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Home My WebLink About182-142 , c r--oidA) S S dt Ferguson, Victoria L (DOA) From: Hunter, Lindsey L <Lindsey.Hunter @conocophilli .com> Sent: Friday,October 25, 2013 1:26 PM To: Ferguson,Victoria L(DOA) Subject: (i2E:W N--03(PTD182-142,Sundry 313-270 SW-06(PTD182-177, Sundry 313-2.8),W TA (' • : - ::, u • • 13-267), Victoria, I'm sorry I haven't sent the information on these yet. We are still trying to decide what direction we want to go with these wells. For now I guess we can withdraw the sundries while we finalize our plans and we will re-submit when the decisions are made. Thanks, SCANNED DEC 2 3 2U13 Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska DS&W 907-265-6427 lindsey.hunter(u�conocophillips.com From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson @alaska.gov] Sent: Friday, October 11, 2013 12:07 PM To: Hunter, Lindsey L Subject: [EXTERNAL]WSW-03(PTD182-142, Sundry 313-270), WSW-06(PTD182-177, Sundry 313-268),WSW- 07(PTD182-188, Sundry 313-267), Lindsey, Please send me an email to withdraw these sundries or information to finish processing. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson nalaska.gov 1 RBDMS OCT 2 9 204)\-\: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 3 0 20 13 APPLICATION FOR SUNDRY APPROVALS � � 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell (""°' Change Approved Program r Suspend r Rug Ferforations r Ft?rf orate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Return to injection 1 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Nu .er: .P t3t3'Ib ConocoPhillips Alaska,Inc. Development r Exploratory r 1-8z 9 t^ j -14/2, 3.Address: Stratigraphic r Service 6.API Number:; a0 81 P.O. Box 100360,Anchorage,Alaska 99510 50-0 9-29846.66- 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No WSW-03 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25648 ' Kuparuk River Field/Lower Tertiary(Upper Ugnu) 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): ,Junk(measured): 3992 ° 3416 - 3890' 3328' none ,i'� none Casing Length Size MD TVD Burst Collapse CONDUCTOR 44 16 80' 80', SURFACE 2437 10.75 2472' '198' PRODUCTION 3986 7 4021' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tu ing Size: Tubing Grade: Tubing MD(ft): 4 from 3334'-3712' _2867-3176' 3.5 J-55 3730 Packers and SSSV Type: Packers and SS" D( $ TVD(ft) PACKER-BAKER MODEL SC1 PACKER • MD • TV'A=2 SUMP PACKER-BAKER F-1 SUMP PACKER D' D=3 NO SSSV 12.Attachments: Description Summary of Proposal fri 13. ''ell Class after proposed work: Detailed Operations Program r BOP Sket r '—[oratory r Stratigraphic r Development Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2013 Oil r Gas r WDSPL - Suspended r 16.Verbal Approval: Date: WIND r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and corre o the best of my knowledge. Contact: Lindsey Hunter @ 265-6427 Email: Lindsey.Huntercop.com Printed Name Lin Hunter Title: Drilling Engineer Signature Phone:265-6427 Date 5/24/13 Commission Use Only Sundry Number:313_270 Conditions of approval: Notify Corn r fission so that a representative may witness u Plug Integrity r BOP T: t r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception r equired? Yes 0 No d Subsequent Form Required: APPROVED BY Approve, .y: COMMISSIONER THE COMMISSION Date: Approved application is valid for 12 months trom the date of approval. \ Form 10-403(Revised 10/2012) Submit Form and Attachments in Duplicate Q` ORIGINAL I 7`\\ ■ KUP WSW-03 - . ConocoPhillips ' Well Attributes Max Angle&MD TD Alaska,inc.. Wellborn API/UWI Field Name Well Status Inei(°) MD(ftKB) Act Btm(MB)x . 500292081700 SHALLOW SANDS DISP 41.85 2,800.00 3,992.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Confia:-WSW-03,5r720138:23:34AM SSSV:NONE Last WO: 41.01 9/25/1982 Schematic-Actual - Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 3,890.0 9/25/1982 Rev Reason:WELL REVIEW osborl 5/7/2013 ', Casing Strings 9 4 HANGER,31 Zr" Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String.. String Top Thrd 'S•. CONDUCTOR 16 15.062 36.0 80.0 80.0 65.00 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 103/4 9.950 35.0 2,471.6 2,197.8 45.50 K-55 BTC ? Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION Tubing Strings 7 6.276 35.0 4,021.2 26.00 K-55 BTC I Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...Slnng..String Top Thrd CONDUCTOR, TUBING 31/2 I 2.992 I 31.4 I 3,730.1 3,191.4 9.20 J-55 I BTC 36-80 Completion Details 7 Top Depth (ND) Top Inc! Nomi... ;;t Top(ftKB) (ftKB) (1 Item Description Comment ID(in) 31.4 31.4 0.49 HANGER FMC TUBING HANGER 3.500 3,065.7 2,652.6 36.95 NIPPLE NATIONAL JET PUMP PROFILE NIPPLE BHA 2.990 3,103.3 Z683.6 38.08 LOCATOR BAKER LOCATOR SUB 4.000 j 7 , 3,103.9 2,684.0 38.08 PACKER BAKER MODEL SC1 PACKER 4.000 SURFACE, 3,108.1 2,687.3 38.05 EXTENSION UPPER PERFORATED EXTENSION 4.000 35-2,472 3,113.8 2,691.7 38.01 SBR SEAL BORE RECEPTACLE 4.000 NIPPLE.3,066 3,115.4 2,693.0 38.00 EXTENSION LOWER CASING EXTENSION 4.000 it 3,120.7 2,697.1 37.97 SAFETYJT 2.992 3,253.9 2,802.6 37.15 SCREEN BAKERWELD.008 GAUGE SCREEN 2.992 wcA3,1 3_ _ 3,716.5 3,179.8 31.18 0-RING 0-RING SUB 1.500 PACKER,3,104 . 3,717.6 3,180.7 31.17 SCREEN BAKERWELD TELLTALE SCREEN 2.992 a 3,727.0' 3,188.7 31.13 SNAP LATCH BAKER SNAP LATCH 2.985 EXTENSION, 3,108 3,727.9 3,189.5 31.13 SUMP BAKER F-1 SUMP PACKER 4.000 SBR,3,114 PACKER EXTENSION, , • X, o' rt 3.115- Perforations& " ;.Shot Shot 1111.. Top(ND) Btm(ND) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date Dens Type Comment MI 3,334.0 3,360.0 2,866.6 2,887.5 9/18/1982 12.0 IPERF Van Guns,60 deg.phasing III 3,383.0 3,431.0 2,906.0 2,944.9 9/18/1982 12.0 IPERF Van Guns,60 deg.phasing 3,437.0 3,470.0 2,949.8 2,976.5 UGNU C, 9/19/1982 12.0 IPERF Van Guns,60 deg.phasing WSW-03 IPERF, 3,478.0 3,492.0 2,983.0 2,994.4 UGNU C, 9/19/1982 12.0 IPERF Van Guns,60 deg.phasing 3,3343,360 _-- WSW-03 3,5020 3,508.0 3,003.8 3,008.5 UGNU C, 9/19/1982 12.0 IPERF Van Guns,60 deg.phasing IPERF, WSW-03 3,3833,431- 3,526.0 3,534.0 3,022.7 3,029.1 UGNU C, 9/19/1982 12.0 IPERF Van Guns,60 deg.phasing WSW-03 IPERF, 3.544.0 3,566.0 3,037.1 3,054.9 UGNU C, 9/19/1982 12.0 IPERF Van Guns,60 deg.phasing 3,4373,470 WSW-03 IPERF, 3,573.0 3,624.0 3,060.6 3,103.0 UGNU C, 9/19/1982 12.0 IPERF Van Guns,60 deg.phasing 3,478-3,492 WSW-03 SCREEN.3.254 3,632.0 3,652.0 3,109.5 3,126.0 UGNU C, 9/19/1982 12.0 IPERF Van Guns,60 deg.phasing WSW-03 IPERF, I . 3,652.0 3,673.0 3,126.0 3,143.4 UGNU C, 9/19/1982 12.0 IPERF Van Guns,60 deg.phasing 3.502-3508 WSW-03 3,677.0 3,697.0 3,146.8 3,163.6 UGNU C, 9/19/1982 12.0 IPERF Van Guns,60 deg.phasing WSW-03 IPERF, 3 1,526-3,534 3,697.0 3,712.0 3,163.6 3,175.9 UGNU C, 9/19/1982 12.0 IPERF Van Guns,60 deg.phasing WSW-03 PERF, 3. 11,73% IPERF, 3,573-3,624 IPERF, 3,6323,652 IPERF, 3,852-3.673 IPERF, ii 1 3,6773,897 IPERF, 3,6973,712 0-RING,3,717 0 SCREEN,3,718 ,0 9_0 o � SNAP LATCH. 3,727 i : SUMP PACKER.3,728 ,_ .. TO 3.992 PRODUCTION, A • 354,021 Ferguson, Victoria L (DOA) Q ' /9'Q� From: Hunter, Lindsey L <Lindsey.Hunter@conocophillips.com> Sent: Wednesday, June 19, 2013 3:57 PM To: Ferguson, Victoria L(DOA) Cc: Wallace, Chris D(DOA); NSK FId Drig Supv; Jolley, Liz C Subject: RE: ConocoPhillips Water Source Step rate test SEAMED l- =r Victoria, Please see the information you requested below. I wanted to verify diesel was our preferred fluid for step rate tests with our field drilling supervisor before I responded, which is why you received the email today. From now on you can consider me the single point of contact for this project, I apologize for the confusion. WSW-02—PTD 182-137 1. MITIA's in 1989, 1993 and 1997 passed. Well was used to dispose of pigging fluid in 1991 and was not in use after 1991. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1710 psi on 5/9/13. 