The URL can be used to link to this page

Home My WebLink About184-012 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. 7th 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 2AͲ25 50Ͳ103Ͳ20239Ͳ00 196062_2AͲ25_LDL_15Jul2022 196062_2AͲ25_Patch_12Jun2022 2BͲ01 50Ͳ029Ͳ21147Ͳ00 184115_2BͲ01_PPROF_18Feb2023 2BͲ02A 50Ͳ029Ͳ21154Ͳ00 184122_2BͲ02A_LDL_26Jul2023 2BͲ13 50Ͳ029Ͳ21138Ͳ00 184104_2BͲ13_PPROF_02Jun2023 2DͲ07 50Ͳ029Ͳ21169Ͳ00 184143_2DͲ07_IPROF_10Jun2023 2DͲ08 50Ͳ029Ͳ21158Ͳ00 184127_2DͲ08_PPROF_28May2023 2DͲ13 50Ͳ029Ͳ21070Ͳ00 184012_2DͲ13_PPROF_03Jun2023 2DͲ15 50Ͳ029Ͳ21184Ͳ00 184160_2DͲ15_PPROF_04Jun2023 _2EͲ10 50Ͳ029Ͳ21246Ͳ00 184230_2EͲ10_CBL PostͲBiSN_21Aug2023 184230_2EͲ10_CBL PreͲBiSN_28Jul2023 2FͲ13 50Ͳ029Ͳ21032Ͳ00 183156_2FͲ13_WFL_29Jun2023 2HͲ02 50Ͳ103Ͳ20032Ͳ00 184073_2HͲ02_IPROFͲWFL_13Jun2023 6 of 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 T38362 T38363 T38364 T38365 T38366 T38367 T38368 T38369 T38370 T38371 T38733 216-087 2DͲ13 50Ͳ029Ͳ21070Ͳ00 184012_2DͲ13_PPROF_03Jun2023 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:48:05 -08'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other :Report of psi event ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7627 feet N/A feet true vertical 6216 feet N/A feet Effective Depth measured 7426 feet 7146 feet true vertical 6062 feet 5863 feet Perforation depth Measured depth 7249 - 7408 feet True Vertical depth 5936 - 6049 feet Tubing (size, grade, measured and true vertical depth)3.5" J-55 7176' 5884' Packers and SSSV (type, measured and true vertical depth)Packer Backer FHL 7146' MD 5863' TVD SSSV Baker FVL 1875' MD 1875' TVD 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 5/30/2020 Contact Phone: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jan Byrne / Dusty Freeborn n1617@conocophillips.com 659-7224 Well Integrity & Compliance Specialist N/A Authorized Name: Authorized Signature with date: ----- Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure N/A Representative Daily Average Production or Injection Data ----- 4320Production7559'7"7593'6182'4980 2020Surface3262'9.625"3297'3139'3520 Junk measured Burst Collapse Conductor 75'16"110'110' N/A Kuparuk River Unit/Kuparuk River Pool Plugs measured Packer measured true vertical Casing Length Size MD TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: 184-012 50-029-21070-00-00 ADL0025658 KRU 2D-13 P.O. Box 100630, Anchorage, Alaska 99508 t Fra O Ot 6. A G L PG R t Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:23 am, Jun 01, 2020 Digitally signed by Matt Miller DN: C=US, OU=Wells, O=ConocoPhillips, CN=Matt Miller, E=Matthew.Miller@contractor.conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-05-30 15:54:44 Foxit PhantomPDF Version: 9.7.0 Matt Miller DSR-6/1/2020 RBDMS HEW 6/1/2020 VTL 7/27/20 SFD 6/01/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 30, 2020 Commissioner Jesse Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the OA pressure event that exceeded 45% of the burst rating of its casing & the immediate actions taken to remediate it. KRU 2D-13 (PTD 184-012). Please contact Dusty Freeborn/Jan Byrne or me at 659-7224 if you have any questions. Sincerely, Matt Miller Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Matt Miller DN: C=US, OU=Wells, O=ConocoPhillips, CN=Matt Miller, E=Matthew.Miller@contractor.conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-05-30 15:55:17 Foxit PhantomPDF Version: 9.7.0 Matt Miller Date Event Summary Executive Summary 2D-13 : Waivered for IAxOA communication, Operations identified a faulty OA gauge, replaced OA gauge & found OA pressure above 45% of burst, immediately bled OA pressure & monitored for stabilization. 05/22/20 Operations identified faulty gauge, replaced gauge & found OA pressure above 45% of burst pressure, immediately bled OA pressure from 2000 psi to 1250 psi. 05/23/20 Operation bled OA from 1700 psi to 900 psi. 05/29/20 T/I/O = 175/1310/1040 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 35.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.921 Top (ftKB) 35.1 Set Depth (ftKB) 3,297.2 Set Depth (TVD) … 3,139.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 33.9 Set Depth (ftKB) 7,592.8 Set Depth (TVD) … 6,182.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 31.5 Set Depth (ft… 7,175.7 Set Depth (TVD) (… 5,883.8 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.5 31.5 0.02 HANGER FMC III TUBING HANGER 3.500 1,875.4 1,874.9 7.30 SAFETY VLV BAKER FVL SAFETY VALVE - LOCKED OUT 2/16/92 2.810 7,132.6 5,853.6 45.61 PBR BAKER PBR 3.000 7,146.3 5,863.1 45.53 PACKER BAKER FHL ROTATE RETRIEVABLE PACKER 2.937 7,163.3 5,875.1 45.43 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,174.9 5,883.2 45.37 WLEG BAKER BALL CATCHER SHEAR OUT SUB, WIRELINE ENTRY GUIDE. ELMD TTL @ 7170' during SWS PPROF on 08/08/04 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 7,495.0 6,111.3 43.64 FISH 1" SL tool string 10 6/2/1992 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 7,249.0 7,264.0 5,935.5 5,946.1 C-4, UNIT B, 2D-13 12/11/1987 8.0 APERF 60 deg. Phase; 2 1/8" EnerJet II 7,320.0 7,328.0 5,985.9 5,991.6 A-5, 2D-13 12/20/2001 6.0 APERF PowerJet, 60 deg phase 7,354.0 7,408.0 6,010.1 6,048.7 A-4, 2D-13 12/31/1984 4.0 IPERF 120 deg. Phase; 4" Carrier Gun Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 1,930.8 1,929.7 MMH FMHO 1 GAS LIFT GLV BK 0.156 1,243.0 9/19/2013 2 3,693.2 3,436.7 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,291.0 9/19/2013 3 5,513.2 4,720.9 MMH FMHO 1 GAS LIFT GLV BTM 0.188 1,296.0 9/20/2013 4 6,558.0 5,473.0 MMH FMHO 1 GAS LIFT OV BK 0.250 0.0 9/20/2013 5 7,092.2 5,825.4 MMH FMHO 1 GAS LIFT DV BTM 0.000 0.0 9/20/2013 Notes: General & Safety End Date Annotation 7/5/2009 NOTE: IA x OA WAIVERED. OA IS ALLOWED TO EQUALIZE. 10/5/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: LOCKED OUT2D-13, 6/24/2015 4:46:31 PM Vertical schematic (actual) PRODUCTION; 33.9-7,592.8 FISH; 7,495.0 IPERF; 7,354.0-7,408.0 APERF; 7,320.0-7,328.0 APERF; 7,249.0-7,264.0 WLEG; 7,174.8 NIPPLE; 7,163.3 PACKER; 7,146.2 PBR; 7,132.6 GAS LIFT; 7,092.2 GAS LIFT; 6,558.0 GAS LIFT; 5,513.2 GAS LIFT; 3,693.2 SURFACE; 35.1-3,297.2 GAS LIFT; 1,930.8 SAFETY VLV; 1,875.4 CONDUCTOR; 35.0-110.0 HANGER; 31.5 Annotation Last Tag: SLM Depth (ftKB) 7,406.0 End Date 6/22/2015 Annotation Rev Reason: TAG Last Mod By lehallf End Date 6/24/2015 KUP PROD KB-Grd (ft) 39.79 Rig Release Date 12/11/1984 Annotation Last WO: End Date 2D-13 H2S (ppm) 150 Date 10/29/2014 ... TD Act Btm (ftKB) 7,626.0 Well Attributes Wellbore API/UWI 500292107000 Field Name KUPARUK RIVER UNIT Wellbore Status PROD Max Angle & MD Incl (°) 50.77 MD (ftKB) 6,600.00 Lc6 4- r 2 )A% WELL LOG TRANSMITTAL#902851667 DATA LOGGED u/30/2015 K.BENDER To: Alaska Oil and Gas Conservation Comm. November 20, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2D-13 Run Date: 10/22/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic c Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2D-13 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21070-00 Production Profile Log 1 Color Log 50-029-21070-00 0404 ' - w PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Mxixadw...„17) �,�:+�I ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 1St, 2010 Mr. Guy Schwartz Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Guy Schwartz: C~ ~.~,~..~~`~ JA~1 ~ ~ ~Q1J a~~ ~3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. 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 November 10th, 20th and 24th, 2009. The corrosion inhibitor/sealant was pumped December 29th and 30th, 2009. 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 Peny Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Fieid Date 01/01/10 ~ laad 2a. 2c_ 2v 8'<sK Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbts ft al 2A-26 50103205750000 2080940 12" n/a 12" n/a 4.25 12/30/2009 2A-27 50103206040000 2091070 36" n/a 36" n/a 12.75 12/30/2009 2C-14 50029212260000 1842100 18' 2.5 50" 11/20/2009 12.32 12/30/2009 2C-15 50029212190000 1842030 SF n/a 26" n/a 4.67 12/30/2009 2C-16 50029212180000 1842020 SF n/a 33" n/a 7.22 12/30/2009 2D-02 50029211770000 1841520 SF n/a 24" n/a 4.45 12/30/2009 2D-03 50029211780000 1841530 SF n/a 24" n/a 4.67 12/30/2009 2D-04 50029211760000 1841510 SF n/a 24" n/a 4.45 12/30/2009 2D-05 50029211570000 1841260 SF n/a 24" n/a 4.45 12/30/2009 2D-08 2D-13 50029211580000 50029210700000 1841270 1840120 SF 21' n/a 3.0 28" 27" Na 11/10/2009' 4.67 5.1 12!30/2009 12/30/2009 2D-14 50029211830000 1841590 SF n/a 24" n/a 6.37 12/30/2009 2D-16 50029211850000 1841610 28' 4.0 26" 11/10/2009 5.1 12/30/2009 3K-27 50029227510000 1970460 7' 1.0 12" 11/24/2009 2.97 12/29/2009 04/06/09 s ~rt1~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 5151 Company: Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3B-02 AYS4-00050 INJECTION PROFILE ' 03/23!09 1 1 1 L-16 AYS4-00048 INJECTION PROFILE - ( 03/21/09 1 1 1 F-13 AYS4-00046 INJECTION PROFILE J - t/ 03/19/09 1 1 2N-310 8146-00018 INJECTION PROFILE ~}-{~ 03/21/09 1 1 2D-13 B14B-00017 PRODUCTION PROFILE / - 012- l~- 03/20/09 1 1 3B-05 AZCM-00013 INJECTION PROFILE i '~- p'~5 (~ ~ 03/29/09 1 1 2U-01 AYS4-00051 PRODUCTION PROFILE - aj 03/24/09 1 1 iC-131 AYS4-00047 INJECTION PROFILE ~ ~ - ~" 03/20/09 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. 2D-13 PTD # 184-012, notice of SeT X IA Regg, James B (DOA) . Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, October 21,20078:45 PM To: Maunder, Thomas E (OOA); Regg, James B (OOA) Cc: CPF2 Prod Engrs; CPF2 OS Lead Techs NSK Subject: 20-13 PTO # 184-012, notice of SCP, T X IA Attachments: 20-13 90 day TIO.gif; 20-13.pdf K æ~I~> }~J{ q , Tom, ::~,Gt4NNED NOVO 1 2007 .~ .. 20-13 PTO # 184-012, gas lift producer, notice of sustained casing pressure, T X IA 20-13 is shut in and was found with 2150 psi on the IA T/I/O= 1950/2150/1400 Immediate action will be to bleed and troubleshoot the cause of T X IA ,/ The well is internally waivered for IA x OA communication. Attached are the 90 day T/I/O and a schematic. ,~f= if/bops; ./7 JA - J55> ZbJi. (7"t) <17, I tc ¡VWÑI~ 4<3 'tc : '5CP -:=. 2/5Dp5; ðA .--7 ,'v\;V<{f' ~ .7;,',)ZOf'$: /qçzl ) " 'SCp= ¡40ðv.-.., ; :;;. CJî;5 3lo-iJ. L' 8/' ,- I c~o fJt.:>¿lf'~ 3 if? .,?o Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com Lìö 4q4 ctÛâWS opeÎC~ fo Û:~L\(e t{p -fv 4 <,,~ fI:Þý f' «20-1390 day TIO.gif» «20-13.pdf» 1 0/22/2007 21 I' HI HUH! lSIJI) 1200 900 6íHI 31HI o WEEK FLOW PRESSURE SCRATCH_37 OUTER ANNULUS PRES file:ll/qitempffemporary internet FHes!OLK24/2D-13 9{J day TIOgif W/22/2007 PM . . KRU 2D-13 API: 500292107000 Well Tvpe: PROD Anale (éìJ TS: 45 dea (éìJ 7249 SSSV Type: TRDP Orig 12/11/1984 Angle @ TD: 44 deg @ 7626 sssv Completion: (1875-1876. Annular Fluid: Last W/O: Rev Reason: PULL PLUG, GLV OD:3.500) C/O Reference Loa: Ref Loa Date: Last Update: 6/17/2007 Last Taa: 7401 TD: 7626 ftKB Last Taa Date: 12/20/2006 Max Hole Anale: 51 dea (éìJ 6600 Gas lift MandrelNalve DescriDtion Size TOD Bottom TVD Wt Grade Thread 1 CONDUCTOR 16.000 0 110 110 62.50 H-40 (1931-1932. SUR. CASING 9.625 0 3297 3139 36.00 J-55 PROD. CASING 7.000 0 7593 6182 26.00 J-55 ;: <'::'~~r--'~-""~'WY~;III-' ~~: Size I TOD Bottom TVD Wt Grade I Thread Gas Lift I 3.500 I 0 I 7176 I 5884 . 9.30 I J-55 I EUE 8RD I MandrelNalve 2 "_.,' (3693-3694. Interval TVD Zone Status Ft Date TVDe 7249 - 7264 5936 - 5946 C-4,UNIT 15 8 12/11/1987 APERF 60 deg. Phase; 2 1/8" B Ener Jet" 7320 - 7328 5986 - 5992 A-5 8 6 12/20/2001 APERF Power Jet, 60 dea phase Gas Lift 7354 - 7408 6010 - 6049 A-4 54 4 12/31/1984 IPERF 120 deg. Phase; 4" Carrier MandrelNalve Gun 3 (5513-5514, 'Ifill'· St MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Cmnt 1 1931 1930 MMH 3 1/2 X 1 GLV 1.0 BK 0.156 1249 12/21/200 Gas Lift 2 3693 3436 MMH 31/2 X 1 GLV 1.0 BK 0.188 1298 12/21/200E MandrelNalve 3 5513 4721 MMH 3 1/2 X 1 GLV 1.0 BTM 0.188 1307 6/11/2007 4 _73 MMH 3 1/2 X 1 GLV 1.0 BK 0.188 1323 12/21/200E (6558-6559. 5 5825 MMH 3 1/2 X 1 OV 1.0 BTM .. 0 12/21/200E Depth Type Description ID Gas Lift 1875 1874 SSSV Baker 'FVL' (Pull AVA Maxibore WR-SSSV 5/24/96) 2.810 MandrelNalve 7133 5854 PBR Baker 3.000 5 7146 5863 PKR Baker 'FHL' Retr 3.000 (7092-7093. 7163 5875 NIP Cameo '0' Nipple NO GO 2.750 7175 5883 SOS Baker 2.992 7176 5884 TTL 2.992 PBR (7133-7134, Depth I DescriDtion I OD:3.500) 7495 11" SL tool string 10 1 PKR (7146-7147, 00:6.151) NIP (7163-7164. OD3.500) TUBING (0-7176. OD:3.500, ID2.992) 50S (7175-7176. OD:3.500) Perf ..'" ... I······... (7249-7264) ....' ......- ~ ,-- .......... I...... ~- ~ ._~ ~- Perf -.._'- ----- (7354-7408) -----. --- ... .- ------ ......... I ........ "1- 1"SL tool i strin910 (7495-7506. OD:1.000) 06/08/07 Schlumbergel' NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ], 120m Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Gfjn~.cnmß~~NED JUN 142007 ~v Field: Kuparuk /~tI-O/d- Well Job # Color CD Date BL Log Description .. .." ,-............ ..