #1 0096.5-7348.5 ref# 71074 Receipt Acknowledged: 'STATE OF ALASKA* ARCO Alaska. Inc. ~s a Subs~d~ar~ of Alla~t~cRicht~eldCom~an~ Date: ARCO Alaska, Inc.~ '~ Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. 0. BOX 100360 Anchorage AK 99510-0360 Transmitted herewith are the f~ltowing items. return one signed copy of this transmittal. Open Hole Final Prints/ Schl/ One * of each 2A-8 ~' 5" DIL/SFL-GR 1Q-29-85 Run #1 ~ 2" DIL/SFL-GR 10-29-85 Run #1 ~5" Den/Neu (poro) 10-29-85 Run #1 "~2" Den/Neu (poro) 10- 29-85 Run #1 ~5" Den/Neu (raw) 10-29-85 Run #1 ~' ~~2" . D'en/Neu (raw) 10-29-85 Run #1 ~ ~Cyberlook 10-29-85 Run #1 2Mr 12%/~ 5" DIL/SFL-GR 11-07-85 Run #1 ~-~ ~2" DIL/SFL-GR 11-07-85 Run #1 ~5" Den/Neu (poro) 11-07-85 ~un #1 ~2" Den/Neu (poro) 11-07-85 Run #1 5" Den/Neu (raw) 11-07-85 Run #1 ~2" Den/Neu (raw) 11-07-85 Run #1 ~ ~Cyberlook 11-07-85 Run #1 3c-1~ ~5" DIL/SFL-GR 10-26-85 Run #1 ~,' 2" DIL/SFL-~R 10-26-85 Run #1 ~5" Den/Neu (poro) 10-26-85 Run #1 %~2" Den/Neu (poro) 10-26-85 Run #1 ~-~ 5" Den/Neu (raw) 18-26-85 Run #1 ~ 2" Den/Neu (raw) 10-26-85 Run #1 '~ Cyberiook 10-2~7-85 Run #1 Date; 12-19-85 Transmittal No: 5481 A Please acknowledge receipt and 3407-8492 3407~8492 3407-8466 3407-8466 3407-8466 3407-8466 7850-8443 2743-6829 2743-6829 5500-6803 5500-6803 ~500-6803 5500-6803 6300-6780 2698-9420 2698-9420 8750-9394 8750-9394 8750-9394 8750-9394 9024-9315 Receipt Acknowledged: State of AK *bl/se Rathmell *bl NSK Clerk *bl Drilling *bl Vault *Films DeGloyer & MacNaughton *bl Date: ARCO Alaska. Inc. ~s a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Bd> 360 Anchorage, Ala~lk'~99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the November monthly reports for the following wells: 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-'29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures RECEIVED O EC $1985 41~ske, ~Jii ~ .Gas Cons. Corll~iss[oll /~nchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany. -. STATE OF ALASKA ALASKA 01~.~N D GAS CONSERVATION CO'~...~,'SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-262 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20053 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well 170' FNL, 714' FEL, $ec.35, T11N, R8E, UM at surface 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 130' RKB ADL 25587 ALK 2673 10. Well No. 2H-1 2 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of November ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1230 hfs, 10/30/85. Drld 12-1/4" hole to 2755'. Ran, cmtd & tstd 9-5/8" csg. to 5776'. Lost circulation. Pumped pill. Cont'd drlg 8-1/2" hole to 6840'TD (11/7/85). cmtd, & tstd 7" csg. PBTD = 6786'. Secured well & RR @ 08:30 hrs, 11/10/85. Drld 8-1/2" hole Ran logs. Ran, 13. Casing or liner ru.n and quantities of cement, results of pressure tests · 16" 62.5#/ft, H-40 weld conductor set ~ 114' Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 2741'. Cmtd w/700 sx CS Ill & 300 sx CS Il. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 6834'. Cmtd w/300 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/6829' - 2743' FDC/CNL f/6803' - 6300' & 5800' - 5500' Cal f/6803' - 2743' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None Alaska OiJ & Gas Cons, OormnJssior~ Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Associate Engineer 1~-I~',~ SIGNED _ TITLE DATE NOTE--Report~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~104 TEMP2/MR66 Submit in duplicate MEMORANDUM TO: THRU: Lonnie C. Smith Commissioner FROM: Doug Amos~ Petroleum Inspector State, of AlaSka A~/,:OIL AND GAS CONSERVATION CO~ISSION AL . rton DATE: December 9, 1985 . FILE NO: D. ADA. 5 5 TELEPHONE NO: SUBJECT: BOP Test ARCO KRU 2H-12 Well Permit No.' 85-262 Kuparu_k Ry. Field Thursd.a_y, October 31, 1985: After witnessing the meter proving at the C.O.T'. 'Pla6't I t~a~eled to Kuparuk to witness the BOP test at ARCO's KRU 2H-12 Well. Friday, ~ovember 1, 1985: The testing commenced at 7=00 AM and was COnclUded at 8-:15' AM. Th'ere were no failures and I filled out an A. O.G.C.C. BOP Inspection Report which is attached. In summary, I witnessed the successful BOP Test at ARCO's KRU 2H-12 well. Attachment 02-00IA(Rev. 10/79) .~ . .~ O&G #4 4/80 · . STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date ~l -I- ~ Operator ~ ~ Representative ~ ~%~%4~ .~. Well ~{ ~-~, _ Permit # ~ ~g~ Location: Sec ~ T)%~ R'A~ M ~V~ ~/~ Casing Set @ Zq'S~. ft. . ~ Drilling Contractor ~k~PO~-~ Rig #~--~D~D Representativ~ ~ ~~~ L~ation, General Well Sign General Housekeeping ~Reserve pit:i~.. ~ BOPE Stack Annular Preventer ~l Pipe Rams ~ ~ ~ O~ ,~_.,.' Blind Rams I Choke Line Valves ~/3/~_ H.C.R. Valve ?/~ I' Kill Line Valves ..~/~ Check Valve Test Pressure ~. Goo ACCUMULATOR SYSTEM Full Charge Pressure ~Ckf) psig Pressure After Closure ~O psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: N2 !~g~!~;~'/~OOI 1~OO I~'~'/0 psig Controls: Master Remote f)~f Blinds switch cover Kelly and Floor Safety Valves Upper Kelly I ~k~Test Pressure .~; .~fDO Lower Kelly ~ /Test Pressure Ball Type._. I ~Test Pressure Inside BOP ~ ~Test Pressure Choke Manifold I ~Test Pressure No. Valves ~ I~ No. flanges ~/ ~ Adjustable Chokes o~ Hydrauically operated choke min ~ sec min.~ sec Test Results: Failures .kl~f)k~ ~ Test Time ~ Repair or Replacement of failed equipment to be made within Inspector/Commission office notified, Remarks: nrc. days and Dis tr ibut ion orig. - AO&GCC' cc - Operator cc - Supervisor Inspect~or ~'~ ~,e, ARCO Alaska, Inc. Post Office'~*b"~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 .. SUBJECT: Conductor As-Built Location Wells 9-12 Plats - 2H Pad Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L65 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ ~ x ~." ' '''' ' . r ' -- : ' ' --'""-""-' ;J-:.i---?~4.;,-~::-~,~_: -:'L:-~ DRIL' SITE 2-H CONDUCTORS:~:),..',: '_~ :*:---;: :u: :.'~-? 5-.J 9 · : O ! 6:.~;'-5: :.:~..:: ~_.':':-5-. _2:.;:- -WELL 1 ........ · '- "-- .... - .... - ...... ' '" ' -' · . -'~ , -....; . .. .... . z... -.. ....... =.=.~.. ~. ~ - .... -:. - ',_:- '-%:.' 5'.- .: '-. - ' :. -" - -:.. ~ _E :.- __:/-~-.,-. ..... ;--:'hc-;- 4i' ..; .... ?.:.-'.'-. ...... ::~' .:..:.'.... '-m-.-- :'-.. --~.,.~,..~.:,~. ..: ..... :~:;._-.,-;:_ .I?O._FNL,: 594 F~L-m--:E~'~_~.:g .8,OG.. - 9ot~. ' ~'. ,t. -;-:.~ ":-.~ '" ' t't, 5 '_. '.. '--'." --:-'-"~ _';'L '7_.F,t~ . i~;:" 57;. ..--.L; :~:.: L:7,'-4'-Z-P .-~:::'~t-.:~'F-: . :. :-:, "' .: 7 ~...~.:::~:.t-~. ::~ ;.~? :~?~%_.%:; X:_~.-: · .'.'