2. Plan forward for this well is to complete further investigation to see if it will be an adequate slurry injection well, this is the only well we are considering for slurry injection at this time, the rest of the WSWs will remain class 2 fluid disposal wells. Once the sundry is approved we plan to use this well to inject class two fluids while monitoring other well pressures on 1B pad to confirm that they are not in communication with this well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We are currently verifying cement bond logs of surrounding 1B wells and confirming upper shale zone confining pressures from previous modeling results. We are currently working on a plan to monitor surrounding wells while using WSW-02 as a class 2 fluid disposal well to confirm that it will be an adequate slurry injector. We plan to submit all of our results when our studies are complete and the sundry requesting slurry service is submitted. WSW-03—PTD 182-142 1. MITIAs in 1988, 1993 and 1997 passed. Well was used for pit dewatering from 1997-2001 and was not in use after 2001. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1700 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-05—PTD 182-164 1. MITIAs in 1988, 1992, 1996, 2000, 2004, 2006, 2009 passed. Well was used for pit dewatering from 1996- 2001, has not been used since 2001 but was kept current on its MITIA schedule. Well passed MITIA to 1715 psi on 3/29/12 and passed a state witnessed MITIA to 1700 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. i 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-06—PTD 182-177 1. MITIAs in 1988, 1993 and 1997 passed. Well was never used for injection. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1690 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-07—PTD 182-188 1. MITIAs in 1993 and 1997 passed. Well was used for pit dewatering from 1997-2001 and was not in use after 2001. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1735 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-09—PTD 182-196 1. MITIAs in 1992, 1996, 2000, 2004, 2006, 2009 passed. Well was not used for injection but was kept current on its MITIA schedule. Well passed MITIA to 1715 psi on 3/29/12 and passed a state witnessed MITIA to 1700 psi on 5/9/13. A step rate test was performed on this well on 6/8/13 using diesel. 2. Plan forward is to use this well as a class 2 fluids disposal well. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunter@conocophillips.com From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson @alaska.gov] Sent: Wednesday, June 19, 2013 2:16 PM To: Hunter, Lindsey L Cc: Wallace, Chris D (DOA); NSK Fld Drlg Supv Subject: [EXTERNAL]FW: ConocoPhillips Water Source Step rate test Lindsey, 2 We sent you an email on 6/6/2013 outlining the following information request for the Sundries on the WSWs: We received Sundrys for the subject wells and are requesting the following information: 1. Brief history of each well including results of previous MITs 2. Plan forward including planned MITs and step rate tests 3. Plans for hydraulic modeling prior to slurry injection We have not received this information but instead the request to Jim Regg from the NSK Drilling Supervisors was received as outlined below. Please provide the information requested to process these sundries and we would appreciate a single point of contact for review and approval of this work. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonaalaska.00v From: Wallace, Chris D (DOA) Sent: Wednesday, June 19, 2013 1:19 PM To: Ferguson, Victoria L (DOA) Subject: FW: ConocoPhillips Water Source Step rate test Victoria, Did you get a response from the CPAI town engineer on the Sundries? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace @alaska.Rov From: Regg, James B(DOA) Sent: Wednesday, June 19, 2013 10:37 AM To: Wallace, Chris D (DOA) Subject: FW: ConocoPhillips Water Source Step rate test Jim Regg 3 AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: NSK FId DrIg Supv [mailto:n1335Pconocophillips.com] Sent: Wednesday, June 19, 2013 10:34 AM To: Regg, James B (DOA) Subject: ConocoPhillips Water Source Step rate test Good morning Jim, I am emailing you in regards for permission to perform a step rate injection test utilizing diesel in our class two injection wells on 1B pad in Kuparuk, Alaska-specifically WSW-02,05,09.. We choose diesel in the event a well locks up during injection for permafrost concerns. WSW-02 =API 500292081200 WSW-05=API 500292083800 WSW-09=API 500292086800 We have intentions of installing a G&I unit on 1B pad in Kuparuk and would like to perform this preliminary feasibility test. We would assume a max bottom hole pressure of 2500 PSI based of our TVD of 2,850'-3,181' along with a current proved MIT on each wellbore. We would like to inject less than or equal to 1 1/2 time our tubing volumes to perform this test. Currently these wells are freeze protected with diesel and we do not see an issue with pushing this into the formation but do wish your guidance. Best regards, Rock Bobby Morrison/Rock Rauchenstein NSK Field Drilling Supervisors 907-659-7726 Pager 907-659-7000, 243 n 1335(a)conocophillips.com 4 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Thursday, June 06, 2013 10:20 AM To: 'lindsey.hunter @cop.com' Cc: Wallace, Chris D (DOA) Subject: WSW-02, WSW_03, WSW-05, WSW-06, WSW-07, WSW-09 Attachments: 1821640 WSWeII 05 Class II Permit Lindsey, We received Sundrys for the subject wells and are requesting the following information: 1. Brief history of each well including results of previous MITs 2. Plan forward including planned MITs and step rate tests 3. Plans for hydraulic modeling prior to slurry injection Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson(a�alaska.aov From: Wallace, Chris D (DOA) Sent: Thursday,June 06, 2013 9:59 AM To: Ferguson, Victoria L(DOA) Subject: FW: WSW Path Forward From: Wallace, Chris D (DOA) Sent: Monday, May 06, 2013 12:27 PM To: 'NSK Problem Well Supv'; Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Hunter, Lindsey L; NSK DHD Field Supervisor Subject: RE: WSW Path Forward Brent, As in the attached email, if the well status and intent of use is being changed then a 10-403 should be prepared with all relevant information. If these wells are to be used for slurry injection,then the appropriate hydraulic modeling should be performed to establish the injection pressure and rate limitations to avoid fracturing the well into the confining layers. This would then be included into the MIT test pressure consideration. The MIT you speak of should be performed to the maximum anticipated surface pressure, 1500 psi, or 0.25 psi/ft x packer depth TVD ft whichever is greater. As per Guidance Bulletin 10-002 MIT,Shut in Wells "The Commission's preference is to witness an MIT while a well is actively injecting and wellbore conditions (rate and temperature) are stable. If the well is in a short-term 1 shut-in status when the MIT is due,the Commission should be notified and provided an alternate date for testing based on when injection will be recommenced. Injection wells that are shut in long-term (undetermined when injection will restart) need not be tested until they are ready to recommence injection. In lieu of an MIT for the long term shut-in well, the operator must provide to the Commission a quarterly graph of tubing, inner annulus and outer annulus pressures." Please schedule MITs with the inspectors at your earliest convenience, to the maximum that you feel is adequate for your path forward. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace @alaska.gov From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Friday, May 03, 2013 11:12 AM To: Wallace, Chris D (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; DOA AOGCC Prudhoe Bay; Hunter, Lindsey L; NSK DHD Field Supervisor Subject: FW: WSW Path Forward Chris, As described below and with Lindsey previously,there are 6 wells that CPAI would like to perform witnessed MIT's on while the well is shut in. Currently there is no injection piping connected to these wells in order to test while injecting. The tests are to bring them current in their compliance testing and then to apply for the appropriate approvals as needed. Would this be an acceptable plan? Please advise. Please let me know if you have any questions. Thank you. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907)659-7000 pgr. 909 From: Hunter, Lindsey L Sent: Friday, May 03, 2013 10:37 AM To: NSK Problem Well Supv Subject: WSW Path Forward Brent, The plan I discussed with Chris Wallace is to use the Ugnu water source wells on 113 pad(converted to class 2 injectors in 1988) to replace the ailing 1R-18 class 2 injection well. We plan to start by injecting class 2 drilling fluids while monitoring the reservoir 2 performance, in the near future we'll be requesting permission from the state to use 2-3 of the wells for slurry injection of drilling cuttings. Please let me know if you need any other information from me. Thanks, Lindsey Lindsey Hunter Senior Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunterna,conocophillips.corn 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg _ DATE: Wednesday,May 15,2013 P.I.Supervisor efe, 7 f(7 V I 0 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC WSW-03 FROM: Lou Grimaldi KUPARUK RIV UNIT WSW-03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 3-1." NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT WSW-03 API Well Number 50-029-20817-00-00 Inspector Name: Lou Grimaldi Permit Number: 182-142-0 Inspection Date: 5/9/2013 Insp Num: mitLG130509100202 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min YP J Well T e In' Test psi 100 167s 1670 1821420 TVD 2684 • I IA 1ao - PTD WSW-C/3 TYPe Testll p - , OA 210 1 210 210 '---_ --- � 1500 100 [— SPT � g 1150 . 1150 1150 Interval LOTHER P 1150 ! P/F � ;, 'Tubing Test for possible restart..3 bbl's pumped.Good test. ,i SCAt4t4ED FEB 2 Q 204 Wednesday,May 15,2013 Page 1 of 1 • Nov ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 RECEIVED NOV 022O Commissioner Dan Seamount Alaska Oil and Gas Commission . Oil Can C crnjSSioo 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16, 10/17 and, 10/18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, / Martin Walters ConocoPhillips Well Integrity Projects Supervisor r • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26111 1A,1B,1C,1D, 1E & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date _ ft bbls ft gal 1A -22 50029221270000 1910030 SF N/A 18" N/A 2.55 10/18/2011 WSW -01 50029205370000 1801400 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 2'10" N/A 2'10" N/A 6 10/16/2011 WSW -03 50029208170000 1821420 12" 1.00 20" _ 09/11/2011 4.25 10/16/2011 WSW -07 50029208610000 1821880 SF N/A 19" N/A 1 10/17/2011 1C -170 50029231540000 2030780 19'3" 1.20 10" 09/11 /2011 18.74 1 0/15/2011 1C -174 50029231400000 2030270 7' 1.00 8" 09/11/2011 14.8 10/15/2011 1C -190 50029231360000 2030030 9'4" 1.50 8" 09/11/2011 15.2 10/16/2011 1D-08 50029220266000 1770530 5'2" 1.20 6" _ 5/28/2011 3.8 10/15/2011 1D -12 50029229480000 1990840 18" N/A 18" N/A 3.4 10/15/2011 1D-41 50029232880000 2051880 16" N/A 16" N/A 3.55 _ 10/15/2011 1D-123 50029229140000 1981700 11'5" 2.30 5" 09/12/2011 4.4 10/15/2011 1E-11 50029207870000 1820510 22" N/A 15" N/A 1.2 10/17/2011 1Y -09 50029209350000 1830520 7' 2.00 5" 09/12/2011 1.7 10/18/2011 SENT BY :ARCO ALASKA ;u~/~i~.~/CNSTIPROJ-,,,,,,.,,,,,..,..~,.,.___._____ 907 276 7542;# 11 4 8:18A~I ? ~ ,,, --:' 3:':' -~ ...... ii _,,,, _ ' ..... - ..... ~ - i MEMORANDUM State of Alaska /~~~(3\ Alaska Oil and Gas Conservation Commission TO: Julie Heusser q~ v DATE: August 11, 2001 Commissioner t. SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder /l/~r~f~)~d~, Phillips Alaska P !. suPervisor~/~ -.,-~'~, KRU 1BPad · I~.~''5 ,~- WSW-02 & WSW-03 FROM: John Crisp Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Deplh Pretest Initial 15 Min. 30 Min. ~ w~.~! wsw-o2 IType~nj.I ;~::N .... !T.V.D.I'2727I Tubi.ngl 2O0 I' 2oo' I i "I*r"~l'4 I P.T.D.l'~s2'~3~0'lYypetestI P i,Te~ ~,1.30~,' I ~='~' I 240 I !700 ,i , I I P/F I _F ~ Notes: WSW.-03 1821420 Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. NmNOT :INJECTING ~ Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Phillips Alaska Kuparuk River Field to witness the 4 year MIT's on WSW-02 & WSW-03. We attempted to pressure:test thesewells w/no success. The wing valves on the tree's were serviced but still leaked causing un-successful MIT's. PhilliPs ReP. Pete Nezaticky has requested faulty valve be blinded to allow us to pressure test these wells. M.I.T.'s performed: _2 Number of Failures: _2 Total Time during tests: 2hm. Attachments: cc: MIT report form 5/12/00 L.G. MIT KRU lB 8-11-01jc.xls 8/13/01 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser o'v~v' DATE: July 21, 2001 Commissioner ~'3~~ \ THRU: Tom Maunder Phillips Alaska P.I. Supervisor lB Pad ~,....~"~"5,''~r''~ WSW -02 & 03 FROM: John Cdsp GKA Petroleum Inspector Kuparuk River Field NON- .,CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. "w,~l wsw-o2 ITypelnj-I ' N i T-v-D- I 2727' I Tubing I 2o0 I '2oo I ~'00 I ' ' I~.te~il' 4' ,P.T:D.I 1821370ITyPet~t! S" IT~I'I~X)."I'Ca~nol '2O0 I ~'700 I ~0 I .. I P/FIE i..'. W'~;I IType,nJ.i 'N' I T:V.D. I ~ I'Tubing"l 420 I ~o,, I ,~b I ,, I,nterva, l' 4' .,~-I " ITypetestl's IT~,~,'I ~ i'~in~,! ,~,20 I !7001 ~00,,I .. I WSW-03 1821420 .... IY~'~-i" IT.V.D.! '1 T~'~n~ I I' I 'I ' I,.t~,l ~ I'rypetestl ' I T,es~.,"~I I c~,l ' ' I , I I , I "~:, I I TypelnJ. l' I T.V.O. !' I ~ng I ' '1 I I l l.te-all Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS IN J, S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= lntemal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Suspected leak on the blOck valve to the flow line would not allow us to finish the MIT on WSW-02. A definate leak on the block valve to the flow line would not allow us to successfully test WSW-03. These wells will possibly test after all blOCk valves are serviced or :repaired. jerry Dethlefs will have this done before next MIT's are performed. M.I.T.'s performed: 2 Attachments: Number of Failures: 2 Total Time during tests: 2 hrs. CC.' MIT report form 5/12/00 L.G. MIT KRU WSW lB 7-21-01jc.xls 7/23/01 OPERATOR: AFICO Alaska~ /nc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test :::' ',~ .~--~--2~----~-~' I':- mI ~,,~v-- ='~.;I' '.:....,.m ~J ' J ~,fll~ n WSW-02 ~ J N ~.. P. I ~ 3,032 7" / 26~ / J55 Ob~md initial pressure for ~ min. no leakage. W~W.~ P Pie~! 3,104 7" / 26~ / J55 FIELD / UNIT i PAD: 26# / J55 L WSW- 11 3,29.2 J 7' 1 26# ! J55 26t//J55 Kuparuk'/KRU ;~~.-~ '1:-. 1500 170 160 250 2,000 250 880 3.5 J 1500 t0:45 0 1,980 t, 880 1,880 10:00 3.5 1500 200 1960 t860 1650 100 I 9:07 1960 I J [t°°110°t100 15ooI I ooo 196o 1500 100 1660 1580 1580 TBS. IN,J. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. $ = SALT WATER INJ. N = NOT INJECTING Dislributfon: orig- Well File c - Operator c- Database c- Trip Rp! File c - Inspeclor TESTTYPE: M = ANNULUS MONITORING P =STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TP, ACER SURVEY A =TEM PERA'FdRE ~Y TEST D = Dh=FER~ TEMPERATURE TEST MIT WSW 10/0.5/97 ANNULAR FLUID: P.P.G. Grad. WELL TEST: DIESEl. ! 