~, 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 NIA MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT 05/25/07 1 2V-08A 11629013 PM IT 05/15/07 1 1 J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1H-07 11665436 SBHP SURVEY OS/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1 Y -11 11632708 INJECTION PROFILE OS/23/07 1 1 G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1 F-08 11665435 SBHP SURVEY OS/20/07 1 1J-170 11632709 INJECTION PROFILE 05/24/07 1 10-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ~ /'--, . ~ 1f ~ 1f Œ (ill ~'A:~O~ ~: / CONSERVATION COMMISSION í FRANK H. MURKOWSKI, GOVERNOR May 12, 2004 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage,AJ( 99510-0360 ff54 - 0 L'd-- Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at Kuparuk River Unit 2D (KRU 2D) pad on May 6, 2004. Attached is a copy of the Inspection 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 ofthe SVS. An SVS component failure rate of 12.5 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 threshold. Effective May 6, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2D 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. iel T. Seamount, Jr. Commissioner Attachment cc: AOGCC Inspectors (via email) Safety Valve & Well Pressures Test Report - Review Reviewed By: P.I. Suprv Comm Pad: KRU_20 Inspection Dt 5/6/2004 Inspected by Chuck Scheve Interval: InspectNo: svsCS040507072635 Src: Inspector Field Name KUPARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Reason 90-Day Well Number Permit Number Separ PSI Set PSI UP Trip Test Test Test Code Code Code Date SI Oil,WAG,GINI, GAS,CYCLE, SI Inner PSI Outer PSI Tubing PSI YeslNo YeslNo f-- 20.13 1840120 98 70 60 P P I-OIL 20-12 1840940 98 70 65 P P I-OIL I 20-09 1841030 98 70 65 P P I-OIL 20-08 1841270 98 70 65 P P I-OIL 20-068 1981760 98 70 65 P P I-OIL 20-03 1841530 98 70 65 P P I-OIL 20-15 1841600 98 70 50 P 4 I-OIL 1000 1000 150 Yes Yes IA x OA communication ~ L 20-01 1841710 98 70 0 10 P I-OIL ) Comments Performance Pilot on well 20-01 failed to trip on initial test, was replaced and passed retest. Surface Safety Valve on Well 20-15 had very slow leak when pressure tested. Valve to be repaired and retested by operator. Wells 8 Components 16 Failures 2 Failure Rate 12.5% ) Wednesday, May 12, 2004 . PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 January 29, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2D-13 (184-012) Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforations on the KRU well 2D-13. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 127 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK-99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 691' FNL, 142' FEL, Sec. 26, T11 N, R9E , UM (asp's 529625, 5953508) 2D-13 At top of productive interval 9. Permit number / approval number 1339' FSL, 1202' FEL, Sec. 26, T11N, R9E, UM 184-012/ At effective depth 10. APl number 50-029-21070 At total depth 11. Field / Pool 4184' FNL, 1301' FEL, Sec. 26, T11 N, R9E, UM (asp's 528482, 5950011) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7626 feet Plugs (measured) true vertical 6206 feet Effective depth: measured 7372 feet Junk (measured) true vertical 6023 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 187 sxCS, 110' 110' SUR. CASING 3170' 9-5/8" 800 sx AS III, 450 sx Class G 3297' 3139' PROD. CASING 7466' 7" 450 sx C~ass G, 250 sx AS ~ 7593' 6182' . _ -, ,-i~~ .~- if~ ~ ;' ~ :. , ~ ~: ;;. ~i~'~- i.1 ~ Perforation depth: measured 7249' - 7264', 7354' - 7408', 7320' - 7338' true vertical 59351 - 594411 60081 ' 60471! 59861 ' 59991 i-'4;,.;::' t: i"'~ Tubing (size, grade, and measured depth) 3-1/2", 9.31¢, J-55 Tbg @ 7176' MD. Packers & SSSV (type & measured depth) BAKER 'FHL' RETR @ 7146' MD. BAKER 'FVL' (PULL AVA MAXlBORE WR-$SSV 5124196) @ 1875' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 372 1215 1703 165 Subsequent to operation 469 1559 1804 164 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil __ X Gas__ Suspended __ Service_ 17. I hereby certify that the fore oing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263.4574 Michael Moone~/ Prepared by Sharon Al~sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2D-13 Event History 12/06/01 12/20/01 INHIBITION SQUEEZE: PUMP 16 BBLS SW W/50 GALS WAW-5206 PRE FLUSH @1 BPM @1350 PSI. PUMP 91 BBLS SW W/500 GALS SCW-4004 TRETMENT @ I BPM @1150 PSI. [SCALE INHIBITOR] PERFORATED 7320-38 (A5 SAND) W/6 SPF 60 DEG PHASED GUNS Page I of I 1/21/2002 'MEMORANDUM TO: THRU: Julie Heusser, Commissioner Tom Maunder, p. I. Supervisor FROM: Chuck Scheve; Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: SUBJECT: January 28, 2001 Safety Valve Tests Kuparuk River Unit 2D & 2E Pads Sunday, January 28, 2001: I traveled to the Kuparuk River Field and witneSsed the semi annual safety valve sYstem testing on 2D & 2E Pads. As the attached AOGCC Safety Valve SyStem TeSt Report indicates I witnessed the testing of 9 wells and 18 Components with one failure on 2D Pad and 5 wells and 10 components With one failure On 2E Pad. The Surface Safety Valve on Well 2E-16 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. The Surface Safety Valve on well 2D-05, a WAG injector, could not be tested due to a leaking wing valve. This valve will be tested as soon as the wing valve is repaired. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a Pleasure t°. work with All the wellhouses entered at these locations were clean and all related equipment appeared t© be in good conditiOn. Summary: I Witnessed the semi annual SVS testing at 2D & 2E Pads in the Kuparuk River Field. KRU 2D Pad, 9 wells, 18 comPonents' KRU 2E Pad, 5 wells, 10 cOmponents, 24 wellhouse inspections 1 failure 5,56% failure rate 1 failure 10% failure rate AttaChment: SVS KRU 2D & 2E Pads 1-28-01 CS X UnclasSified Confidential (Unclassified if doc. Removed) SVS KRU 2D & 2E Pads 1-28-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Prillips Operator Rep: Eamie Bamdt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk /KRU / 2D Pad Separator psi: LPS 99 HPS 1/28/01 ,, , Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI:il PSI Trip Code Code Code Passed GAS or CYCLE 2D-01 1841710 99 70 65 P P OIL 2D-02 1841520 2D-03_ 1841530 2D-05 1841260 3750 2000 1750 P 7 wAG 2D-06B 1981760 99 70 55 p p oIL 2D-07 1841430 3750 2000 ,1'850 . P P " WAG 2D-08 1841270~ 99 70 60 p P OIL 2D-09 1841030: 991 70 55 P P OIL 2D-10 1841010 2D-11 1'840990 2D-12 1840940 99 70 60 p p OIL 2D-13 - 1840120 99 70 60 p p oIL 2D-14 1841590 2D-15 1841600 99 70 60 'P P OIL i2D-16 1841610 Wells: 9 Components: 18 Failures: 1 Failure Rate: 5.56% [] 00 var Remarks: Surface safety on 2D-05 not tested due a slow leaking wing valve Grove valve could be closed due to snow drifts. RJF 1/16/01 Page 1 ofl SVS KRU 2D Pad 1-28-01 CS.xls Alaska Oil and Gas Conservation Commission Safety Valve SYstem Test Report Operator: Phalips Operator Rep: Eamie Brandt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 2E Pad Separator psi: LPS 99 HPS 1/28/01 Well Permit Separ Set L/P Test Test Test Date on, WAG, Gm J, Numbe, r Num,her psi PSI Trip Code Code Code Passed GAS or CYCLE ' 2E-07 193104C , , , 2E-08 1931890 99. 70 60 P 'P 2E-09 1842400 ' , 2E- 10 1842300 99 '70 60 P P , 2E-11 , 1842260 99 70 50! - P · ,P , ,, 2E-15 1841890 99 70 50 · P P , , , 2E-16 1841900 99 -. 70 50 P 4 t -. , , , Wells: 5 Remarks: 10 Failures: 1 Failure Rate: 10.00°13 9o my Components: , , . Surface safety on 2E-16 had Slow leak when pressure tested. Valve will be serviced a retested by operator~ RJF 1/16/01 Page 1 of 1 SVS KRU 2E Pad 1-28-01 CS.xls 1. Type of Request: '-'" STATE OF ALASKA '-'-" _ AL/-,,~KA OIL AND GAS CONSERVATION COMM,._.,ION -~ REPORT OF SUNDRY WELL OPERATIONS Stimulate X Plugging Perforate _ Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Ins. 3. Address Operation Shutdown Pull tubing Alter casing 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 692' FNL, 144' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1339' FSL, 1202' FEL, Sec. 26, T11N, R9E, UM At effective depth 1168' FSL, 1271' FEL, Sec. 26, T11N, R9E, UM At total depth 1095' FSL, 1301' FEL, Sec. 26, T11N, R9E, UM Present well condition summary Total Depth: measured true vertical 7 62 6' feet Plugs (measured) 6205' feet 6. Datum elevation (DF or KB) 6200'SS 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-13 Producer 19. Permit nTer ._v¢ 84-12 ~3pro ~mb...~ 10. APl number 5o-02~)-21 070 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 751 0' feet Junk (measured) true vertical 6121 ' feet Casing Length Size Cemented Structural Conductor 1 1 0' 1 6" 187 Sx CS II Surface Intermediate 3297' 9 5/8" 1250 SX Production Liner 7593' 7" 700 Sx Perforation depth: measured 7249'-7264', 7354'-7408' true vertical 5935'-5944', 6008'-6047' 12. Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55 7176' Packers and SSSV (type and measured depth) Baker FHL @ 7146', Baker FVL 1875' 13. Stimulation or cement squeeze summary Measured depth True vertical depth 110' 110' 3297' 3138' 7593' 6180' Final pressure was 3200 psi. 14. Intervals treated (measured) 7249'-7264', 7354'-7408' Treatment description including volumes used and final pressure Gelled water frac w/ 102,000# fo 16/20 Carbo-Lite. Tubing Pressure Prior to well operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Subsequent to operation 1300 650 0- 900 130 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 3000 1500 O- 900 140 Service 16. Status of well classification as: Water Injector__ Oil X Gas Suspended SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 ~ 05/17/89 ARCO Alaska, Inc~ Su~'~idlary of Atlantic Richfield Company WELL' _~D"/~ cONTRACTOR H~ !/, ~.. ~ ~'~ ~ .MARKS IPBDT IFIELD- DISTRICT- STATE I DAYS OPERATION AT REPORT TIME WELL SERVICE REPORT IDATE Iq3o - p w ~$$~ w ~_ ~ sTc.f 7'0 1-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK 1. Type of Request: . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AKL 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 692' FNL, 144' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1339' FSL, 1202' FEL, Sec. 26, T11N, R9E, UM At effective depth 1168' FSL, 1271' FEL, Sec. 26, T11N, R9E, UM At total depth 1095' FSL, 1301' FEL, Sec. 26, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7626' feet 6205' feet Plugs (measured) Other 6. Datum elevation (DF or KB) 620O' SS 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-13 Producer 9. Permit number/approval number 84-12 feet Effective depth: measured 7510' feet Junk (measured) true vertical 6121 ' feet Casing Length Size Cemented Structural Conductor I 1 0' I 6" 187 Sx CS II Surface Intermediate 3297' 9 5/8" 1250 Sx Production Liner 7593' 7" 700 Sx Perforation depth: measured 7249'-7264', 7354'-7408' true vertical 5935'-5944', 6008'-6047' Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55, 7176' Packers and SSSV (type and measured depth) Baker FHL 7146', Baker FVL 1875' 13. Attachments Description summary of proposal Fracture A & C Sand with gelled water sand frac. Measured depth 10. APl number 50-029-2107000 11. Field/Pool Kuparuk River Oil Pool True vertical depth 110' 110' 3297' 3138 7593' 61 80' 14. Estimated date for commencing operation 6/5/89 16. If proposal was verbally approved Name of approver Date approved r~ Cons _ Detailed operat~gram~0~8~0BOP sketch Status of well classification as: Oil m Gas __ Suspended Service P r o d u c e r 15. Date 17. I hereby certify that the foregoing is true and correct to [~he best of my knowledge. ' F~ ~MI~USE ~LY Conditions of approv~.h Notify Commission so representative may witness Plug integrity m BOP Test_ Mechanical Integrity Test_ Location clearance Subsequent form ORIGIN""I,,-'m'":~':D, :_. BY LONNIE C, SMITH Approved by the order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SUNDRY NOTICE - WELL 2D-13 Pump a combined A and C Sand gelled water fracture treatment utilizing 1300 bbls of gelled water and 100,000 lbs proppant. NO BOP'S WILL BE UTILIZED DURING THIS PROCEDURE. The treatment will be pumped through a surface manifold. A and C SAND PRESSURE (6200' SS) = 2033 psi 1/27/88 WHP/FL NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. 1. 5000 PS1 ?" W[LLHr. AD CONN[C~OR FLANG[. 2. 5000 PS1 WIR[LINr. 3. ~000 PSI 4 1/6" LUBRI~OR 4. 5000 PSI 4 1/6" FL~ TUBE PACK-Orr 2 .H! REI..__] NE BOP _EOU I. PHENT Messrs. Lyden and Wade May 5, 1989 Page 3 Kuparuk Well 2D-13 Refracture Procedure 5/5/89 CC: K80101 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) MIRU Slickline. RIH w/tubing end locater and tag fill. Pull GLV's @ 1931', 3693', 5513', 6558' and 7092' and run DV's. RIH w/Standing Valve and set in "D" nipple. Pressure test tubing to 4500 psi to ensure DV's are set. RIH and pull SV. RDMO Slickline. 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. If a CTU cleanout is pedormed, at least 150 feet of ratho~ desirable. MIRU fracturing equipment with ball sealer dropping capability. Install largest ID "tree saver" available. Carry out all quality control procedures(Onsite Operations Engineering). The specific procedures will depend on the vendor selected. Check Carbo-Ute for fines due to excessive handling. Obtain a sample of the Carbo-Ute and the gelled water with breaker and from the pad and slurry stages. Record the proppant weight before and after'the treatment. Pump fracture treatment per the attached schedule. Expected wellhead treating pressure: Tubing Friction= 270 psF1000 ff (7176' MD)~ 20 BPM Tubing Friction= 350 ps~1000 ff (7176' MD)e 25 BP~~~ Recommended Max Treating Pre~ure= 6,500 psi NOTE: If treating pressure during pad exceeds 5500 psi, shut down job and confer with Operations Engineering. 1 1 ) SI well and rig down frac equipment. 1 2 ) Begin flowback after the gelled water samples break in a water bath and the logging is complete. Initial flowback rate for the first day should be 200 BPD(5 to 10 BPH). Record tank straps (rates), choke settings, and WHP's during flowback period. Inspect samples for Carbo-Lite. If CL is produced, reduce rate and contact Operations Engineering. 'Messrs. Lyden and Wade May 5, '1989 Page 4 1 3 ) Take BS & W samples after every choke change and every 8 hours. Bring well back on production per attached flowback schedule after first day (Drop the wellhead pressure 50 psi per 12 hours). I 4 ) Once well has completed flowback, obtain a 24 hour well test. Contact Operations Engineering for a new gas lift design when necessary. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate X Plugging Perforate_ Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. ©. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service !4. Location of well at surface 692' FNL, 144' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1339' FSL, 1202' FEL, Sec. 26, T11N, R9E, UM At effective depth 1168' FSL, 1271' FEL, Sec. 26, T11N, R9E, UM At total depth 1095' FSL, 1301' FEL, Sec. 26, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7626' feet 6205' feet Plugs (measured) 6. Datum elevation (DF or KB) 6200' SS 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-1 :~ Pr~)cll~cer 9. Permit number/approval number 8-403 10. APl number 50-0292107000 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 751 0' true vertical 6121 ' feet Junk (measured) feet Casing Length Size Structural Conductor 1 1 0' 16" Surface 3297' 9 5/8" Intermediate Production 7593' 7" Liner Perforation depth: measured Cemented Measured depth True vertical depth 187 Sx CS II 110' 110' 1250 Sx 3297' 31 38' 700 Sx 7593' 61 80' 7249'-7246', 7354'-7408' MD true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 5935'-5944', 6008'-6047' TV 3 1/2", 9.3 Ib/ft, J-55, 7176' Baker FHL 7146', Baker FVL 1875'~. I 7249 7264' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure C Sand non-acid solvent breakdown, 50 bbls N-VER-SPERSE, 5 bbls xylene, 5 bbls musol, 5 bbls acetic acid, 2000 psi. 14. Representative Dally Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1305 676 0 1100 123 Subsequent to operation 1535 894 0 1100 125 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned ,Z~ ¢~.,,~ .,~ ~ ~¢-~-~.~¢.~,~/' Title ~. Subsidiary of Atlantic Richfield Company ~VVELL BDT I FIELD - DISTRICT- STATE [OPERATION AT REPORT TI M E CONTRACTOR rt.-MARKS DAYS .... Oq30 //:gO PT +o PooH, IZ.'.O0 !~-:~o 17on JT~o Weather Repod ~'r ~ ~q zoo.°? CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Temp. Chill Factor I Visibility I Wind Vel, OF OFI miles I sig~ knots STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: 2. Name of Operator ARCO Alaska. Inc. Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Pull tubing Other 3. Address P. O. Box 100360, Anchorage, AKL 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 692' FNL, 144' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1339' FSL, 1202' FEL, Sec. 26, T11N, R9E, UM At effective depth 1168' FSL, 1271' FEL, Sec. 26, T11N, R9E, UM At total depth 1095' FSL, 1301' FEL, Sec. 26, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7626' feet 6205' feet Plugs (measured) 6. Datum elevation (DF or KB) 6200' SS 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-13 Producer 9. Permit number/approval number 10. APl number 50-029-2107000 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7510' feet Junk (measured) true vertical 6 121 ' feet Casing Length Size Cemented Structural Conductor I 1 0' 1 6" 187 Sx CS II Surface Intermediate 329 7' 9 5/8" 1250 Sx Production Liner 7593' 7" 700 Sx Perforation depth: measured 7249'-7264', 7354'-7408' true vertical 5935'-5944', 6008'-6047' Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55, 7176' Packers and SSSV (type and measured depth) Baker FHL 7146', Baker FVL 1875' Measured depth 110' 3297' 7593' MD TVD True vertical depth 110' 3138 6180' 13. Stimulation or cement squeeze summary 14. ., Stimulate C Sand with non-acid solvent. ' Intervals treated (measured) 7249'-7264' Treatment description including volumes used and final pressure NARS 200 (50 bbls), Xylene (5 bbls), acetic acid (5 bbls), musol (5 bbls), 3800 psi Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1305 676 0 1000 125 Subsequent to operation 1530 888 0 800 125 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations m 16. Status of well classification as: Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Re~ (~6~15/88 ~" / Service SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Compar~'''' WELL iPBDT I FIELD. DISTRICT- STATE P-,B-!.5 I 7~/c) K'~_~u~ IOPERATION AT REPORT TIME CONTRACTOR n,-MARKS W~ELL SERVICE REPORT IDAYS .. _ oqgo I~:0o Ii:~0 I?..:00 Jrr~ r;L~ oo'r (7. ~ Pu~P!o~ PTo~ iq.:~o HAL_l gU RT04/ ,~.','~,~, -'D~v. OF'I:' /_ocA'r'~o.,~' ~. RDr~ O. cO_ ¢, sq zow.~ [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. Date: August 12, 1988 Transmittal if: 7257 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O: Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 I- 1 2 Kuparuk Well Pressure Report 6 - 1 5 - 8 8 Amerada 1 G-04 Kuparuk Well Pressure Report 7- 1 6 - 8 8 Amerada 2T-06 Post Frac Job Report 7-1 8-88 Alio Frac A-10 3Q-15 Kuparuk Stimulation Summary 8-07-88 #230DS36QL 3J-10 kuparuk Stimulaiton Summary 8-08-88 #230DS36JL 2V-11 Kuparuk Stimulation Summary 8-03-88 #230DS28VL 1 R- 1 5 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Tubing 1 F- 0 7 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing 2 D- 1 3 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil STATE OF ALASKA .... ALAS,., OIL AND GAS CONSERVATION COMk..SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ".; Operation Shutdown i ] Re-enter suspended well FI Alter casing El, Time extension' Change approved program L: Plugging _F-j Stimulate~ Pull tubing'' Amend order F-i Perforate [' Other [] 2. Name of Operator ARCO A!aska~ 3. Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 692' FNL, 144' FEL, Sec. 26, TllN, R9E, UH 5. Datum elevation (DF or KB) 6200' SS feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2D-13 Producer At top of productive interval 1339' FSL, 1202' FEL, Sec. 26, At effective depth 1168' FSL, 1271' FEL, Sec. 26, At total depth 1095' FSI , 130'1' FEL, Sec. 26. 11. Present well condition summary Total depth: measured true vertical TllN, R9E, UM TIIN, R9E, UM T11N. R9E. UM 7626' feet 6205' feet 8. Permit number 84-12 9. APl number 50- 0292107000 10. · P°°lKuparuk River Oil Pool Plugs (measured) Effective depth: measured 7510' feet Junk (measured) true vertical 6121 ' feet Casing Length Size Cemented Structural Conductor 110' 16" 187 Sx CS II Surface 3297' 9-5/8" 1250 Sx Intermediate Production 7593' 7" 700 Sx Liner Perforation depth: measured Measured depth 110' 3297' 7593' 7249'-7264' 7354'-7408' MD True Vertical depth 110' 3138' 6180' true vertical 5935'-5944' 6008'-6047' TVD Tubing (size, grade and measured depth) 3 1/2", 9.3 lb/ft, J-55, 7176' Packers and SSSV (type and measured depth) R~L,,-,,,, ~1-11 71/!~;' R~I,',',~ FVI 1R7E' 12.Attachments Description summary of pro~o~l I~-' -Deiailed operations program gf. imlilaf. P fl. %and wi~_h a nnn-acid _~olvent. 13. Estimated date for commencing operation 5/2O/88 14. If proposal was verbally approved ,~u,~¢~(~[~ ~ ~ /...J'-~ Name of approver ell~itl311~l ~--~]~:~11tI!1~"~2'=~ Date approved BOP sketch 15. I hereby certify that the foregoing is true and correct to the best of my knowledge 2 . Signed .~ ,~/o.i~..,,,~.~ ~ Title O,FfC~..~-~-,~t Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test ~. Location clearanceI ~ -"'~ ~---")~-~ Approved by ORIGINAL SIGNED BY LONNIE 6. SMITH Form 10-403 Rev 12-1-85 &poroved Copy Returned Commissioner [..---., by order of the commission Date Submit in triplicate Messrs. Lyden and Wade April 28, 1988 '~' Page 2 Kuparuk Well 2D-13 C Sand NARS Stimulation 4/28/88 CC: 230DS28DL Procedure: 1) MIRU Slickline, set up surface flowback tank. 2) RIH to pull GLV's and set DV's @ 1931', 3693', 5513', 6558' and 7092'. 3) RIH with standing valve and set in "D" nipple. 4) 5) 6) Pressure test tubing to 4000 psi to ensure DV's are set. RDMO Slickline. MIRU Pump Truck and Coiled Tubing Unit (CTU). Displace well with diesel at slow pump rates (1/2 BPM). 7) RIH with CTU circulating hot diesel at minimum rates. 8) Tag fill at approximately 7389' RKB. Pull up the CTU between 5 and 10 feet and begin to pump Temblok pill. Pump a total of 4 bbls of Temblok at slow pump rates (1/4 to 1/2 BPM). Displace with diesel to end of CTU. Shut down pumping and pull up CTU to 7280' RKB. Slowly begin pumping again to ensure Temblok is completely out of CTU. Maintain approximately 500 psi on the surface to ensure the Temblok remains in place. Pull up CTU to 7100' RKB and shut down. ~-~o / NOTE' Temblok (Halliburton trade name) pill should ~J mixed with between 100 and 125 lbs/lO00 gals. polymer with brine. The Temblok should also contain enough breaker for a 12 hour break. Ensure sufficient chemicals are on hand for extra Temblok if needed. 9) After approximately 3 hours (Temblok set time) begin circulating with CTU to 7280' RKB to ensure C Sand perfs are uncovered. Pull up CTU to 7240' RKB and begin pumping a mixture of 50 bbls NARS- 200, 5 bbls xylene, 5 bbls Varsol-3139 (ARCO Stock No. 2175584), 5 bbls acetic acid and 10 lbs/lO00 gal. iron sequestering agent (L-58). Displace to treating fluid with hot diesel at formation breakdown rates. NOTE: NARS-200 and L-58 are Dowell trade names. 10) Open well to surface flowback tank and begin circulating 3-4% HCL mixed with jiesel at 1/2 BPM. Slowly move CTU to 7389' RKB (10 FPM). Pull CTU back[Op to 7280' RKB (10 FPM) while continuing to slowly circulate 3-4% NOTE: Ensure HCL strength is less than 4% and is inhibited to prevent A Sand formation damage. Messrs. Lyden and Wade April 28, 1988 ~ Page 3 11) POH with the CTU and shut in the well for 6 hours to soak and allow the Temblok to break. 12) RDMO CTU and Pump Truck. 13) Open well to surface flowback tanks. Flow back treating fluid and broken Temblok. Once the BS&W content falls below 2%, the well can be turned into the plant. 14) Obtain a 24 hour well test for designing a new gas-lift string. SUNDRY NOTICE - WELL 2D-13 C SAND STIMULATION TREATMENT NO BOP'S ARE USED DURING THE TREATMENT, THE FLUID WILL BE PUMPED THROUGHT A COILED TUBING UNIT ON SURFACE, A SAND PRESSURE (6200' SS) = 2600 PSI 5/6/86 PBU NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. .... STATE OF ALASKA --' ALASK, ,.)IL AND GAS CONSERVATION COMM. .~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 P.O. Box 100360~ Anchora§e~ Alaska 99510 4. Location of well at surface 692' FNL, 144' FEL, Sec. 26, T11N, R9E, UN At top of productive interval 1339' FSL, 1202' FEL, Sec. 26, T11N, At effective depth 1180' FSL, 1265' FEL, Sec. 26, T11N, At total depth 1095' FSL, 1301' FEL, Sec. 26, T11N~ 11. Present well condition summary 7626' Total depth: measured true vertical 6205' R9E, UM R9E, UM R9E ~ UM feet Plugs (measured) feet 5. Datum elevation (DF or KB) 6200' SS Feet 6. Unit or Property name Kuparuk River' Unit 7. Well number 2D-13 8. Approval number 7-977 9. APl number 0~ 50-- 029_2107~,,_00 10. Pool ~. Kuparuk RiVer Oil Pool Effective depth: measured 7510' feet true vertical 6120' feet Junk(measured) Casing Length Size Structural Conductor 110 ' 16" Surface 3297' 9-5/8" Intermediate Production 7593 ' 7" Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Cemented Measured depth True Vertical depth 187 Sx 110' 110' 1250 Sx A.S. III 3297' 3139' 700 Sx Class "G" 7354'-7408' MD 7593' 6008' -6047' TVD 3-1/2" 9 3 lb/ft J-55 7176' 6181' RECEIVED AlaSka Oil & Gas Cons. 6omm. .F,r A,qc, ........ Packers and SSSV (type and measured depth) SSSV' Baker FHL 7146' Packer: Baker FVL 1875' 12. Stimulation or cement squeeze summary Intervals treated(measured) Perforate C Sand (7249'-7265' MD, 8 SPF) through tubing· Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 978 541 0 1200 120 1154 675 0 1200 120 14. Attachments Daily Report of Well Operations 'l~ Copies of Logs and Surveys Run [] I hereby certify that the foregoing is true and correct to the best of my knowledge ~ /c~-~--/'- °c~/~ 15. Form 10-40'4 Rev. 12¢5 Date -5/:'...2 t: Submit in Duplicate . ARCO Alaska, Inc:~ Subsidiary of Atlantic Richfield Company WELL .2,/)-/3 NTRACTOR REMARKS '--" WELL SERVICE REPORT IPBDT IF,ELD-DISTRICT-STATE J k,.,p ~,~,., k.' IOPERATION'AT FLEPORT TIME DATE - I i~ ~o ' ¢~ P, ~ / Cc/__ 5"/'~,'~ Cu~ ~,T~o~ ~ . r I I / - J--J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK JSigned . 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] " '~" STATE OF ALASKA .. ~ ALASK.. OIL AND GAS CONSERVATION COMb,. ~31ON APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator AREO Alaska. Tnt. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 692' FNL, 144' FEL, Sec. 26, T11N, RgE, UM TllN, R9E, UM T11N, R9E, UM T11N, R9E, UM 7626' feet 6205' feet Plugs (measured) 5. Datum elevation (DF or KB) 620fl' SS 6. Unit or Property name Kuparuk River Unit 7. Well number 2D-13 feet 8. Permit number 84-12 9. APl number 50-- 02c~21 f) 7 f'l f) r) fl 10. Pool Kuparuk River Oil Pool At top of productive interval 1339' FSL, 1202' FEL, Sec. 26, At effective depth 1180' FSL, 1265' FEL, Sec. 26, At total depth 1095' FSL, 1301' FEL, Sec. 26, 11. Present well condition summary Total depth: measured true vertical Effective depth: measured 7510' feet Junk (measured) true vertical 6120' feet Casing Length Structural Conductor 110 ' Surface 3297' Intermediate Production 7593' Liner Perforation depth: measured Size Cemented Measured depth True Vertical depth 16" 9-5/8" 7" 187 Sx 110' 110' 1250 Sx A.S. III 3297' 3139' 700 Sx Class "G" 7354'-7408' MD 7593' 6181' 6008'-6047' TVD true vertical Tubing (size, grade and measured depth) 3 1/2", 9.3 lb/ft, d-55, 7176' Packers and SSSV (type and measured depth) ',7.fLS'' ''''J¢'' ~. %?.$ C3t-'~$!\~:~.,~,~,~r.,,,,~,,_ Baker FHI. fa 7146'. Raker FVI 0 lg7.~' 12.Attachments Description summary of proposal I~ Detailed operations program [] BOP sketch Perforate C Sand (7249' to 7264' MD, 8 SPF) through tubing. 13. Estimated date for commencing operation 12/12/87 14. If proposal was verbally approved Name of approver I onnie Smith Date approved 1_2/7/87 15. I hereby certify that the foregoing is true, and correct to the best of my knowledge Signed /"'-,~F O.,¢_,,~a /~' /~~"~'*~ Title ¢~/t [2/~~-,'1 ¢r.41~._c.z,'x.-, OZ"/~. Date Commission Use O~nly Notify commission so representative may witness I Approval No. -~.