.'/.~ -:?-' ':. '..-.:-. .~..:~ ".- - :~ ~ -~. 4-'_i', 'F :..~_:;-wt .... 5--~. . -- ~; .... .~- :...~:.- .... .. ~.,.-;.:...-- .....:- . ~, --? -~:._._::_ .-, .:.::~:- -.- _ :-:. ~70_.;FN~,. ~5~-:~..;~-_~. ~.k:~ ..... ~S,..0C_..~.~.2q-5_;-. ~"-.- :, '-:-? ',..'". '~ ,. 80. , , ~ O I-.:~, ..... '-' :- "--~'- -~ .... ~ '-1'2 ..... ; r ~' ~ '"....' - · . . ;-:' ~ ~ -; - - "~'~- .... --' ~-7.. ..... ~ELL -' - -'_:--~;: ;: '-z.' . .... :-_-:-~ - ->. -n-- :- .. :. ..~ :':?' ._..--:~...: .. 5.?- · . 2L5:7 '"' ;.'--"-; ""': "" "~J'~'- 7-n ' ' 0 ~-?/c:t~ .;:-:::_;_?~;5:'_57?_ .. ~- - ...... .: .- ..... -.. - --: ~..: .... ~- ... _~::-: i :-, ~-::~ :-:: -"-'t--'- ':'?::-'-.,:---'-'~-'-~- :'~'.--' '. ' -: '1:' :.~-';.;:5~ ' :':.---'.~.-:-:~ :-':_z ~:Y'::=-5,948,69~t2~%~;:,~T-%~7~.;-,I6:,._I5' 2.9 : · :. :..--:;.:-,:"~,. · ~-,' ,' :. .. ---' 4"~'-,- -~ . -.--:---: ::' - '. _- ~ '-',- '--_'-- ,' .': '. -..: . .- ' ~ 5 ~,. '" ~ ,~ . .'. --<.::5 ._'~-L~'--~;~: :?~7 L- -:: ?-- A- .... .~.~;~;'- --:'- t ':'. ' ' '~ .'-' '-~ :.' .<, '~- L'_~' ' ~ .' ~"-/-.~F~: ~-~= ~-7:.;~'%-' ~- ~p:.%~::~-~::~.:-~.;~;-~`~L::~`F~`;t~-~;~`~`~``~:~.;~:~`..~¥~ :~-/'~ - '-- ~ -; :- _z' - -.~, · '. --';',- - .z.,- ;~..'- - .- , · ..... - ?~,~%, -~'~-L~-t~----~%-: ..... t Ft~ - .¢ ~'>~. -. '.. -7 :, .'A ;' ' :"- ; .'.-' ~-L;; %? : ~' - '- , ' "2: %-- '-~-~'9~t 'f%-:?fJ.-~:Lf~5~- ~ ' ~- ': ''--;'i":'-~, -L~?'..;',.,Z:.:'.~. ,~/.:::;U:.~-h'-:- ~ .h-~'~4:~ _-:;~t~Z'7~?~' ~-~i-~-;;.- · ,,-, ,:. ~'~ ~:.; u'~,A*' ~'~,~,~%= ::~::.-.-~-,' .:('- -~:7(::)t:L-'i-~-.':?-:-~_.=:Q':::~- ' "':-.':'. :'. ':' ';f'f : '.:' ::: ~'.." - .-.-::: ..-:.":- ~':-:.-~QT:-':):?:::_-~. ;"._,: An~e- ":'--:'-:':-"--:-"' '" ~- ............ ' .... :':: Jz~ V- -~ ~1-' ~ .: .'X~o.:-':---' ' Y - ' " ' " ' ..:':'.x":.. '..:"('~ .O'-.. ., t.-'-.) .... --_ ,,' ~.. .'u~sE~-' ~V'~ECT S~E~-S,O~ '~',TH~T' ~LL'-6ETA~LS ARE: :" (.".: '.'.' .~ THIS SURV~Y~ '~;.' ['-' ~':'~; t, CO~RECT'~s 0~":.~-':'?'_":--:.-:-'-':..-..'-:, L~i:.'>:.' ':'(:.;;-'-:. ~:'..;'7:'/ _ ., ~,, -'-:_,;-~:.. ~c9' ~as~a, ,nc.'. '.:--' ~.~ ' -_-.. ,.~.J -~. ~:--. - .:.':';-.."' ,.,......-. -..:-_-- .o.,. s,o,. ,.,,,,.~- ';------" nll g -.:' .... ,...._'":.:,."', ..........' . ..... -. ,--. :-'- .--: .... -~7'-.: --:..~ _;. :. -7.-:3- .~---,,, :, ~':? ~-:":",~'"e ~-. :- ~'o,'~ :' ::~-~ ~,: - .7'.-'. ' .".~i'~ · ... . . -:~-(,0 e' '"... : o, ~--.,?":' "-'- '~- ' - ' ,.' . .--_.., ~;:;"~" ®- ' ...~; ........ iL___ :-~: ;.,.'.::.~ .~-.,...~, . ~.: -...- .. _ ~. _ .~ . :... · . .. _v. "'- . :: ,~..-' ~--,;~- _ . . . ~... -~.. ~.-.:~.-~ ~- ~.__ .. . .:~. - ~ ~, .- d -,' ~' - ' - i'~-',~ s o ?,:.. 7~o. . . oz-:.(~ .~........... .2-': 6 O, .. ~ . -.':-_ . _. ';. 50- :' 04_.?;'-, '~ .;.:.. . . _ . _'. ~-- ' :. ':.-- ':~ '-::5_:-.;(; · -. ,~-.::--_ .... - ..- "~:-" '~" "~ '-"" '~ ' 7<- '~ ~'"'.::5 ..... · ',~:_::",-...: ' . .. :' ~:--.?:?:~L~. .~-:),~%? :7 - -- ' .'.~r%-. "~' -2:' ~' t- ?; ~. '- ' ,~-~ .-~: -_-~-~-- '~ ."¢" ~-';~.----.. - ' ,~-- - ._ t-- L~'_': %: .~ _.'%:.¥-,::~ ~..~-~).: . -: . ._ ~;.: ::?, ~-.-~'; ?~..':?:F :~ -.: .......... October 28, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2H-12 ARCO Alaska, Inc. Permit No. 85-262 Sur. Loc. 170'FNL, 714'FEL, Sec. 35, TllN, RSE, UM. Btmhole Loc. !486'FSL, 1388'FErn, Sec. 26, TllN, RSE, L~M. 