0.35 Initial GLYCXT,. O. O0 4 - Year X SALT WATER O. O0 Workover DRILLING MUD O. O0 Oth e r Off-ER 0.00 (Rev 9/17/96) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Type of Request: REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Operation Shutdown w Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X Other X Location of well at surface 321' FNL, 350' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 695' FSL, 401' FWL, Sec. 9, T11N, R10E, UM At effective depth 792' FSL, 489' FWL, Sec. 3, T11N, R10E, UM At total depth 792' FSL, 489' FWL, Sec. 3, T11N, R10E, UM 6. Datum elevation (DF or KB) RKB 100 7. Unit or Property name Kuparuk River Unit feet 8. Well number WSW 3 9. Permit number/approval number 82-141/8-517 10. APl number 5o-O2Cj~ 11. Field/Pool Upper Ugnu 12. Present well condition summary Total Depth: measured true vertical 3992' MD feet Plugs (measured) 3416' TVD feet None Effective depth: measured true vertical 3993' MD feet Junk (measured) 3416' TVD feet None Size Cemented Measured depth 16" 400SxAS II 10-3/4" 1000 Sx AS III & 250 Sx AS I 7" 450 Sx Class G 3437'-3470', 3478'-3492', 3672'-3712' MD True vertical depth 80' MD 80' TVD 2485' MD 2200' TVD 3992' MD 3416' TVD 3502'-3408', 3526'-3434', 3544'-3566', Casing Length Structural Conductor 80' Surface 2 4 8 5' Intermediate Production 3 9 9 2' Liner Perforation depth: measured 3334'-3360', 3383'-3431 ', 3573'-3624', 3632'-3673', true vertical 2850'-3170' TVD (total interval) ,-., ,~, ,:~,,,.~,.,~, .... Oil & Gas Cons. CcmmissJOg Anchorage Tubing (size, grade, and measured depth) 3 1/2", 9.2# BTC, 3730' MD Packers and SSSV (type and measured depth) Baker 3C-1 @ 3105' MD, Baker F-1 @ 3729' MD, No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Conversion to water injection. Tubing Pressure Prior to well operation Subsequent to operation Reoresentative Dally Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 14. 5000 BBI/da¥ 16. Status of well classification as: 1000 Service Water Inj 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of.my knowledge. Signed ,~ ~ -~/t~..,~.~'i~'t~-'~.~W..~...~JTiIIe 2/'- ~)~~~~ ~-~ Form '10-404 ~v 06/15/88 ' ~ ~ ~ Oil __ Gas Suspended SUBMIT IN DU~LIC~TE~ WEd_ ARCO Alaska, inc.~ Subsidiary of Atlantic Richfield Compan,~'-~ CONTRACTOR REMARKS iPBDT IFIELD - DISTRICT- STATE OPERATION A/T REPORT TIME WELL ,SERVICE REPORT DAYS IDATE KUPARUK OP:ER^'I'ION~ ~N~31NEERING . [] CHECK THIS BLOCK IF SUMMARy CONTINUED ON BACK ~,RC~ Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 30, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applicati'ons for Sundry Approvals. Each, is a request for permission to convert water source wells completed in the Ugnu formation into Class II water injection wells. Wel 1 Action Anticipated Start Date WSW 3 Conversion July, 1988 WSW 4 Conversion July, 1988 WSW 5 Conversion July, 1988 WSW 6 Conversion July, 1988 If you have any questions, please call me at 265-6840. Sincerely, lwood Senior Operations Engineer GBS'cp'0194 Attachments cc: File KOE1.4-9 RECE \!ED Alaska Oil 8, Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown ~ i Re-enter suspended well '- Alter camng ['i T,me extension Change approved program)(' Plugging .-7 Stimulate ~' Pull tubing Amend order ,r Perforate [' Other .] 2 ~(~ ~lOaPs~<r~t, OrInc. R~BD~t~ elevation (DF or KB) feet 3 Address 6. Unit or Property name PO Box 100360, Anchorage, AK 99510 Kuparuk River Unit 4. Location of well at surface 321' FNL, 350' FEL, Sec. 9, T11N, RIOE, UH W~.wW~ I I number At top of productive ~nterval 695' FSL, 401' FWL, Sec, 9, T11N, R10E, UM AtTegf~)qotFCLd~eptl~89' FWL, Sec. 3, TllN, R10E, UM At total depth 792' FSL, 489' FWL, Sec. 3, T11N, RiOE, UM pS. Permit,.~u,rnb~r.. erml~ ~--z~ (~-tq~, 9, APl number 029-20816 50-- 10. Pool Upper Ugnu 11. Present well condition summary Total depth: measured 3992' ND feet true vertical 3416' TVD feet Plugs (measured) None Effective depth: measured 3992' MD feet true vertical 3416' TVD feet Junk (measured) None Casing Length Size XXX~ff~t,~XXXXX Conductor 80 I 16" Surface 2485' 10-3/4" x x x ~fryeVdTA(t e Cemented Measured depth 400 SX AS II 80' MD 1000 SX AS III & 2485' MD 250 SX AS I ~ue Vertical depth 80' TVD 2200' TVD Production 3992' Liner Perforation depth: measured 7" 450 SX Class G 3992' MD 3416' TVD 3334'-3360' 3383'-3431' 3437'-3470' 3478'-3492' 3502'-3508' 3526'-3534' 3544'-3566' 3573'-3624' 3632'-3673' 3672'-3712' true vertical 2850'-3170' TVD (total interval ) Tubing (size, grade and measured depth) 3-~" 9 2# BTC 3730' ND 2 , · , i~'c~,keeFS,.~..dlS~S~j~.t(~q al~~me, asured ~le_.l~tl'~ 3729' MD, No SSSV , uaKer 12.Attachments Description summary of proposal ,,~,, nit & Gas Cons. Commission Detailed operations program [71 j~(~il~i'~l~t)tch ~ 13. Eus~l~ecJ.~l~e for commencing operation 14. If proposal was verbally approved Name of approver SaI3sequeat Work Reporte~ oil Form No. ,_ Datecli/._,7--, Date approved 15. I hereby certify that the for(~))ing is true and correct to tJ3e be.st of m.v.knowledqe. .~/.b.,~ ~,,.~~ ~r. uperatlons ~n~jlneer Signed ~J/~¢]~ . Title Commission Use Only Date 6/30/88 Conditions of approval Notify commission so representative may witness ~ Plug integrity i~. BOP Test ~ Location clearance .~pproved Copy Returned Commissioner ORIGINAL $1GI~ ~ech.~,~;.., BY LONNIE C. SMITH Approved by Form 10-403 Rev 12-1-85 IApproval No. by order of the commission Date ?~ ~'~ Submit in triplicate Sundry Notices wsw 3 wsw 4 wsw 5 wsw 6 These wells were drilled for use as creataceous source water in Increment 1 Waterflood at Kuparuk River Field. They are completed in the Upper Ugnu. Water production from these wells to date has been in excess of 70 million barrels. The intent is to convert these wells from producers to injectors to dispose of non-hazardous, Class II reserve pit water. Recent correspondance with the EPA has confirmed the Class II classification of reserve pit water. No BOP will be used for the proposed work. The estimated B HP in the Upper Ugnu is 1000 psi. No workover fluids are required. Procedure for WSW Conversion ll 2. 3. 4. 5. Pull hydraulic jet pump. Pull standing valve. Run 'pump through' jet pump. Install injection piping and associated pumping equipment. Begin injection. June 6, t984 Mx. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: WSW No. 3 Dear Mr. Kewin: It has been brought to our attention, by JoAnn Gruber, that the permit number and API number assigned to this well are the same numbers previously assigned to Sohio Alaska Petroleum Company's C-24 well. In checking the well files, we discovered a typographical error on the WS.~~ No. 3 permit we returned to you. Please change your records to read the following: WSW No. 3 Per-mit No. 82-142 API No. 50-029-20817. We're sorry for any inconvenience this has caused. Sincerely, /? Lonnie C. Smith Commissioner be:!.S,66 ce: Jo~nn Gruber TO AT S U BJ ECT RECEIVED JUN 0 ? ~h~ge ..... ,,.~ DATE I SIGNED ~® 4S 469 SEND PARTS I AND 3 WITH CARBON INTACT. ,',~"~ v ,-,A u' ~g:,,t e_._'~ ~,-, ,za PART 3 WILL BE RETURNED WITH REPLY. NOTE: ~F - FIIM, T ;6':~ ;kT..~, INC. A_"'~: ~ - AFA/31! -AN C HO _PAG~_~:, AK. 99510 -- Transmitted herc~ith are the following: PLF3~E~,~, F- FTr~I, T- TAPE, PC- PH~PY ARCO Alaskc/,-~ Inc. Posl Office' ", 360 Anchorage .... aska 99510 Telephone 907 277 5637 November 12, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- State Reports Dear Mr. Chatterton' Enclosed are monthly reports for October on these drill sites' 1-21 18-7 1-22 18-10 6-23 1E-26 6-24 1E-27 7-15 1F-7 13-14 1F-8 13-15 1G-4 WSW-4 WSW-5 WSW-6 Also enclosed are well completion reports for: 1-20 1G-2 6-22 1G-3 13-16 WSW-3 1E-30 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-20 and 13-16. P. A. VanDusen District Drilling Engineer PAV' JG01' 1 tc Attachments ARCO Alaska. Inc. is a subsidiary ol AtlanlicR,chf!t'-tdCompany ' '--'t. STATE OF ALASKA .--' ALASKA _ ,L AND GAS CONSERVATION C;, ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE E~x Water Source 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-14%2. 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-2081~' 4. Location of well at surface 9. Unit or Lease Name ? - 320' FNL, 348' FEL, Sec. 9, T11N, R10E, UN iLC, CATION$ Kuparuk River Unit i VERIFIED 10. Well Number At Top Producing Interval 850' FSL, 532' FWL, Sec. 3, T11N, R10E, UM iSurf.