~/'~ / [] Plug integrity ~ BOP Tcs. J;. [] Location clearanc,~l~, Approved L;opy F:mam,..q,m~ ~ ~ - Returne~ Conditions of approval Approved by ORIGINAL SIGNED BY Commissioner Form 10-403 Rev 121~1~1E C. SMITH by order of the commission Date Submit in triplicate '~'~'~ STATE OF ALASKA ALASKA OiL AND GAS CONSI=RVATION ~,C~qMISSION WI=LL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well ,/~(~;/~_ 1. Status of Well REV I SED OIL j~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-12 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21070 ~ 4. Location of well at surface 9. Unit or Lease Name 692' FNL, 144' FEL, Sec.26, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1339' FSL, 1202' FEL, Sec.26, TllN, R9E, UM 2D-13 At Total Depth 11. Field and Pool 1095' FSL, 1301' FEL, Sec.26, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 126.6' ADL 25658 ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 1 2/02/84 1 2/09/84 01/01/85I N/A feet MSLI 1 17. TotalDepth(MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7626'MD, 6205'TVD 7510'MD, 6121 'TVD YES ~] NO [] 1875' feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/Cal/FDC/CNL, CBL, Gyro (GCT), Temp/CCL 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 110' 24" 187 sx CS II 9-5/8" 36.0# J-55 Surf 3297' 12-1/4" 800 sx AS Ill & 450 sx Class G 7" 26.0# J-55 Surf 7593' 8-1/2" 450 sx Class G & 250 s AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2'' 7176' 7146;' 7408 ' -7388 ' 7388'-7368' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7368'-7354' w/4 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Addendum dated 7/26/85. 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 iTEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c'o~;r) 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. N~s~ 0it & Gas ~0~s. C0mm~sst0~ Form 10-407 Rev. 7-1-80 WC3/65: DAN I CONTINUED ON REVERSE SIDE Submit in duplicate y 7 - 30. 29. .( :--,: . GEOLOGIC MARKERS 'FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7248' 5934' N/A Base Upper Sand 7263' 5944' Top Lower Sand 7299' 5970' Base Lower Sand 7471' 6093' · / . : 31. LIST OF ATTACHMENTS Addendum (dated 7/26/85) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~//~~ ~,,~_~_, Title Associate Engineer Date ~'1"~7 Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10407 ADDENDUM WELL: 12/18/84 4/08~85 7/01/85 2D-13 7510' PBTD, SI Rn CBL f/7504'TD to 5425'. Rn gyro f/TD to surf. Frac well in 7 stages w/316 bbls gelled diesel, 750# 100 mesh & 13,800# 20/40 mesh. RIH w/CCL tl, tag fill @ 7357' (153' of fill w/ll' of "A" sand perfs covered.) RU WL, RIH w/2-1/2" swage, tag fill @ 7418'. Drilling ~uperintendent Date STATE OF ALASKA ALASKA(. _AND GAS CONSERVATION CO AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-12 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21070 4. Location of well at surface 9. Unit or Lease Name 692' FNL, 144' FEL, Sec.26, T11N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1339' FSL, 1202' FEL, Sec.26, TllN, R9E, UM 2D-13 At Total Depth 11. Field and Pool 1095' FSL, 1301' FEL, Sec.26, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 126.6' RKB ADL 25658, ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 12/02/84 12/09/84 01/01/85I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 1 20. Depth where SSSV set 21. Thickness of Permafrost 7626'MD,6205'TVD 7510'MD,6121 'TVD YES I-~X NO []I 1875 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run, D IL/SFL/SP/GR/Cal/FDC/CNL, CBL, Gyro (GCT), Temp/CCL 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 110' 24" 187 sx CS II ..9-5/8" 36.0# J-55 Surf 3297' 12-1/4" 800 sx AS Ill & 450 sx Cla~ G 7" 26.0# J-55 Surf 7593' 8-1/2" 450 sx Class G . 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) 7408' - 7388' 3-1/2" 7176' 7146' 7388' - 7368' I 7368' - 7354' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addel~dum dated 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 I~ I - Flow Tubing Casing Pressure CALCULATED 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. NONERECEIVED Alaska 0ii & Gas Cons. C0rnmissiorl . . Form 10-407 GRUg/Wc32 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :' - . ., . ' ' ~ GEoLoG:i'd I~ARI~E~Rs ': '-- : - : FORMATI:ON-TESTS NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7248' 5934' N/A Base Upper Sand 7263' 5944' Top Lower Sand 7299' 5970' Base Lower Sand 7471' 6093' I 31. LIST OF ATTACHMENTS Addendum' -- 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' 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- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ~.~ ARC, O Alaska, Inc. Post Office BoxI :160 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 10, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following wells: 2C-16 2D-10 2D-13 2G-16 1Q-8 2U-6 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUg/L41 Enclosures RECEIVED JUN 1 2 lSB§ Alaska 0il & Gas Cons. comm~ssio~ Anchorag8 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ADDENDUM WELL: 12/18/84 - 4/08/85 2D-13 7510' PBTD, SI Rn CBL f/7504'TD to 5425'. Rn gyro f/TD to surf. Frac well in 7 stages w/316 bbls gelled diesel, 750# 100 mesh & 13,800# 20/40 mesh. RIH w/CCL tl, tag fill @ 7357' (153' of fill w/il' of "A" sand perfs covered.) Drilling~Superintendent Date .. ARCO Alaska. Inc. ~ Post Office b,.,x 100360 Anchorage. 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 TRANSMITTAL # 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 R'~n #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 Ruin #1 5500-6776 ~W-15 02-02-85 Run #1 6500-8096 ~3A-4 11-03-85 Ruin #1 6792-8329 ~3F-4 11212-85 Run #i 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: Vault*~films NSK Clerk*bl Gas Cons. Commission ARCO AlasiKa Ir1¢. Fi · S,,l:)l~Cli·ry Ot Atllnt~cRichfae~4Comoany ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 22, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2D-13 Dear Mr. Chatterton' Enclosed is a copy of the 2D-13 Well History to include with the Well Completion Report, dated 02/12/85. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/L48 Enclosure RECEIVED xc' 2D-13 Well File Alaska 0il & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -, · . ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a wall is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Fiald Kuparuk River Auth. or W.O. no. AFE 802883 Parker 191 Operator ICounty, parish or borough North Slope Borough ILease ADL 25658 or Unit ITitle Drill ARCO Alaska, Inc. Spudded or W.O. begun Spudded Dale a~2~O~ / 84 as of 8:~O-~.m. 12/04/84 IState Alaska Well no. 2D-13 API 50-029-21070 IDate IHour 12/2/84 2015 hrs. ~Irbf~e~:_~'reported 1375', (1375'), Drl~ Wt. 9.8, PV 22, YP 26, PH 9.5, WL 12, Sol 12 Accept rig @ 1600 hrs, 12/2/84. NU diverter sys. 2015 hrs, 12/2/84. Drl 12¼" hole to 1375'. 12/05/84 12/06/84 12/07/84 The above is correct Signature For form preparation and d~tribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Complete IARCO W.I. Prior status il a W.O. Spud well @ 56.24% 16" @ ±110' 3317', (1942'), C&C mud Wt. 10.0, PV 22, YP 16, PH 9.0, WL 9.2, Sol 10 Drl, DD & surv to 3317', C&C mud, short trip to 1400', circ. 1700', Assumed vertical 1973', 11.7°, S19.5W, 1971TVD, 29 VS, 27S, llW 2278', 23.3°, S15.5W, 2261TVD, 122 VS, 1168, 38W 2713', 29.3°, S15.5W, 2650 TVD, 315 VS, 301S, 95W 3282', 37.4°, S15.5W, 3126 TVD, 626 VS, 600S, 180W 9-5/8" @ 3297' 3317', (0'), PU BHA,Cln'g pits C&C mud to rn 9-5/8" csg, POOH. RU & rn 82 jts, 9-5/8", 36#, J-55 butt csg w/FC @ 3214', FS @ 3297'. Cmt w/800 sx AS III cmt w/1/2#/sx cellophane flake, followed by 450 sx Cl "G" w/2% S-i & .2% D-46. Displ w/248.5 bbls mud using rig pmp, bump plug. No cmt rtns to surf. CIP @ 1700 hrs, 12/4/84. ND diverter sys. Perform top job w/150 sx AS I cmt. NU &tst BOPE to 3000 psi. FoUnd flow in frozen. Cln & thaw flow line. PU BHA. 9-5/8" @ 3297' 4085', (768'), Drlg Wt. 9.2, PV 10, YP 8, PH 10.5, WL 9.6, Sol 3 PU BHA, GIH to FC @ 3214', tst csg to 1500 psi; OK. DO FC, FS + 10' new formation to 3327'. Conduct formation tst to 12.7 ppg EMW. Drl f/3327'-3569', POOH. PU turbo drl, CO venting vlv on MW D, GIH, drl f/3569'-4085' 3282' 37.4° ~ , , S15.5W, 3126 TVD, 6 6 VS, 600S, 180W 3524', 41.6°, S17.5W, 3313 TVD, 780 VS, 748S, 224W 3970', 47°, S18.5W, 3631TVD, 1091VS, 1045S, 320W - 9-5/8" @ 3297' 5883', (1798'), Drlg Wt. 9.4, PV 18, YP 10, PH 9.5, WL 7.8, Sol 6 Att to drl w/turbine, POOH, CO turbo-drl, CO bit, drl f/4085'-4095', att to orient OS stab, MWD not wrk'g. Drl f/4095'-4190', att MWD surv, tl wrk'g. Corrective turbo drl f/4190'-4787', corrective turbo drl f/4787'-4831'. Drl f/4831'-5009', corrective drl f/5009'-5072'. Drl f/5072'-5115', MWD surv, WL surv. Corrective turbo drl f/5165'-5258' f/5258'-5883'.4146', 46.8°, 820.5W, 3751' TVD, 1220 VS, 1166S, 363W 4146', 46.8°, S20.5W, 3751' TVD, 1220 VS, 1166S, 363W 4619', 45.1°, S18.5W, 4081TVD, 1559 VS. 1485S. 478W 5275', 49.7°, $20;5W. 45453 TVD~ 2014 VS. lq14R, 628W 5589', 42.7°2D~9.5W, 4782 T~t~ 2229 va, 2116S, 702W / 1/2/85 I DrY11 ~n~ ~,par~n~mnd~n~ Alaska Oil & 6as Cons, Commission Anchorage , drl ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICountyorParish [Slate Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25658 Date and deptl~ as of 8:00 a.m. 12/0E84 thru 12/10/84 12/11/84 Complete record for each day while drilling or workover in progress Alaska IWell no. 2D-13 9-5/8" @ 3297' 7625', (1743'), Cond hole f/7" csg Wt. 10.1, PV 20, YP 15, PH 9.5, WL 5.8, Sol 10 Drl & surv to 5975', POH, LD Turbo Drl. PU semi-angle bldg assy, GIH to 5920', wsh & rm to 5975', drl to 6512', POH, chg BHA. RIH, wsh & rm 30r to btm, drl to 7626', CBU, 20 std short trip, C&C f/logs, POH. RU Schl, rn DIL/SFL/SP/GR/CAL/FDC/CNL; hit bridge @ 5354', unable to wrk thru, POH, RD, Schl. RIH w/BHA, wsh & rm f/5296'-5420', fin RIH to 7610', sweep hole w/40 bbl hi vis pill, CBU, slug pipe, POOH. RU Schl, rn DIL/SFL/SP/GR/CAL/FDC/CNL f/7600'-3298', POH, RD Schl. GIH to 9-5/8" csg shoe. 5900', 39.9°, S17.5W, 5016 TVD, 2434 VS, 2311S, 767W 6309', 46.9°, S16.5W, 5313 TVD, 2715 VS, 2580S, 849W 6653', 49.9°, S15.5W, 5537 TVD, 2975 VS, 2831S, 919W 7247', 44.6°, S23.5W, 5940 TVD, 3410 VS, 3244S, 1058W 7587', 42.5°, S25.5W, 6186 TVD, 3644 VS, 3457S, 1155W 7" @ 7593' 7625', (0'), Prep to set 7" slips Wt. 10.2, PV 21, YP 8, PH 9, WL 6.2, Sol 12 Fin RIH to 7504', wsh & rm to btm @ 7626', C&C mud f/7" csg, POOH, LD DP. Chg top rams to 7", t~-~t--o' 3000 psi. RU & rn 192 jts, 7", 26# BTC csg w/FS @ 7593', FC @ 7510'. Lost rtns 170 its in hole. Broke circ @ csg shoe. Break circ, partial to no rtns @ 350 psi/2-3 BPM. M&P 200 sx C1 "G" w/1.5% D-79, 1.2% D-112, .5% D-65, .25% D-13 & .2% D-46, followed by 250 sx C1 "G" w/3% KC1, .8% D-10 & .2% D-46. Displ w/10 ppg NaCl/NaBr using rig pmps, bump plug. PU BOP stack, set 7" slips. Alaska 0il & (;as {~;oils. C;o:~m-]issio~'! Anchora~o The above is correct Signature For form preparation a.r~_ distribution see Procedures Manual ~ection 10, Drilling, Pages 86 and 87 IDale 1/2/85 JTit,e Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instruclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporling the entire operation if space is available. I Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Field ILease orUnit IWell no. Kuparuk River ADL #25658 29-13 Auth. or W.O. no. ~Title AFE 802883 I Drill Parker 191 Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun ~Date I Spudded Date and depth as of 8:00 a,m. 12/12/84 12/18/84 Complete record for each day reported API 50-029-21070 W.I. rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well I IHour I Prlor status if a W,O, 12/2/84 / 2015 hrs. I / 7" @ 7593' 7510'PBTD, RR Lift BOP stack, set slips. Blow out 7" to 120'. Make final cut on 7". NU. Tst pkoff to 3000 psi, ok. Release Rig @ 1300 hrs 12/11/84. TT @ 7175.65' SSSV @ 1875.41 FHL pkr @ 7146.25' D nipple @ 7163.34' Rn CBL f/7504'-5425'. Rn gyro f TD-surf. Alaska Oil & ~;;ts Cons, Corn. mission Anchorar.j3 Old TD I New TD I PB Depth 7625' (12/10/84) 7510' PBTD Released rig ] Date IKind of rig 1300 hrs 12/11/84 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test IGas 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 For form preparation and (~l'stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. [Title 1/2/85 Drilling Superintendent ARCO Alaska, Inc. Post Office BC~-.~60 Anchorage, A. .;a 99510 Telephone 907 277 5637 Date: 02/20/85 Transmittal No: 50'63 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ' '~Tr~nsmitted herewith are the following items. and return one signed copy of this transmittal. Please acknowledge receipt OPEN HOLE FINALS (One%blumtine amd'one sepia each) Schlumberger 2D-13 ' 5" Cyberlook 12/10/84 Run 91 2" DIL/SFL-GR 12/10/84 Run 91 5" DIL/SFL-GR 12/10/84 Run 91 2" Density/Neutron-GR 12/10/84 Run 91 (Raw Data) 5" Density/Neutron-GR 12/10/84 Run 91 (Raw Data) 2" Density/Neutron-GR 12/10/84 Run 91 (Porosity) 5" Density/Neutron-GR 12/10/84 Run 91 '' (Porosity) · . 2E-13 ~" Cyberlook 2" Density/NeutrOn (Porosity) ~" Density/Neutron (Porosity) 2" Density/Neutron (Raw Data) 5" Density/Neutron (Raw Data) 2" DIL/SFL-GR 5" DIL/SFL-GR 12/03/84 Run 91 12/03/84 Run #1 · 1~/03/84 Run 91 12/03/84 Run 91 12/03/84 Run 91 12/03/84 Run #1 12/03/84 Run 91 Receipt Acknowledged: B. Currier BPAE Chevron Drilling Geology Mobil DISTRIBUTION 4000-7500 3298-7592 3298-7592 3298-7566 3298-7566 3298-7566 3298-7566 7500-7900 7500-7900 7500-7900 7500-7900 7500-7900 W. Pasher G. Phillips Phillips 0il 3721-8047 3721-8047 · Alaska 0ii & Gas Cons. C0mmis~ Union D&M NSK Drill Clerk J. Rathmell Well Files ARCO Alaska· Inc. is a subsidim,y o! AtlantJcR.icb~;eidCom-.pany ARCO Alaska, Inc. Post Office Bo, ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 13, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-13 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU4/L146 Enclosures RECEIVED FEB 1 5 19B5 Alaska Oil & Gas gons. gommissiog Anch0ra[t~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '--" STATE OF ALASKA ALASKA~'_ ,..AND GAS CONSERVATION CQ /llSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-12 ;~. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21070 4. Location of well at surface 9. Unit or Lease Name 692' FNL, 144' FEL, Sec. 26, T11N, RgE, UN ~,~,'~!O?qSi Kuparuk River Unit At Top Producing Interval t VE~IFi[L) ! 10. Well Number 1339' FSL, 1202' FEL, Sec.26, TllN, R9E, UM iSurL ~__~_~. 2D-13 At Total Depth ! 