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186-096
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-10 KUPARUK RIV UNIT 2T-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2T-10 50-103-20064-00-00 186-096-0 W SPT 5716 1860960 1500 1430 1430 1430 1430 60 60 60 60 4YRTST P Adam Earl 6/21/2025 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-10 Inspection Date: Tubing OA Packer Depth 740 2220 2150 2130IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625073005 BBL Pumped:1.2 BBL Returned:1.1 Tuesday, July 22, 2025 Page 1 of 1 Originated: Delivered to:2-Jan-25 Alaska Oil & Gas Conservation Commiss 02Jan25-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1G-103 50-029-20824-01-00 219-110 Kuparuk River WL WFL FINAL FIELD 9-Dec-24 1G-01 50-029-20805-00-00 182-130 Kuparuk River WL IPROF FINAL FIELD 11-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 15-Dec-24 1F-14 50-029-21022-00-00 183-146 Kuparuk River WL PPROF FINAL FIELD 17-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 18-Dec-24 1L-05 50-029-21155-00-00 184-123 Kuparuk River WL IPROF FINAL FIELD 19-Dec-24 1Y-29 50-029-21852-00-00 188-091 Kuparuk River WL PPROF FINAL FIELD 20-Dec-24 2T-10 50-103-20064-00-00 186-096 Kuparuk River WL IPROF FINAL FIELD 21-Dec-24 2H-05 50-103-20043-00-00 185-168 Kuparuk River WL PPROF FINAL FIELD 22-Dec-24 1Q-12 50-029-21210-00-00 184-193 Kuparuk River WL LEE-IPROF FINAL FIELD 23-Dec-24 MT7-91 50-103-20881-00-00 224-020 Greater Mooses Tooth WL TTiX-IPROF FINAL FIELD 29-Dec-24 MT7-92 50-103-20872-00-00 223-114 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 31-Dec-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39899 T39900 T39901 T39902 T39901 T39903 T39904 T39905 T39906 T39907T39908 T39909 2T-10 50-103-20064-00-00 186-096 Kuparuk River WL IPROF FINAL FIELD 21-Dec-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.03 08:13:20 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday, July 9, 2021 P.I. Supervisor IC�cJ�q SUBJECT: Mechanical Integrity Tests (G ConocoPhillips Alaska, Inc. 2T-10 FROM: Jeff Jones KUPARUK RIV UNIT 2T-10 Petroleum Inspector Sre: Inspector Reviewed By P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-10 API Well Number 50-103-20064-00-00 Inspector Name: Jeff Jones Permit Number: 186-096-0 Inspection Date: 6/5/2021 - Insp Num: mitJJ210628155334 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Well zT-10 Type Inj w' TVD 5716 -Tubing 2200 - 2200 - 2200 2200 PTD! 1860960 Type Test SPT Test psi 1500 IA 1360 2930 2850 2850 ' BBL Pumped: 1.3 BBL Returned: 1.2 . OA 120 120 - 120 - 120 - Interval 4vRTST P/F P Notes: 1 well inspected, no exceptions noted. Friday, July 9, 2021 Page I of 1 • • . y of F4 c ,\ \I// ,'6.. THE STATE Alaska Oil and Gas ofZLZV 1 Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `wh Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Roger Winter SCANNED WI Field Supervisor ConocoPhillips Alaska,Inc. P.O Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 2T-10 Permit to Drill Number: 186-096 Sundry Number: 318-104 Dear Mr. Winter: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, WEE Hollis S. French Chair DATED this S day of March, 2018. RBDMSL MAR 21 2018 • • RECEIVED STATE OF ALASKA MAR 1 3 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION 3 / /5/1 .P APPLICATION FOR SUNDRY APPROVALS AGCC 20 MC 25.280 1.Type of Request: Abandon D Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ SC Repair 0• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory 0 Development ❑ 186-096 3.Address: Stratigraphic ❑ Service 2 „ 6.API Number: P.O Box 100360,Anchorage Alaska 99510 50-103-20064-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA KRU 2T-10 Will planned perforations require a spacing exception? Yes ❑ No Rir 44 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025569 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total cfsp rl(ft): Total Depth`�yq(ft): Effectiv -.t. MO: Effective th TVD: MPSP(psi): Plugs(MD): Junk(MD): C7 8 1 _ ,� � 1 0 76 / 4 3000 NA NA Casing Length Size MD TVD Burst Collapse Structural NA NA NA NA NA NA Conductor 72 16 110 110 NA NA Surface 3262 9 5/8 3296 2800 NA NA Intermediate NA NA NA NA NA NA Production 8202 7 8233 6097 NA NA Liner 2943 2 3/8 10870 7968 NA NA Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7852-7898,7910-8081 , 5832-5864,5872-5990 3.5 L-80 7968 Packers and SSSV Type: PBR-BAKER PBR Packers and SSSV MD(ft)and TVD(ft): MD=7654 TVD=5701 PACKER-BAKER F-1 PERMENT PACKER MD=7899 TVD=5864 No SSSV CAMCO DS NIPPLE MD=507 TVD=507 12.Attachments: Proposal Summary El Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 1=1' 14.Estimated Date for 3/24/2018 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 ' GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Roger Winter Contact Name: Roger Winter/Roger Mouser Authorized Title: WI Field Superv'sor Contact Email: N1927(a)conocophillips.com Q/j� r Contact Phone: 907-659-7506 Authorized Signature: •G^"'vc,,t,i/l, Date: 3/11/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:s i s /d,{ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance 0 Other: d7hC,/v doGvkt---- z ., o Post Initial Injection MIT Req'd? Yes ❑ No f Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: y1) �D!¢ / APPROVED BY Approved by: COMMISSIONER THE COMMISSIONDate: 3 fi z ie q)( BDMSEL rI NAL Attachments Duplicate �1`� Form 10-403 Revised 4/2017 Approved t v li from the date of approval. Attachments in Duplicate • S ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 11, 2018 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Hollis French: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2T-10, PTD 186-096 for repairing surface casing leak. Please contact me at 907-659-7506 if you have any questions. Sincerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor Enclosures: Description Summary of Proposal 10-403 Application for Sundry Approval CD2-73 Wellbore Schematic S ConocoPhillips Alaska,Inc. Kuparuk Well 2T-10 (PTD 186-096) SUNDRY NOTICE 10-403 APPROVAL REQUEST March, 2018 This application for Sundry approval for Kuparuk well 2T-10 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow._ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing. 2. Remove the floor grate,well house, flow lines,and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to—20'. 4. Install nitrogen purge equipment for the conductor and OA(if needed)so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test(OA cemented to surface)to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s)and return the well to injection. 13. File 10-404 with the AOGCC post repair. KUP INJ 2T-10 Y ConocON1illips Well Attributes us Max Angle&MD TD Alaska,)C. Vf Wellbore API/UWI Field Name Wellbore Status ncl)°) MD(ftKB) Act etm(ftKB) ,,,,,,,...fps 501032006400 KUPARUK RIVER UNIT INJ 50.88 5,600.00 8,256.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2T-10,.92320151;41 29 PM SSSV:NIPPLE Last WO: 3/3/2014 41.02 6/20/1986 Vertical schematic(actuap... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;283 -""til--- )"'r- Last Tag:SLM 8,101.0 5/1/2014 Rev Reason:OC smsmith 9/23/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED I Casing Description OD(in) ID(in) Top)ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread L ) SURFACE 9 5/8 8.921 34.0 3,295.5 2,800.2 36.00 J-55 BUTT Lnumuniunamanim�naum sauuk timmu a ten' aluk Casing Description 01)(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread /'CONDUCTOR;38.0-110.00- /'"" -�rMi PRODUCTION TIE- 7 6.276 30.3 1,779.5 1,726.2 26.00 L-80 TCII BACK Casing Description OD(in) ID(in) Top(ftKB) Set Depth(BOB) Set Depth)TVD)...WtlLen(I...Grade Top Thread NIPPLE;507.3 -c PRODUCTION 7 6.276 1,779.5 8,232.7 6,097.9 26.00 J-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread WINDOW L1-01 7 6.276 7,924.0 7,934.0 5,888.0 q"� Tubing;Strings 3 Tubing Description !String Ma...I ID(in) Top(ftKB) Set Depth(ft..I Set Depth)TVD)(...Wt(Ib/ft) Grade Top Connection , TUBING-Upper 3 1/2 2 992 28 3 7,906 9 5,869.5 9.30 L-80 EUEBmd PRODUCTION TIE-BACK;30.3- Iyyy I g '1I Completion 1.778.5 8g • Completion Details 3,. Nominal ID. GAS LIFT;2,998.6-.9Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 28.3 28.3 0.02 HANGER 'CAMERON TUBING HANGER 3.500 507.3 507.3 1.07 NIPPLE CAMCO"DS"NIPPLE(2.875') 2.875 7,645.4 5,695.2 48.71 LOCATOR BAKER NO-GO LOCATOR 2.990 7,646.3 5,695.8 48.71 SEAL ASSY SEAL ASSY 8'Space out 2.990 SURFACE;34.0-3,295.5-4 4 7,654.3 5,701.0 48.73 PBR BAKER PBR 2.990 I 7,676.8 5,715.9 48.77 PACKER BAKER FHL PACKER ASSY 2.970 GAS LIFT;4,197.0 'I: 7,729.5 5,750.6 48.62 NIPPLE CAMCO"DS"NIPPLE(2.813") 2.813 7,839.0 5,823.6 47.76 BLAST JOINT 3 1/2"Blast Joint EUE 8rd 3.000 GAS LIFT;5,123.5 7,899.7 5,864.6 47.17 LOCATOR BAKER NO-GO LOCATOR 2.980 7,900.5 5,865.1 47.16 SEAL ASSY BAKER 80-40 SEAL ASSY w/1'Space out 2.980 Tubing Description !String Ma...'ID(in) !Top(ftKB) -Set Depth(ft..1 Set Depth(TVD)(...1Wt(Ib/ft) 'Grade 'Top Connection TUBING-Lower 31/2 3.000 7,899.0 7,967.6 5,911.1 9.30 L-80 IBTM GAS LIFT;7,588.4 i Completion Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) LOCATOR;7,645.4 7,899.0 5,864.1 47.18 PACKER BAKER F-1 PERMANENT PRODUCTION PACKER 4.000 SEAL ASSY,7.6403 7,901.4 5,865.8 47.15 SEE BAKER 80-40 SEAL BORE EXTENSION 4.000 PER;7,654.3 PACKER;7,076.8 7,905.8 5,868.8 47.10 XO Reducing Crossover Sub 43/4"ACME Box x31/2"EUE Pin 2.920 7,959.3 5,905.4 46.46 NIPPLE CAMCO"D"NIPPLE 2.750 rr ' 7,966.7 5,910.5 46.37 SOS SOLID SEAT SHEAR OUT SUB pinned to 3500 PSI 2.990 NIPPLE;7,72953. Other In Hole(Wireline retrievable plugs,'Yalves,pumps,fish @W)„ - � I® Top(TVD) Top Incl 11 Top)ftKB) (ftKB) F) Des Com Run Date ID(in) 7,932.0 5,886.7 46.79 WHIPSTOCK Baker XL MonoBore Whipstock 6/6/2014 GAS LIFT;7,782.0 - - MONOBORE I: Perforations&Slots ---'111.?:' Shot BLAST JOINT;7,839.01 _.. Dens (PERF;7,852.0-7,898.0- aTop)TVD) Btm(ND) )shotslf ( Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,852.0 7,898.0 5,832.3 5,863.5 C-4,UNIT B, 9/10/1986 ' 12.0 IPERF 5"HyperJet II:90 Deg. 1 2T-10 Ph LOCATOR;7,899.6-, 11` LI 7,910.0 7,913.0 5,871.6 5,873.7 A-2,2T-10 6/2/2014 3.0 APERF 3'Gun,120 DegPh. PACKER;7,898.9 /' to 7,968.0 8,018.0 5,911.4 5,946.1 A-4,A-3,2T- 6/22/1988 4.0 RPERF 2 1/8"EnerJet SBE;7,901.4 10 SEAL ASSY;7,900.41 7,968.0 8,025.0 5,911.4 5,951.0 A-4,A-3,2T- 7/2/1991 4.0 RPERF 2 1/8"DynaStnp;0 Deg. -, 10 Ph 7,968.0 8,025.0 5,911.4 5,951.0 A-4,A-3,2T- 9/10/1986 1.0 IPERF 4"HyperJet II;90 Deg. APERF;7,910.0-7,913.0 10 Ph __ 8,051.0 8,081.0 5,969.2 5,990.3 A-2,2T-10 7/2/1991 4.0 APERF 2 1/8"DynaStrip;0 Deg. Ph '" 8,052.0 8,081.0 5,969.9 5,990.3 A-2,21-10 9/10/1986 4.0 RPERF 4"HyperJet II;90 Deg. Ph WINDOW L1-01;7,924.0- Mandrel Inserts 7,934.0 It ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sane TypeType ype (in) (psi) Run Date Com li 1 2,998.6 2,601.2 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 4/10/2014 NIPPLE,7,959.3 2 4,197.0 3,396.