~__ WSW-3 At Total Depth'lB. H.___-----'~'~! 11 . Field and Pool 1076' FSL, 815' FWL, Sec. 3, T11N, R10E, UN ' - Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Lower Tertiary (Upper Ugnu) 98' RKB ADL 25648 ALK 466 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116' No. of Completions 09/09/82 09/13/82 09/25/82 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ I-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 3992'MD,3416'TVD 3890'MD,3328'TVD YES FX] NO [] none feet MDI 1625' (approx) 22. Type Electric or Other Logs Run DLL/FDC/CNL/GR/Cal, CBL, CCL/CNL/GR, CCL/NFD/GR, NFD 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 80' 24" 230 sx AS II 10-3/4" 45.5# K-55 Surf 2473' 13-1/2" 1000 sx AS Ill & 250 sx AS I 7" 26.0# K-55 Surf 3983' 8-3/4" 450 sx Class G & 110 sx 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) 3334'-3360' 3544'-3566' see attached l:ubing detail 3383'-3431 ' 3573'-3624' 3437'-3470' 3632'-3673' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 3478'-3492' 3677'-3712' DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 3502 ' -3508' N/A 3526' -3534' w/12 sPf 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR. OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RE[EIVFD NOV .1. 8 ]982 Alaska 0il & Gas Cons. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 6RU2/WC13 CONTINUED ON REVERSE SIDE 29. NAME Upper Ugnu Lower Ugnu GEOLOGIC MARKERS MEAS. DEPTH i! TRUE VERT. DEPTH 3330' ,, 3763' 3863' 3219' 30. FORMATION TESTS Include interval tested, pressure data. all flu,ds recovered and .qrav,w, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History, Tubing De'cai], Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water' In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". WSW-3 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0130 hrs, 09/09/82. Drld 13-1/2" hole to 2485'. Ran 62 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2473'. Cmtd 10-3/4" csg w/lO00 sx AS III & 250 sx AS I. ND diverter & Hydril. Instld 10-3/4" packoff & tstd to 1500 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form. to 12.5 ppg EMW. Drld 8-3/4" hole to 3992' TD (09/13/82). Ran DLL/FDC/CNL/GR/Cal f/3992'-2453'. Ran 87 jts 7", 26#/ft, K-55, BTC, ERW, csg w/shoe @ 3983'. Cmtd 7" csg w/450 sx Class G. Arctic packed 7" x 10-3/4" ann w/300 bbls H20, 110 sx AS I, & 220 bbls Arctic Pack. Instld 7" packoff & tstd to 3000 psi - ok. Drld cmt to 3890' PBTD. Tstd csg to 2500 psi - ok. Ran CBL f/3890'-2000'. Disp well to NaC1. Ran' gyro/CCL. Perf'd the following intervals w/12 spf: 3334 -3360 3383 -3431 3437 -3470 3478 -3492 3502 -3508 3526 -3534 3544 -3566 3573 -3624 3632 -3673 3677 -3712 Ran CCL/CNL/GR f/3729'-3000' & CCL/NFD/GR f/3729'-3000'. Washed perfs. Ran CNL/GR/CCL f/3720'-3000' & NFD/GR/CCL f/3720' to surf. Performed cased-hole, gravel pack over perforated interval. Ran NFD f/3729'-3000'. Ran 3-1/2" completion assembly (see attached tubing detail sheet). ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well to diesel. Set BPV. Released rig @ 0230 hrs, 09/25/82. JG'llm 10/20/82 GRU2/DH16 t CEIV£D NOV 8 1982 Alaska Oil & Gas Cons. Commission Anchorage ' C"~':~'IG/TUBING/LINER DET'--'x( DRILL SITE ~'0~ '~='='~ '"'"~-P/~ ARCO Alaska,Inc. ~r Page / of / pages Subsidia~ of AtlanticRichfieldC~m~an~ ' #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH .- , ' q?.-/7 --~ ~~~, ~/_ ~/.~5 ~" F~c H6~,. ~.5~.sl.~ +' ~ B~'~ ?.~ ~~< ~p~ /g~./a~ ~1~1,75 ~~. ~~ ,47 i , . g 'CEIVED NOi~ ., Alaska n. ~ , A ~cl' ' C°m~l BOSOM OF TUBING TAIL 7 Remarks R. Supervisor / ........ ,' ......... ~ ............ ..':.-~ ................... ::<',.:. ................... ~ ............ - .'?.:',.:.~' ',.':~:.'~:,:'<:.' :":,:: :~,:..-'.<,'.:.: ~ i~ .......... ~ ........... .~ ' :.': '<'::,: ..... :.'~' ~ ' , '.'. ... :: ......... ' .... ~ ~ ....... '~., ,~ ~' . ...... ~ ..... ~-~' · .... :: .................. ::::::::::::::::::::::::: ........ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:.:..'....~ -~.~ .,;:..:.: ::: '.'.'.>' '." .' '", ...:: ......... ..... '"'~ ~r ,,-~:-~-' ~ ,,.~:"~-_-i~.'1"~:~: ..... .~. l....-~ ,...~ ~ - -~ ;~ · - . .~...-r 1 I ~ -...I o~..~.,I ,. T ~..,. · .... ' - '-' ' ' ~ m ~" - '' bOMF?UTATIUN~' ' ~ ]::]ATE 'BO,.,o~'-' UYRu,:,L. UPIC-' -'"'-'- ".:,UR~,EY'-' -' ~" W:SW-:.:: ~:::;EL.. 'Y Tl lN RlO~o _ J"~' I<UPAFcLII< m'-' ..-,° s,~ ,,.,..,. SEPTEMBER 17, 1:.-?:92 dOB 'NLIMBE.-,R BOSS-I/_-,1 i7.' ,"",I ...",. ,-. b.' ,.", ~, .,.i~ .., . ' ' . ' · · t..'m'm ~ v ~l,i I,'"-I_l'rl,.ll'"_. ?'" ~' '~':':'~":<.::~*'.,.'s::.:.,':.:.. ','¥ s,:. ~:'. :t:':..(.:?:~.~:~i'."4. ':~ ,~,~':~'. ~ '~;~..,...~:. ':'~'' '"' .... '' ~. i::'.'~..,: ' .... ~'×':~':,t :~-',.~::~:,~ .,:.. ~. 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' ' ~ I'" ' THE: C:~i...~::::l...ll...~'l" ~ ON 'F R.JCEDLIRE'.~' ~RE B~:~;ED' ON' THE USE :OF THRE:E I3 ~ ME:NS ~ , . , :, O 0 0 .",~ ~:~:::,:~ :;:-::::: ~::::: :.< :::. ::~ c ~ :.".:~ ~,~-~.~':.,~~.,.~ ' .:~s~..'":'::"'"" 1,~.., ..... ,~: ~ ~:~ .x'c,'~ D' ':' ~.::. :':':'~'~¥: .:x,.~.~..~ ~ ~.~:';"~:.: ,~.c:~:: .-...~,,,..'.~:::.'::.:.:.:.xx.;.:,~.:.:-:¢,¢.:..x.:.:::.;,::,'::..',,:::, ,.xx.:.~:.. COP1PUT~TION D~TE ' 'SEPTEMBER'j 1 ?',' 1982 :.J'~.'JoB' NUMBER BOSS- 16112 ,..x '":":.'":'.'.'C'¥,':::'~'~:~" ~'~ ..,~,,~,"::~..~ ~ %>.,.: s. ¥.:.:.c..~x~.~G~ '~'""vc'v'""':v:"":'4":v"'"'~ ~:':::`':`:`c~/~.~~~i!i4:::~.~':::~.~:~:~..4':~.~.~.`~:.~?~v':.:~:~:~:.~:.v..:.:~:::~:~.:~...:~.:~:.:c~.~.:.~ ~: ~t~ ~:~ .,,%j '.~ ..,~ .... ' ......~""~' ": ......... ~'~ ......... ,'-,. ' :~"'" ::~.~::.>.,~;*;~::.:.'~:::~ ....... ..'.:.,:::::i.,.;:?.~::~:~:i ...... :,:~::.::~(,.~,: .... ~ . ., ,, ~ . .~ .......... ~::.:~...,.: .......................... ~ .......... ~.:,~.~' ' ~:,:.~..¥,x~.~' ~,~<.. 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' ........ :'?4': ':~ .... ::'":" : : . · . '.' DLISH ~ NC~ :ELEV-FT. . ' . . . . - .- . Suggested ~o~,n to be inserted in each "Activ~ well folder to d~eck for timely cca~liance with our regulations. ' ~Peratdr', ~ell Name and Number . Reports and Materials to be received by: /6 --~~'-~ Date Required Date Received Remarks ~~on ~~ ~es / · Wel 1 HistorY Yes / _Samples . /~O - PI ,/" L'" ' Mua ~.o~ .., /k:_n P! ~re ~ips Core ~scription .~'~ ~..' Registered ~ey Plat 7 ~: ~... Inclina~on S~ey" , ~D Drill Stm Test Re, ms ~// ,,:~ ~s ~. ~ 7-/~-' / KUPARUK ENG~ING TO: William VanAlen FROM: D.W. Bose/Lorie L. Johnson DATE: / t / ~/ ~ ~ W~.L NAME : Transmitted her~vith are the following: PT,VASE NOTE: - FILM, T- TAPE, PC - PHOTCL~PY No i o ~laska Oil & Gas Cone. · AnChorage O°r~r~iSeiot~ R~CEIPT ACI(I~OWLEDGED: -~'~-/---~- DATE: //_ ~o- ,~ ~- / / PT,FASE RETURN RSEEIPT TO: ARCO ~, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 TO: William VanAlen D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE:~~ F - FITM, T - TAPE, PC- PHOTOCOPY ~/PLFASE RETURN RECEIPT TO: ARCO ~, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. O.. BOX 360. ANCHORAGE, AK. 99510 TO:' William VanAlen FROM: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLWASE 5K7i~:~~ F - FILM, T- TAPE, PC- PHOTOCOPY 0C¥ 2 2~§82--~- ,Aiasi<a Oii ~, ~as uons. commission ~ ALASKA, INC. Anchorage ARTN: LORIE L. JOHNSON - AFA/311 P. O...BOX 360 .- AN(~ORAGE, AK. 99510 ARCO Alaska, Inc. ~ Post Office Box J Anchorage, Alaska 99510 Telephone 907 277 5637 October 14, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Co.nservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are monthly reports for September on these drill sites' 1-19 18-6 1-20 18-7 6-21 1E-28 6-22 1E-29 13-16 1E-30 13-34 1F-6 1G-2 1G-3 WSW-3 WSW-4 A1 so enclosed are well c°mpletion reports for' 2-26 1G-1 6-20 14-15 (completion report & subsequent sundry report) 1E-17 1F-5 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG'llm Enclosures GRU2/L15 ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany . , ?-. STATE OF ALASKA ~-~. ALASKA ...L AND GAS CONSERVATION C(. 'MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~(~] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-14~'~ 3. Address 8. APl Number 7 029-208~ P. O. Box 360, Anchorage, AK 99510 50- 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 320' FNL, 348' FEL, Sec. 9, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 98' RKB I ADL 25648 ALK 466 10. Well No. WSW-3 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of September ,1982 12.Depthatend~fm~nth~f~~tagedri~~ed~fishingj~bs~directi~naldri~~ingpr~b~ems~spuddate~remarks Spudded well ~ 0130 hrs, 09/09/82. Drld 13-1/2" hole to 2485'; ran, cmtd & tstd csg. Drld 8-3/4" hole to 3992'TD; ran open hole logs. Ran, cmtd & tstd 7" c~g. & gyro/CCL. Perforated. Performed gravel pack over perforated interval. Ran completion assembly. Disp well to diesel. Released rig ~ 0230 hfs, 09/25/82. SEE DRILLING HISTORY 1 0 - 3 / 4~." Ran CBL 3-1/2" 13. Casing or liner run and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, conductor set ~ 80' (pad level) Cmtd w/230 sx AS II 10-3/4", 45.5#/ft, K~55, BTC csg w/shoe @ 2473'. Cmtd w/lO00 sx AS I II & 250 sx AS 7" 26 O#/ft, K-55, BTC, ERW, csg w/shoe ~ 3983' Cmtd w/450 sx Class G SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DLL/FDC/CNL/GR/Cal f/3992'-2453' CBL f/3890'-2000' CCL/CNL/GR f/3729'-3000' CCL/NFD/GR f/3729'-3000' NFD f/3729'-3000' 6. 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. SIGNED ~" TITLE .~n~nr F) r'~l]~nn I:nn~n~r'DATE ~ NOTE--Repor~on t~his f~rm is ~eequir~d for each ~alendar month, r~a-rd;le-s~ of the status'~f op~r~t-i0n~,-a'nd must be f~led in duplicate with the Alaska Oil and Gas G/onservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU2/MR1 4 Submit in duplicate , , C~[' IG / TUBING I LINER ' ' ~.,~ s,, ARCO Alaska, Inc. '~' ~/'7~d~. DATE - '~' Page / of / pages Subsidiary of AtlanticRiChfieldCompan), ' ,, , #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH ,. ,' -~.~. -~ z~~.~ ~L "' ,. ~K~[ L~~ 5o~ ~/'~.~F ~L5. ~ · 5/S/o3, ~a. ~~ ,47 ~7/7,// . , ....... ...... , BOSOM OF TUBING TAIL Remarks WHe~ Lcy~~ ~"T'~. ~r~,~ ~ -'E4~& ~'C-/ - P~, WSW-3 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0130 hrs, 09/09/82. Drld 13-1/2" hole to 2485'. Ran 62 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2473'. Cmtd 10-3/4" csg w/lO00 sx AS III & 250 sx AS I. ND diverter & Hydril. Instld 10-3/4" packoff & tstd to 1500 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form. to 12.5 ppg EMW. Drld 8-3/4" hole to 3992' TD (09/13/82). Ran DLL/FDC/CNL/GR/Cal f/3992'-2453'. Ran 87 jts 7", 26#/ft, K-55, BTC, ERW, csg w/shoe @ 3983'. Cmtd 7" csg w/450 sx Class G. Arctic packed 7" x 10-3/4" ann w/300 bbls H20, 110 sx AS I, & 220 bbls Arctic Pack. Instld 7" packoff & tstd to 3000 psi - ok. Drld cmt to 3890' PBTD. Tstd csg to 2500 psi - ok. Ran CBL f/3890'-2000'. Disp well to NaC1. Ran gyro/CCL. Perf'd the following intervals w/12 spf: 3334 -3360 3383 -3431 3437 -3470 3478 -3492 3502 -3508 3526 -3534 3544 -3566 3573 -3624 3632 -3673 3677 -3712 Ran CCL/CNL/GR f/3729'-3000' & CCL/NFD/GR f/3729'-3000'. Washed perfs. Ran CNL/GR/CCL f/3720'-3000' & NFD/GR/CCL f/3720' to surf. Performed cased-hole, gravel pack over perforated interval. Ran NFD f/3729'-3000'. Ran 3-1/2" completion assembly (see attached tubing detail sheet). ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well to diesel. Set BPV. Released rig @ 0230 hrs, 09/25/82. JG:llm 10/20/82 GRU2/DH16 I i i I II II I I III I 0 o o ~) o o o 0 o o ~4~eee~ ~s~ #l~7 7 TO: William VanAlen FRCM: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: - . PT.VASE NOTE: BL BIT/ELINE, S - SEPIA, F - FII~4, PC - PHfIIIXDOPY E RETURN RtI/EIt~ TO: ARCO ALASKA, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. 0.. BOX. 360 ANCHORAGE, AK. 99510 ~dr. Jeffrey ~. Kewin S~r~ior. Dril!ing Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: t<uparuk River Unit ARCO Alaska, Inc. PeRit No. 82-142 Sur. Loc. 321'FNL, 350'FEL, Sec. 9, 'fllN, R10E, ~t~ole Loc. 977'FSL, 628'FV~L, Sec. 3, TllI<, ~10E, Dear Mr. Kz~viu: Enclosed is the approved application for peru{it to drill the above referenced well. ~ell ~pies and a amd log are not required. A continuous directional survey i~ required as per 20 AAC 25o0§0(b)(5). If available, a ~a~e eontainin~ the digitized log infor~oation ~hai1 ~e ~ubu~itt~d on all logs for copying except e×perin~ental log~, velocity survey~ and dipme~er surveys. 5~r~y rivers in Alaska and their drainage syste~:s have been classified as importanl for the spav~nin~i or migration of anadro~,ous fish. C~perations in these areas are subject to AS i6.0§.~70 and the re~lations promulgated thereunder (~itl¢ 5, Alaska Administrative Code). Prior to coi~nencing operations you ~ay be contacted t~y the l{a~ttat Coordinator's Office, Depart~ent of Fish and Game. pOllution of any ~aters of ti~e State is prohibited by AS 46, Chapte~ 3, Article ? and the regulations ~ro~nulgatod thereunder (Title 18, Alaska A~mini~trative C~de, Chapter 70) and by the Federal ~i~ter Pollution Control Act, as a~ende(i. Prior to oc~n~.~eneing operations you m~y ~,e contacted by a representative of the Department' of Envirorm~entaI Conservation. To aid us in scheduling field ~ork, please notify this office 24 ho~rs prior to e~:~encing tn~tallation of the i~lowout prevention equipment so that a representative of the Co~i~sion n~ay be present to ~itne~m testing' of tI~e equip~nent before tho ~r. Jeffrey B. F. ewin KUapruk' River Unit WSW-30 -2- August 26, 1982 surface casing shoe-is drilled. Where a diverter system is required, please also notify this office 24 hours prior to co~nencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly Yours, ' C. V. ~atte~tou Chai r~n of Alaska Oil and Gas Conservation Co~ission Erie I o sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. t~/C:be ARCO Alaska, Inc. ~ Post Office B~,.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 11, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk Water Source Well #3 Dear Mr. Chatterton' Enclosed are' o An application for permit to drill Kuparuk WSW #3, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projec- tions of the wellbore. o A staking drawing of "B" pad indicating the proposed surface location. o A proximity map indicating the relative location of Kuparuk wells 1B-8, 1B-7, 1B-6, 1B-5, WSW-1, WSW-2, WSW-3, WSW-4, and WSW-5. o A determination of the maximum pressure to which BOP equipment could be subjected. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. o An analysis of drilling wells on 60' spacing. R £ IVED AUG 2 5 1982 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanlicRichfieldCompany Mr. C. V. Chatterton August 11, 1982 Page 2 We anticipate spudding this well on or before September 6, 1982. Any questions regarding these wells should be directed to Mr. Rich Gremley in our office at 263-4972. Sincerely, Senior Drilling Engineer JBK:RBG:I lm Enclosures GRE1/L1 Enclosures GRE1/L1 Alaska Oil & Gas Cons. Commission Anchorage · ~"'- STATE OF ALASKA ~-", ALASKA L,,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] Water Source XXDEVELOPMENTOiL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L~ SINGLE ZONE ~( MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 321' FNL, 350' FEL, Sec. 9, T11N, R10E, UH At top of proposed producing interval 711' FSL, 428' FWL, Sec. 3, T11N, RIOE, UN At total depth 977' FSL, 628' FWL, Sec. 3, T11N, RIOE, UM 9. Unit or lease name Kuparuk River Unit 10. Well number WSW-3 11. Field and pool Kuparuk River Field Lower Tertiary (Upper Ugnu) 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 57' GL, 62' PAD 98 RKB I ADL 25648 ALK 466 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de 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 I 30 Mi. NW Deadhorse 16. Proposed depth (MD & TVD) 3900' MD, 