3. H. ¢;J__i 11. Field and Pool 1095' FSL, 1301' FEL, Sec.26, T11N, R9E, UM ----~------ ' Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 126.6' RKB ADL 25658, ALK 2584 121 Date Spudded12/02/84 13. Date T.D. Reached1 2/09/84 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns01/01/85 N/A feet MSL 1 17. Total'Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7626'MD,6205'TVD 7510'MD,6121 'TVD YES [] NO []I 1875 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/Cal/FDC/CNL, CBL, Gyro (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 110' 24" 187 sx CS II 9-5/8" 36.0# J-55 Surf 3297' 12-1/4" 800 sx AS Ill & 450 sx Class G ,, 7" 26.0# J-55 Surf 7593' 8-1/2" 450 sx Class G 24. Perforations open to Production (MDYTVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7408' - 7388' 3-1/2" 7176' 7146' 7388' - 7368' 7368' - 7354' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MI:)) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (FIowing~ gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I , Flow Tubing Casing Pressure CALCULATED OI L-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 Nas~ 0ii & 6~s 60~s. 6omm~sst0n &nr. hOf~98 Form 10-407 GRU3/WC43 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :; .- ... . ~ .. . · . . , ' "~ - ' GEoLoG;c MARKERS'" ' . ii'"':. :I~ORMATION'TEsTs · NAME Include interval tested, pressure data, all fluids recovered and 'gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7248' 5934' N/A Base Upper Sand 7263' 5944' Top Lower Sand 7299' 5970' Base Lower Sand 7471' 6093' 31. LIST OF ATTACHMENTS W~.ll Hi_~tnrv (in~_l.ding mrtd~.nH,,m); Cyro.~_n,nim..~,,rv~.y (? 32. : ' I hereby~ce~tify that the foregoing is true and correct to the best of my knowledge Signed ~]K) 0/'~~--y -)~~ 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' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". I::nrrn 1 t'1_~f'1'7 ADDENDUM WELL: 12/18/84 2D-13 7510' PBTD, SI Rn CBL f/7504'TD to 5425'. Rn gyro f/TD to surf. Drillin~ Superintendent Date ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation ii space is available. District County or Parish Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25658 Auth. or W.O. no. T t e AFE 803883 Completion Roll'N #4 API 50-029-21070 Accounting cost center code State Alaska Well no. 2D-13 Operator A.R.Co, W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 12/20/84 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our IPrior status if a W.O. 1930 hrs I Date and depth as of 8:00 a.m. 12/31/84 1/02-/85 Complete record for each day reported 7" @ 7593' 7510' PBTD, 7625' TD, Prep to RD W/L unit 10.2 ppg NaC1/NaBr Accept rig @ 1930 hrs, 12/30/84. ND tree, NU & tst BOPE; OK. RU Go, perf w/4", 4 SPF/120° phasing f/7408'-7388', 7388'-7368', 7368'-7354'. 7" @ 7593' 7510' PBTD, 7625' TD, RR 7.2 crude & diesel Rn 224 jts, 3½", 9.3#, J-55 IPC 8RD EUE tbg &lnd. Set pkr. Shear pins in PBR. Press tst top of pkr w/2500 psi. ND BOPE, NU & tst tree to 5000 psi. Pmp 35 bbls diesel ahead & displ well w/crude. Tst SSSV, tst orifice. Shear out ball catcher sub. Set BPV. RR @ 1000 hrs, 1/1/85. SSSV @ 1875.41' - FHL Pkr @ 7146.25' - PBR @ 7232.60' 7r @ 7175.§5' Old TD Released rig New TD Date 1000 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data PB Depth 7625' 7510' PBTD Kind of rig 1/ol/85 Rotary Type completion (single, dual, etc.) -Single IO[ficial reservoir name(s) Kuparuk Sands RECEIVED Well no. Date Reservoir Producing Interval Oil or gas Test time Production ~___~,~;m~ Anct orage Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date ITitle ((),f ~,~~-~x~j 1/28/85 Drilling Superintendent For form preparatio a ddi ibuti,.,,, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. $ UB-S URFA CE DIRECTIONAL SURVEY '[-'~ UIDANCE r~ ONTINUOUS r~OOL Company ATLANTIC RICHFIELD COMPANY Well Name Field/Location 2D-13 (692' FNL 144' FEL, S26~ T11N, R9E~ UM) KUPARUK~ NORTH SLOPE, ALASKA Job Reference No. 69953 Lo~ed By: MCBRIDE Date 11-JAN-85 Computed By: STEVENS GCT ~i~ECT~ONAI, CusTO~E~ blST~N~ FOR ARCD AbASK~, IMC, ~D-13 ~UPAPUK SU~VKY DATM.' 17-0EC-84 RNGINEER' ~C~,R T. I')~ {ETHODS ~F COMPUTATION TOOb bOCATTON: TANGMNTI~b- averaoed dev{ati~n and azimuth TNTERPOLAT]O~ VER~ICAT, SECTT0W: HORTZ, DIST, PROOECmE~ ONTO A TARCET ~Z~HIITH OF SOUTH lq DEG 47 M~N WEST CCT ~E~TT~NAL ~LI~V~¥ CUSTOMER LiSTTN~ FnR ~RCO ALASKa, 20-1~ YUPAPUK NORTW ~LOP~o ALASKA SU~VFY DaTF: 17-DEC-84 MNCINEF, R: ~CRR1~D~_ METHODS ~F COMPUTATION TOOL LOC~TTOM: TANGENTIAL- averaoed deviation and azimuth V~R~ICAt, SECT~O.: HORTZ. DIST. PROJECTED ONTO A T~RGET ~Z~MUTH OF MOUTH lg DE~ 47 M~N WEST KUP~RIIK COMPUTATION DATE: lO-JAN-R5 ,. PACE DATE OF SURVRY{ l?-DEC-84 KELLY BUSHTNG EbEVATIO~I 126,60 FT INTERPOLATED VALUES FOR EVEM 100 FEET OF MEASURED DEPTH TRUE SUB-SE~ COURSE MEASURED VRRTiCA[, VE~T{CAL DEVIAT[ON AZf~UTH DEPTH D~PTH PEPTH DEG MT){ D~G MTN -126.W0 0 0 N 0 O E -26.60 0 ] S 17 50 E 73.40 0 19 S 97 24 W i7].40 0 4 N 40 0 £ ~73,40 0 1~ S 2 20 ~ ]7],40 0 9 ~ 39 5~ W 47) 40 0 1~ ~ 92 35 E ~7]~40 0 1! N 61 54 W 673. j40 0 1~ ~ W8 In ~ 773,40 0 10 ~ 63 37 W ~7~.40 i17).]9 0.00 100.00 200.00 300.00 400.00 5OO O0 6OO O0 7O0 O0 8OO O0 900 O0 0.00 100.00 200.00 300.00. 400.00 ~00.00 600.00 700.00 ~00.o0 oO0.O0 VERTICAL DO~LEG RECTANGULAR COORDINATES HOR~Z, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/{O0 FE~T FEET FEET DEG MXN 0.00 0 O0 0,00 -0.03 0:1~ 0.04 '0.02 0,~9 0 11 0.18 0.=3 O~lO 0,~2 0.64 0,17 0.33 0.45 0..21 0,48 0 71 0,29 0.45 0~44 0.27 0.64 0,4~ 0.41 0,52 0,54 0,3~ 0.78 053 0.53 0.66 0:56 0.44 n.R2 0 47 0,54 0.75 0:]0 0.60 0.~4 O~ 39 0.46 0.75 0.33 0.68 0.92 0.3? 0,95 1 07 1.69 1,11 4~87 3,68 4,54 1~.~3 4,20 14,52 $ 18 2~ W 33.68 ~ 14 51W 5~.97 $ 14 38 W 80.90 S 14 55 W 127.34 $ 14 3~ W 169.90 $ !5 17 W ~17.~9 ~ ~.6 39' W ~5~.~3 8 16 47 W ]06.11 S 16 38 W 355.55 ~ ~6 39' W 406.~9 1000.00 {,000.00 1100.00 1099,9'q 1~00.'00 1199.99 1~00,00 1299 ,99 1400.00 1399.99 197~.~9 1500.00 1499.99 1600.00 ,599.9~ 147,.39 1700.00 ,699,~ 1~73.39 1,00 O0 1799, .. 1673.~9 1~00~00 18~9.26 177~.66 2000.00 1997 64 1~71,04. 12 14 210o O0 2094 5~ 1067.03 16 2n 2200~00 ~1~9 33 206~.73 20 2300.00 22~1 98 2i5~,38 23 41 2400.00 ~372 7! 2~46.11 25 35 2~00.00 ~462 59 2335.09 26 33 2600 O0 ~5~1.51 2424.01 97 51 2700:00 2639,43 251~.~3 99 2RO0.O0 '27~6.30 2599.70 30 2900.00 ~812.06 268~.46 31 3~ 3000.00 2896 5~ 2769.92 33 3 3100.00 2979 57 2~57.97 34 4~ 3200.00 30610~ 2~34.n2 36 3300 oo ~141 O0 3014.~0 37 4~ 3400~00 32~8 9~ 3099.~2 39 4n 3500 ~0 3294 96 3~6~,36 41 3600:00 3369 3~ 3~47.72 42 57 3700 00' 3441.0~ 3314.45 44 57 3~00:00 35~1,1- 3384,53 a6 7 3~00,00 35T9,89 3453,79 46 47 $ 16 30 w 460.35 S 16 32 W 515.~4 ~ 16 35 W 573.~7 $ 16 47 W 63!.80 ~ ~7 IR W 696.41 $ !7 17 W S 17 59 W ~2~.09 $ ~9 26 W 897.75 ~ 19 56 W 960.08 ~ 20 0 w lO41,69 3,97 4.60 3.65 2.94 0.74 1,46 1.27 1.21 1,31 1.45 1.24 1.76 1.5~ 2.7! 1.8~ 1.40 2.83 0.94 0.21 31 30 54 91 85 67 191 94 162 63 205 03 249 02 294,64 342.07 391,3~ 0,00 E 0,0! W 0.24 w 0~24 W 0 47 W 0:39 w 0,63 w 0.56 w 0,74 w 0,64 W 0,83 w 0,73 W 0,92 W 0,53 W 0.32 W 0 30 w 0~07 W 0,~ W 1. 7 W 6,41 W 1 1~ 50 W 37 20 w 47 58 71 ~5 99 0 O0 N 0 0 E 0:04 N 51 w 0.26 N 65 41 W 0,26 S 66 14 ~ 0,50 S 70 31 W 0,44 S 61 55 W 0,69 S 65 ~6 W 0,62 S 64 7 ') 0,8~ S 60 48 0,72 S 63 26 W 0,99 S 57 33 W 0,85 $ 58 57 W 1.06 S 59 16 W O,BO S 41 22 W 0.56 S 34 19 W ,75 S 23 57 W ~.96 S 4 19 W 1.11 S 3 ~5 w 4~81 S 21 lB W 15~87 $ 23 49 W 33 58 89 127 76 w 169 97 w 213 52 W 259 2~ w 306 48 w 356 1~ W 407 1 45 W 96 S 17 45 W 49 S 16 57 w 50 S 16 21 W 34 $ 16 2 W 09 S 16 I w s 8 ) 24 S 16 12 ... 66 S 16 15 W ,, 442,68 $ 129,4.1 W 461,20 S 16 i7 W 406,06 S 145,24 W 516,89 8 16 19 W 609,1~ S 178,95 W 634,9t 669,07 $ 1~?,46 W 697,60 S 16 711,07 $ 216,77 W 762,5] S 16 30 W 794,83 S 236,87 W 829,38 S 16 35 W 860.76 $ 2~9.37 W 898.99 S 16 46 9~7.91 $ 283.44 W 970.2] $ 16 59 W 996.14 S 308,2~ W 1042.75 S 17 11 W 2~-13 KUPARUK COMPUTATION DATE= lO-JAN-B5 PAGE 2 DATE OF ~URVEY= 17-DEC-84 KELLY 9USHTN~ EbEV~TION= 126,60 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SE~ MEASURED VFRTICAL.VEPT)CA.L DEVIATION AZIMUTH DEPTH DEP?H DEPTH DEG 4000.00 3648 14 3~2~,~4 4100.00 3716:18 358q.~8 46 50 4200 00 3784,7~ 3658.18 46 37 4300~00 38~3,7q 3727 19 46 4400.00 3993,39 3796~72 45 47 4~00.00 39~3.o38 3866.78 45 lq 4600.00 4.063.74 3037o~4 45 13 4700 O0 4134,30 4~07,70 05 4 4800~00 42n4.90 407~,38 44 4qO0,O0 4276,3~ 414q.75 44 6 5000.00 0348 33 4221,73 ~3 50 5100 O0 4490 68 4~94.08 03 28 5~00~00 4483 43 4366,~3 43 22 5300.00 45~5 77 4439.12 43 51 5400,00 4637 84 4~11.24 43 43 5~00.00 ~710 3~ 4583,71 43 15 5600,00 47~3 44 4656,04 42 44 5700,00 ~857 24 4730,64 42 5800,00 4932 43 4~0~.M3 40 36 5900.00 ~008 5~ 4~83,08 40 10 6000 O0 5005,04 495~.44 40 6100:00 5160,49 5033,~9 42 4 6700.00 ~233,20 5106.68 44 24 6300.00 ~303.57 5176,92 46 22 6400.00 5371.,05 5~44 45 48 42 6500.00 ~435.66 530~:06 KO 43 6600.00 5498,50 5373.~0 50 46 6700.00 5562.30 543~.?0 49 49 7000.00 $760,73 5,34.,3 07 7100.005978~, 5 5703,~5 45 4~ 7~00 O0 ~89~.z' 5773.11 45 l! 7300100 ~ v o97. ~ 5~43.q4 aa 47 7400.00 ~001.8 5015.28 0421 7~00 oO 6113,7o 5~87.~0 aa 36 7600:00 6186.14 605~.54 0334 7626.00 6204.9n 6~7~.38 0330 VERTICAb DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 1.9 55 W 1~14,77 19 4~ W 1188.06 19 49 w 1260.81 20 11 W 1333,18 1926 W 1405.05 19 2 W 1076.41 18 4~ w 1547.d6 18'15 W 161~.30 18 6 ~ 1680.01 ~8 16 W 1750.03 ~ ~7 49 W 182~,41 ~ 18 41. W 1997.42 ~ 19 14 W 1066.03 ~ 20 59 W 2035.11 S 20 2~ W 2104.37 S 19 55 w 2173.28 g 19 20 W 2241.48 $ 18 3~ w 2308.~5 ~ 18 17 w 2374.~6 ~ ~7 26 w 243~.64 S 16 4 W 2503.98 ~ 15 50 w 2569.46 $ 15 48 W 2637.85 S ~.5 5~ W 270~.85 S 16 3 w 2787.44 S ~6 5 w 2858.~9 S 16 20 w 2q36.74 $ ~6 26 w 30~3.10 $ ~7 26 w 3080.88 $ lB 16 w 3~64.00 S 18 55 w 3937.01 ~ !9 50 w 3310.77 $ 21 13 w 3381.71 S 22 13 w 345~.25 $ 22 ~ w 3527.97 S 22 8 W 3591,80 ~ ~2 1~ W 3660.66 ~ 72 ~2 W 367~.~7 0.45 1.16 0,81 0,71 0.63 0,3~ '0,47 0,30 0,73 0.7~ .1064 83 ,q 333,25 w 1.115,76 S 17 22 W 1133 75 S 358,14 W 1108,98 S 17 31 w 120223 S 382,73 w 1261,613 S 1739 W 1270 18 S 407,64 W 1333,90 $ 17 47 W !337 80 $ 432,00 w !405,8~. S 17 53 w 455.4~ w .16 17 57 W ,405 l0 S 1477 S 1472!47 S 478.48 w i548,201 8 18 0 W 1539 6~ ~ 500,92 w ,6,9, 6 S 18 I ) ,.606,87 S 5~2.8, w ,689.80 $ 18 1 1673.36 S 544.91 W ,7,9,85 S 18 2 W 0,33 0,43 0,5~ 0~86 0.75 1.04 1739 39 S 566 1804 1869 1934 1999 2064 2175 7102 ~254 2316 W 1879 26 $ 18 2 W ,33 97 S 5n7,80 W 1808 93 $ 610,01 W 1.966 70 S 634,05 W 2035 46 $ 658,63 W 2105 14 S 692 38 W 2174 36 S 705 34 W ~242 15 S 7?7 3~ W ~3~9 69 S 748 22 W 9375 39 S 7~8 09 ~ 9440 30 $ 18 2 W 91 S 18 4 w 94 $ 18 8 W 14 S 18 13 W O1 S 18 17 w 19 S 1~ 20 w 66 S 18 21 w 50 S is) 21 w 41 S 18 9~0 'w 0,91 2,29 1,7m 2,22 2,3~ 1.97 0,94 1,28 1,1~ 1,31 ~378,09 S 786,64 W ~504.82 S 18 18 W 2441,22 S 804,59 w 9570.39 S 18 14 W 2507 18 S 823,27 w ~638,89 S 18 10 W ~575 63 S 842.73 w 7709.9q $ 18 7 W ~646 54 S 863.03 W ~7~3.70 S 1~ 3 W 27~9 86 S 884.1~ W 9859,97 S 18 0 W 794 56 S 905.90 W 9937.72 S 17 57 W 868.43 $ 9?7,69 W 30~4,69 S 17 55 99al,07 ~ 949,57 W 3090,56 S 17 53 30~2..55 S 972.78 w 3165,72 $ 17 53 W 1,46 1,46 0,60 1,10 2.53 0.00 0,00 3002.6] S 99631 w 3239,64 S 1754 W 150.90 S 1020 30 W 3311,98 S 17 56 W {217 77 S 1045 45 W 3383 35 $ 17 59 W 3283.31S 1071 67 w 3453.7q S 18 4 W 33a8.1~ S ~098 1~ W 3593.69 S 18 9 W 3412.69 ~ 11~4,26 W 3593,11 S 1~ t4 W 3~76,51 S ~150,3~ W 3661.88 S 18 ~8 W 34~3.10 S 1157.09 w 3679.76 S lg 19 W ARco 2~-13 KUP~RUK N~RTH SLOPE, T~UE SU~-SEA COUPSF ~EASURED' VERTICAL VERTICAL DEVIATION AZIMUTH ~EPT. D~PTH 'nEPTH DEG MIN D~G MIN COMPUTATION DATE: lO-JAN-g5 PAGE 3 DATE OF SURVEY: 1.7-DEC-84 INTERPOLATED VALUES FOR EVEN 1000 FEET OF M~ASURED DEPT VERTTCa£, DOGLEG R~CTANGULaR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NnR~H/SOUTH EAST/WEST DIST, ~Z~MUTH FEET DEG/100 FE~T FEET FEET DE~ ~Iw N 0 0 E 0.00 S ~9 40 F 0.78 $ ~8 2~ W 3].68 S ~6 30 w 460.35 S ~9 55 W ~14.77 $ ~7 49 W S 16 4 W 2503,~8 ~ ~8 5~ W 3~37 S 92 12 W 367P.57 0.00 0 00 '1.26.60 0 1000.,00 ~000 00 ~73.40 0 2000 O0 ~997 64 ~ ~4 ,.2 14 ooo.oo ?oo .oo 0o00 0.53 3,97 0.3~ 0 9~ li46 0 O0 126.60 FT 0.0o N :0.00 E 0.00 N 0 0 E 0'53 S 0,83 W 0.99 S 57 33 W 31,30 S 1.2 50 w 33,70 S 21 45 W 442.6~ S 129:41 w 461.20 S [6 ~7 W 1064,8~ S 333,25 W 11~5,76 S 17 ~2 W ~739.39 S 566.33 W 1829,26 $ 18 2 W 2378,09 ~ 706 6~ W ~504 82 S 1" 18 W 30~2.63 S 9e6:31 W 32~9:64 S 17 54 ) 0q W 3679'76 S 18 ~9 - ~493,~0 S ~157, - AI~C~ AI, ASKA, ]'NC. KFPARUK ~OR'PH SLOPE, ALASKA COMPUTA?I~N DATE: lO-JAN-R5 PAGE 4 DATE OF SURVEY: 1,7-DEC-84 KELLY ~USHTNG EbEVATIONt 126,60 FT ENGTNEER= MCBRIDE I~TERPOLATED VAt,UES FOR EVEN 100 FEET OF SUB-SEA ~EPTR TRU~ ~U~-$Ea COU~S~ MEASURED V~RTICAI. VE~TTC~L D~VTATfON AZIMUTH DEPT~ O~PTH 9EPTN DEG M~N DEG MiN 0.00 26.60 !2~.60 26.~0 26.60 426.60 ~26.60 626.60 726,60 g26,60 0 O0 -i26.60 26:60 -100.00 126 60 226 6O 396 60 426 6O 5~6 60 6~6 60 8~6 O 0 n N 0 0 E 0.00 0 6 8 3 ,5 ~. lO0.Oo 0 10 $ 17 11 w ~00.00 0 ~ ~: 61 30 w 300.00 0 10 $ 47 53 W 400.00 0 17 N 73 43. w 600.n0 0 13 S R5 36 W 700.00 0 0 N m3 15 F VE~TTCAL DOGLEG R~CTANGULAR COORDINATES HORIZ. DEPARTURE SECtiON SEVERITY NORTH/$~UTH E~ST/WEST DIST, AZTMUT~ F~E? ~E~/IO0 FEET PE~T WEFT DEG MIN 926.60 996. 60 ~00.00 0 19 ~ 75 46 W 1026.60 1096.:60 900.00 0 o S 79 '5 F 1~26.61 ~1~6.60 1000.00 0 ~ N R4 43 W 1926.61 ~226.60 11OO.nO 0 19 ~ 56 ~ E 1326.61 i376.60 1~00.00 0 14 ~ F3 2 F 1426.61 14~6,60 1]00,00 0 7 S 2 24. ~ 1~26,61 !526,60 1400.00 0 12 ~ 45 6 ~ 1626,61 16~6,60 1500,00 0 5 ~ 33 5 E 1726.61 17~6.60 1600.00 1 n $ 78 21W 1826.n0 18~6.60 1700.00 5 21 S ~5 26 w 1927.66 1976.60 lgO0.O'O 9 24 2029.70 20~6.60 1000.00 13 23 2133.~7 ~126.60 2o00.00 17 57 2239.93 ~276.60 2100.00 2! 46 234~.09 7326 60 2200.00 ~4 52 2459.m5 2426 60 2~00.00 ~6 4 2571.87 25~6 60 240n.00 27 3n 2685,33 ~6~6 60 2500.00 78 5~ 2800.35 ~7~6 60 2600,n0 ]0 1~ 2917.08 2826 60 2700.00 ]1 5~ 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 ~ -0.06 0.48 0.07 N 0.01 w 0.06 0.47 0,04 ~ 0.29 W 0.~6 0.47 0.08 $ 0,27 W 0.38 0.60 0.25 S 0.43 W 0.~ O.4a 0.17 S 0.47 w 0.52 0.57' 0.35 S 0.57 W 0.46 0.53 0 25 S 0 66 W s w 3035.m8 ~926 60 2~00,00 33 36 3157.53 3026 60 2900,00 35 34 32B1.~8 3126 60 3000.00 37 2~ 3410.01 ~2~6 60 3100.00 39 50 3~42.~4 33~9 60 3?00.00 41 4m 3979.$9 342~ 60 3,27.37 357:60 396..40 ~6,i!60 4,15.~1 372 60 '4~60.69 ,82 60 0.55 0.51 0.32 S 0.73 W 0.81 0.61 0.5~ $ 0.78 W 0.66 0.34 0.41 S 0.80 W 0.