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. Where 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. V t_~r.uly.~ypBr.~s ,~ ~ C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enci. Mr. Doug L. Lowery STATE OF ALASKA ALASKA O~ AND GAS CONSERVATION COk~/IISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~)X REDRILL [] DEEPEN [] lb. Type of well 2. Name of operator ARCO Alaska, Inc. 3. Address · P. 0. Box 100360, Anchorage, Alaska 99510 EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] sTRATIGRAI~C SINGLE ZONE I~ MULTIPLE Z O ~'~.J~] 9. Unit or lease name Kuparuk River Unit 4. Location of well at surface 170' FNL, 714' FEL, Sec.35, T11N, R8E, UM At top of proposed producing interval 1268' FSL, 1299' FEL, Sec. 26, T11N, R8E, UM At total depth 1486' FSL, 1388' FEL, Sec.26, T11N, R8E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 130', PAD 95' 6. Lease designation and serial no. ADL 25587 ALK 2673 10. Well number 2H-12 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2H-13well 280' ~ Surface feet 16. Proposed depth (MD & TVD) 6886' MD, 6311' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 3400feet. 21 14. Distance to nearest property or lease line miles 170' ~ Surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 39° (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date November 2, 1985 3!09 psig@ 80OF Surface 3573 . psig@ 5975 ft. TD (TVD) SIZE Hole 24" 12-1/4" Casing Weight 16" 62.5# 9-5/8" 36. O# 8-1/2" 7" 26.0# 22. Describe propose0 program: CASING AND LINER Grade Coupling Length H-40 Weld ! J-55 BTC I 2714' I HF-ERW J-55 BTC / 6851 ' / HF-ERW SETTING DEPTH MD TOP TVD 80' 36' I 36' i 36' I 36' 35' I 35' MD BOTTOM TVD 116' I 116' 2750' 12750' I 6886' 6311' I QUANTITY OF CEMENT (include stage data) ±200 cf 630 sx CS III & 300 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6886' MD (6311' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3500 psig upon installation and weekly thereafter. Expected maximum surface pressure is 3109 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uneemented annuli through the permafrost interval. 2H-12 will be 280' away from 2H-13 at surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby certify~/rr~ the foregoing is true and correct to the best of my knowledge SIGNED TITLE The space belo~f0'r C~r~on use ' ' Reqional Drilling Engineer DATE CONDITIONS OF APPROVAL Samples required I--IY ES '~IN O Permit number APPROVED BY Form 10-401 Rev. 7-1-80 Mud log required I-lYES Approval date _10/28/85 Directional Survey required J] APl number~. ~,"ES []NO 50--/0,3 - 'OO;-:J.'.'.5. ~. SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMM ISSl ON ER DATE by order of the Commission October 28, 1985 Submit in triplicate PERMIT TO DRILL 2H-12 Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. --?:~--;;::.;-PAD-2H:-:~ELL-NO'-/-"..-~;'-I~ V]:SED:P SAL .... KUPAEUK--.F t ELD ;i-NOET _----~:, ........E^S TI~? -- I.'H I PSTOCK~.---I N C __-. _ ! I : --. + .... .{,, I ' ' i .................. -- ....... : -=~ .~ ......... 1,------ --F- .................... BASE-'PERMAFROST TVD=t465 --~ : , ~, : : ~ .... ~ ....