3424' TVD 15. Distance to nearest drilling or completed NSW#2 well at surface,60 feet miles 3964 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 35 o (see 20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 09/06/82 19. If deviated (see 20 AAC 25.050) 1 537 psig@ 8__0° Surface KICK OFF POINT 500 feet. 1500 psig@_3424 ft. TD (TVD) 21 ! SIZE ~ Hole I Casing '~4" 16" t3-1/2" 10-3/4" 8-1/4" 7" Weight 65# 45.5# 26# 22. Describe proposed program: CASING AND LINER Grade Coupling Length H-40 Welded K-55 BTC K-55 BTC I 3869' SETTING DEPTH MD TOP TVD 80' 35' I 35' 2434' 33.5'1 33.5' I 31.5'1 31.5' I MD BOTTOM TVD 116'1 116' 2467' 2250' I 3900'13424' I I QUANTITY OF CEMENT (include stage data) 250 cf ± PF II 1025 sx Arctic Set III 250 sx Arctic Set I 250 sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field, Kuparuk River Unit, water source well to approximately 3900' MD, 3424' TVD. Selected intervals will be logged. A 20" 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" RSRRA BOPE stack will be installed on the 10-3/4" 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 will be 1537 psig based on warming of a gas bubble rising at constant volume. A 3-1/2" gravel pack screen will be run to ± 3100' TVD and gravel packed. The interval will be produced by a downhole pump set above the gravel pack packer on 3-1/2" 9.2# J-55 BUTT. TBG. Non-freezing fluids will be left in uncemented annuli through the perm~.fr~s.t_i~erval. Selected intervals will be perforated within the Ugnu formation and reported on subsequentNJ~lVED AUG 2 5 ]982 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~ TITLESr. Drilling Engineer Arich0rageDATE The space belo¢~ ~~io~use' CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number []YES I~NO L--lYES [~NO ~YES []NO 50-- O'1. ~ * Permit number .. , App~date APPROVED BY SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER by order of the Commission DATE Form 10~401 GRU1/PD24 Submit in triplicate RESERVE PIT , . . _-¢ _ - · . . . . _ . MARKER Z61' Z60' RESERVE PIT Added Gyro Morkers 8-12-82 c.i.f. Revised WS-8 Thru WS.--t2 8-12-82 c.l.f. 160' 80' 160' - ~ -IO 80' lB-lO GI-~ -v '11 8o' 16o 1- ~ -12 . 1{o' GYRO MARKER $ DATE EXISTING WELL PROPOSED WELL ARCO ALASKA; INC. DRILL SITE "B" PROPOSED WELL LOCATION STAKING DRAWING PREPARED BY BOMHOFF & ASSOCIATES, INC. ANCHORAGE, ALASKA 7/22./ 82 $C,e, LE i"= 200' DRAWN R.R.K. CHECKED 'T"/'~ ~ Ft| ! i i : : : I ' ' i ' ' . . . ..... .. i _ , ' i ...... ' .... ....... ! i ' juu- ,;. ~uui- . ~ . i,, ;ii -' : . - i ~ i . : - ..J . ~ ' ' ' . , i i : i i i . i ', ', ~ : '" :' '.' i ~ 1--" i i-.q' ,,t ; :. ~, ,,,. .. i ii~ i il'j ~ , . : ,- . ~ . ,~ :,, , i~ ::: ! ~., : I :ii: iii ~iii ,i il ~ ~i ~ ~!i! !ii! i , , - ' ' ' ' ' ' ~ 1 [ · · : ; , , , ~ : : · ' ' ' ~ ' : i ~ ~ ~ ~ . ' ! ' i ~ · " : '° ' · . ~ '.-- i~ . . : : ' : :.-~---' !' ~ : ~I7I'Ii 1.41 i.~"iKM.; ~INI;... :. } .: ... ;, :.~ : ~. ! : : ~ ~ : : . . , ,iff! '- . . "'--., :'--7--- :-_: ..... - · iLL - i . ,,,: -- ~: , ~, ; I""I-!1] :t.!. I,~ILL .~'4]l :i,i~"~_ i~--;!--4--. 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I I i i i i i ! i ! i i-~ ~!i i i i i I ', i i I ! i I i i ,, ... . , _. _ ~,1, ii!i !ili i',~! ii!I Jill ''I~ iXi~:b..- iI;~ ilii I1~ iil I ' ' "'-'~-' i.I i i ~ i i i i i ' ' ' ' ; i i i~I i I i i~i i -'~ I il,,..,, I il I l. [ "~ ~i ;' il !!!~ !_ :._4.M_.~.---. --~,, ~ ! I ! i i i i : ! t i i . iI ~i [ [ ¥ I ,-!-~ I I , ~, ~ ~ -,.-~.. !,~ - ; : ~ _'r.o'--"''""' 1,__Ii~ I i-- i · ~ ~ ~ ! ! : ' : ; :~ . · ' ' ':'--! .... . ~"~,~ , . ,,,,,.i~ Iii~ ~ii ~' 'i'~~" '"~ ~'""'~" '"~"'""~" ~ 'ii:-, -' ,~ ~.,. ,iit ~,,, .,. .,,, l,!i !ii,~! ,ili ii~.,i i it N[ i!ii .-...,,,, :~_. ~. i ! i i i i ! ~ I . i i i i I i i~ i i i i i i ! i I -i-i-i i ! ! ! ,.~ I i 1 ~r ,. ~Lr].,~.i i i I i ! ~'"~! ~ ~: : I : i ' . .... ] i i ."-~~- i i i ~ I s i ~ ': i ! ~ i i i! ~ I i I IN, i t I I- I i I I 1 ! I I i I i i i i i !i i . i I I I . I I'~ I ~ i ! I I I I . j, ~ . ~ , ~ , , , , ~ ~ ' . . . ~:. ,,,~ ~i, ii~i ii,, ~!~ I,,!..,,,,,;-,,ii~., . !iii ~ ~"~'~"~"-~. .. ' i ..... ; : ~ : i i i ! i i I I I I ~ i i i ; ' i ~ i '~ I [ i i I, i i i I i'~ !'-"~R:,..,I,.J I ! : . , ..... . , . i ' · . , ,;; i ! i - i ; , i ,~i ... i i i ill, ... ', i I i I i ~ i I ~ i ii i i i ! I !1 i i i I I i ii ii i~ll ~1!i i iI~ illi ~'; i i!i i! i i!!l ft!.l .- il!! !ii! · ~ ~ ~ ':,`. i ~ ! ~ ' , ~ ! i ! i ...... ~, i ~ ~ ! i I i i ! i i ii i I i I, iXI~'~- i i ! i ~ i i 1.1 ~ "NJ~'~'~'i."r"'~l~[ i ;--~,:,,~,[~! :~i..: ; . i ] : .~.l ' : · ~ ~ ~ ,. ~,: fill ii~i ii[~ , ~. .~!i iili i!I! I11l Jill I :!! 'i ' i I i ! I il~ ~ ~ Iii~ ii; i! i~!i II~!i i!il i!1i ~D-~ ' ' '' , ' '' ' ' ~ ~ ~ ~ i [ [ ! · i i i , i ! iI ! i I ~ ,~i~ ~ I i I I I i i i i i ,.-I i ! ': ' ' ' . , i:_ ~ :!~' , ii'i, :i'~,. , ~ : ~;i!i i~!i, i:~ , ! il'~i !~i~, ,i!l ii!l i',ii ilii i ,i~, ,i l'h: ,iii ~ii;.'i ~ ' ' : ; , , i . . ' ' ' ~ ! ' '- ., 1 :',ii ii!', !!'i, i i i i i i i ~ i i i i iii iiii i I i~ ~ i i [, ,' ' ; :: ~ : ' : : i i i .,m~. : ' ' ' ' ': ~ ; i 'i i i I itl! i ! ~ , t i ! '. ' ' ' ~ iili iili '~'1 ;iii i j ~ : ,. ~ . _ · , , i , ~ I , .... , . I , . , . ~ , ''~' ilii il!i ~iii ~!ii ii!i iiii ~i;! !i:.~.~ili iii: - , ....... : i '':--- ' : -' ANTICIPATED PRESSURES WSW #2 is being drilled as a water source well which will required artifi- cial lift during production. The zone of production (Upper Ugnu) lies about 291-0'-3220' below ground level. From other wells drilled on the pad (1B-b and 1B-1), it is known that Ugnu formation pressures are less than 1500 psi. This pressure @ 3326' SS : 3424' TVD will be balanced by 8.42 ppg mud weight. During the drilling of the 'Upper Ugnu} 9.0 ppg mud will be used. This will result in a 100 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 1537 psi during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (67°F, 1500 psi), gas migration to the surface without expansion, and warming to 80°F cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi : volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf: volume final (surface) PiVi = PfVf Ti Tf Since Vi = Vf,.i.eo, no expansion. Pi : Pf Then Pf : PiT_____~f : (1515 psia) (80°F + 460) + Pf = 1552 psia = 1537 psig Alaska Oil & Gas Cons. Co¢nrnission 4nchorage -® Surface Dive~.t..er System I. 16" Bradenhead. 2. 16" x-20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. lO" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cal ly upon closure of annular preventer. 5o 20" 2000 psi annular preventer. 6. 20" bell ,nipple. O. 16" Conductor Maintenance & Operation I. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines eYery 12 hours. 3; Close annul ar preventer in the event that gas or fluid flow to surface is · detected. If necessary, manual ly over- ride and close ball valve to upwind diverter line. Do not. shut in well , under any circumstances. · g!l~.,ska Oil & Gas Cons. Co~rnis$ion /,~riChorageI 13-5/8" 5000 PSI ,~SRRA BOP sTACK i I ~NNUL~qR PREVENTOR BLIND P..RHS-- PIPE RRMS 7 I o 2. 3. 4. 5. DRILLING . SPOOL ; lo 16" Bradenhead tt ~-"t'" * 15 2000 PSI x lO" ~3 ?SI ~s;ng head 10" 3000 PSI tubing head 10" 3000 PSI x 13-5/$" 5000 adap ter s pool 12-5/8" 5000 PSI pi~ 13-5/8" 5000 PSI drill in~ ~o~l w/choke and kill lin~ .m '-' . 13-5/8" 5000 PSI pi~ ra~- _-..... 13-5/8" 5000 PS/blind ~ --- -. 13-5/8" 5000 PSI an~lar . - -- . . . .. . . A:-~~ ~A~I~ ~JT . .... " -. . ~r~'i: ~ :'. C~ '~ FILL A~L~XOR ~~[~ ~'~ WITd HYDP~ULIC ~ID~ ~ ~T A~-~T~ P~E I5 ~ ~I - ~S~Y[ TIHE ~ C~E ~ L~ITS ~IT IS 45 SE~(~ ~=I~ T~2 ~ 1T~ PSI P~I(II~ P~SU~. - ot ' 13-5/2" [0P STXC( TEST BILL BOP STACK A~ F~,,'~[.=OLD W[i'1-~ ~-'~---TIC DIE. SEI.. ~E~ T~AT ~ ~0~ ~ S~ A~ ~Y P~- ~D. P~D~E~I/~ DEPT~ T~AT ~N S~AS I ~ ~jT ALL C~(~r~ITS TO ~ ~Z ~ ~D F~2 lO MIl;UTES. B~ED TO ~0 ~I. PIPE ~'~. ~E V~V~ OI~ ~~'~ OF ~. ' Y~YE ~;D Z~ PSI ~I~.. TO ~RO PSI. - _ ~ TOP S~ OF PIPE S~ ~ PIPE ~j. IN~E~' PP. ESSU?