~7 0.50 0 61S 0 86 W o:s4 s w o. t s o w 0.78 0.24 0.75 ~ 0:24 W 0.95 0.2~ 1.00 S 0.04 W 1.t6 ],9~ 1,36 S 0.2~ W 7.09 4.30 6.55 $ 2.7a W ~ ~1 5 w 20.07 8 17 34 w 40.25 S 14 21 w 6~.13 S !5 5 w 1.04.16 S 14 31W 147.48 $ !4 49 W 19~.15 ~ !6 12 w 245.49 $ !6 40 w ~99.00 ~ 16 3g w 355.72 S !6 32 w ale.g5 S 16 30 w $ !6 34 w $ 16 41 w ~ 17 lq w S 17 24 w 3300,00 44 46 '~ 19 17 w 3400.00 46 21 S 19 59 W 480.n6 54q.03 622.B2 70~.82 780.~5 R83.33 085.24 350o.00 47 I ~ 19 5~ W 1091.65 3600.00 46 40 S 19 47 W 1190.13 3700.00 46 1~ ~ 20 1~ W 1304.79 4.26 3.92 4.37 3.2~ 2.04 1.1] 1.43 1.07 1.30 1.37 1.85 1.37 2.06 1.80 1.23 1.07 0.2~ 0.81 0.51 18 44 $ 37 54 $ 64 49 $ 99 50 S 141 52 $ 1~7 84 S 236 48 S 0,00 N 0 0 g 0.00 N 9O 0 E 0.07 N 6 12 W 0.29 N 81 51W O.2g S 74 ~3 W 0.50 $ 59 52 W 0.50 S 70 30 W 0.67 S 58 99 ) 0.71 $ 69 18 . 0.79 S 56 ,52 W 0.80 S 66 25 W 0.97 $ 53 22 W 0.90 S 62 ,5O W 1.06 S 54. 31 W 0.68 S 3B 3 W 0.59 S 31 9 w 0.78 S 1R 1W l.OOS 2 16 W 1,38 S 9 1.0 W 7,10 S 2~ 43 W 8.01 w 20,11 $ 23 28 W 14.55 w 40.26 S 21 11 W 22.00 W 68.14 $ 1R 50 W 31.11 W 104 26 S 17 21W 42.3! W 147 71 $ 16 38 W 54.34 W 195 54 S 16 8 W 67.8] W 246 02 S 16 0 W R3.2~ W 299 6] S 16 7 ) 99.53 w , 2~7.82 $ 342.23 $ 356 41 $ 16 12 399.95 S 116.73 W 41.6 64 S 16 16 W 461.6,0 8 135 02 W 480.94 $ 16 18 W 52 83 $ 154 69 W 550.03 $ 16 20 W~i 59 65 S 175 623,93 675.10 ,5 199 37 $ 16 9.7 W 757 7q $ 2?5 847 17 S 254 943 10 $ 2~8 1043 09 $ 325 80 W S 16 21 W w 704.01 10 w 790.5~ S 16 32 W 57 w 884.59 $ 16 43 W 96 W 9~6.37 S 17 2 W 3'5 W 1092.65 S 17 19 W 1144 18 $ 361 89 W 1200.04 S 17 33 W 1243.55 $ 307.80 w 1305.6~ S 17 44 W 2D-13 KUP 1~ RllK NOR'I'H SLOPE; ALASKA CONPUTATI~N DATE: lO-dAN-85 PAGE 5 · DATE OF SUPVE¥~ 17-DEC-84 K~bY ~USH~NG ~b~VATION~ 126.60 F~ ENGXN£EP~ HCB~IOE I"TERPOLATED VALUES FOR EVEN 100 FE~T OF SU~-SE~ DEPTN MEASURED VER?ICAI. V£PTTCAB DEVIATION AZIPUTH DEPT, D~PTH DEPTH DEG M~N. D~G M~N 4404 69 ~9~6,60 3~0~.00 45 46 4~47:~2 4076.60 3000.00 45 17 4689,09 41~6,60 4000,00 45 4 4030.45 a2~6,60. 4~00,00 44 37 4969,~4 43~6 60 4~00,00 A3 55 5~0~,~6 a4~6 60 4300,00 43 26 5~45,77 45~6 6'0 440n,~0 43 49 5384,43 ~6~6 60 4~00,00 43 47 5~2.~,~3' a7~6 60 4600,00 a3 5~5~,56 a8~6 60 470o.00 42 23 579~,33 a976 60 4~Om,OO aO 30 5923 ~7 5076 6~ 4~0o O1 6054:71 5126 60 5oon:o0 41 6~90 68 52~6 6. 5 oo,oo 6~33 67 ~3~6 60 5~OO,O0 6485 70 54~6 60 5300 O0 SO 26 6644 28 55~6 60 5400~00 ~0 2~ 679~ ?3 56~6,60 5500,00 49 3 6949,57 57~6,60 5600,00 47 41 709~,49 ~8~6,60 5700,00 45 50 '~738,04 59~6. 60 5800,00 44 54 37~,6! ~026:60 5900,00 44 25 7517 RO 6176,60 6000,00 43 34 7626~00 6204,98 6078,38 43 34 VERTTCAb DOGbEG RECTANGUBAR cOoRDTNATES HOR~Z, DEPARTURE SECTION SEVE~I?Y N~RTH/S~UTH E~ST/WEST DIST, AZIMUTH FEET DE~/IO0 FERT ~EET FEET ~EG uXW $ ~8 17 W 1610.~? ~ ~8 16 W 1710,45 S ~7 5~ W 1~07,~2 S ~8 45 W 1903,03 S 20 18 W lg97,56 S ~0 3~ W 2093,~0 $ ~9 50 W 218g,54 ~ ~8 59 W 2281.06 ~ ~8 16 W 236n.87 ~ %7 ~ W 2454.~0 ~ ~5 50. W 253¢.48 $ !5 4~ W 2631.36 ~ 15 57 W 2733.31 S 16 5 W 2947,56 S ~6 23 W 2970,40 ~ ~7 2~ W 3087,~2 ~ ~8 37 W 3?00,79 ~ ~9 55 W 3307,03 ~ 21 41. W 340~.60 S 22 W W 3~07.31 $ 92 17 W 3604.05 S 92 1~ W 367~.57 0 63 1340 7 S 433 1; O~ 16~7.25 ~ 5?9 O; 3° 1810.29 S 5~9 80 ~899.60 S 6~0 1'5~ ~9~9o3~ S 654 60 2078.50 S 7~ 21&5.75 S 71 0,?~ 1,01 2,1g 1,91 2,25 2,17 0,79 t,IP 1,20 1,16 0 9~. 0 O0 O:OO 5g W 94 w 180 6q w ~903 67 w ~998 84 w 2094 5~ w 2189 36 w ~2~1 25 S 1~ ! w 36 S 18 2 W 91 S 18 2 w 43 $ 18 5 w s 18 27 S 1~ ~8 .. 2249 94 S 746.67 W 9370,60 S 1~ 21W 9330 ~7 S 772.62 W 2'455,5~ $ 1~ ~0 W ~412 31. $ 796.39 W 75~0.37 S ~ ]6 W ~500 9~ ~ 871 50 w ~632.39 S 1, ,1W 9599 21 5 849:46 W 2734.50 $ 1, 5 W 2799 24 $ 8~1i~ w ~848.92 S 1~ O.W ~897:39 S 9~5 $ w 7971.93 S 17 56 W 3047,47 $ 9~4.39 W 3202.5? S 17 54 W 3147.86 $ ~0~9.20 W 3300.74 S 17 56 w ~]~42,82 S 1055.2i~ W 34{0. 20 S ll~ 1 W 34~4,32 $ 1092.54 w 3508:75 ,5 18 8 W .05 S i]78.90 W 3605.35 S 1, 14 w 3493.10 $ I 57.09 W 3679,76 $ 10 19 W ARC~ ALASKA, ?NC, 2P'~3 KUPARUK MARKER TOP:UPPER SAND B~S~ ~PPER ~A~D TOP LO~R SAND B~5~ bOWER T~T~L D~P?H COMPU?A?[ON D~TE= 1.0-JAN-R5 INTERPO[,A?ED vALUES FOR cROs£N HO~.IZOM$ MEASURED DEPTH PAGE 6 ~A?E OF SURVE¥I tT-DEC-84 KELLY 8USHTN~ ~LEVSTION~ 126,60 FT ENGINEE~ MCBRIDE 5U~'FACE bOCATION ORIGIN= 699~ FNL, 344' FEb. SEC 26. 711N, Rgb, U~ TVD R~C?ANG!IbAR COORDINATES F~OM KB SIJR-SEa ~O~TH/$OIITW E,~ST/WEST 7248.00 593~.66 5807.06 3~49,34 7263.00 5q44.29 58~7.6q 325q.~6 7299,00 596q.83 5843.23 3~B~.66 S 747~.00 6097.77 596~ 17 3394,09 75~0.00 6120.95 599 35 341g,07 76~6.00 6~04.98 607B.3R 3493.30 1057 qO W 1061 B4 W 1071 ~1W 1116 2 W 1126 86 W 2D-13 KUP~RUK ~A~K~R ?DP UPPER SAND BASE UPPER TOP bOWeR TOTAL D~PTH COHPUTATI~N D~T~ 10-dA~-~5 MEASURED DEPTR PA~E ? DATE OF SURV£Y~ ~7'DEC'84 KELLY ~USH~NG ELEVAT~ON~ [26,60 F~ ENGTNEER~ NCB~IDE SURFACE LOCATION OR~G~Nm 69~~ FNL, ~44~ F~L, SEC AT ~6 TI~N. RgE, U~ TVD RECTANGULAR C~ORDINATE$ F~O~ KB SUB-SE~ "ORTH/$OUTH EAST/WE~T 248 O0 5933 66 5807.05 72 O0 5060. 3 ~843.23 ?1 O0 6092, 7 59~6.}7 751.0,00 6120,q5' 5994, 76~6,00 6~04,q$ 60?8, 3~4q,34 $ 1057 90 W 3259,16 S 1061 84 378~ 66 S 1071 41 3394:09 S 1116 72 W 3410,07 S '1126 86 3493.10 $ 1157 09 ?INA[., NELL 60CAT~O~ TRUE SUB-SEA .M~ASU~En VFR?ICAr, VEPT~CAL DEOT~ DEPTH ~EPTH , 7676,00 6~04,q8 6078,3m HORIZONTAl, D~P~R?URE ~ISTaNCE AZIMUTH FEET DEG ~TN 3670.76 S 1~ 19 W SCHLUMBERGER ARCO ALASKA, INC. 20-1~ KUPARUK NORTH SLOPE, ALASKA OECEMBER ]?, 1984 TVW PLOT FROM OCT DATA JOB REFERENCE 699S3 -'WELL: . 2D-13 ~ ~-.. SURFACE LOCATION: _~2' FNL 144' .FEL, S26, T11N, R.9-. UM NE VERTICAL PROJECTION -4000 -3000 -2000 - 1000 0 0 1000 2000 2000 4000 .~l. : ~ [ ! :. : ~ ~ ! i ~ ~ ~ ~ :. ~ : , : i i ~ ~ j i · ' j SW +-'~---~-"~-'4---~-~--.~-¥-b~-~-~-~--4---~-~.-4---~ ..... ~-.-¥.~-~-~--.~--.~.--b4-~'~---~' 4---~--:~-~ 4 ....... ~...i.--~-..~-b4---~-.-~---~--- '"f"r"f"f"h'f"~"'?~ ...... +"-f"f--r+-t"-f"?-'~ ...... t'"?'?'f"~'"f-'?'t'"~ ' ' ' ~ : ~ ~ : : , ' : : : , ' ; : '- : ' : : [ : : i ..... ..-~-.~-~-~ ~ ~._N4_:: -~.~-N4-.~4-b .~4~i..4.-~-.f-.~-.:'-..b-.%-~:+..L.f..~-~-~ ...... ---f.. ~.-4.-~---~--.&--~..4...f ..... f-..?..f..-~...{.-.~-.-?f-..~ ~.-f--.f.-.f..~...?..::. ::[:j;:~--~[:[:[~2--~::[:?~f--~.--h~---H---~ ..... ~-+-~++4---hH---*-+-H-H+-~-~---f-.-.-t--H---H--H--H ...... U'+?--i--'?'-t:'?-'t ...... '-'.,-~,..' ....... '-'.--'.~ ...... ~---?+.F-?..f'..~.+' : : : : ~ : : : : ...~...~...~...:..~..,..~...~...? -..~.4-.4...;...J..4.--;..;...~... ......... hr! .......... ...,oSe..~...~...~...i.!..i;i ................ :!~'"i"'H'"i:!::.. ....'. . ============================== ...~.-.=,-..,..-,-~..+..~.-.~.-. . . : : ~ . ; : : : t'"r"T"f'"? .....7'"T'T'T"7'?'"T" ~ ' ~ i ! :}' .~:':.: . . PROJECTION ON VERTICAL PLANE OF AZIMUTH 200 SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT 1 -WELL: 2D-13 ~_... SURFACE LOCATION' ,.~2' FNL 144' FEL S26, T11N, R9E, . HORIZONTAL PROJECTION NO~TH lO00 REF ~9~;~ SCALE : l/lO00 IN/FT : ~ ~ ~ ~ ~ ~ ........ ............... ---b¥-HHt---i---.~-.;----} ....... -? : : : ' : ' ' ; b-;.-~ ' ~.~.~ ; ~ ~ ~ i I ~ ~ ......... ~ ~ ~ ~ i ~ : ~ ........ - · : ~ : ; .' ......... ........ ~ ~ : : i ' : : ...~..;..t..., ~...;. ; .... - . - 0 ......... t"t"i"-?'~ ' ~ t l ........ .......... ~...~...~...~...~...,...~... ......................... ?'-? ....... I I ...... ~ ...... ?'"?7" m~--'~--'i"-?-'-?'--~-'- -x-?. -r "r'-'~---7 ]'--: --- -!-'-~---! ........ ~'-'~---~-'-i-'-~-'-~'-'~'"7"t ........... s ........ l ........ ~ ........ ~-' k'": ................. i ....... : ........... ~ .................. F'": ............ ~"'~' ': ...... ~ ..... · ......... ~'"~ .......... ~ "~" 1 --=---~-.~ ....... ~.-4 ...... =..~ ...... ~.-~..-~ ...... ~ ....... ~-.~...~ ..... ~...~...~...~...;....=..~...~...~...H~...~...~....~...H.~...~..~...~. ~ - ~ ~ i ~..> .... ~---~---'~---~---s ...... + ....... ~-~ · ~' ~ ~ ~ - · ~ ~ '..~ ..... ~ --~---~---~----~---i---~---~---~ ....... t-++++--bH---~-H---H-+-?~ ....... H-++-.b,+--H.-.b~...bb~-.-~ ....... ~ ....... ~ ..... ~-..~ ....... ,.,++.+-, ................. ~...~...~ ....... ,..~ ...... ~ ............. ~. ~...~ .... , ........ -, ---;- --;----;-- ~ ;'----:-----~----¢---~-,.., ;- -;----7-<----H-~-----~---;----~-~---~--b-~----~---~---+--;----;----¥-~--.;;,. -~ , . : , . , . . , . ] .'-"-~'--'b-}---'b"='HH<'---'L*" ;.. <-...:....~....:....:....~..,: ..... .~...~ .............. ;... L.:...' ,.:. ~: ..... ::"' ....... ~...'..... ' ..... . :...~ ..'. : .... "~'"? ....... ~'"~'"~'"~ : , . ',' ........... :'"'. ...................... f---t--t .............. t---t-'-~"'?"~ ............... ? ...... ? .............. ~ ..... t .............. ;--? ........... f ................... · ....... f ..... ~...: ....... ~ ....................... '"?"5i ....... * ................ ~"-{ ....... ; ............ ~ ....... ~---*-..H---;---;---~---;---H;-.-;-L;---b;---H---;-4---;---~---;---¥-~---+ ....... ;...H...;...z. LL~ ....... e---; ...... ¢-.-; ........... ;..-~...~ ........ : ....... ~ ................... i ................ : .................. ;...~ .... ,,,. , .... , .... ., ~-%T~--~-'~-~'~-i-~4-~'"~ i ; ; ~ ~ I ~ ~ ~ ~ ~ ; ', ; ; ~+~---L+'-b'~--~"H'~-: .... ~--4 ............. :'-~ ................... ~---~--~ ........... ~ ................. ~ .................. ....... .... ............... ...... ..... ....... ...... L..L.] ....... ,--.~--.~---~-..~--~ ........... ~.-..:...-¥-~ ....... ~...~...~...~...~...i..~...~...~...~...~...~...~...~...~...:...~...~...~...~...`...~..~...~...~...~...~...~ ....... ~...~...~ ....... ....... ~...~ ....... ~...~ ....... :..~ ....... ~ ...... ~..~ ..... ~ ,..: ....... : : : : ~ ; , ~ : ; i ~ - ; i : . . ~ i : : : ~ ~ ~ ~ : : : .... ' · ' ; . I . . i ' ' ' i , . ' ..L.L.:..:..~ ........ ~..~ :..~...~ ....... L..~...~ ~..L.L.L.L.L.~.-- - l~ ....... L.;...~...L.L.~...L.L.L.~.]. ~ .~ ~.~ , : ~ ~ - ~ l..: ...... ~.:.. :. i ...... :. - . :.-i... : : ..... : ] . :. ~ ~. ~ ~ , . ~ ~ ! ~ - : · .~ - - ( ~ I ~ - ~ ~..~. L...,. L..~..~ : ~ ~ ~: L - ~ : - : : : . .. : ~ . : - : . · I .... ' ' ' .' i ........ ~ I - ........ ,..1,..1t ........... ?.l,1..~ ................... !'''' ....... ' ....... *','--'--:'--','--,1--1~ .................. , ................... : ................. ~ .................................... ' ............... , .................. ~ ....... I : . . . I : - : : : : . - . : : : : : ~ : . : . - . : - ] . I : . i . : : . . 1 1.~...l~..~.., ~l.~.~.lll~l...,ll~l.1,..: ¢.ll~lll~l.ll~ll.l~...?;1.'.l.~lll~..l~lll~lll~l__Hl.~__H.~ ''''''''~' ~...~. [l'~''~l''H''~ , ....... ,' ' ', .... , .......... ~'ll'~ ........ : ' .' ~ ..... ; , ~ ......' ' lll;lll;----l~l----;1----p--:--l--;--'.:.'l.~lll~ ............ :':';'''b''L;'l';lll; ...... :'';''4''l;''l~ ........ ;l--l;1----; ...... ~----; ........ bl~ ....... :Il':''': ........ ;'4 ...... ~llll:l----: ....... ;l''~''':'l.: .......... hil'll;lll;'Z''lL1;''l;''LIL'~'lL'Zll;l';'~l'L1;'';l';ll ;1;1 ;l'~ ,o~,, -~ooo ........ ;'--'~--'-;---i--~'----~--~-+-b----~--~' ........ i---' ........ ........ t'"~'"'~'"; ~"i'"'~'"':"':'""~'"t'"?"':'":' .... i'"~ .... :' ..... t ...... ."~'",'"~ .... :'.":' t '"" ."i ...... -?000 -800g -BOO0 -4000 -9000 -2000 - 1000 0 1000 NEST E~ST m ' Suggeste'~'7orm to be insertcd in each "Ac'-~-~.,e'' well folder to d%eck for timoly ce~liance with ou._ ~'c~:julatiorm. Operator, ~eli Nam~ and Numker Reports and Materials to be received by: l' _ Required Date Received Remarks · _-- , · Ccmpletion Report Yes ~.. .. ., , ~. __t'__e .LWo11, History. Yes ~ --/~&5'~'.. " ~_ ~'~-~:~L · · · Core Chips '' Core Description /~Fg~?~ ..... ....................... ' (/~//~ · Registered Survey Plat ~ · ,. Inclination Survey · Dril 1 S ten Test Reports ~-.~' .~ ,~./ ~ ~ - _ . ~ - __ __ ., ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 14, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports - December, 1984 Dear Mr. Chatterton- Enclosed are the December monthly reports for the following wells' DS 6-11 (Workover) 2C-15 1Q-12 DS 11-12 2C-16 2W-9 DS 11-15 2D-13 2W-10 DS 15-16 (Workover) 2E-10 2W-11 DS 15-17 (Workover) 2E-11 2W-12 DS 17-13 2E-12 CPF-1A DS 17-14 2E-13 WSP-3 2X-9 2X-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L68 Enclosures RECEIVED JAN Al~asi~a uti m Gas Cons. C~mmiss~ Anchorage ~Dm'~ A~o~b~, iff,- ;= ~ c~,,h=irlimrv ~f AllanticRichf|eldComDany ~-~.. STATE OF ALASKA ALASKA C,_ AND GAS CONSERVATION CO~,..¢IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~X Workover operation [] 7. Permit No. 2. Name of operator ARCO Alaska, Inc. 84-12 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21070 9. Unit or Lease Name 692' FNL, 144' FEL, Sec.26, TllN, R9E, UM Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.} I 6. Lease Designation and Serial No. 127' RKBI ADL 25658 For the Month of. December 19 84 10. Well No. 2D-13 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2015 hfs, 12/02/84, Drld 12-1/4" hole to 3317'. Ran 8-1/2" hole to 7626'TD as of 12/09/84. Ran OH logs, Ran 7" csg, Displace 7" to brine w/diesel in 9-5/8" x 7" annulus, Secured well 12/11/84. 9-5/8" csg. Drld PBTD is at 7510'. & RR @ 1300 hfs, 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ¢ 110'. CIP w/187.5 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/FS (~ 3297.'. CIP w/800 sx AS II I, 450 sx Class G & 150 sx AS I (Top Job). 7", 26.0#/ft, J-55, BTC csg w/FS @ 7593'. CIP w/450 sx Class "G" cmt. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR/Cal/FDC/CNL f/7600' - 3298' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· RECEIVED JAN 1 5 19 5 Al~_ska Oi~ & Gas Cons. oommissi(~ A~cb0ra0~e · ' , ' i-14-~-" SIGNED }'~-.' ~L.J.. ~./~/' DATE TITLE As sec'.' ate Engineer NOTE--Report ~j~ 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. Submit in duplicate · ' ARCO Alaska, Inc. ~-~ Post Office L ,360 Anchorage, AlaSka 99510 Telephone 907 277 5637 RETURN TO: Date: 1/.