~~_ ~ L , ~-- , . ;. . ~00_ _ ~. ' ; ~ : -~ ..................... TOP~-W- SAK--SNDS- TVD=2150 ~~' ~ : ....................... ~ ........i i ; ............. - '--~ ..... ~ ......... ~-9-5~8"- cSG '-PT~-TVDe2750 -~i c ..... : ....... ~ ~. '' '- ' ' ' -0 ....... ; ............ ' ; ~ ~ . ~ ..... . - ~ ' ~ ' 'r . _ _.; ~. __ , .......... ~.--: ....... t __.~_:. i __ _ : j ._ ! ........... ............................., : ] ..... ~' --:_~~~'~ ........ ~ ' 11 - ~ . '.~ - -~ ....... : ................... ~ .... ~ ~- -.~ ....... -~- i ......... snno ........ ~ - TX--ZONE--C-- -T~D=59Z5-T~D=6456-DEP=1520 .... ~ ................. &-! ....... ~ ---J .... ~ ....~BASE-KUP. ......... ~noo .... ! , i _ . : , ~~~~ -- - ...... ~--- Z.:3 O0 " ~000 :: -,r ...... _ ...... l ' ~ ' ~chora~ , i .... f ..... KUPAIRUK IRIVEIR UNIT 20' .DIVESTER SCHEMAT:IC 6 DE S CR I PT I ON i. 16" COhEXJCTOR. 2. TANI<O STARTER NEAD. 3. TANKO SAVER SUB. 4, TABOO LOWER QUICK-C~CT ASSY, 5. TA~O U~ER ~I~-C~CT ASSY. 20' W/I O' ~TLETS, I0' DIVERTEE LI~S. VALVES ~EN AUT~TICALLY UP~ CLARE A~AR PREVE~ER, 8. 20" 2~ PSI A~LAR P~~ER. 5 2 MA :[ NTENANCE & OPERAT.]:ON I. UPON INITIAL INSTALLATION~ CLOSE PREVENTER AND VERIFY THAT VALVES '- HAVE OPENED PROPERLY, CLOSE A~,4ULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS, 5; CLOSE ANt~LAR PREVENTER IN THE EVENT 'THAT AN INFLUX OF WELLBORE . - FLUIDS OR GAS IS DETECTED. IF .. NECESSARY, hiAt~ALLY OVERRIDE AN~ CLOSE - APPROPR ! ATE VALVE TO ACHIEVE D~Ihl:) DIVERSION, DO NOT SHUT IN ~ELL UNC)ER ANY CIRCUMSTANCES. Alaska Oil & Gas Co~is. 7 ! 6 3<~o~ DIAGRAM #1 ~3-5/8' ,~ PSI RSRRA B~ ~TA~ 4. 1~8' - ~ ~I PI~ ~ 5. !~8' - ~ ~I ~I~I~ ~ ~~ ~ KI~ LI~ 7. 1~8' - ~ ~I ~ ' .ACCLIvtJt, ATOR CAPACITY TEST !. CHECK At~) FILL AC~TCR RESERVOIR TO LEVEL WITH HYDRAULIC FLUID. 2. ~ ~T A~T~ ~ IS ~ ~I WI~ 3, ~ TI~, ~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ T~ ~ i~ ~I 5 13-5/8" BC~ STACK TEST 1. FILL BOP STACK AhD CHCKE MANIFOLD WITH ARCTIC DIESEL. 2. C~CK THAT ALL LOCK DO, IN ~ IN Y~ ARE FUU_Y RETRACTED. SF_AT TEST PLUG IN WITH RUNNING JT A~ RUN IN LEX~ SC~. L.TI~E: VALVES ADJACENT TO BCP STAQ~ ALL OTHER 4. PRE~ UP TO P--~HO_D F(3:~ I0 MIN. IN- CREASE PRESSURE TO,~_ ~_PS~ AhD HOD FC~ I0 MIN. BLEED PRE~ TO 0~~ 5. CPEN ~ PF~-VF_NTE~ Ah~ MANUAL Kill AhD Q-K~KE LIhE VALVES. CLOSE TOP PIPE RAMS AhD H(:R VALVES 'CN KILL AhD Q-IO<E LI~ 6. TEST TO 2.~ PSI AhD(~0'9~ AS..IN STEP 4. ?. C~I~ TESTINO ALL"~VE,~r~J~. AhD WITH A 2.50 PSI L(~ AhD ~::~"PSI HIGH. TEST AS IN STEP 4. EX3 NOT F~ES-~ T~ST ~ C:-K~K~ THAT IS bDT A FULL CLOSING PO~ITI¥~ .~EAL C~. girLY Fl.~lgi4 TEST C~$ THAT DO bDT FI.LLY CLC~=~. 8.OPEN TOP PIPE ~ AhD CLOSE BOTTOM PIPE TEST BOTTOM PIPE RAN~ TO 2.50 PSI AAD 9. OPEN BOTTOM PIPE P.A~. EACX OUT ~dh~JIhK~ dT AhD CLoes TEST TO. PSI. - - II. ~ BLIhD RAMS AhD RETRIEVE-TEST PLUG. MAKE. SURE 'N;ANIFOLD AhD LIh~S ARE FULL ~F -- FLUID. SET ALL VALVES IN DRILLING POSITION. '12: 'TEST STAhDPIPE VALVES, K~I[Y, KI~ lY COCKS, DRILL PIPE SAFETY VALVE, AhD INSIDE BOP TO 250 PSI AAD 3000 PSI. 13. REC~ TEST INFCF~ATION ON BLONOJT PR~ TEST FO~o SIGN, AhD SEAD TO DRIllING SUPERVISOR. 14. PERFC~ C~E BCPE TEST AFTER NIPPLINS UP A~D WEEKLY THEREAFTER FUNCTI~Y OPERATE BCPE DAILY. .. 