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 4/10/2014 SOS;7.066.7 III 3 5,123.5 3,999.6 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 4/10/2014 RPERF;7,968.0-8,018.0 .l 4 7,588.4 5,657.5 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/28/2014 RPERF;7,968.0-8,025.0a (PERF;7,968.0-8,025.0 T- 5 7,782.0 5,785.5 CAMCO MMG 1 1/21INJ HFCV RK 0.250 0.0 8/14/2015 _ Notes:General&Safety I ' ri ` • End Date Annotation _ ._12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 I�_ - 6/20/2014 NOTE:ADDED LATERALS L1,L1-01(L1-01 IS OFF MAIN WELLBORE) APERF;8,051.0-8,081.0 _ RPERF;8,052.0-8,001.0 ' c 7/31/2014 NOTE:SC LEAK UNKNOWN DEPTH. SC CEMENTED DURING 2014 WORKOVER. _ 8/13/2015 NOTE:TAG 2 3/8 tubing liner at 7882'VIILM It 1111(C - PRODUCTION;1,779.5-8,232.7 SLOTS;8,057.0-9269.4 WHIPSTOCK-MON0130RE; 7,932.0 SLOTS;8.094.7-10,869.0 LINER,L1 LATERAL;8,0453 10,771.0 LINER,L1-01 LATERAL; 7,926.9-10,870.0-"--- • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jun Begg DATE: Thursday,June 15,2017 P.I.Supervisor � q oli7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-10 FROM: Lou Laubenstein KUPARUK RIV UNIT 2T-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-10 API Well Number 50-103-20064-00-00 Inspector Name: Lou Laubenstein Permit Number: 186-096-0 Inspection Date: 6/5/2017 Insp Num: mitLOL170607151630 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-10 ' 1Type Inj W- TVD 5716 - Tubing 2240 2240 2240 - 2250 - PTD 1860960 Type Test SPT Test psi 3000 - IA 1030 3300 - 3220 - 3200 - BBL Pumped: 1.8 - BBL Returned: 1.9 - OA 15 15 - 15 15 - Interval REQVAR 1P/F P Notes: MITIA per AIO 2B.092 to MAIP SCANNED EP 13 201?. Thursday,June 15,2017 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,October 03,2016 TO: Jim ReggI P.I.Supervisor f en 101 13 I 41(e- SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-10 FROM: Bob Noble KUPARUK RIV UNIT 2T-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry:leg-- NON-CONFIDENTIAL 13' -NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-10API Well Number 50-103-20064-00-00 Inspector Name: Bob Noble Permit Number: 186-096-0 Inspection Date: 9/30/2016 Insp Num: mitRCN161001065304 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-10 Type Inj W TVD 5716 Tubing 2345 " 2345- 2345 - 2345 - PTD 1860960 (Type Test SPT Test psi 1 3000 - IA 1350 3310 3220 - 3210 Interval REQVAR P/F P ✓ OA 0 0 0 • 0 Notes: AIO 21_3_...02;1,41TIA to max anticipated injection pressure every 2 years.OA is cemented to serface. 1.5 bbls pumped.✓ NNED jUN 0 r7 2(1U7. Monday,October 03,2016 Page 1 of 1 APR 0 5 2016 WELL LOG TRANSMITTAL# AOGCC To: Alaska Oil and Gas Conservation Comm. March 30, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Cp Anchorage, Alaska 99501 M K.BE�NDE RE: Injection Profile : 2T-10 SCANNED ' Run Date: 9/29/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-10 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20064-00 Injection Profile Log 1 Color Log 50-103-20064-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ' At4 c MZk., O WELL LOG TRANSMITTAL#902894345 To: Alaska Oil and Gas Conservation Comm. December 11, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501t l4/201‘ .vi.K.BENDER RE: Static Bottom Hole Pressure Record: 2T-10 Run Date: 11/9/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20064-00 Static Bottom Hole Pressure Record (Field Print) 1 Color Log 50-029-20064-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 SC144* i Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: D�✓a��v `���'�C , . ,l, ,il Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (do.e) /~Two-Sided REscAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Grayscale items: [] ~ Poor Quality Originals: Other:. [] Diskettes, No. [] Other, No/Type TOTAL PAGES: 6~ NOTES: ORGANIZED BY:~REN VINCENT SHERYL MARIA LOWELL Project Proofing [] Maps~: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: [] By: Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ SCANNED BY: ~BREN VINCENT SHERYL MARIA LOWELL DATE: ReScanned {done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) Rev1 NOTScanned.wpd • �'m s , \ �':t _ _ — - 333 Vvic SEvc ,h AvL—ue ,- - j.�� (;(;A Ii RN(); C9AN 'ARNEI 1, AnchorGae A's a y95U1 3572 t '�j r/O,. yrs? 2/9 1/133 0y uu.L i F- Ron Phillips Sr. CTD Engineer SCANNED JUL 2 9 2014 Q ,6, �� CTD ConocoPhillips Alaska, Inc. ii S. U P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-10 Sundry Number: 314-300 Dear Mr. Phillips: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / P-) e-e,,o Cathy '. Foerster Chair DATED this /CP day of May, 2014. Encl. • STATE OF ALASKA RECEIVED AL-.......A OIL AND GAS CONSERVATION COMM. ON APPLICATION FOR SUNDRY APPROVALS MAY 0 8 2014 20 AAC .280 (/'' s//G//sz. 1.Type of Request: Abandon r Rug for Redrill y/4,"-F (orate New Pool r Repair well r Chanc OGCQam r Suspend r Rug Perforations r"• Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 186-096 • 3.Address: 6.API Number: Stratigraphic r Service r . P.O. Box 100360,Anchorage,Alaska 99510 50-103-20064-00 • 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 r 2T-10 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 • Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8256 • 6114 ' 8148'. 6038' none none Casing Length Size MD ND Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 3262 9.625 3296' 2800' PRODUCTION 8202 7 8233' 6098' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7852-7898,7968-8025,8051-8081 • 5832-5864,5911-5951,5969-5990 3.5 L-80 7968 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER FHL PACKER ASSY ' MD=7677 TVD=5716 PACKER-BAKER F-1 PERMANENT PRODUCTION PACKER . MD=7899 TVD=5864 SSSV-CAMCO TRDP-1A-SSA MD=1778 TVD=1725 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service Fr, . 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: /"S4s'I'1 5/21/2014 Oil r Gas r WDSPL r Suspended ,. • 16.Verbal Approval: Date: WINJ r GINJ r WAG Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ron Phillips @ 265-6312 Email: Ron.L.Phillipsna conocophillips.com Printed Name Ro hillips Title: sr. CTD Engineer s / Signature W.41 Phone:265-6312 Date / 7 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -7• 11—l.--20() Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RBDMS° . MAY 16 2014 Other: Spacing Exception Required? Yes ❑ No Ef/ Subsequent Form Required: / 6 y O c./ 1 / APPROVED BY /tom / Approved by: - COMMISSIONER THE COMMISSION Date: 5 Approved applicatiot] valid for 12 months from the ,�dat t approval. Form 10-403(Revised 10/2012) S'4L, 'v 6'101� Submit Form and Attachments in Duplicate RIGINAL , ,7%.Z y KRU 2T-10 CTD Summary for Plugging Sundry (10-403) Summary of Operations: Well 2T-10 is a Kuparuk A-sand/C-sand injection(service)well equipped with 3'/2"tubing and 7" production casing. The well was recently worked over by removing the original 3'/2"X 2-7/8"tubing and replacing it with a 3-1/2"completion. The CTD laterals drilled from the injector well will target the Kuparuk A-sand in fault blocks adjacent and corresponding to the wells current locations. 2T-10 is planned for 2 laterals or 5,798' of total hole in the A-sand reservoir. Prior to drilling,the existing A-sand perfs in 2T-10 will be plugged with cement to provide a means to kick out of the 3-1/2"and 7"casing.Note the C sand perfs are still accessible through a Camco MMG injection mandrel. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand perfs in this manner. After plugging off the existing A-sand perfs with cement, a mechanical whipstock will be placed in the 3-1/2"tubing tail at the planned kickoff point. The 2T-10L1 and 2T-10L1-01 laterals will exit through the 3-1/2"tubing and 7"casing at 7932' MD and will target the A3 sands north and south of the existing well. The laterals will be completed with 2-%" slotted liner from TD with the final liner top located inside the 3'/2"tubing at 7927' MD. CTD Drill and Complete 2T-10 Laterals: May 2014 Pre-CTD Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs—T&IC 3. MIT-IA 4. RU slickline. Drift tubing with dummy whipstock,tag PBTD 5. RU Eline: Obtain SBHP and run GR/CCL for jewelry correlation log 6. E-Line: Perforate the 3-1/2"tubing tail from 7907' —7912' MD 7. RU coil: Cement Squeeze A-sand perforations, and fill 3-1/2"x 7"annulus 8. RU slickline. Tag top of cement and pressure test. 9. RU coil: Mill out cement in the 3-1/2"tubing 10. RU E-Line: Dummy WS drift to 7959'. Run and set WS. 11. Prep site for Nabors CDR2-AC, including setting BPV p f9k r"e. fe v�'e,,� /lccefSarj✓ vie) IlGn2 w 1 coif /41„..e_ S � V,'ti rteI l�'ni/ fir back 1.110 ethr'`— bort- s / Page 1 of 2 5/7/2014 Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2T-10L1 Lateral(A3 sand north) a. Mill 2.80"window at 7,932' MD. b. Drill 2.74"x 3.00"bi-center lateral to TD of 10,950' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8,020' MD 3. 2T-10L1-01 Lateral(A3 sand south) a. Kick off of the aluminum billet at 8,020' MD b. Drill 2.74"x 3.00"bi-center lateral to TD of 10,800' MD c. Run 2%" slotted liner from TD up to 7,927' MD, inside the 3'/2"tubing 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Flow back for clean-up then return to injection. Page 2 of 2 5/7/2014 ' € KUP INJ 2T-10 • ConocoPhillips I Well Attributes Max Angle&MD TD Alaska,Ilr Wellbore API/UWI Field Name Wellbore Status ncl(") MD(MB) 'Act Btm IftKB) [nn.,,c, pc 501032006400 KUPARUK RIVER UNIT INJ 50.88 5.600.00 8,256.