%0/85 Transmittal No: 4965 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 chorage, AK 99510 · itted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS TAPES .Schlu_mberger . ~/69857 2D-13 12/10/84 Run 1 3283 - 7548 (Computed 1/07/85) ~/69762 2E-15 11/17/84 Runs 1, 57.5 - 6956.5 (Recomputed 1/07/85) 3 /cat DISTRIBUTION B. Currier D~illing W. Pasher BPAE Geology Chevron Mobil G. Phillips Phillips Oil Sohio Union D & M NSK Ops. J. Rat~mell Well Files ARCO Alaska. Inc. is a subsidiary o! AllanticRichfieidCom,~anv MEMORANDUM State of Alaska ALASKA OIL AMD GAS COMSERVATION COMt~ISSION TO: Chai~d'--- Lonnie C. Smith ~./' [~' Commissioner FROM: Doug Amos -~-:' i<~:_~.i-- SOSJECT: Petroleum Inspector DATE: December 21, 1984 FILE NO: D.41.46 TELEPHONE NO: Witness BOP Test at ARCO Kup. 2D-13 Well. Sec. 26, TllN,R9E, UPI, Permit No. 84-12 on Parker Rig 191. Wednesday, December 5, 1984: After witnessing the BOP test at parker Ri~N0-, .... i41,"I traV'~led to Parker Rig No. 191 to witness the BOP test there. The BOP test commenced at 7:30 pm and was concluded at 9:30 pm. There were no failures and I filled out an AOGCC'BOPE Inspection Report which is attached. In summary, I witnessed the successful BOP test at ARCO's Kup. 2D-13 well. At t acP~nent 02-00IA(Rev. i0/79) O&G '~4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date Well Operat~~ -~_P Representative ~~ ~-~A~ Well ~'~L/A2 ~ D--/~ Permit # _~ -/~ Location: Sec ~ T//~ R ~ M ~/,A//, ~ Casing Set @ ft. Drilling contractor ~/~/C~_~ Rig # /~/ Representativ~ /-/~5/ /~ ~/~- Location, General Well Sign. General Housekeeping . Reserve pit '~/~ Rig BOPE Stack Annular Preventer Pipe Rams ~ L~ g2 Blind Rams ~ Choke Line Valves~.~.~ H.C.R. Valve ~ Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure ~Oe20 psig Pressure After Closure /l~¢p~ psig 200 psig Above Precharge Attained: / rain ~ sec Full Charge Pressure Attained: + min ~)sec / Controls: Master 0 ~ . Remote ~ Blinds switch cover ~ Kelly and Floor Safety Valves Upper Kell~ Lower Kelly Ball Type Inside BOP Choke Manifold ! No. Valves /~ No. flanges ~ Adjustable Chokes Hydrauically operated choke / ~'Test Pressure / ~est Pressure / ~'Test Pressure / ~'~Test Pressure Test Pressure l/ Test Results: Failures ~_.)~.,,,./~-~. Test Time ~ hrs. Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks .. days and Distribut ion orig. - AO&C4~C~ cc - Operator . cc - Supervisor InsPector ARCO Alaska, Inc Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2D Pad Wells 1-4, 13-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L25 Enclosure RECEIVED ~!aska Oil & Gas Cons, Commission Anchor~[/e ARCO Alaska, Inc, is a Subsidiary o! AtlanlicRichfieldCompany CONDUCTORS !-4 t~ 13-16 ;..OOATED IN PROTRACTED $1[OTION TOWNSHIP i! N, RANGE 9 E,, UMIAT MERtDAN.. -41as/<a Oil & Gas Cons. DRILL ;ITL 2. D CONDUCTORS AS- BUILT LOCATIONS WELL 1 Y --5,954,045,13 Lot, 70~17'07.882. Z'' 529, 129.90 Long. 14cJ~45'51.2{~8'' [§:~' FNL, 636'FEL EL.. 89.7 ,QC~ 86.1 WELL Y = 5,954,089.31 Lot. ?0°t7'08.:~185:' X = 5~9~089.24 Long, 149~45'57,.458'' 109' F NL, 677 'FEL EL. 89.6 , 0.0. 86.3' WELL 3 ¥ = 5,954, t:~3.42 I. at. 70°i7'08.7=~55'' X= 529~048.58 Long. t49°45'53,648'' 65' FNL, 717' FEI. EL. 89.7', 0.$. 86.1' WELL 4 Y= 5;9§4,177.47- Lot. 70°{7'09.1880" X= 5?.9,008.09 Lo~g. 1~,9°~,5'54,8?,2'' 2l' FNLz757'FEL EL. 89.~J, 0. G. 86.$ WELL 13 Y = 5,955,508. ~ Lot. 70° 17'02,5842" WELL 14 X= 529,624.74 692' FNL, ~44' FE:L , Y · 5~953~55Z X = 5Zg~ 584.2?. 647' FNL, 184' ;EL Lor~. 149°45 (36.932" EL. 89.6~ O.G 86 8' Lot. ?0° 17'03.0204" Lo~'~. t49°45'38,108'' EL. 89,8', 0.$, 86 8' WELL 15 ¥: 5,953,596.78 Lot. 70~ [7 ' 03 .4564'' X: 529~5415.57_ Long. 149°45';)9.287'' 60;5' FNL, 225' FEL EL. 89.6', O.G 87. I' ~-~LL-i~', 5,955,640.81 Lat. 70°17'03.S9~0'' X = 529,503.~ L~g. 149°45'40.464" 559'FNL~ 265'FEL EL. 89,5', 0.G.86.5' AS. B.U ILT tS ~NUMEN~S 2D NORTH ~ 8DSOUTH PER L~O ~AS~. ~ ELEV. TAKEN AT TOE OF PAD~3.W. OF WELL. , , , DAVID F~LUCCI 527S-S Dote~ Jonuory~ ~9~4 Sc~le~ 1"=400' S -D CAT~ O~~ J.B, ~ ~.n~N~ 9.05~t July 3, 1984 Mr. J. B. Kew in Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-036 Re: Kuparuk River Unit 2D-13 ARCO Alaska, Inc. Permit No. 84-12 Sur. Loc. 692'FNL, 144'FEL, Sec. 26, TllN, R9E, Btmhole Loc. lll2'FSL, 1394'FEL Sec. 26, TI!N, RgE, L~. Dear Mr. Kewin: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated January 18, 1984, accompanying the original approved permit are in effect for this revision. Very truly yours, Lonnie C.( Smith Co~ssioner of Alaska Oil and Gas Conse~ation Co~ssion be EnclosUre cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. ARC-O Alaska, Inc. Post Office b,.,,~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 19, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2D-13 (Revised) Dear Mr. Chatterton- Due to a change in the bottomhole location, an application for 2D-13. Enclosed are: ° A revised application for Permit to Drill ° Diagrams showing the proposed horizontal projections of the wellbore o A proximity plat o A diagram and description o A diagram and description Since we estimate spudding earliest approval would be If you have any questions, AS~~erely' ~. ~~ Engineer JBK/JG:tw GRU8/L04 Enclosures we are resubmitting Kuparuk 2D-13 and vertical of the surface hole diverter system of the BOP equipment this well on July31, 1984, your appreciated. please call me at 263-4970. RECEIVED Alaska 0il & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' STATE OF ALASKA ALASKA ,,..,iL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL I~X REDRILL [] DEEPEN [] lb. Type of well 2. Name of operator ARCO Alaska, Inc. 3. Address EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 692' FNL, 144' FEL, Sec.26, T11N, R9E, UN At top of proposed producing interval 1394' FSL, 1293' FEL, Sec.26, TllN, RgE, UM At total depth 1112' FSL, 1394' FEL, Sec. 26, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 127', PAD 90' 6. Lease designation and serial no. ADL 25658 ALK 2584 SERVICE [] STRATr~iRAPHIC L_~ SINGLE ZONE [] MULTIPLE ZONE [~X '-"; 9. Unit or lease name Kuparuk River Unit 10. Well number 2D-13 11. Field and pool Kuparuk River Field Kuparuk River 0il 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 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi, NW of Deadhorse miles 692' feet i. Sak River State #3 4407' (~ surface 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7662' ND, 6197' TVD feet 2560 07/~1/84 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2758 psig@ 80°F Surface KICK OFF POINT 1770 feet. MAXIMUM HOLE ANGLE 45 oI (see 20 AAC 25.035 (c) (2) psig@ 6057 ft. TD (TVD) 3095 21 Proposed Casing, Liner and Cementing Program SIZE SETTING DEPTH QUANTITY OF CEMENT Hole Casing i24" 16" 112-1/4" 9-5/8" Weight 62.5# 36.0# 7" 26. O# 22. Describe proposed program: CASING AND LINER Grade Coupling] H-40 Wel ~ J-55 BTC/ H F- E RW J-55 BTC/ HF-ERW Length 80' 3265' 7634' MD TOP TVD 29' I 29' 29' I 29' I 28' I 28' MD BOTTOM TVD 109' 109' 3294' 13137' 7662' I 6197' I I (include stage data) ± 200 cf 1150 sx AS III & 340 sx Class G 400 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7662' MD (6197' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3294' MD(3137' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2758 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig using 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space ~wTCf,~yssion use CONDITIONS OF APPROVAL Samples required I Mud Iogrequired I-lYES ~JO F-lYES ~NO Approval date _ . / Permit number g~ APPROVED BY DATE Dir/~ctional Survey required APl number Es []NO 50- ~Z~7- ~_./o'70 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE~Tuly 3.. ] 9RZI by order' of the Commission GRUS/PDO1 Form 10-401 Submit in triplicate a~6 %~e. ce ace ~o 30.~5 ~ev~ _ co~9~e~'~ _.,~here ~'~ ~he ~uPar~ ~t ~h a ,' ~ ~ ~es~ed ~9°~,.,e~boreS ~e ~o9 o~ ~ ~ be ~e~ G~vo~ .~ ~oro~ ,,. .~,~, /~'-- RECEIVED JUN 2 91984 Alaska Oil & Gas Cons, Commission Anchorage . . _ - : : .... - ' : ~ ' . ~ , ~ I ~ , · ~ ~ . , ~ ~ ~ , , ~ ...... I ~~ - '~ ~ ~ .... IANNULAI~ PRE¥£NT~R 9 BLIND R~ ~D 2 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/B" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/B" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill -lines 7. 13-5/B" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ~J.L UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MNtIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HF.J~D. 3. CLOSE ANNULAR PREVENTER AND Vfl~L¥~S lJ-1)S~ 01~ C~-IO~S. DON'~T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSi AND HOLD FOR 10 B. ~.~'PRESSURE DOWNSTREAM OF CHOI~ ISOLATION VALV~S~ TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED I~UkNIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BO1FOM SET OF PIPE RAMS. BACK OFF RUNNING jOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND P,~,MS AND RECOVER TEST PLUG. MAKE SURE I~tANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSl WITH KOOMEY PUMP. 15.RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. eECEIVED JUN£ "'~,';,.'a Oil & Gas Cot/,,, 2. 3. 4. .5. . Surface Diverter System 16"-2000 psi Tankco starting head. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/10" side outlets. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. m Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify Ghat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED JUN2 J9 4 Alaska Oil &AGas Cons. Commission nchora,qe ARCO Alaska, In, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 1, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2D-Pad Wells 1-4 & 13-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG5/L155' tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' '~= DRIL'~'SITE 2. D CONDUCTORS ArS- BUILT LOCATIONS i WELL I Y: 57954,045.13 Lat. 70°17'07.882Z'' X = 529, I :>9.90 Long. 149°45'51.288'' ~ 15~' FNL, 636'FEL EL. 89.7',~ 86. l' WELL 2 Y = 5,954,089.31 Let. 70°17'08.3183'' X = 5~9~089.24 Long. 149°45~52.468" 109' FNL~ ~7'FEL EL. 89.6'~ O.G. 86.3' WELL 3 Y =5,954,13~.4Z Lat. 70°17'0~.~5~8'' X = 529~8.58 Long. 149°45'53.648'' 65' FNL~ 717' FEL EL. 89.7'~ ~.G. ~.1' WELL 4 Y = 5~954,177.4~ Lat. ~°17'09.1880" X= ~9~008.~ L~. 149045'~.8EZ" 25~ ~24 21' FNL~ 7'57' ~L EL. 89.8'~ 0. G. 86.3~ e Z-D~ X = 529~624.74 .Lon~. 149°45 ~36.952" D.S. 69~' FNL, 144'FEL EL. 89.6'~ O.G, 86 8' WELL 14 Y = 5,953,552.61 Lat. 70°1~'03'.0204'' . X = 529~584.2~ Long. 149°45'38.108'' 647' FNL~ 184' FEL EL. 89.8'~ O.G. 86.8~ , , , WELL 15 Y = 5,953,596.~ Lat. 70°17'03.4564'' X = 529, 543. 5 7_ Long. 149o45'39.287" 603' FNL ~ 225'FEL EL. 89.6'~ O.G. 87.1' , , WELL 16 Y= 5,953,640.81 Lat. 70°1Z'03.8910'' X= 5~9~3.00 Long. 149°45'~.~" 559' FNL, 265' FEL EL. 69.5 ', O.G. 86.5' i i i i i i i CONDUCTORS I-4 ~ 13-16 AS- BUILT ~~,-..,.. ' ~..-'~ A-' LOCATED IN PROTRACTED SECTION ~6 BASIS OF ELEVATION IS TBM ~D-12~ BASIS OF ~O~Y~ IS ~NUMENTS 2D NORTH ~ ~D SOUTH PER LHD ~A~OC. ~ ELEV. TAKEN AT TOE OF PAD,S.W. OF WELL ...... ,LUCC s S-s i U~~ ~ ~T1CE LAND SURVEYING IN THE ~ATE OF ~ ~~ · ~AT ~IS ~T RE~~NTS .A SURV~ MADE 22 ' ~3 ~ 24I~ ~CT AS OF JANUARY 25 1984 i ~~ ARCO A~ska, Inc. : Ka~ruk ~oject N~ Slope Drilling .s. ~-, ~~H~TO~ ~8- ARCO Alaska, Inc.' Post Office b,~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 19, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2D-13 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on March 15, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ~~<g E~ngt'neer JBK/GRU5L135'tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... ALASKA _ .~ AND GAS CONSERVATION C[ ~IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 2. Name of Operator ARCO Alaska, Inc. DRILLING WELL [] 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 692' FNL, 144' FEL, Sec.26, T11N, RgE, UN COMPLETED WELL [] OTHER I~X 5. Elevation in feet (indicate KB, DF, etc.) 125' RKB 6. Lease Designation and Serial No. ADL 25658 ALK 2584 7. Permit No. 84-12 8. APl Number 50- 029-21070 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2D-13 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ ~,_ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note' Report multiple compietions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 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). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2#/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within ~ the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. EStimated Start: March 15, 1984 .... '~ "!' ";~'~ Date 14. I hereby c,~Miify that the foregoing is true and correct to the best of my knowledge. Signed Title The spac~l~f~'g C~ m ,ssio s ConditiOns of APproval/ ', if any: ' BY 1.§~,"ilE C. $1111Til Approved Copy Returned By Order of COMMISSIONER the Commission Approved by Form 10-403 Rev. 7-1-80 GRUS/SN75 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate January I8, 1984 Mr. Jeffrey B. Kewin Are Drilling Engineer ARCO Alaska, inc. P. O. ]~ox !00360 Anchorage, Ata~ka. 995!0 Kuparuk River Unit 2D-13 AR. CO Alaska, Inc. Permit ~!o. 84-12 Sur. Loc. 692'~?~rL, 144'FEL, Sec. 26, TI!N, R9E, 1~4. Btmhole Loc. ll41'FSL, 1400'FW~, See. 25, TllN, R9E, UM. Dear Mr. Kewtn: Enclosed i8 the approved application for permit to drill the above referenced well. If coring t~ conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional ~urvey is ~ 5) i!able, a tape required a~-per 20 AAC ~5.050(b)( . If ava containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dtpmeter ~urveys. Many rivers in Alaska and their drainage systems have been clas~ified as important for the spawning or migration of anadromous fish. Operation~ in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Ala~ka Ad~ninistrative Code). Prior to commencing operations you may be contacted by the Hah{tat Coordinator's Office, Department of-Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Adminlstrative Code, ~%apter 70) and by the Federal ~ater Pollution Control Act, as amended. Prior to commencing operations you ~a~ be contacted by a representative of the Department of Environmental Conservation. To aid us in schedul!n~ field work, please notify this office 24 hour's prior to commencing installation of the blowout prev~_.ntion. Mr. Jeffrey B. Ke~a -2- January !8, !984 Kup~ruk River Inlt equip~nt so that a repre~mtat!ve of the Commission may be present to witness te~ting of the equl. pmemt before fha surface casing shoe is dr!.!!ed, %~ere a dlverter system is required, please a!