5100~001" REV. 2 U&W I~_ ARCO Alaska, Inc. Post Office Bb~-,~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2H-12 Dear Mr. Chatterton- Enclosed are' An application for Permit to Drill Kuparuk 2H-12, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on November 2, 1985. any questions, please call me at 263-4970. Sincerely, ~~~~g~~~ii neer JBK/lt PD/L98 Enclosures If you have RECEIVED OCT 2 4 gfl§ Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (2 thru 8) (8) . (3) Admin ~..~.- ! ~"T 3"'~' 9. (t~' thru 12)z 'V'-'"- 10. .'' ,,_.,.:.,: :, (10 and 12:) ~ 12. (4) Ca sg~~( (13 thru 21) (22 thru 26) 13. .14. 15. 16. 17. 18. 19. 20. 21. YES NO Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. ~,~-~ 3. Is well located proper distance from property line ':~__~ 4. Is well located proper distance from other wells .. .~. 5. Is' sufficient undedicated acreage available in this pool ............ /~ 6. Is well to be deviated and is wellbore plat included ................. , ~' 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before ten-day wait .......................... /'k~- REMARKS 22. 23. 24. 25. 26. 27. Does operator have a bond in force .................................. ~,,- Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... z'~, Is conductor string provided ........................................ Is enough cement 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 surface casing protect fresh water zones... ....... te~sl;~'~ ~ Will all casing give adequate safety in collapse, Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ...... Are necessary diagrams of diverter and BOP equipment attached ....... ~ ..... Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API ~-53 (Feb 78) ' ~,(~; ~.,',,'d~. ,d/ ' · ..... . · .... . .... . · zvt;..~' ~,,,,~?~, ~:,',,,:',,,,~'.~ Is th pre f H2S gas prob bl ' e sence o a e ..... . ..................... . .... Additional requirements ............................................. Additional Remarks: ~ ~ ~~ ~p~. . 0 Geology HWK ~ ~A~ J'gI, Engineering: .~ rcs,/ s .w ~,, .? MTM/~Z HJH ' "' rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~,.t' "" , Well Histo.ry 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 APPENDIXi .. No special'effort has been made to chronologically ' .. organize this category of information. ********************** LVP OlO.HO~ VERIFICATION L~$TING PA~E 1 NAME {149251 ~ONT?NUA?ION # PRFVTOU$ R~EL COMMENTS {LIBRARY TAPE OR,G, ~1,./1000 TAPE NRM~ {0947 CONTINUATION t PR~V)OUS T~PE COMMENTS ILIBRARY TAPE EOF * DER FIbE NAME IEO~T .001 SERVICE NAME ~ DATE l MAXIMUM L~NG?H I 1024 ~Z~E TYP~ { PReViOUS F'TbE { ,$ INFORMATION RECORDS ~N J AR~O ALASKA ~N~ · N ! KUPARUK ~ANG~ RE STAT'I SKA CTWYt USA ** COMMENTS ** UNYT TYPE CATE SIZE CODE oo~, o,oo ~ i~° ooo o~ 0~0 000 002 ~ ooo°°° g~i o6~ 000 000 003 065' UNTT TYPE CATE SIZE CODE 0o0 000 001 O65 LVP OiO,MO~ VERIFICATION LTSTING PAGE 2 * SCHLUMBERGER * ALASKA COMPUTING CENTER CONPAN¥ = ARCO ALASKA WELL = fX;LD = KUPARUK COUNTY =,NORTH SLOPE STATE = ALASKA NUMBER AT ACC~ 70947 RUN #O~B. DATE ~OGGEDI O?-NOV-~5 CASING = 9,625" P 2140.0~ - B~T S~E = B.5" ?0 6840,0' TYPE FLUID = bSND POLYMER ~H =. 9.~ R~C · ?.,50 , 63:~ ~f ~ATR~X SANDSTONE $*,*** TH)S D~A HA8 NOT BE~N .D~PTH $~FTED - OVERLAYS ~I£LD PRINTS ***** bVP 010..02 VERIFICATION L~STI~G PA~E 3 SCHLUMBERGER L~GS ~NCLUDED W~TH ?HT$ MAGNETIC DUAL INDUCTION SPHERICALLY FOCUSED LOG_(DIL) D~TA AV~ZbABLEt 6629,0' TO ?743.0' DATA AVAILAebE: 590i.0' TO 550u,v' ~N?RY ~bOCKS TYPE ,ZZE ~EPR CODE ENTRY 2 1 66 0 8 4 60 9 4 ~6 ! 