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2T-10,5/2/2014246.37 PM SSSV:NIPPLE Last WO: 41.02 6/20/1986 Vertical schematic(actual) Annotation Depth(MB) End Date Annotation Last Mod By End Date ..__._.. ....._.... Last Tag:SLM 8,101.0 5/1/2014 Rev Reason.WORKOVER,GLV C/O,TAG haggea 5/2/2014 HANGER;28.3 ' I Casing Strings ,__ Casing Description OD(in) ID(in) Top l(tKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I Grade Top Thread CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED 1 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND) W Len(I...Grade Top Thread l SURFACE 95/8 8.921 33.6 3,295.5 2,800.2 36.00 J-55 BUTT ICasing Description OD(in) ID(in) Top(ftKB) Set Depth(11K8) Set Depth(ND)... Wt/Len0...Grade -Top Thread • PRODUCTION TIE- 7 6.276 30.3 1,779.5 1,726.2 26.00 L-80 TCII •MI CONDUCTOR;38.0-110.0• r. G Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 1,779.5 8232.7 6,097.9 26.00 J-55 BUTT Tubing Strings NIPPLE:507.3 Tubing Description String Ma...ID(in) Top(565) Set Depth(ft...Set Depth(ND)(...WI(Ibitt) Grade Top Connection TUBING-Upper 31/2 2.992 28.3 7,906.9 5.869.5 9.30 L-80 EUE8rnd Completion Completion Details 4 ' Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 28.3 28.3 0.02 HANGER CAMERON TUBING HANGER 3.500 PRODUCTION TIE-BACK;303- r.:: 507.3 507.3 1.07 NIPPLE CAMCO"DS"NIPPLE(2.875") ° 2.875 1,7755 16 7,645.4 5,695.2 48.71 LOCATOR BAKER NO-GO LOCATOR 2.990 7,646.3 5,695.8 48.71 SEAL ASSY -SEAL ASSY 8'Space out 2.990 GAS LIFT,2.990,6 _ 7,654.3 5,701.0 48.73 PBR BAKER PBR 2.990 7,676.8 5,715.9 48.77 PACKER BAKER FHL PACKER ASSY 2.970 7,729.5 5,750.6 48.62 NIPPLE CAMCO"DS"NIPPLE(2.813") 2.813 1 7,839.0 5,823.6 47.76 BLAST JOINT 3 12"Blast Joint EUE 8rd 3.000 SURFACE;33.6-3295.5- . 7,899.7 5,864.6 47.17 LOCATOR BAKER NO-GO LOCATOR 2.980 7,900.5 5,865.1 47.16 SEAL ASSY BAKER 80-40 SEAL ASSY w/1'Space out 2.980 1 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(1111(1) Grade Top Connection GAS LIFT;4,197.0 E TUBING-Lower 312 3.000 7,899.0 7,967.6 5,911.1 930 L-80 IBTM Completion Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;5,123.5 7,899.0 5,864.1 47.18 PACKER BAKER F-1 PERMANENT PRODUCTION PACKER ' 4.000 7,901.4 5,865.8 47.15 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 • al 7,905.8 5,868.8 47.10 XO Reducing Crossover Sub 4 3)4"ACME Box x 3 1/2"EUE Pin - 2.920 • 7,959.3 5,905.4 46.46 NIPPLE CAMCO"D"NIPPLE 2.750 GAS LIFT;7,580.4 II 7,966.7 5.910.5 46.37 SOS SOLID SEAT SHEAR OUT SUB pinned to 3500 PSI 2.990 E El Perforations&Slots Shot LOCATOR;7,645.4- Dens Top(TVD) Bier(ND) (shots/f SEAL ASSY;7,646.3 Top(18(B) Btm(9KB) (ftKB) (ftKB) Zone Date t) Type Com PBR;7,654.3 7,852.0 7,898.0 5,832.3 5,863.5 C-4,0 UNIT B, 9/10/1986 12.0 IPERF 5"HyperJetII;90 Deg. PACKER;7,6768 " -'1' 7,968.0 8,025.0 5,911.4 5,951.0 A-4,A-3,2T- 7/2/1991 4.0 RPERF 2 1/8"DynaStrip;0 Deg. _ 10 Ph 7,968.0 8,018.0 5,911.4 5,946.1 A-4,A-3,2T- 622/1988 4.0 RPERF 2 1/8"EnerJet +� 10 N NIPPLE;7.729.5 7,968.0 8,025.0 5,911.4 5,951.0 A-4,A-3,2T- 9/10/1986 1.0 IPERF 4"HyperJet 11;90 Deg. • 10 Ph _ 8,051.0 8,081.0 5.969.2 5,990.3 A-2,2T-10 7/2/1991 4.0 APERF 2 1/8"DynaStrip;0 Deg. Ph GAS UFT;7,782.0 8,052.0 8,081.0 5,969.9 5,990.3 A-2.2T-10 9/10/1986 4.0 RPERF 4"HyperJet II;90 Deg. i Ph Mandrel Inserts a st v. ab BLAST JOINT;7.03901 I - on Top(ND) Valve Latch Port Size TRO Run IPERF;7,852.0-7,898.0- N Top(ftKB) (ft613) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com { 2,998.6 2,601.2 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 4/10/2014 2 4,197.0 3,396.1 CAMCO MMG 11/2 GAS LIFT 'DMY RK 0.000 0.0 4/10/2014 3 5,123.5 3,999.6 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 4/10/2014 LOCATOR;7.899F."a7�1 61 4 7,588.4 5,657.5 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 5/1/2014 PACKER;7,090.9 5 7,782.0 5.785.5 CAMCO MMG 11/2 INJ DMY RK 0.000 0.0 4/10/2014 A, to11. Notes:General&Safety SBE;7,901.4 1 SEAL ASSY;7.900.41 vi, End Date Annotation 12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 a • NIPPLE;7,9593 'i SOS;7,966.7 IIII III RPERF;7,968.0-8,018 0 IPERF;7,968.0-8,025.0 RPERF;7,968.0-8,025.0 - APERF;8,051.08,081.0 ..- ' O RPERF;8,052.08,081.0 5 PRODUCTION;1779.58,232.7 • �i,'��1/7%,d� THE STATE Cw -C C ._ a ec � 'r) a .c C �_ S� p � 333 est Sevenih Avenue V.,,::.,,-1--- :- (�O\%FR ORS ,AN PARNhI.1 Anchorage Aiaska 99501 3512 Main 90/.77c )433 0,4.yS�ua47W.� yi ,,c)/ / WE° NAY20GG14 Brett Packer Supervising Workover Engineer ConocoPhillips Alaska, Inc. —. d q 6 P.O. Box 100360 ` i . 6 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-10 Sundry Number: 314-045 Dear Mr. Packer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,-„, 11-9--;(.4. - Cathy P. Foerster Chair DATED this Z4' day of January, 2014. Encl. STATE OF ALASKA eifi� �� ''' a `-, AL A OIL AND GAS CONSERVATION COMM` _,ON 1 tir • APPLICATION FOR SUNDRY APPROVALS1' T _ A6 j z 511}.4__ 20 AAC 25.280;•., )t --1_, r 1.Type of Request: Abandon (— Rug for Redrill r Pertr orate New Pool r Repair w ell Change Iot�EiN� m Suspend r Rug Perforations r Perforate r Pull Tubing r . Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing 1 .!, +Other: (- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Developrrent r 186-096 - 3.Address: Stratigraphic r Service r,r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20064-00 • 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 r7. ... 2T-10 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 . Kuparuk River Field/Kuparuk River Oil Pool d 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): 8256 • 6114 - 8148' 6038' 7783' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 3262 9.625 3296' 2800' PRODUCTION 8202 7 8233' 6098' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7852-7898,7968-8025,8051-8081 5833-5864,5912-5951,5969-5990 3.5x2.875 J-55 7946 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL HYD SET PACKER . MD=7760 TVD=5771 PACKER-BAKER D PERMANENT PACKER W/5'SBE , MD=7923 TVD=5881 SSSV-CAMCO TRDP-1A-SSA % MD=1778 TVD=1725 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service F • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/15/2014 Oil r Gas r- WDSPL r Suspended r 16.Verbal Approval: Date: VVINJ r` , GINJ r WAG r Abandoned r Commission Representative: GSTOR r- SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Email: J.Brett.Packeraconocophillips.com Printed Name Brett Packer Title: Supervising Workover Engineer Signature / Phone:265-6845 Date l//C/l Commission Use Only Sundry Number: 5114-1)/15 Conditions of approval: Notify Commission so that a representative may witness / 1111 Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r RBDMS= "AY 0 9 2014 Other: 5'0P 7L.e-s U 3000 p5 t' /7--- !A r c- yr vt-d q,c� r lab'for /1 De d i vt j ec ti o'4 ( fat-r �v� /�' inc55 td�" � Spacing Exception Required? Y s ❑ No Subsequent Form Required: /O _ 4 O APPROVED BY �t Approved by: COMMISSIONER THE COMMISSION Date:/— ZT /� pproved application is valid tor 1�rgonth 12 J theJ date of approval. Form 10-403(Revised 10/2012) NAL / 1117-11i Submit Form and Attachments in Duplicate VLF IP3//1- ConocoPhillips Alaska A t P.O. BOX 100360 1 .a ANCHORAGE,ALASKA 99510-0360 January 16,2014 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Injector 2T- 10(PTD# 186-096). Since 2009, ConocoPhillips has been monitoring subsidence rates on all of our drillsites and has been proactively drifting the wells at regular intervals depending on the severity of the subsidence on each pad. Once a well is no longer able to drift for a tubing plug, the well is shut-in and either put on the worker schedule or P&A'd. Drillsite 2T is one of the highest subsidence afflicted pads in the field, of which many of the wells on 2T pad have already been worked over or P&A'd. 2T-10 has had as much as 43 inches of subsidence since the first wellhead measurement was taken in 1995 and based on recent measurements,is subsiding—3.1 inches/year. 2T-10 was originally drilled & completed as a 3 '/2" selective single A&C sand producer in 1986. It was on production for nine years at which point it was converted to a WAG injector. The well has remained an injector ever since. In 2005, a drift&tag indicated the A-sand perfs were mostly covered with fill. In 2007,an attempt to FCO the well was aborted due to excessive pick-up weights; this was the first sign of corkscrewed tubing. The well still maintained tubing&casing integrity and therefore remained online. In March 2009,the well failed an MIT-OA, and subsequently a surface casing leak was found at 324' MD and the well was shut-in. In November 2011, a waiver was granted for water-only injection and the well was brought back online, but only three months later, the well failed its proactive subsidence drift and was therefore shut-in permanently pending a workover or P&A. This well has been chosen as a CTD candidate, and therefore we would like to perform a workover to fix the well and set it up for coiled tubing drilling. The proposed workover plans are to pull the entire 3 ''/2"tubing completion, perform our typical subsidence workover which involves cutting & pulling the 7" casing above the top of cement, running new premium threaded 7"casing and cementing the OA to surface. This Sundry is intended to document the proposed work on the injection well, including the modification to the production casing, as well as request approval to workover the well. If you have any questions or require any further information,please contact me at 265-6845. Sincerely Brett Packer Supervising Workover Engineer CPAI Drilling and Wells • 2T-10 Rig Workover Subsidence Style RWO, P&R Selective for CTD Setup (PTD #: 186-096) Current Status: This well has been SI since February 2012 because the well failed its proactive subsidence drift. The well is isolated from the reservoir with a composite bridge plug at 7,783' MD. Scope of Work: Pull the entire completion,perform our typical subsidence workover which involves cutting& pulling the 7 casing above the top of cement and running new premium threaded 7"casing,cementing the OA to _ surface,and running a new 3 '/2"selective completion setting the well up for coiled tubing drilling. General Well info: Well Type: Injector ✓ MPSP: 1,200 psi using max stabilized SITP on 5/4/12 prior to a plug being set. Reservoir Pressure/TVD: 3,277 psi/5,947' TVD(10.6 ppg EMW)after loading the well w/6.7 ppg diesel on 4/1/12. Wellhead type/pressure rating: CIW Gen 4,7-1/16"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-IA passed on 9/27/13 MIT-OA failed on 8/25/11 Earliest Estimated Start Date: February 15,2014 Production Engineer: Deanna van Dam/Mike Balog Workover Engineer: Brett Packer(265-6845/j.brett.packer@cop.com) Pre-Rig Work 1. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Reverse circulate 8.6 ppg seawater. Verify well is dead. 3. Set BPV&blanking plug or two-way check,ND tree,NU BOPE&test. 4. Pull blanking plug&BPV or two-way check,MU landing joint,BOLDS's,unland tubing hanger&POOH laying down tubing. a. If tubing will not pull free,RU E-line&cut the tubing in the middle of 1st full joint above the PBR. 5. RIH w/7"casing scraper on drillpipe to top of PBR or tubing stub,circulate well clean. 6. RU E-line: RIH w/caliper,gyro,and CAST-M. Log from PBR/tubing stub back to surface to determine condition of casing and top of cement. Fire a string shot across the 2nd collar above the top of cement. 7. RIH&set an RBP(or IBP)below the top of cement. PT to 3000 psi and drawdown test to 0 psi. Dump 50'of sand on top of plug. 8. ND BOP stack,ND tubing head using Hydratight Tensioners, spear the 7"casing and re-land in the slips. Cut off excess casing growth. 9. NU BOP stack to the casing head. 10. RIH w/5 '/2"multi-string cutter(MSC),cut the 7"casing above the top of cement. 11. Spear the casing&circulate out the Arctic Pack from the OA w/heated diesel&seawater. 12. Split the stack&remove the casing slips. Nipple back up stack. 13. POOH laying down 7"casing. 14. RIH w/a 9%"casing scraper to the top of the 7"stub,circulate well clean. 15. RIH w/tandem string mills to gauge the 9%"casing for the ES cementer,dummy drift the ES cementer. 16. RIH w/the backoff tool to the top of the 7"casing stub,engage stub and backoff casing. 17. RIH w/7"casing spear,retrieve 7"casing stub. 18. RIH w/new 7"TC-II casing and ES cementer,screw into top of 7"casing,PT casing to 3000 psi. 2T-10 Rig Workover Subsidence Style RWO, P&R Selective for CTD Setup (PTD #: 186-096) 19. RU SLB cementers,cement the 7"x 9 5/8"annulus to surface. 20. ND BOPE,pull 7"casing in tension and land in the slips. Cut excess 7"casing. NU new tubing head&BOP stack,PT BOP's. 21. RIH w/6 1/4"mill tooth bit to top of cement,drill up cement, closing plug,and ES cementer. RIH w/6 %" concave mill and dry drill any remaining debris on top of sand. RIH w/wash string assembly and circulate out sand on top of the RBP/IBP. POOH standing back drillpipe. 22. RIH w/RBP retrieving head to top of plug,engage RBP and pull to release. a. If tubing was cut,MU overshot and RIH on drillpipe to top of tubing stub and jar seal assembly from the PBR. POOH standing back drillpipe,lay down fish. 23. MU 2.5"milling assembly on 2-1/16"CS Hydril tubing crossed over to 3 '/2"drillpipe,RIH to top of sand in the PBR,circulate well over to 11.0 ppg mud. 24. Begin circulating out sand&mill up composite bridge plug at 7783'MD. Once through plug,circulate bottoms-up, SI well&monitor. If any pressure at surface,weight up mud and repeat circulation. Chase cuttings down to the 2'/8"crossover at 7,920' MD. 25. MU wash shoe&RIH on drillpipe to top of PBR. Washover PBR to clear sand,circulate well clean. 26. RIH w/PBR overshot,engage the PBR,jar FHL packer free,POOH standing back drillpipe. a. If seal assy will not pull free,RU E-line and RIH w/2"undersized cutter,cut the tubing at 7820'MD (mid jt below the inj.mandrel). b. RIH w/Flipper-dog sub and washpipe,washover blast rings, engage collar below blast rings and pull seal assy.from the SBE. 27. MU packer mill and RIH to the Baker'D'packer at 7923'MD,commence milling'D'packer until it releases. 28. MU spear and RIH to retrieve'D'packer. 29. RIH w/double string mills and cleanout to PBTD at 8149'MD. Reverse circulate until well is clean. 30. MU tailpipe assembly and F-1 packer w/wireline setting tools,RIH on drillpipe to 7965'MD. 31. RU E-line: RIH with GR/CCL and correlate packer depth. 32. Make depth correction,drop a ball,pressure up drillpipe to set the F-1 packer. Release from packer. 33. POOH laying down drillpipe. 34. MU FHL straddle packer assembly and single in on 3 '/2"tubing to just above the F-1 packer. 35. Spot corrosion inhibited mud below FHL. 36. Sting into SBE until fully located,space out 1 ft from fully located,drop ball&rod,set the FHL packer. PT the IA. Shear the PBR. 37. Swap the entire well over to corrosion inhibited 9.6 ppg brine. 38. Space out w/pups,MU hanger&land,RILDS. 39. PT the tubing&IA,shear the SOV. 40. Install BPV or two-way check,ND BOPE. 41. NU tree. If BPV is installed,pull BPV&install tree test plug. Test tree. Pull test plug/two-way check. 42. Freeze protect well w/diesel. 43. Set BPV. 44. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Pull ball&rod. Pull SOV&run new SOV,pull RHC plug,pull plug in nipple. 4. Turn well over to CTD for perf&cementing tbg tail. • • Proposed Subsidence RWO - CTD Setup Modified byJBP(1-12-14) 16"62#H-40 %/' shoe @ 110'MD j/ _ 3-1/2"Camco DS nipple©500'MD(2.875"min ID) // New 7"26#TC-lI 3-1/2"9.3#L-80 EUE 8rd Tubing to surface Casing to-2000'MD Cemented to Surface // 3-1/2"Camco MMG gas lift mandrel @ 1800'TVD. 9-5/8"36#J-55 shoe @ 3296'MD 3-1/2"Camco MMG gas lift mandrel. Baker 3-1/2"PBR (3"ID) Baker FHL packer @-7748'MD(3.0"ID) 3-1/2"Camco DS landing nipple(2.813"min ID) C-sand perfs 3-1/2"Camco MMG injection mandrels. 7852'-7898'MD — +.� ' Baker Model'F'packer @ 7900'MD(4.0"ID) Baker 3-1/2"SBE @ 7903'MD MIS 3-1/2"IBTM-SCC R3,40'long KO joint @ 7910'-7950'ELM 7"short jts @ (tie to SWS CET 9-4-86) 7903'MD 7924'MD 3-1/2"Camco D nipple @ 7956'MD(2.75"min ID,No-Go) 7946'MD 3-1/2"WLEG @ 7965'MD. A-sand perfs 7968'-8081'MD 7"26#J-55 shoe @ 8233'MD _ ° KUP 2T-10 • COnOCoPhillipS " *MattiWell Attributes Max Angle&MD TD IncWellbore APUUWI Field Name Well Status Mel(°) MD(ftKB) Act Btm(ftKB) . Alaska, 501032006400 KUPARUK RIVER UNIT INJ 50.88 5,600.00 8256.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date ... Well Confer-7.r-7 o,10/2/2012 935:11AM SSSV:LOCKED OUT Last WO: 41.02 6/20/1986 Schemasc-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,971.0 10/17/2011 Rev Reason:WELL REVIEW osborl 10/2/2012 P' Casing eescript g String 0... String ID...To (ftKB) Set Depth(f C sl D Set Depth(TVD).. String Wt..String..String Top Thrd HANGER, "' •' CONDUCTORIon 16 15.062 P 38.0) 110.0( 110.0 6250 H-40 WELDED CURFACEcrI tion String 0... String ID...Top33 6 $e3,295.5 th). Set Depth(TVD)...String Wt...String...String Top Thrd 2,800.3 36.00 J-55 BUTT Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 30.3 8,232.7 6,097.9 26.00 J-55 BUTT Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd lilt/ .' TUBING 3.5x2.875 3 1/2 2.992 28.3 7,946.5 5,896.8 9.30 J-55 EUE8rdABMOD Completion Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (1 hem D.emiption Comment ID(In) 28.3 28.3 -0.12 HANGER CIW TUBING HANGER 3.500 CONDU3CTTOR6_. 1,778.1 1,725.0 32.08 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE(LOCKED OUT 3/7/96) 2.812 7,746.6 5,762.2 48.64 PBR BAKER PBR(ID 4.25"),SEAL(ID 3.00) 3.000 11. 7,760.3 5,771.2 48.51 PACKER BAKER FHL HYD SET PACKER 3.000 SAFETY VLV _c7"; 7,837.0 5,822.6 47.93 BLAST RINGS CARBIDE BLAST RINGS(2) 2.992 1,770 L,' 7,901.8 5,866.1 47.15 SLEEVE AVA BPL w/BPI ISOLATION SLEEVE 2.312 7,919.9 5,878.4 46.93 XO Reducing CROSSOVER 3.5 x 2.875 2.992 7,922.1 5,880.0 46.90 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.400 7,923.2 5,880.7 46.89 PACKER BAKER D PERMANENT PACKER w/5'SBE 3.250 j ' 7,937.9 5,890.8 46.71 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,945.8 5,896.3 46.62 SOS CAMCO SHEAR OUT SUB 2.375 SURFACE, [ [ 1 34 Other In Hole !reline retrievable plugs,valves,pumps,fish,etc.) Top Depth GAS UFT, (TVD) Top Inel 7.702 Top(ftKB) (MKB) (°) Description Comment Run Date ID(in) 7,783.0 5,786.2 48.29 PLUG BAKER OIL TOOLS 225 QUIK-DRILL COMPOSITE 5/4/2012 0.000 BRIDGE PLUG Perforations&Slots PER.7,747- -�' Shot Top(TVD) Btm(TVD) Dens =- Top(ftKB)Btm(RKB) MB) (ftKB) Zone Date (eh--- Type Comment PACKER'7.768 7,852.0 7,898.0 5,832.6 5,863.5 C4,UNIT B, 9/10/1986 12.0 IPERF 5"HyperJet II;90 Deg.Ph - 2T-10 7,968.0 8,025.0 5,911.5 5,950.6 A-4,A-3,2T-10 9/10/1986 1.0(PERF 4"HyperJet II;90 Deg.Ph PLUG.7.783- 7,968.0 8,018.0 5,911.5 5,945.6 A-4,A-3,2T-10 622/1988 4.0 RPERF 21/8"EnerJet 7,968.0 8,025.0 5,911.5 5,950.6 A-4,A-3,2T-10 72/1991 4.0 RPERF 21/8"DynaStrip;0 Deg.Ph 8,051.0 8,081.0 5,969.0 5,990.3 A-2,2T-10 7/2/1991 4.0 APERF 21/8"DynaStrip;0 Deg.Ph GAS UFT, 7.799 8,052.0 8,081.0 5,969.8 5,990.3 A-2,2T-10 9/10/1986 4.0 RPERF 4"HyperJet II;90 Deg.Ph Notes:General&Safety End Date Annotation 12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 7,852-7, (PERF, __ ° 5/24/2011 NOTE:PU WEIGHTS ERRATIC ALL THE WAY OUT TBG 898 SLEEVE.7,902 - I I SEAL ASSY, 7,922 .73 iiimmi- PACKER,7,923- i NIPPLE.7.938al SOS.7.946 I. RPERF. 7,968-8,018(PERF. PERF, 7.9688.025 *„,,; RPERF, rt 7.96e-e.025 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run !"" '- Stn Top(ftKB) (SKB) (°) Make Model (In) Sere Type Typo (In) (psi) Run Date Com... APERF, 1 7,701.8 5,733.1 49.07 OTIS LBX 1 12 GAS LIFT DMY RM 0.000 0.0723/1995 ® 2 7,798.9 5,796.7 48.14 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 2/18/1998 8,0518,081 RPERF, 8,052.8,081 PRODUCTION. To e.2s6\ A I. STATE OF ALASKA ` ALA OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 186 -096 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 e 50- 103 - 20064 -00 '00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 '° 2T -10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): - none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8250 feet Plugs (measured) 7783' true vertical 6110 feet Junk (measured) None Effective Depth measured 8148 feet Packer (measured) 7765, 7928 true vertical 6038 feet .