~ TO 3~ ~ ~.,D'" ~ ~ lO H!!~J. B~ED TO Z~ PSI. ~J( 80~ S~ OF PIPE P~. ~' .~iD TEST TO 3~ B~ED TO ZERO PSI. ~'~iIFOLD ~D ~ ~ ~ ~ ~C · ~I~q. , -. T~ ~;DPIPE Y~Y~ TO ~ ~I. ' T~ ~Y ~~D I~I~ P~ TEST I~(F~TI~ . ·.i- ' '.: _- ANALYSIS OF WELL PROXIMITY WATER SOURCE WELL NOS. 2 AND 3 ARCO Alaska, Inc., proposes to drill Water Source Well (WSW) No. 3 on 60' spacing adjacent to existing WSW No. 2, as shown on the attached wellbore proximity plot. The wellbores for the subject wells are vertical to 500' TVD, which is the point where both wellbores are kicked off. At this point, the areas of uncertainty of the individual well surveys would be 18' in diameter based upon typical field-observed accuracies for the surveying tools utilized. Assuming a worst-case situation, the areas of uncertainty would not intersect or overlap one another. Further, after reaching kick-off point, the subject wellbores are directionally drilled at diverging angles further widening the margin of safety. In light of the above, we feel we can safely drill Water Source Well No. 3 and avoid proximity problems with the adjacent wellbore. JBK:llm 08/25/82 KEW1/AWP CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE / (2) :Loc :.,,. ~.. 1 '~!'"' :, th~u S) 1 Is the permit fee 'attached 2. Is well to be located in a defined pool ............ 3· Is well located proper distance from proPerty line iiiii!!!iiiiiiiii 4. Is well located proper distance from other wells .. 5. Is sufficient undedicated acreage available in this 6. Is well to be deviated and is well bore plat included .............. , 7 Is operat the Only ffected party · or a ee®eeeeeee®eeeeeeeeee®®e®eeeeeee 8 Can permit be approved before ten-day wait · ,(~ thru 11) 10. 11. X~/7 ~-~l~-~- thru 20) (5) BOPE ~F~ ~d~.25-.J~~_ (21 thru 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO . _ R~ARKS ,mI 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 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 all 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 ........................... Is a diverter system required ....................................... ~ . Are necessary diagrams of diverter and BOP equipment attached ....... j~ __ Does BOPE have sufficient pressure rating - Test to ~rD-ZP psig .. ~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. , , ~ Additional Remarks: o Geolosy: Engineering ~.cs /'" ~EW ~'VA (~ ,I~~..~RAD .~. rAL .... M~f' ..:- HJH ? :ev: 08/19/82 INIT IAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ........~::...,..-. ,~, _ ,....~ : ?. ~, o ,..;,,..'., .,., ~ ,:~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. bis TAPE VERIFICATION LISTING LVP 010,H0! VERIFICATION LISTING ** REEL HEADER ** SERVICE NAME :$ERVIC DATE :82/09/27 ORIG1N : REEL NAME :REEL ID CONTINUATION # :01 PREVIOUS REEL : COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAME :SERVIC DATE :82/09/27 ORIGIN :FS1A TAPE NAME CONTINUATION # 501 PREVIOUS TAPE COMMENTS :TAPE COMMENTS EOF ** FIb£ HEADER ** FILE NAME SERVICE NAME : VERSION # 0ATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE ** INFORMATION RECORDS MNEM CONTENTS CN : ARCD ALASKA INC, ~N : WSW-3 B-PAD FN : KUPARUK RANG: iOE TO~N: lin SECT: 9 COUN: N. SLOPE STAT: ALASKA CTRY: MNEM CONTENTS PRES{ DILOOIE RECORD TYPE 047 ** UMIT ~'YPE CAT~J SIZE (,) 00 00 o t) ! 6 065 00o 0 o() 012 Ob5 000 000 008 065 000 000 0,34 Ob5 000 000 004 065 (.) 0 o 000 () 02 065 000 00 (,') 00 B 065 000 000 ~)0o 065 UNIT TYPE CATE 000 000 uu 7 0~5 bVP OiO,HO1 VERIFICATIOi'~,~ LISTING [~G~': 2 ** RECORD TYPE 047 ** RECORD TYPE 047 ** ** COMMENTS ** t SCHLUMBERGER ~ ALASKA COMPUTING CENTER COMPANY FIgLD COUNTY STATE ATLANTIC RICHFIEhD COMPANY wsw-3 B-PAD KUPARUK NORTH SLOPE BOROUGH ALASKA JOB NUMBER AT ACC~ 10707~65566 RUN #1, DATE BOGGED: 13 SEP 1982 UDP{ BOTTO~ DEPTH TOP DEPTH CASINg 8IT SIZE TYPE FLUID 3979 10 ]/4 IN, 2454 FT, DUO¥I$/NACL BRINE bVP OlO,HO1 VERIFICATION LISTING PAGe: 3 DENSITY = 9 0 bB/G VISCOSITY = 3~,0 S PM = 8 8 FLUID bOSS = 3~.4 C3 RM ~ O,lgO ~ 45,0 DF RMF = 0,190 ~ 45.0 DF R~C = 0,113 8 45,0 Df' RM AT BHT : 0,096 ~ 90,0 DF MATRIX SANDSTONE ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 1 66 8 4 73 60 9 4 65 .1I~ 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP1 AP1 AP1 AP1 FILE SIZE P~t£..~:SS SA~,'~ [.,g REP~ ID ORDER # LOG TYPE CLASS MOD DEPT FT 0 0 0 0 0 4 bLS DLL OHM~ 0 0 0 0 0 4 LbD Dbb OH~ 0 0 0 0 0 4 SP DLL ~V 0 1 0 0 0 4 GR DLL GAPI 0 31 32 0 0 NPHI FDN PU 42 68 2 0 0 4 RHOB FDN G/C3 42 35 1 0 0 GR FDN GAPI 42 3! 32 0 0 4 CALl FDN IN 42 28 3 0 0 4 DRHO FDN G/C3 42 44 0 0 0 RNRA 002 0 0 0 0 0 4 NCNb FDN 42 ~4 92 0 0 4 FCNL FDN 42 34 93 0 0 4 b;P OIO,HO1 VERIFICATION LISTING DATA ** DEPT .4~00,0000 bbs GR 99,2500 NPhl CAGI 8,7500 DRHO FCNL -365,0000 DEPT $900,0000 BLS GR 59,8750 NPHI CALl 9,3984 DRHU FCNL 204,3750 DEPT 3800,0000 LbS GR 39,5000 NPHI CALI 10,0000 DRHO FCNL 226,7500 DEPT 37~I,0000 bbs (IR ,7813 NPHI CtkLI 9 4688 DRHO FCNL 221:5000 DEPT 3600,0000 bLS GR '32,6250 NPHI ALI ~1.3359 DR"O CFC~I.., 2 .1250 DEPT 3500,0000 bbs 99:5000 N HI GR 7 P FCN h 215 ' 50 DEPT 3400 0000 bbs OR 53:5625 NPHI CAbI 11,398.4 DRHO FCNb 422,7500 DEPT 3300,0000 bLS GR 74,5000 NPHI CADI 10.6328 DRHO FCNL 262.2500 DEPT 3200,00?0 bbs GR 39,68 5 NPHI CAb! 9,9609 DR~D FCNh 278,2500 DEPT 3100,0000 bbs LI 1 O, 62 DRHO FCi~L 297,0000 DEPT ]000,0000 hl,$ GR 68.3125 NPHI '999,2500 45,1172 '32768.0000 8,8856 44.7754 0.0283 7.0596 47 7539 0:0469 8,0604 4~.8730 0,0400 9,0559 50,9277 0.0215 7,5705 53,4180 0,0723 5 7576 ,0620 5 4824 56~10 0,05]~ 8,7523 49,7070 0,01.71 'i76 4, 258 , 420 5.58 LbO -999.2500 2P RHOB -32768.0000 G~ RNRA -1429000.2500 NC~.~L LLD 10.3244 SP RHOB 2.1562 GR RNRA 3.9805 ~'~Cmb bbU 9.4880 SP RHUB 2,1016 GR RNRA 4,3042 NC~b bLD 9,8544 RHOB 2,1426 RMRA 3.9640 bbD 11.4247 $~ RHOB 2,0898 GR RNRA 4,1987 NCNL bbD 8.5514 SP RHOB 2.1934 GR RNRA 4,b318 ...... bbD 7,1278 SP RHO'B 2,1934 RNRA 3,6538 Lb[) 6,4480 SP RHOB 2,1016 GR RNRA 4.9665 NCl~b bbD 10,8309 SP RHOB 2. 0605 GR RNRA 4,221,7, ~'.C~,,h IaLD ~,71.51 S;" RHOB ,1699 GR RNRA 4.3214 ;<C{5~1.~ bbD ~,4855 SP RHOB .1660 GR -999.25{)0 -~5. 625('~ - 1429. 59,~750 '62.b250 1024. 0000 '10S,9375 902,500t: 32.625t~ 1049,0000 -96,025U 79. 5000 1 C, 9 o. 0 (',, 0 ,,.,~ -81.9375 5 ~. 5t, 25 583.0000 -94,1'250 137~' 5()00 2 U . 0 (..t t) 0 -59. 6563 39.6.~75 1206.00U0 -gq.125u 68,3125 '92,1250 o8.3125 bVP OiO,HO1VERIFICATIO{,,~ LISTING PAGF 5 CAbI 12,1328 ORHO FCNL 276,0000 D PT 2900 oooo BLS GR 47'.8437 NPMI ALI 12,0313 DRHO CFCNL 392,2500 OEPT 2800,0000 bLS GR 80,1875 NPHI CAbI 12,2266 DRHO FCNL 294,2500 DEPT 2700,0000 LbS GR 63,9375 NPHI CALI 12,1250 DRHO FCNL 363,2500 DEPT 2600 0000 BbS GR 38i9687 NPHI ALX 12 8516 DRHO CML 420,5000 OEPT 2500,0000 GR 42.5625 CAbI 11 5234 DR"O FCN6 344:2500 ' DEPT 2441,0000 bLS GR '999,2500 NPHi FCNL .0000 0,0625 9,9886 43.0176 0,0112 6,9091 52,4902 0.0513 7 5451 0,0474 8.8980 45,2637 -0,0029 8 9455 47i2168 0 0107 -999,2500 53,3691 -0.4985 RNRA RHOB RNRA 66D RHOB RNRA bbP RHOB RNRA I~LD RHOB RNRA bLD RHOB RNRA RHOB RNRA ** FILE TRAILER ** FILE NAME ISERVIC,O01 SERVICE NAME VERSION # : DATE I MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME **:******** EOF ** TAPE TRAILER ** SERVICE NAME :$ERVIC DATE 182/09/27 ORIGIN :FSIA TAPE NA~E CONTINUATION # NEXT TAPE NAME COMMENTS :TAPE CO~ENTS 4.5609 13,3632 ~P 2,12B9 G'~ 4,01~7 NChL 9.6013 SP 2,1562 GR 4,5699 c~CNL, 10 4495 SP 2:1348 GR 3.9855 14,71.30 SP 2.0859 (;R 4,2679 NCNL 13.1918 2.1035 GR 4,3094, '999.2500 1,9~73 4,9630 NCNB 11. 96. - b u, 3750 47,8437 1. 544. OUO0 -7'7. 8750 80.1875 1218.000u -?U 1250 63:9375 c,. 1, O 00 (.' 3~.9087 1806,0000 -67 , 6~75 42.5625 :1 5 9 0.0 t) 0 0 -999,2500 23.81.25 bVP 010,H01 VERiFICATiOI'~ [.,ISTING ~AG? t!.; ~* REEL TRA~EER *~ SERVICE NAME ~$ERVIC DATE ~82/09/27 ORIGIN C REEL NAME IREEL ID CONTINUATION # tO1 NEXT REEb NAME ~ COMMEN~S ~REEL COMMENTS EOF ********** EOF