6~ 0 ~ 6~ 0 { tVP 010,HO~ VE~IFI~A?ION LTSTING PA~E 4 DA?U~ SPECTF~CAT~ON BbOCKS #NEM SERVICE SERVICE UNIT APl ID ORDER # LOG TYPE CbA$$ MOD DEPT FT OD o0o o0 o SFLU DIL OHMM O0 220 O! 0 lbo ~Ib OHM, O0 '20 46 0 ih. OIL OH,M O0 120 44 0 SP ~l',, .V O0 OlO 01 0 CAb! ~O~ IN O0 ~80 O1 0 RHOB FDN ~/C3 00 350 02 0 Oa.o rD. ~/¢3 o0 356 Ol 0 .RA? rD, O0 420 01 0 RNRR rO~ O0 000 O0 0 ~PHI rD, PU O0 890 O0 0 .C.b rDN ~P8 00 330 31 0 ,tNb ,D~ CPS 00 330 30 0 2,9241 lbo 11{0,9023 ~R ,05t{I MRAT 229].'5000 PCML SP. , 139 RHOB 2,4749 ORHO NPHI 44, ?266 MC'Nb , tONI,, OEPT 6?00:0000 SFLU 05 ~R RH~B ..' 105 12 2:459 ;020 : ?CN'b DEPT 6~00.0000 SrLU SP~ 42,1758 ~R RHOB ~,4592 DRHO NPHI 3, .5020 NCNb NRA? r C N L: DEPT 6~00.0000 FLU SP,, 46,0820 ~R RHOB 2,6.682 ORHO NPHI 39.746:1 ~CN6 9-~: ,5647 {bD · 7148 GR 8'75 F'CNL r)EPT 6300.0000 SFLU 7.7781 lbo I85.6875 ~R NO, 0 0 0 0 0 0 0 0 0 0 O. 0 0 0 0 SIZE SP6 REPR PROCESS CODE (OCTA6) 4 ! 68 00000000000000 4 1 68 00000000000000 4 I6800000000000000 ~ ,~,oooooooooooooo ~ ,~oooooooooooooo ~,~~oooooooooooooo ~ ~~oooooooo~ooooo ~ ,~ oooooooooooooo ],4924 ?i'.3~3t25 11~.,9045 8'3~8 ~o~'~t.~ 87 ;I' 4,29'37 I85.6875 l~bl~ 2 9 )4 ~A[~I Si:)~ 0 {~NRA 3 ' RNRA !bH 2,2561 CAb~[ 9,9:4 ;5: I~N:RA 1.~ 14 DVP OI,~.HO~ VEPZFICA?ION LTS'?ING PAGE 5 RwOB DRHO NPHI NCNb DBPT SFLU Sp ~R RHOB DRHO OEP? gFbU RHOB DRHO NpH! NCNb SP,:, OR RHOB DRHO ~PHi NCNb SP, ~R RHOB DRHO DgPT SFL, U RHOB DRHO RHOB DRMO NPH! t~CNb RHOB NPHI RHOB NPH! ~ 4377 32~2266 6200.0000 -49.7383 -999.2500 -999,2500 6}00.0000 . 62,9883 .999,~500 999,2500 6000,0000 -5~'?070 ~999,~500 ~999,~500 -99g'2500 -99~5B0 5800 0000 Z .oooo 5600.00O0 ,44~7 42,9~99 .?9tO 5400,0000 -~99, iO0 -999. 5200,0000 DRHO ~C~b 8FLU DRHO ~R DRHO SFLU -O.O09B NRA? 1098.6875 FCNb .5 4109 .Tb~ 346:3906 GR -999.2500 NRAT .,999,~500. WCNL '99 ,2500 NRA? "~99o2500 ~CNb 4,4343 IbD 106.,4648 ~,R -999.,2500 MRIT '999,2500 rCNL 1.08,5293 ~R :999.'2500 NRA? 99,m.2500 FCNb 6 0437 ~bD I4.568~75 OR "0 ~01 ' N.RRT 2057 5000 FCN{L, 3,1760 ;0 ~0005 NRa,~ 20:61 "5000 rCNb 11 220 3,0198 999.~500 999, 50 5.2625 NRA'T F'CNL ~R ~R:A~ '! bD 2,9749 663.31~5 2.9749 -999,}500 -999, 500 -999,2500 3.?151 q99.2500 -999. ~,~151 -999, '999,2500 ~046 .999.~$00 999.~500 o. 4 , ?5 ! 2:I' :509,:: 6 6 3 2.9924 RNRA CAb! RNRA CALl RNRA RNRA RNRA RNRA ! M Ck[,I RNRA CASI IRNRA R NRA ~AbI R N R A IbM 3.0120 3,2913 -999.2500 "999.2500 .99~ '9514 .2500 -999.2500 3,3674 -999,2500 "q99.2500 -99~ ,7507 ,2500 -999,2500 4,3953 . 1 , :7483 ,0254 ,5:608 3,5842 . :S 4 t 0 ,'0437 2,935'8 i [,VP OlO,H02 VERIFICATION b'{$?lNO PAGE 6 SP RHOB RHOB RHOB ~EPT SP. RHOB NpH! ~PHI RHOB NPHI MP~I ~PHI DEPT RHOB NPHi D~PT RHOB 99 ~500 r)RHD q992500 NCNb 5100,0000 8FLU ,.50,4883 ~R 9.,2. O0 qCNb 5000 0000 SFt, U .222'/ GR 4900 0000 SFt, U -50~q258 GR '999.2500 DRHO -999.2500 NCNb 4800 0000 8FLU -67'0977 Git ,,,99V~2500 r)RHO -999,2500 NCNb 49.0o.90~~ SFLU 69, GR -999,~5i~0 ORHO -999,~500 ~CNb 460(~,0000 8'FLU -999. DRHO -999.2500 NCNb ,5FLU ~R D:RHO NCNb 4400,0000 SFt. U "57,05:08 GR -999,2500 ORHO -999.2500 NCNb 300,0,000 8FLU .,'61,90~0 OR ,,999,2500 ORHO -999.2500 NCNb .990.500 qgq.2500 7093 .999,2500 q99.2500 ),5159 113.8398 '999.2500 '999.2500 3,$370 126,1523 -999o2500 -999°.2500 '3,4163 .135.5625 999.2500 '999..2500 '99q,2500 -999,~500 i 9186 -999, 999, -999. -9991:2500 2,'$139 77,9148 '999.2500 NRtT nCNb CR NRAT FCNL ILD NRAT FCNL GR NR~T FCNL ~R NRA. T PCNb ~CNL ~R NRiT PCNb N:R'A T PC'Nb ,Tbr) :OR NRIT ~RAT PCNL OR -999.2500 -9992500 -999~2500 ,2500 ,2500 . 