•--- , - ""`- (true vertucal) 5774, 5884 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 SURFACE 3262 9.625 3296 2800 PRODUCTION 8202 7 J U� `" -g 6098 RECEIVE Perforation depth: Measured depth: 7852'- 7898', 7968'- 8025', 8051' -8081' jUN 2 1 2012 True Vertical Depth: 5833'- 5864', 5912' - 5951, 5969' -5990' A O^ GC Tubing (size, grade, MD, and TVD) 3.5x2.875, J - 55, 7951 MD, 5900 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL HYD SET PACKER 7765 MD and 5774 TVD PACKER - BAKER D PERMANENT PACKER W/ 5' SBE @ 7928 MD and 5884 TVD SSSV - CAMCO TRDP -1A SSSV @ 1783 MD and 1729 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service • Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ WAG ig GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -132 Contact Tyson Wiese , 263 -4250 Printed Name T Wiese Title Wells Engineer 6--'}O -11, Signature Phone: 263 -4250 Date Form 10-404 Revised 11/20 DMS JUN 2 12012 ,t1 • 17-- Submit Original Only • • Alisup- Drake, Sharon K From: Wiese, Tyson M Sent: Tuesday, June 19, 2012 4:17 PM To: Alisup- Drake, Sharon K Subject: FW: 2T -10 Well Secure Changes to Plan Forward for Secure (PTD 186 -096) fyl From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Tuesday, June 19, 2012 4:16 PM To: Wiese, Tyson M Cc: McMains, Stephen E (DOA) Subject: [EXTERNAL]RE: 2T -10 Well Secure Changes to Plan Forward for Secure (PTD 186 -096) Tyson, Since only part of the sundry work was completed a 10-404 should be submitted documenting the wellwork. On the form check box "plug perforations" and well status should remain a service well. The intent is to come back with a RWO to fix the upper well issues) and bring the well back into service... Please submit this email with the 10-404 for further documentation and clarification. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Wiese, Tyson M [mailto: Tyson .M.Wiese @conocophillips.com] Sent: Tuesday, June 19, 2012 3:21 PM To: Schwartz, Guy L (DOA) Subject: 2T -10 Well Secure Changes to Plan Forward for Secure Guy, 2T -10 Sundry Reference #: 312 -132 The asset has decided that they no longer want to pump the sand plug /cement plug above the top packer, as it will make the RWO quite a bit more difficult in 2013. We were able to get a composite bridge plug set and tested, so they were ok with that secure for now. Because the Sundry included the sand plug and cement job for the well secure, I need to cancel the sundry, as we will no longer be performing that work. I have been through this process before but I cannot remember if there is anything I need to turn in to cancel the sundry? Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1- 907 - 263 -4250 Cell:1- 907 - 230 -5388 6/19/2012 a KUP 2T -10 Conoc if Well Attributes Max Angle & MD TD Alaska, Inc, Wellbore API /UWI Field Name Well Status !nci (°) MD (ftKB) Act Btm (ftKB) 501032006400 KUPARUK RIVER UNIT INJ 50.88 5,600.00 8,256.0 t... Comment 1 (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: LOCKED OUT Last WO: 41.02 6/20/1986 Well Can(q_ - 2T -10 5/19/201 2 10 '.48'.53 AM schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,971.0 10/17/2011 Rev Reason: SET PLUG ninam 5/19/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (1_. Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 Wt. H- 40 String WELDED i 0, " Casing Description String 0... Siring ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd •` SURFACE 95/8 8.921 33.6 3,295.5 2,800.3 36.00 J - 55 BUTT BANGER, 33 ?' ' Casing Description String 0... String ID ... 'Top (MB) Set Depth (1... Set Depth (TVD) ... String .. ... String Top Thrd PRODUCTION 7 6.276 30.3 8,232.7 6,097.9 26.00 J -55 BUTT Tubing Strings Tubing Description String 0... String ID ...Top (kKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 3.5x2.875 I 3 1/2 2.992 I 33.1 I 7,951.3 I 5,900.1 I 9.30 I J -55 EUE8rdABMOD Completion Details Top Depth - (TVD) Top Intl Nomi... Top (ftKB) (kKB) ( °) Item Description Comment ID (In) 33.1 33.1 -0.10 HANGER CIW TUBING HANGER 3.500 CONDUCTOR, �. 1,782.9 1,729.1 32.21 SAFETY VLV CAMCO TRDP -1A -SSA SAFETY VALVE (LOCKED OUT 3/7/96) 2.812 38 - 110 7,751.4 5,765.3 48.60 PBR BAKER PBR 4.250 7,765.1 5,774.3 48.47 PACKER BAKER FHL HYD SET PACKER 3.000 SAFETY VLV, �, 7,841.9 5,825.8 47.87 BLAST RINGS CARBIDE BLAST RINGS 2.992 1,783 7,906.6 5,869.4 47.09 SLEEVE AVA BPL w/ BPI ISOLATION SLEEVE 2.312 C_a 7,924.7 5,881.7 46.87 XO Reducing CROSSOVER 3.5 x 2.875 2.992 7,926.9 5,883.3 46.85 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.400 7,928.0 5,884.0 46.83 PACKER BAKER D PERMANENT PACKER w/ 5' SBE 3.250 7,942.7 5,894.2 46.66 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,950.6 .6 4. . • • • - ' - OUT SUB ./'; ,,................----...4.441 SURFACE, ,• j 343,298 er In Hole Wireline retrievable plugs, valWaa�, G mps, fish, etc.) 0 tV1p --7 Top Depth GAS LIFT, (TVD) Top Inc! 7,707 Top (ttKB) (RKB) (°) Description Comment Run Date ID (in) y � 7,783 5,786.2 48.29 PLUG BAK ER OIL TOOLS 225 QUIK -DRILL COMPOSITE 5/4/2012 0.000 / "` ' BRIDGE PLUG Shot I ' t�rfora ions & Slots i PBR, 7,7 ' F 51 .1------)ftKB) ns Top (TVD) Btm(TVD) .✓' Top (ftKB) Btm (RKB) (ftKB) Zone Date (sh... Type Comment PACKER, 7.755 7,852 7,898 5,832.6 5,863.5 C-4, UNIT B, 9/10/1986 12.0 IPERF 5" HyperJet II; 90 Deg. Ph 2T -10 = , � 7,968 8,025 5,911.5 5,950.6 A -4, A -3, 2T -10 9/10/1986 1.0 IPERF 4" HyperJet II; 90 Deg. Ph PLUG, 7.763 y / / ' �j 7,968 8,018 5,911.5 5,945.6 A-4, A -3, 2T -10 6/22/1988 4.0 RPERF 21/8" EnerJet i ` � �� 7,968 8,025 5,911.5 5,950.6 A-4, A -3, 2T -10 7/2/1991 4.0 RPERF 2 1/8" DynaStrip; 0 Deg. Ph GAS LIFT, r ,.,, 8,051 8,081 5,969.0 5,990.3 A -2, 2T -10 7/2/1991 4.0 APERF 2 1/8" DynaStrip; 0 Deg. Ph 7,804 8,052 8,081 5,969.8 5,990.3 A -2, 2T -10 9/10/1986 4.0 RPERF 4" HyperJet II; 90 Deg. Ph 1 Notes: General & Safety - End Date Annotation I . 12/12010 NOTE: View Schematic w/ Alaska Schematic9.0 . IPERF, L - 1 5/24/2011 NOTE: PU WEIGHTS ERRATIC ALL THE WAY OUT TBG 7,852 -7,898 j 1 III SLEEVE, 7,907 - i 1 . 1 SEAL ASSY, 7.927 -- PACKER, 7,928 ',• NIPPLE, 7,943 I SOS, 7.951 RPERF, 7,988 -8,018 IPERF, \ 7,968-S025 RPERF. RPERF, 7,968.8,025 Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top)RKB) (RKB) ( °) Make Model (!n) Sery Type Type (in) (psi) Run Date Corn... 1 7,706.6 5,736.2 49.03 OTIS LBX 2 7,803.7 5,800.8 48.33 CAMCO KBUG 1 12 GAS LIFT DMY RM 0.000 0.0 7/23/1995 1 INJ DMY BK 0.000 0.0 2/18/1998 APERF, 8,051.8,081 RPERF, 8,052 -8,081 I PRODUCTION. 30 .8,233" A TD. 8,258 2T -10 Well Work Summary DATE . SUMMARY 1/1/12 ATTEMPT TO DRIFT TBG. ..78 WRP DMY DRIFT AND UNABLE TO PAST 121' SLM, RAN BRUSH AND 2.78 GAUGE RING; BRUSH AREA AND DRIFT FREELY DOWN TO ISO SLEEVE @ 7906' RKB. UNABLE TO DRIFT PAST 121' SLM W/ 2.78 WRP DMY OR PAST 344' SLM W/ 2.69 WRP DMY DRIFTS. IN PROGRESS. 1/2/12 ATTEMPT TO DRIFT TBG W/ 2.5" IBP DRIFT UNABLE TO GET PAST 1040' SLM, RAN 2.25" IBP DRIFT TOOLS FALL FREELY TO D NIPPLE @ 7942' RKB, SET CAT SV @ 7942' RKB; MIT TBG 3000 PSI PASS; PULL CAT SV COMPLETE. 4/1/12 DISPLACED TBG WITH 70 BBL "776" DSL -BASED FRICTION REDUCER. DRIFTED WELL WITH 10' x 2.5" DRIVE DOWN BAILER AND DRIFTED WITH 2.66" BARBELL ASS'Y TO AVA NIPPLE © 7906' RKB; NO PROBLEMS. COMPLETE. 4/12/12 RIG IN HOLE WITH A 24 ARM MIT CALIPER LOGGING TOOL TO DEPTH OF 7951' AND LOG TO SURFACE 5/4/12 SET BAKER OIL TOOLS 255 QUIK -DRILL COMPOSITE BRIDGE PLUG AT 7783'. LOG CORRELATED TO TUBING DETAIL RECORD DATED 09 SEP 1986. 5/6/12 DUMP BAILED SAND ONTO WRP @ 7783' RKB TO 7761' SLM, RIG DOWN FOR MAINTENENCE, IN PROGRESS 5/17/12 DUMP BAILED SAND f/ 7752' - 7717' SLM. IN PROGRESS. 5/18/12 ATTEMPTED BREAK UP SAND BRIDGE; BAILED f/ 7710' - 7713' SLM. IN PROGRESS. 6/11/12 MIT -T TO 2000 PSI PASSED. MIT -IA TO 1750 PSI PASSED. WELL READY FOR SLICKLINE TO PULL DV, IN PROGRESS. 6/19/12 PULLED DV @ 7706' RKB. TAGGED SAND @ 7687' SLM. COMPLETE. Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, June 19, 2012 4:16 PM To: 'Wiese, Tyson M' Cc: McMains, Stephen E (DOA) Subject: RE: 2T -10 Well Secure Changes to Plan Forward for Secure (PTO 186-096) Tyson, Since only part of the sundry work was completed a 10 -404 should be submitted documenting the wellwork. On the form check box "plug perforations" and well status should remain a service well. The intent is to come back with a RWO to fix the upper well issues) and bring the well back into service... Please submit this email with the 10 -404 for further documentation and clarification. Guy Schwartz Ll) Senior Petroleum Engineer JUL AOGCC 793 -1226 (office) 444 -3433 (cell) From: Wiese, Tyson M [mailto: Tyson .M.Wiese @conocophillips.com] Sent: Tuesday, June 19, 2012 3:21 PM To: Schwartz, Guy L (DOA) Subject: 2T -10 Well Secure Changes to Plan Forward for Secure Guy, 2T -10 Sundry Reference #: 312 -132 The asset has decided that they no longer want to pump the sand plug /cement plug above the top packer, as it will make the RWO quite a bit more difficult in 2013. We were able to get a composite bridge plug set and tested, so they were ok with that secure for now. Because the Sundry included the sand plug and cement job for the well secure, I need to cancel the sundry, as we will no longer be performing that work. 1 have been through this process before but I cannot remember if there is anything I need to turn in to cancel the sundry? Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1- 907 - 263 -4250 Ce11: 1 - 907 - 230 -5388 6/19/2012 • • 1,16-016 .4555 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 7, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2T -10 Run Date: 5/4/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20064 -00 XtlikihtE0 JUGV2ZW /_ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 1\-1/V2— Signed: ,,6 ;� �.