~o notify this offzc~ 24 hours prior to co~menctn~ ~quip~nt installation so that the Cor~nlssion ~ay witness testin~ before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give thi~ o,~ce adequate advance notification so that witness present. Very ~ruiy yours ~ C. V. Chatterton Cha!~an of By OfiD~ O~ Alaska 0~1 and Gas Conservation be Enclosure ec~ Department of Fish & Game, ;{abitat Section w/o ,~e! Department of ~nvironmental Co~ge~zat~on w/o eno!. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 10, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2D-13 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2D-13, along with a $100 application fee. Diagrams showing the proposed horizontal and vertical projections of the wellbore. A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment.. Since we estimate spudding this well on January 27, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. ng' Engineer JBK/JG5/L110'tw Attachments Ar./,;hom. qe ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany r.STATE OF ALASKA ~. ALASKA ( : AND GAS CONSERVATION CE :MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC L_~ DEVELOPMENT OIL ~ SINGLE ZONE []XX DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operr, tor , ARCO Alaska, Inc. ,. ' 3. Address :- : '' P. 0. Box 100360, Anchorage, Alaska 99510 9. Unit or lease name 4. Location of well at surface 692' FNL, 144' FEL, 5ec.26, T11N, RgE, UN At top of proposed producing interval 1381' FSL, 1293' FWL, Sec. 25, TllN, RgE, UN At total depth , 1141' FSL, I~-drOO~ FWL, Sec. 25, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF etc.) t 6. Lease designation ~l'~d serial no. RKB 125', PAD 89' I ADL 25658 ALK 2584 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 Kuparuk River UnYt 10. Well number 2D-13 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 14. Distance to nearest property or lease line 1141' West Sak 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7493' FID, 6169' TVD feet 2560 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1000 feet. MAXIMUM HOLE ANGLE 40 15. Distance to nearest drilling or completed River State #3 @ surface 4407 feet 18. Approximate spud date 01/27/84 2694 20. Anticipated pressures psig@ 80°F Surface o (see 20 AAC 25.035 (c) (2) 3095 psig@ 601~ ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole I Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) i I 116' ± 200 cf ~4" 16,, 65.5# H-40 Weld 80' 36, I 36, 116'I ~2-1/4" 9-5/8" 36.0# J-55 HF---RW BTC 3484' 35' 35' 3519'I 3133' 790 sx Permafrost E & ~ J 250 sx Permafrost C B-1/2" [7" 26# J-55 HF-':RW BTC 7460' 33' ~ 33' 7493'16169' 293 sx Class G annulus of this well. The 7" x 9-5/8" -in the disposal process. 22. Describebroposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7493' MD (6169' 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 BOPE stack will be installed on the 9-5/8" pipe. it will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2694 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 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Completion operations with the workover rig will be covered under a separate sundry notice. 2D-13 will be 4407' away from West Sak River State #3. There are no other close wellbores anywhere downhole. Reserve pit fluids will be disposed of down the 7" x 9-5/8" annulus will be left with a non-freezing._ fluid during any interruptions . The spac/~iohr'~use Samples required I Mud log required []YES []NO i []YES [-INO Permit number TITLE Area Drilling Engineer CONDITIONS OF APPROVAL i Approval date Directional Survey required []YES []NO APl number 50- 029-21070 APPROVED BY Form 10~401 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE January 18, 1984 by order of the Commission Submit in triplicate ^RCO- ALASKA, - -~--- t .... ~ ........................................ looo ~n~'~n,,~nnnirMn- nnn m¢~-n - , ..... ! ........ T ........... ~ .... [ ....... T ........... ~ .... ~ ~ ~ ~ [ .._~ ~ ' ' : i __L ............... ' ........ I ...... ~ .......... '-- -' Maintenance & Operation Upon initial installation close annular preventer and verify thai; ball valves have opened properly. . Close annular preventer and blow air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is 'detected. If necessary, manually over- ride and close ball valve to upwind diverter lineo Do not. shut i_~n well under an~, circumstances. ~ Surface Diverter Ssstem 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell ~nipple. 16" Conductor Maintenance & Operation ~- l~ Upon initial installation close annular I preventer and verify that ball valves ) . have opened properly. I 2. Close annular preventer and blow air ~_. . through diverter lines every 12 hours. 3: Close annular preventer in the event 16" Conductor Surface Diverter System 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool .w/10" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell ~nipple. that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do' not. shut in well under any circumst'ance's~---'-' 13-5/8" 5000 PSt ~SRRA BOP STA'CK , TBG · 'CSG · . . . . 1. 16" Bradenhead 2. 16" 2000 PSI x i0' 3. 10" 3000 PSI tubing head 4. lO" 3000 PSi x 13-5/$: S.SOO PSI adapter spool 5. 13-5/8" 5000 PSI pipe ra~s 6. 13-5/8" 5000 PSI drilling s-pool and kill lines . 13-5/8" 5000 PSI pipe_ rams- .-__ 13-5/8" 5000 PSI_blind m,,~s -- -, 13-5/8" 5000 PSI anr=lar ' Jo Ye 3'%3 FSI c=_sing head w/choke _ . ACCI~.IULATOR C. APA£ITT TE. ST _ . . _ . . o _ ~'~IEC'IC ~,1) FILL ACC~%rLA,TOR ~'~ WITH HYDPJULIC ~ID. 1-500 PSI ~m~~ ~= ~r~ ~~R. ~S~VE TIME Th~ ~LY ~ND RECOPJ ~ T~ ~ P~~ ~z~I~ ' OFF. ~IT IS 45 SE~{~ ~I~ T~f ~ l~ PSI 13-5/8' EO? ST2-..~.( TEST FLLL BOP STAC~ A:~ M;.NIF-OLD WITH ~'I~ S~T ~ S~T I~ ~~. ~N SC~S IN H~. ~E ~'L';U~. PR~;~R ~D C~ Y~V~ 0N ~jT ALL C~4~S TO INC~E PR~S~ TO l~ ~I ~(D lO MINUTES. B~ED TO ~0 ~I. PIPE ~J. I~;~E-PR~SU~ T0 ~ ~I' A';D ~E V~V~ DI~r ~~ 0F V;!Y~, IF ~;Y, RI~ ~VE ~iO Z~m~ PSI ~~. TO ~ PSI. - _ ~1 TOP S~ OF PIPE S~ ~ PIPE ~N~. I~E~' PRESSUP~ TO 3~ ~ ~J~D M[!~T~. B~ED TO ~ PSI. ~" .~D TEST TO B~ED TO ZERO PSI. ~ ~iIFOLD ~',O LI,~ ~ ~ T~ ~iDP I PE T~ ~Y ~ P~ TEST I~;F~TI~I T~T FO&N SIG~ YI~. : o - J J-b/fY' bUUU Fbi 'KbKKA SUP S IAC)L 'F--1 I RNNUL~R '1 . _ .) C , ) ..,-., ¼ BLIND RFtH$ - -. 8 '¸ 7o - . _ _ . PIPE RRRS ( L-) .( ) P iPF_' RRM$ CSG RD 2- -- _ i .- . 10.- ---..~--. ....' _-. :~-~_:::~'~.::':j!:i:~ 14.. 1. 16" Bradenhead 2. 16" 2000 PSI x i0° 3. 10" 3000 ?SZ tubing head 4, 10" 3000 PSi x 13-5/5:5.S00 PSI adapter spool 5. 13-5/8" 5000 PSI pipe ra:s 6. 13-5/8" 5000 PSI drilling s-po~l and kill lines 13-5/8" 5000 PSI pi~e'ra~s- 13-5/8" 5000 PSI_bli,~d r-~ -- . 13-5/8" 5000 PSI anr~lar · FSI c~sine head w/choke . _ . _ . ACCL~-IULATO;~ CA,?g£ITIr TEST _. ._ .- 1. L'~IEt~ A~,'D FILL I_~'El~ WITH HYDP~qULIC FUJID. 2. ASSUPJE TI~AT ACCLI.~_A¥O~ P~L~.,E I$ 3020 PSI ~m~ZT~ 1'500 PSI DO',~TP-~A,~ ~-~ 3. OBSEP, YE TI~E Th~ C~E ~ t~:iTS S~T~- ~LT ~qO RECOPJ T~ T~ ~ P~ ~I~ P~ OFF. ~IT IS 45 SE~';~ ~I~ T~E ~ l~ PSI 13-5/8' ~OP ST2~.( TEST . 1. FILL BOP STAC~ A~ HY~N[,:OI_D ~FIT'.~ ~L-'~--"IC DI~SEI.. W'I~ S~T ~ S~T I~ ~U~. ~ I~ L~ ~N S~S IN ~jT ALL ~4~S TO ~ ~I ~ ~D F~2 lO MII~TES. B~ED TO ~0 ~I. PIPE ~. 7. I);~E-PP,~SU~ TO ~ ~I' ~'~D H~ ~R lO H!~J. 8. ~E V~V~ OI~ ~~ OF ~. ' V;~YE ~iD Z~:j PSI ~~. B]~ TO ~ PSI. 9. ~gl TOP S~ OF PIPE S~ ~ PIPE ~. H!I~j. B~ED TO ~ PSI. B~ED TO ZERO PSI. ' ~ ~iIFOLD' ~'Jg LI~~ P~ ~ ~C · ~I~'l. , -. ~ ~JDPIPE Y~Y~ TO ~ ~I. m T~ ~Y ~ ~ I~I~ ~I~ ~ P~.. P~ TEST INF~ATI~I T~T FO~ SIGN ~D S~ TO YI~. - .-. . .. (2) Loc (9 thru 11) (10 and 1~) (4) Cas~ ~ ~/~ ' (12 thru ~0) (~1 thr~ 24) (6) Add: /'/~'/~ 7/4/,~ ? (2 thru 8) 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Lease & Well NO. . . YES NO REMARKS ' is the permit fee attached e®eeeeeeleleeeeeeeeeeeeeeeeeeeee®e®eeeeeee Is well to be-located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedieated acreage available in this pool Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... ... Is conductor string provided ...... ............................ Is enough cement used to circulate on co;ductor ;n~ ;urface Will cement tie in surface and'intermediate or production strings .. Will cement, cover all known productive horizons ................. Will surface casing protect fresh water zones ........ i .... i . Will all casing give adequate safet'y in collapse, tension and burst Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 .......... Is adequate well bore separation proposed ......................... F~££1" k~r~LL ~ ~0 Is a diverter system required ...................................... Are necessary diagrams of diVerter and BOP equipment attached Does BOPE have sufficient pressure rating - Test to _~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. O I-.-3 ~Z HO o3,-3 Additional Remarks: Geology: H~ ,~ J~ ---.- Engip~e~ing: ' Lcs s .w rev: 12/08/83 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, (2) .oc, , PERMITS, 1-17-$'/ (3) Admin(8~-~ (~. th.ru 11) nd 11) <4) Casg /-/ (12 thru~0)' ' (21 thru 24) (6) Add: 3. 4, 5. 6. He 9~ 10. llJ 12. 13. 14. 15.{ 16. 17. 18. 19. 20., the i' e Is' p t f e attached ................ . ......................... , Is~well, to be located in a defined pool ............................ Is well located proper distance from property line ................. Is well located proper distance from other wells ................... Is sufficient undedicated acreage available in this pool ........... Is well to be deviated and is Well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day, wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...e.....o..........ee®....e..m...®e-. Is'administrative approyal needed ................................... 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 ....................... Will alI casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. ..,. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... · 21. 22. 23. 24. 25. Is a diverter system required ................................. Are necessary diagrams of diverter and ~8~'e~ulpment attached· . . 'Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. REMARKS · Additional Remarks: 0 Geo logy: Eng~e.~r ing: WVAjAL J~ HJH ~--~ rev: 12/08/83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information, L,~S 3 ::. ,R V :. C ' N A t,;;: ' --,2 "T 3R'G-N ..... :~T 'NjATZ3N ,~ : )L PR 'V-&uS T~P- ' :C S ,~;I ~i ,"' N T S ZN C TY?~ O 3 C 000 030 GO0 C~T2 015 Ol 2 T'-- L'G$:,-Z.2 t"J ~'SC ,S.'~ _. ,.,-'~; ._- ~ ~ -- .~ -_--. _- -_- --__ _--. ~ --__ _- %- __- _- -. ~.: .- .,_ _. -. _ .- ........ ~. ........................... ~ 9~TU.",,t SF 'C ':F "C STSC.', -2.-). £137 3i-T 73,33. 3338 .~=, SP' -32,.7530 i,iP ~ ~'+ ':~. 6'.3 ~ -.3 ~:.., .:, ~..; db,PT 7 / 0.'J. '3 C00 RHS:5 ,:. 3,J, ~",. 3 ~ P 'T '730 J. O0 'J 0 S "" ,r,.. u SP -3~ ~: 03 i.) 5R 'N P :.d 1. - -) '5 .~, 2, ;~ 0 O N C N L ,3 F"P T 5~U).00CU 5F_U SF -_:5.0033 ,S& m P ,n ' - :~ S' '? ,. Z 50 0 N C ','i L 3 ~ !~ T .'.:, 70 3 · 3030 S F, ,L U S P -,-,,, ,.,,.., 7 ,:.,, 13 S & NPh.. '-')'~ ~.£530 NCNL .5. C'7 : 2 : L-, Z. 3.~.L,5 O. l,~ -7,,: !,q .:,T 9,'+. ~375 SR ,".PS b. 0000 FOmL LZl.l,2~O 'JR 0 ,. 0 ':J 77 ,N R ~ T /533.0000 FC '~L - q 99. Z 5S 0 .',':C NL iz3,.,~375 .Sk -9'99,.2~00 FC,NL 91i.'50'30 3.3770 os. 5o5000 i21.5~25 .49o.7500 .LZi. ZZSO 3,1582 ,~ o ,.-' . 5000 -99 ) . Z 530 '-'~9'9.2'5'00 ,2 A ,_ £ ,.<NRA [ l ,"I ~R N ~ A C A ,U i ,R N ;~ A C~ _! RN 'k A i L ,'4 R N R ,~ i 7.572 =.710'4 i. 79 3.'7793 S..i .,5 i" ,L 734 '¢. C, '? :, i -99 ~. 2~Ou 1 C. 11 72 -99 ::,. Z6 dO 3.3 ;5 .. '9 2~ i .? T S P :;,nCc :~P nl SP DF_PT NPni 3E?T ~P ~P N P .m i 3EPT N P n_ D~F T 3 ! P T .L. 2547 1 t+ .... ? ' ' 3 ~ o 2 3 ' C 3.6074 13~.3135 - ~S' ~ . Z 5 3 u - ¢ 9 ~. 2 ~ 0 ~ 5.13,:7 5.4102 ,OZ.2.50O Ii.7, :3'750 ~ i .~ .... o ,2 S 0 -,- ~ ~' ~ ,. 2.5 0 0 ,,:C "~ - '- ,... ] i'~.R A T "-" C 'i' L., :',~ R .:, T ':= C N L 3R r'~t ,R A T iL" N R A T F C :'~ L NR 4T FC ,',~ L ¢~'F~ A T ~C NL LL F 3, :"~,~_ " ~; ~ I ~ L I L 3 ;,, R: - 9':.) :~. £.olS~ YLr, ~2~.12SC CA,l -'~'~ ~. 25 JO 3.4277 ~L:~ S · 5 7 :~ 2 £ L ", i ;,2..J'75 O CAL': - )9 g. L :~ '38 -'~9 ~. cSOO ,., .. ,38.5 '~ 'i L - '9 :.J '.~. 25:'0 O 3.~iJ2 ! "O ,. 5 ,~ :: 9 9. ,~c J7 - :~5 :~,. i 5 "' g. 7 $ 3 C' ,9 3 ,. 5 7 Z ':: 9..: .k ::; ,7 ~FT SP j~ F"T S? 5+8 3. u 0 J,.) 3F,.U 35 C 3. :30 :] C 5F _b - ;, ; .. 5 O '3 '2 ,: R - '3 'E; ,. :_.. 33 ' ;, :~ _ Z.7~i2 .LJ L.7.~56 LLb " :~,027 .':L3 99 .. ,:~ 2.5 O 3 R 107.375C CA,-i --9'3'3. i 5 O O "'. '~ L '77 .Z L Y, -3~3,£588 'L.". ,~ :~ '7 -+ l L 2. ,~ 5 i 4- ill ~ 5:~7:~ C~,LZ 2. 5230 ~d. ,~500 -~:99,. Z530 -~,99.Z590 E. ~,j '3 ~ iLM 99. 5 t25 ~A.Li -,. ~ ~ '.35 -,99 3.,Z530 ~2 5.37 50 C,~tl - 399 .~508 - ~ 9 ~. 2 5 3 O i 0 5,6 i .E .5 C A ~_ i -399. ZSOO RNR~ ,£ ,. ~ ,'l 3 '7 :.) E. ? T 3P N? 3c?T S~ .RH3~ D~F T S P R~:~ ~';P -~ L SP b ' ~ T SP SP RH~: NF Hi. S P RH3:~ NPmL SP NPn £ J E 'P 'T SP N P h ! O ::': .~ T .S ? - · .L 4. ~ z; 3 q n .b . - 7 ? "' "" '3 O - 'R ,37.3 ~5 5, NC NL -79.3030 SR 3~00.30 .... O SF:_L -81. ~SdO 3R .L. 'I -~ S O 3 R ;t C -E i. ;,O JO ,~',= 2. ~,b~ JRHO 3,~G0.. OOO0 SE:L:.; 4 :+. o ::'" ,9':~ 3500.0030 SFLU -S ~ · :3030 I ,o S 9 94 3 R '-t S' q. '~. ,3 b 07 f,.i C N L 3300. O02;Ct SF~_L, J,.397~ '~E~T L,L£.3O30 =C.1L 3 '-';.~' .5 ;'3, l L 3 ,67.30 ,SA l Z 7a. ,',,R AT ,'- 3i~. 8CO0 F- C :,IL 'o~c60 1C9.3!25 3.112o NR,~T ~..JC78 o_~. 75;30 -~R L3345,. O00C =CNL O,lOOl NRiT 1~65.3000 FCNL. .£. 9355 ZL,J 87. }3'75 SR 0.0850 NRAT 170.1.0000 ~Cqu ~,. 7969 9 ~. '3 ? 50 .! .: 0:3 .. 0 S 00 = C 'N t :'~ .. ,'L 2 7 0 i L 7 ,£. 75 8 0 ,,~ R ~l+.'~O'~O :5.7.1250 .I 9'.3'93'5 iL 35. E 7; 0 CA,L '1 103.31£5 C&Ll 3.5530 AN2A 575.3000 ~.0352 ZLM 83.7500 CALl 5.~727 RNRA 3.b69i log,. 9375 573.2000 ,7 ....7 ~L LO6.50O0 C~. 3.093.2 RNRA 557...50~0 8'7.9375 500.¢000 i5..2655 00.2500 ~i 3.7158 RNRA 52 9.00 O u' · ,nn.n goo0 iL~ ,~-~'~,j~ .,, 7".7580 CALl 3.'51L .:,. ~ - .:' £ 2. 5.5 9i 3. 2985 3..., .g 97 9.09.38 3, 4.S 7 5 3 ,. 2 578 !2.125.0 ,,+.. 5,25 9 9.7'9 b9 .ii 8.uOU ~.773~ 52.71'35