3.44~7 999'25 0 -999,2500 '999,2500 1.9805 -999,2500 -999.~500 'q99,2500 3 .62i3 999,2500 -999.2500 4,0085 -999 2506 '999.{~0 ..990'~5 0 O0 O0 '99:~ 2'500 )627 .-9 ~'i233 '999, 500 '999. 500 '999 ' 2500 CALl RNRA IbM CALl RNRA IbM CALl RNRA ! M ~kbI RNRA RNRA RNRA ~NRA 1RNRA RNRA RNRA RNRA -'999. -999,]500500 2.'3167 -999.2500 -999,2'500 3,5315 -999.2500 -999,~500 . 2,2366 999,2500 -999,2500 3,. 038 '999.~0 =999.2 0 4,0789 -999,2500 -999,2500 I,'7159 -'9~:~.:2'500 -q ,2500 -¸9 3 ' 999 * 2:500 2,6194 99.~500 LVP OIO.MO~ VERIFICATION blSTING PA~E ? v~px 41. oo oooo srcu a ~HOB -999.2500 DRHO -999 ~P~I -999, ?500 NC~b -qgq 3206 .~,500 ~RAT 2500 rCNb OEPT 4000,0000 SFLU 2.7971 7bt) ~P -69. 4102 ~R 103.0273 gR RHOB -999.2500 DR.O -999 ,2500 N~ ,PHI -999.~500 ,C~ -999:.2500 rC,b OEPT 3900.0000 SrLU 2 SP_ -29.2 3 -999,~I095 ~R 110 RHOB 0 DRHO -999 ~PH! -999.2500 ~CNb "qgq .9573 Zbt~ ,2148 GR 2500 NRt~T OBPT 3RO0 0000 SFt, U 2 RHOB -99 ..25 DRHO . NPHI -999.2'500 NCNb -999 .i499 TED 773 OR ,' .500 ~RRT 2500 F'C'Ni, DEPT 3700,0000 SF~U ~ SP ~3..67583 ~R 9t RHOB -999,2500 DRHO -999 NPHI -999o2500 ~CNb -999 ,,9026 ,4648 GR O0 rCNb ,6643 ,0898 , ,2560 ,2500 FCNb DCPT 3400, I~HOB '999, ~PX~! '999. .0000 SFLU 2 . '0 GR.: 9~9 DRHO ~ C N b' ., 99 9 ,,,2500 · ~2500 OEPT 3~00.0000 SP -40,9570 RHOB -9.99,,~5:00 ~PHI -999.2500 srt, u ORHO 8FbU OR DRHO P "46,89 o RHOB ,.,,999,,~:500 ~P~! -~99.'~500 DRHO ~C~b 2,5940 ZED 9~'~' '89.8 ~R , NRRT ""990. 'FCNb 999. 3.2913 -090.~500 -999. 500 -999,2500 2.9045 -999.2500 -999, 0 3,04710 -999,'250 -~99,2500 "999.'2500 "99 5803 2500 .,999. 2 9260 ,2SO0 :'gl,' "999:2'500 -9 ;00 ,,9 CALl ~NRA IbM RNRA IbM CALl RNRA At, I RNRA RNRA CAIJI RNRA IbM R:NRA RNRA RNR:A ]. ] 030 -999'2500 -999.2500 2.9163 -999.25'00 -099.2500 -999.2500 -999.2500 3,0081 99.2500 999 ~ 2500 -099 5,00 - 999, '250 2, ~487 ,.99~' -999 999. 4 4 -999 LVP OlO.H02 VERIFICATION LYS?I~IG PAGE DEPT 3000.0000 SFt, U RHOB -99q,~500 DRHO ~P~l -999.2500 NCnb DEPT 2000.0000 SFt, U SP. -51.23~3 DR RHOB -999,2500 DRHO NpH! -qgq,~500 NCNL SP RHOB -999 ~JP{4I ,,999 0000 SFt,U ]945 DR. 2500 DR.O 2500 SE~V,C~ NAME ~ATE ~ {AXI~UN LENGTH PILE'TYPE I~E ~EXT FYL~ ~ 5.1!40 YLD 97,8 98 DR '~99.2 O0 FCNL 4 t570 ,TLC} 999, .2500 I~RA'~ "-~9~.~500 rCNL 4,72'/3 ILO 79' 4648 GR -999,2500 NRAT -999.2500 FCNb :6827 ILD 5 29~0 ~R -999.2500 ~RAT -999..2500 FCHL .001 1024 EOF NEXT T'{PE NAME { COMMFNTS {LIBRARY TAPE SERVI~R ~AM'E {EDIT DAT~ .85tiii19 ORYGYN: · _ CONTTNUATION # JOi EXT,R~EL NA~E ~ OMM~NTS :t.I~RARY TAPE 4.9812 -999.2500 -999.2500 -999,2500 4.6511 -999.2500 '999.2500 ~99'9~500 5.7546 999.2500 -999,2500 -999.~500 .1992 .2500 -999,2500 RNRA CALl ~NRA IbM CALl RNRA RNRA 4, 250 -999,~500 -~99,2500 4,~187 -q99,2500 -q99,2500 5.4265 -999,2500 -999.~500 ~000.6875 .999,2500 999,2500 [,VP 01o,~{0~ VE~I~ICA?ION [,,~STfNG PA~E 9