�/ As • • 295 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 16, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 fitlitiNEX MAY 0 2012 RE: Multifinger Imaging Tool (MIT) : 2T -10 Run Date: 4/12/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -10 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 103 - 20064 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 12, Signed: 1 6/0 • L-N113- d SEAN PARNELL, GOVERNOR ALLAMA ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tyson Wiese Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 , 0 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -10 Sundry Number: 312 -132 Dear Mr. Wiese: a° LUIZ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P-741-e-14 Cathy . Foerster Chair DATED this Iv day of April, 2012. Encl. x e • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED April 3rd, 2012 Commissioner Dan Seamount APP 0 .. 2012 State of Alaska Alaska Oil & Gas Conservation Commission Alaska Oil & Gas Cons. Commission 333 West 7th Avenue Suite 100 Anche aLiu Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to suspend well 2T -10 (PTD #: 186 -096) due to subsidence damage. 2T -10 was originally completed in 1986, as an A and C Sand producer. The well was converted to an injector in 1995. A surface casing leak was found @ 324' KB in 2009, and a waiver was required to keep the well on PWI. Recently the well failed a subsidence drift that prevents a WRP from being set below the top packer. Due to the fact that we can no longer drift the tools required to confidently isolate the reservoir, CPAI has made the decision to suspend the well, until a subsidence RWO can be completed. The objective of this well suspend is to allow the well to be setup for a future subsidence RWO, • before continued subsidence damage prevents access to the wellbore. The current estimate for SBHP is 3,088 psi @ 5,899' TVD. The MASP is estimated at 1700 psi, which is the highest recorded SI tubing pressure since 2009, when PWI was suspended due to the Surface Casing Leak. The attached well suspend proposal illustrates the current plan forward. In order to proceed, variances to Section 20 AAC 25.112 (c) (1) (E) will be required. This section states a mechanical bridge plug will be set no more than 50' above the top of the perforated interval with 75' of cement on top of the plug by the displacement method. ConocoPhillips requests the following variances: 1.) A bridge plug will be set below the top packer. ConocoPhillips requests the production packer and bridge plug combination to be substituted for the mechanical bridge plug. 2.) The production packer is 87' above the top perforation. ConocoPhillips requests a variance to the 50' max footage above the top perforation. 3.) The bottom of the cement plug would be approx. 114' above the production packer. This will facilitate a future rig workover if ConocoPhillips decides to reenter this suspended well. Section 20 AAC 25.112 (c) (1) (E) does not state the cement plug must be directly on top of the bridge plug, but it could be inferred. ConocoPhillips requests a variance stating approval for the cement plug to be approx. 114' above the production packer. If you have any ques ns or require any further information, please contact me at 1- 907 -263- 4250. Sincerely, Tyson Wiese Wells Engineer CPAI Drilling and Wells STATE OF ALASKA 4 / t Q / Z A OIL AND GAS CONSERVATION COMM N f / APP FOR SUNDRY APPR ALS 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill f Perforate New Pool r Repair well r Change Approved Program r Suspend J ' Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 -096 ' 3. Address: Stratigraphic r Service ry" - 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20064 -00 ° 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No ) 2T -10 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25569 , Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD My, Total Depth T (ft): Effective Depth MD (ft): Effective,epth TV (ft): Plugs (measured): Junk (measured): 4 ' i 'fi2 Z.5b 4,10 6 .t.4rP 8148' &O55 /' � '°" � . / . / l Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 3262 9.625 3296' 2800' RECE VFn PRODUCTION 8202 7 8233' 6098 APR 0 3 23 2 i /Alas to 0i1 &, Gas Con. Commission I ft Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 1 Tubing r� 1 ` '7 ubin g M O:1 1 7852'- 7898', 7968'- 8025', 8051' -8081' 5833'- 5864', 5912'- 5951', 5969' -5990' 3.5x2.875 J:65 " "'9'951 -- Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL HYD SET PACKER MD= 7765 TVD= 5774 O PACKER - BAKER D PERMANENT PACKER W/ 5' SBE MD= 7928 TVD= 5884 SSSV - CAMCO TRDP -1A -SSA MD =1783 TVD =1729 12. Attachments: Description Summary of Proposal r"4" 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory Development ( Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/1/2012 Oil r Gas r WDSPL r Suspended I✓ 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG 1 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Printed Name T so Wiese Title: Wells Engineer Signature % Phone: 263 -4250 Date 04 - (1.- 7.00-, Commission Use Only Sundry Number. \7 5 ., .. l2j Conditions of approval: Notify Commission so that a representative may witness Plug Integrity A BOP Test /vaf _r Mecha icalIntegrityTest r Location Clearance r P./ .Las e_ s T. 1; c- r:_ Other: l / / ��. "c�L�r .,t '� // G>Cl1) .*, ^ / t� _ fin- re uc, /� ( C�.e..e,- ..� ., / -e- j`L O / 1/17-0-e--- Subsequent Form Required: APPROVED BY Approved by: p4.e....vdL,.....__ COMMISSIONER THE COMMISSION Date: 4- /0 — Form 10 -403 Revis d 1/2010 _ '/G• <L- f !' APR 11 201 2' �s Submit in Duplicate 4.11/ • 2T -10 Well Suspend Permit to Drill #: 186 -096 Well Status: The well recently failed a WRP subsidence drift. As a result, the PWI waiver was cancelled, and the well is now shut in. The well has a competent AVA isolation sleeve across the C- sand perfs, with the A -sand perfs still open to the tubing. A state witnessed MIT -IA to 3,300 psi passed on 11/19/2011, and a MIT -T to 3,000 psi passed on 01/02/2012. A surface casing leak was previously found @ 324' on 03/28/2009. Scope of Work: The objective of the 2T -10 Well Suspend is to temporarily abandon the perforated interval with a Packer /Bridge plug combination, a sand plug, and a 300' cement plug above the top packer. A circulation point will be shot above the cement and KWF will be placed, until a z subsidence RWO, or further suspension operations can be performed. General Well Info: MASP: 1700 psi (Max. SI tubing pressure recorded since the well was SI in 2009) Recent SBfP: 3088 psi @ 7,950' KB (5,899' TVD) recorded on 10/17/2011 IA/OA Status: MIT -IA passed on 11/19/2011, MIT -OA failed on 03/27/2009. OA Surface Casing Leak found at approx. 324' KB. Proposed Well Suspend: (Future Subsidence RWO) E -Line / Little Red: 1. RIH and set Bridge Plug @ 7,783' KB. If the 2.55" composite plug is used, pressure up tubing to 2,000 psi to test. Record Results. If the 1.69" IBP is used, and the CA -2 plug is still below, tag IBP to verify set depth. Slick Line / Little Red: 1. Dump bail sand plug from top of bridge plug 27,783' K_B to7 ,651' KB Approx. 48.2 gallons or 644 Ibs of 20/40 Sand. 2. RIH and tag top of sand plug to verify that the GLM #1 @ 7,707' KB is covered with approx. 50' of sand. 3. RIH with DPU and 1 3/8" tubing punch to shoot holes at approx. 7,595' KB, or in the middle of closest full joint near this depth. 4. Pump 20 bbls of diesel down the IA (at least 2 BPM pump rate) to ensure adequate comm. with the tubing. U -tube diesel at surface, from IA to tubing for F.P. TW • • Schlumberger Pumping: 1. RU to IA and displace sand plug down to the tubing holes @ 7,595' KB. 2. Shut down pumps and close in tubing prior to sand reaching the tubing holes. Allow sand to settle out in the IA. Approx. sand volume and weight to fill IA from packer @ 7,765' KB to 7,651' KB is 3 phis or 1688 Ibs of 20/-40 sand.. C � Slickline / Little Red: 1. RIH and tag top of sand in tubing. Checking to ensure that the IA sand plug did not migrate into tubing, and potentially block the circulation holes © 7,595' KB. 2. Pump 20 bbls of Diesel down tubing at a min rate of 2 bpm, to ensure tubing holes are not plugged with sand and provide adequate rate for cementing. 3. If tubing is plugged @ 7,595' KB, and circulation cannot be achieved, punch a second set of holes in tubing @ 7,533' KB, and establish circulation. Schlumberger Pumping: 1. Ensure an approved Sundry has been received from the AOGCC. 2. Displace 11 bbls of 15.8# cement to form a 300' plug in the IA and the tubing, from o 3 7 A 7,651' KB to 7,351' KB. 3 It. 3. Freeze Protect the well, and WOC for 24 hours. Slick Line / Little Red: 1. Notify the AOGCC inspector at least 24 hours prior to tag and pressure test. 2. RIH and tag TOC @ approx. 7,351' KB. Record Results. 3. PT cement plug in the tubing to 1,500 psi. Record Results. G 4. PT cement plug in the IA to 1,500 psi. Record Results. E -Line / Little Red: 1. RIH and tag TOC with tubing cutter at approx. 7,351' KB. 2. PUH to cut depth and cut tubing at approx. 7,282' KB. . 3. If cutting tools will not drift, RIH with 1 3/8" tubing punch and punch holes. , 4. Pump 185 bbls of 11# inhibited brine (KWF) above cement plug. 5. Pump 70 bbls of diesel for freeze protect. U -Tube at surface. TW 0 • 2T -10 Pre and Post Well Suspend Current Completion Proposed Well Secure i TRDP SSSV 1,783' KB L Circin1WF �° � and 9 5/8" 36# J -55 Casing @ 3,296' KB 6.) Cut tubing or punch : " holes @ approx. 7,282' KB 5.) Pump spacer and 300' cement plug; TOC @ 7,351' KB 4 „Ito- _ . 3.) Punch Tubing Holes •' @ approx 7,595' KB 7,707' KB - DMY 4.) Pump Sand -��� �`���� ��� Plug down IA to ..:' `:.: ;; a.. fillup to approx. ;.— ; i 7 ,651' KB ' "f'` "f'" 2.) Dump Bail Sand Plug � ∎■ aaa �owaoa ooaa ; :•:;•::• ri.•ui ,, i ri a 1 2 ,4 .51 �uirir . ;.• t0 7,651' KB FHL Hyd. Packer @ 7,765' KB 1.) Set Bridge Plug @ , 7,804' KB - DMY 7,783' KB 3, s C Sand Perfs: - - -- t_______:_....=__ 7,852' — 7,898' KB C -0'I AVA Isolation sleeve © 7,907' KB i` 0 I 3.5" 9.3# J -55 Tubing © 7,919' KB Hyd. Packer @ 7,928' KB i Camco D Nipple © 7,943 KB Me 2 7/8" Tubing © 7,951' KB : Tag:FiJI O. ?A 3CB � :: T Fill:@ 871 •. KB ::..� -- •A Sand Perfs: 7,968' — 8,081' KB ........:': ` 7" Prod. Casing TD @ 8,233' KB 4..:.:...... ..•: ` TW 04 -03 -2012 KU P • 2T -10 ConocoPhilkkpS �'«, ' 1 Well Max Angle MD TD Attributes Field Well Status B Act tm(nxe) Alaska, tr x'r 501032006400 KUPARUKRIVERUNIT INJ 50.88 5,600.00 8,256.0 GAnoCaRVINps Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date "' SSSV: LOCKED OUT Last WO: 41.02 6/20/1986 Well COnfia -2T -10 11/3/20118: 01' 46 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,971.0 10/17/2011 Rev Reason: TAG ninam 11/3/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 33.6 3,295.5 2,800.3 36.00 J - 55 BUTT HANGER, 33 111 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd PRODUCTION 7 6.276 30.3 8,232.7 6,097.9 26.00 J-55 BUTT Tubing Strings Tubing Description String 0... String ID ... (ftKB) Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd TUBING 3.5x2.875 3 1/2 I 2.992 I Top 33.1 I Set 7,951.3 I 5,900.1 9.30 I J-55 EUE8rdABMOD Completion Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (') Item Description Comment ID (!n) 33.1 33.1 -0.10 HANGER CIW TUBING HANGER 3.500 CONDUCTOR, 1,782.9 1,729.1 32.21 SAFETYVLV CAMCOTRDP -1A -SSA SAFETY VALVE 2.812 38 - 110 7,751.4 5,765.3 48.60 PBR BAKER PBR 4.250 7,765.1 5,774.3 48.47 PACKER BAKER FHL HYD SET PACKER 3.000 7,841.9 5,825.8 47.87 BLAST RINGS CARBIDE BLAST RINGS 2.992 SAFETYVLV i 7,906.6 5,869.4 47.09 SLEEVE AVA BPL w/ BPI ISOLATION SLEEVE 2.312 1,783 7,924.7 5,881.7 46.87 XO Reducing CROSSOVER 3.5 x 2.875 2.992 7,926.9 5,883.3 46.85 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.400 7,928.0 5,884.0 46.83 PACKER BAKER D PERMANENT PACKER w/ 5' SBE 3.250 7,942.7 5,894.2 46.66 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,950.6 5,899.6 46.56 SOS CAMCO SHEAR OUT SUB 2.441 SURFACE. 1 1 Perforations & Slots 343,296 Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment GASH 707 7,852 7,898 5,832.6 5,863.5 C -4, UNIT B, 9/10/1986 12.0 IPERF 5" HyperJet II; 90 Deg. Ph 2T -10 7,968 8,025 5,911.5 5,950.6 A-4, A -3, 2T -10 9/10/1986 1.0 IPERF 4" HyperJet II; 90 Deg. Ph 7,968 8,018 5,911.5 5,945.6 A-4, A -3, 2T -10 6/22/1988 4.0 RPERF 2 1/8" EnerJet 7,968 8,025 5,911.5 5,950.6 A-4, A -3, 2T -10 7/2/1991 4.0 RPERF 2 1/8" DynaStrip; 0 Deg. Ph PBR, 7,751 8,051 8,081 5,969.0 5,990.3 A -2, 2T -10 7/2/1991 4.0 APERF 2 1/8" DynaStrip; 0 Deg. Ph PACKER, 7,765 8,052 8,081 5,969.8 5,990.3 A -2, 2T -10 9/10/1986 4.0 RPERF 4" HyperJet II; 90 Deg. Ph Notes: General & Safety End Date Annotation GAS LIFT, 1211/2010 NOTE: View Schematic w/ Alaska Schematic9.0 7,804 - - 5/24/2011 NOTE: PU WEIGHTS ERRATIC ALL THE WAY OUT TBG IPERF, 7.852 -7,898 It SLEEVE, 7907 ill SEAL A.927 ). 7,527 PACKER. 7.928 NIPPLE. 7,943 S09,7,951 RPERF. 7.968-8,018 IPERF, \ \ \v 7.968 -8,025 RPERF, 7.968 .8,025 Mandrel Details Top Depth Top Port (TVD) 1881 OD Valve Latch Size TRO Run Stn Top(864B) (ftKB) 6.2 49. (1 3 OT Make S LBX Model 1 (!n) 2 Sery LIFT DMY Type T ype RM 0.0 (in ) (psi) Run Date Com.., 1 7,706.6 5,730I 1/ 0 0.0 7/23/1995 RPERF, 2 7,803.7 5,800.8 48.33 CAMCO KBUG 1 GAS INJ DMY BK 0.000 0.0 2/1 &1998 8,051.8,081 N RPERF, 8.052 .8.081 PRODUCTION. 30 -8,233N ' TD, 8,256 • II MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission i I 12 / - 1 i DATE: Wednesday, December 14, 2011 TO: Jim Regg ` P.I. Supervisor ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T -10 FROM: Jeff Jones KUPARUK RIV UNIT 2T -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry :IX-- NON CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2T - 10 API Well Number: 50 - 103 - 20064 - 00 - 00 Inspector Name: Jeff Jones Insp Num: mitJJ111128113100 Permit Number: 186 - 096 - Inspection Date: 11/19/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T -10 ' Type Inj. W " TVD 5771 " IA 780 3300 , 3210 3210 • P.T.D 1s60960 ' TypeTest SPT Test psi 3000 ' OA 70 100 100 100 Interval REQVAR P/F P ' Tubing 1500 1500 1500 1500 Notes: AIO 2B.062 5 BBLS diesel pumped. One well inspected, no exceptions noted. tildiVtiED 1 E 2W Wednesday, December 14, 2011 Page 1 of 1 Page 1 of 1 0 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 26, 2011 8:20 AM To: 'NSK Well Integrity Proj' Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2T -10 ( -062) aio2b -062 Kuparuk River Unit Attachments: aio2b-062.pdf lq"(a _ o S MJ, When the AA was written, I did not understand there could be a delay in bringing the well back on line. Our preference is to wait until the well has thermally stabilized to perform the regulatorily required MIT. Accomplishing a cold MIT while meeting the wording of the AA will not satisfy the regulatory requirement. It is acceptable to delay the MIT required by the AA until - 2 weeks after the well is returned to service. Keep me advised when the well is returned to service. A copy of this message should be available when the Inspector comes to witness the MIT. Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Saturday, September 24, 2011 6:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 2T -10 (PTD 186 -062) aio2b -062 Kuparuk River Unit ` ," ° 1 ( 2U 'V, Tom, Injection well 2T -10 (186 -096) is not online as it has not cleared our internal waiver process and will not be thermally stable by the Sept 30, 2011 for the witnessed MITIA deadline required in AIO2B -062. ConocoPhillips can complete the MITIA with it shut in and meet the dead line or complete the test with in -2 weeks after the well is brought on injection (it is not currently known when the well will be brought on injection). Please advise what course of action you would like us to take. MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Cell (907) 943 -1687 9/26/2011 • • SifalfEE AELti-SIA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIS SI ON ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 2B.062 Mr. Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. � � t 4 ° P.O. Box 100360 "a= Anchorage, AK 99510 -0360 RE: KRU 2T -10 (PTD 1860960) Request for Administrative Approval Kuparuk River Oil Pool Dear Mr. Walters: In accordance with Rule 9 of Area Injection Order ( "AIO ") 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI) request for administrative approval to continue water injection in the subject well. Kuparuk River Unit (KRU) 2T -10 exhibits a subsidence related surface casing leak at about 324' below pad surface. The AOGCC finds that CPAI does not intend to perform repairs at this time, deferring until a rig workover can be justified. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 2T -10 exhibits at least two competent barriers to the release of well pressure. AOGCC's administrative approval to continue WATER INJECTION ONLY in KRU 2T -10 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MITIA every 2 years to the maximum anticipated injection pressure; 4. IA pressure not to exceed 2000 psi. 5. OA pressure not to exceed 300 psi. 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and AIO 2B.062 • • September 6, 2011 Page 2 of 2 8. Prior to September 30, 2011 after temperature equilibration has been achieved, CPAI should perform a MITIA. DONE at Anchorage, Alaska and date' Sep mber 2011. .,, , A ' al 1 . , ianiel T. Seamount, Jr. . y crorman Cathy Foerster Chair C • mm oner Commissioner o 1y N4D 4 • I \ .0 t ; . Z. RECONSIDERATION AND APPEAL NOTICE ' 0 f I alr As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further ti e a tie , _:ion .44 grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration oft .r .i ed by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the r ;,�+ • - ktike, / order or decision is believed to be erroneous. ,+" The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • Conoco Phillips Alaska RECEIVED P.O. BOX 100360 AUG 2 9 2011 ANCHORAGE, ALASKA 99510 -0360 Alaska Oil & Gas Cos. Commission Aneberage August 12, 2011 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing well 2T-10 (PTD 186 -096) to be online in water only injection service with a known surface casing leak. ConocoPhillips intends to pursue repairs should MI injection be desired in the future. If a successful repair is achieved we will request the well be returned to normal status and resume the ability to inject MI. If you need additional information, please contact myself or MJ Loveland at 659 -7043, or Brent Rogers / Kelly Lyons at 659 -7224. Sincerely, / Martin Walters Well Integrity Supervisor ConocoPhillips Alaska Inc. Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 2T -10 (PTD# 186 -096) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with a known surface casing leak for Kuparuk injection well 2T -10. Well History and Status Kuparuk River Unit well 2T -10 (PTD# 186 -096) was drilled and completed in 1986 as a development well and converted to a service well in 1995. 2T -10 was reported to the Commission on 03/31/09 with a suspected subsidence related surface casing leak. Diagnostics were conducted which verified the surface casing to formation leak with an estimated depth of approximately 324' below the surface (conductor shoe is at 110' RKB). The following pertinent operations have been completed to date: Date Operation Result Comment 07/04/11 Gyro Survey NA 05/15/11 MITIA Passed 06/16/10 MITIA Passed 05/21/10 MITT Passed 06/01/09 MITIA Passed Witnessed by Jeff Jones 05/23/09 Gyro Survey NA 04/19/09 Caliper NA 04/02/09 T &IC POTs Passed 03/27/09 MITOA Failed Considering that the leak is too deep to access via excavation, the well will require a workover or an alternate repair technology to remediate. ConocoPhillips requests administrative approval to continue water only injection until the well can be repaired. Well Integrity Supervisor 8/13/2011 • • Barrier and Hazard Evaluation Tubing: The 3 -1/2 ", 9.3 ppf, J -55 tubing has integrity to the Packer @ 7760' RKB based upon the passing MITIAs as outlined above. Production casing: The 7 ", 26 ppf, J -55 production casing set at 8233' RKB has an internal yield rating of 4980 psi and has integrity to the Packer @ 7760' MD based upon a passing MITIAs as outlined above. Surface casing: The 9 -5/8 ", 36 ppf, J -55 surface casing set at 3297' RKB has an internal yield pressure rating of 3520 psi but does not have integrity based upon a failed MITOA and subsequent diagnostics. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T /IO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed). 2. Perform a passing MITIA every 2 years to the maximum anticipated injection pressure. 3. IA pressure not to exceed 2000 psi (40% internal yield). 4. OA pressure will be maintained as low as reasonably possible. 5. Submit monthly reports of daily tubing & IA pressures, injection volumes, and any pressure bleeds on any annuli. 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. 7. Workover and /or repair the well prior to gas injection consideration with appropriate AOGCC notification Well Integrity Supervisor 8/13/2011 2 ` PS + KUP • 2T -10 Conoc Well Attributes Max Angle & MD TD Alaska i Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) corncaFTalkps 501032006400 KUPARUK RIVER UNIT INJ 50. 88 5,600.00 8,256.0 °` Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Releue Date ••• Well Confle• - 2T -10, 512412011 10:52:24 AM SSSV: LOCKED OUT Last WO: 41.02 6/20/1986 Schematic • Actual Annotation Depth (ftKB( End Date Annotation Last Mod ... End Date Last Tag: SLM 7,980.0 5/23/2011 Rev Reason: TAG, PU WEIGHTS ERRATIC ninam 5/24/2011 1 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE (OC) 95/8 8.765 35.4 3,297.4 2,801.5 36.00 J - 55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 4 PRODUCTION (QC) 7 6.276 30.3 8,232.7 6,097.9 26.00 J -55 BUTT Tubing Strings I Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 0.0 7,928.0 5,884.0 9.30 J - 55 EUE8rdABMOD Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 2 7/8 2.441 7,928.0 7,951.0 5,899.9 6.50 J -55 EUE8rdABMOD CONDUCTOR, I Other in Hole(Wireline. retrievable . plugs, valves, pumps, fish, etc.) 38 -110 Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) (^) Description Comment Run Date ID (In) 1,778 1,724.9 32.08 SAFETY VLV Camco TRDP -1A -SSA *Locked Out 3/7/96* 9/9/1986 2.812 7,702 5,733.3 49.07 GAS LIFT OTIS/LBXJ1.5/DMY/RM // /Comment: STA 1 7/23/1995 2.907 SAFETY VLV. 1.778 il 7,747 5,762.4 48.64 PBR Baker PBR 9/9/1986 3.000 7,760 5,771.0 48.51 PACKER Baker FHL PACKER 9/9/1986 3.000 7,800 5,797.5 48.13 INJECTION CAMCO/KBUG/1/DMY/BK/// Comment: CLOSED STA 2 2/18/1998 2.920 l 7,902 5,866.2 47.15 NIPPLE AVA BPL PORTED NIPPLE 9/9/1986 2.690 7,902 5,866.2 47.15 SLEEVE -C 2.75" AVA NEW STYLE TPI 7 /18/2007 11/21/2005 2.310 SURFACE J 7,928 5,884.0 46.83 PACKER Baker 'D' PACKER w/ 5' SBE 9/9/1986 3.250 - (GC), 35 - 3,297 - 7,943 5,894.4 46.65 NIPPLE Camco 'D' Nipple NO GO 9/9/1986 2.250 7,951 5,899.9 46.56 SOS 9/9/1986 2.441 GAS LIFT, etall 7,951 5,899.9 46.56 TTL 9/9/1986 2.441 7,702 Perforations & Slots Shot Top (TVD( Otto (TVD) Dens Top (ftKB) Btm (ftKB) (RKB) (ftKB) Zone Date (sh•.. Type Comment 7,852 7,898 5,832.6 5,863.5 C-4, UNIT B, 9/10/1986 12.0 IPERF 5" HyperJet II; 90 Deg. Ph 2T-10 PBR, 7,747 7,968 8,025 5,911.5 5,950.6 A-4, A -3, 2T -10 9/10/1986 1.0 IPERF 4" HyperJet II; 90 Deg. Ph 7,968 8,018 5,911.5 5,945.6 A -4, A -3, 2T -10 6/22/1988 4.0 RPERF 21/8" EnerJet { 7,968 8,025 5,911.5 5,950.6 A-4, A -3, 2T -10 7/2/1991 4.0 RPERF 2 1/8" DynaStrip; 0 Deg. Ph PACKER, 7,760 `. 8,051 8,081 5,969.0 5,990.3 A -2, 2T -10 7/2/1991 4.0 APERF 2 1/8" DynaStrip; 0 Deg. Ph r 8,052 8,081 5,969.8 5,990.3 A -2, 2T -10 9/10/1986 4.0 RPERF 4" HyperJet II; 90 Deg. Ph Notes: General & Safety End Date Annotation I 12/1/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 INJECTION. 5/24/2011 NOTE: PU WEIGHTS ERRATIC ALL THE WAY OUT TBG 7,800 t - 7,052 -7-7,89.09 8 I NIPPLE.7,902 SLEEVE -C. I 7,902 I 1 PACKER, 7,928 NIPPLE, 7,943 La ■ TT, 7,951 - z Mandrel Details RPERF, Top Depth Top Port 7.968.8.018 (TVD) Ind OD Valve Latch Size TRO Run 7,998 -,025 Stn Top (ftKB) (RKB) ( *) Make Model (In) Sery Type Type (i (Pail Run Date Com... RPERF, I ' 1 7,70 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 7/23/1995 7.968 -,025 2 7,798.9 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 2/18/1998 APERF, 8.051 -,081 RPE0 8,052 -,081 1 PRODUCTION (0C), 30-8,233N ■ TD, 8,258 Well Name 2T -10 Notes: Administrative Approval Application Start Date 9/1/2010 Days 365 End Date 9/1/2011 Annular Communication Surveillance 1400 —' WHP - 1.2 IAP OAP 1200 WHT —1 1000 - — — 0.8 • 800 _ LL N 0.6 O. 600 111 0.4 400 - 200 0.2 0 1 VI I \fill 11:11 I .1■■•=11■1111111111111r 0 Aug -10 Sep -10 Oct -10 Nov -10 Dec -10 Jan -11 Feb -11 Mar -11 Apr -11 May -11 Jun -11 Jul -11 Aug -11 Sep -11 a < -DGI • o.e �MGI 0 0.7 —PWI 0.6 ammem 0 01 • 1 BLPD U 0.4 0.3 0.2 0.1 0 Aug -10 Sep -10 Oct -10 Nov -10 Dec -10 Jan -11 Feb -11 Mar -11 Apr -11 May -11 Jun -11 Jul -11 Aug -11 Sep -11 Date • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 31, 2011 1:51 PM To: 'NSK Problem Well Supv' Cc: Brooks, Phoebe L (DOA); NSK Well Integrity Proj t r 0 _ 0 Subject: RE: 2T -10 Diagnostic MITIA ' � Brent, I don't need anything else. As discussed, it will be necessary to perform a witnessed MITIA when the well has reached thermal stabilization. Also, for future reference it is appropriate to submit diagnostic MITs used to demonstrate integrity for an AA. If such a MIT is witnessed, then it will qualify for resetting the anniversary date. Cali or message with any questions. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Wednesday, August 31, 2011 1:48 PM To: Maunder, Thomas E (DOA) Cc: Brooks, Phoebe L (DOA); NSK Well Integrity Proj Subject: 2T -10 Diagnostic MITIA AUG ��l Tom, As you requested, attached is a copy of the diagnostic MITIA used in the AA justification. Please let me know if you need anything else. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 8/31/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.repptbalaskasiov:, doa .aogcc.prudhoe.bayaalaskasiov. phoebe.brookstbalaska.00v: tom.maunderralaska.aov OPERATOR: ConocoPhillips Alaska, Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 2T DATE: 05/15/11 OPERATOR REP: Ives - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. _ 60 Min. Well 2T -10 Type Inj. N TVD 5,771' Tubing 1,300 1,350 1,350 1,350 Interval O P.T.D. 1860960 Type test P Test psi 1500 Casing 500 3,000 2,980 2,975 P/F P Notes: Diagnostic MITIA OA 140 140 140 140_ Well Type Inj. TVD Tubing Interval P.T.D. _ Type test 1 Test psi 1 Casing PIF Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA _ Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F YPe t . Notes: OA , TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Infecting A= Temperature Anomaly Si.uveyr T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) I Form 10 -426 (Revised 06/2010) MIT KRU 2T-10 05- 15-11.xls MEMORANDUM • TO: Jim Regg ~,/ q P.I. Supervisor ( ~~~ ~I ~bCL l FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-10 KUPARUK RIV iINIT 2T-] 0 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~ Comm Well Name: KUPARUK RIV UNIT 2T-10 API Well Number: 50-103-20064-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090608121252 Permit Number: 186-096-0 ~ Inspection Date: 6/1!2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-10 Type Inj. ~ w TVD s~~1 IA _ _ _ D 1860960 T si 1500 OA eTeSt SPT Test P T goo _ 160 ~ »oo ~' _ 160 16zo 160 1600 160 yp p . . 4YRTST P ~ Tubin Interval P/F g 24s0 _ ~ 2450 LLL 2450 2450~~- NOteS: 4.1 BBLS diesel pumped, 1 well inspected; no exceptions noted. r •,~"'z ~ . •7 ,, ~ Wednesday, June 10, 2009 Page 1 of 1 RE: KRU DS2T Suspected Surfa~asing Leaks Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Monday, April 20, 2009 2:48 PM ~~~~~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Subject: RE: KRU DS2T Suspected Surface Casing Leaks Follow Up Flag: Follow up Ftag Status: Green Attachments: 2T-11.pdf Jim, Page 1 of 3 k2~,-~ zr- ~~4 p;~ r ~,~ - 143 K~2i,t Zr - ~ e P ~ o ~ `2-~-- G~q k2t,t zi _- l l ~ i ~ ~- c~ q "7 On 4/19/09 CPAI shut in wells 2T-04, 2T-09, and 2T-15. Additional diagnostics indicate tubing obstructions exist in these wells preventing mechanical secure. On 4/18/09 CPAI shut in well 2T-11. The path forward for 2T-11 will to harvest a SBHP then attempt to secure with a plug in the AVA sleeve at 5801' md. All of the above wells will remain shut in until they can be repaired. We will not be submitting a request for Administrative Approval to continue, water only injection for these wells. These wells will be shut in long term. Do they need to be carried on the monthly failed injector report? 2T-10 remains online in water only service. We completed a drift, tag, and caliper of the tubing and intend to pursue and AA for continued water injection. 2T-16 remains online in water only service and is scheduled for a drift and tag with subsequent caliper to follow. If our plans change with regard to 2T-16 I'll inform you immediately. Let me know if you have any questions. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 Voice Pager 659-7000 x937 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, April 03, 2009 3:47 PM To: NSK Problem' Well Supv Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly 2/23/2010 RE: KRU DS2T Suspected Surfac~asing Leaks Page 2 of 3 A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks This is what we agreed to in phone conversation 3/31/2009. CPAI may continue to inject water only in the listed KRU 2T wells. Please add these 7 wells to the monthly injector integrity report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, April 03, 2009 2:47 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks On 04/02/09, the last of a series of diagnostic tests on 7 injectors on Drillsite 2T (2T-02, 2T-04, 2T-09, 2T-10, 2T- 11, 2T-15, and.2T-16) to confirm the existence of 2 barriers was completed. The tests consisted of MITIA's and positive and negative tubing and inner casing pack off tests. All of the tests, without exception, passed and therefore we are continuing to inject water only and have designated each well as being incapable of conversion to miscible injectant (MI). CPAI plans to continue water only injection and begin drafting applications for administrative approval to continue water only injection with a known surface casing leak (OAxForm). Please reply with your concurrence on the proposed plan of action. Martin From: NSK Problem Well Supv Sent: Tuesday, March 31, 2009 6:56 PM To: 'jim.regg@alaska.gov' Cc: 'tom.maunder@alaska.gov'; NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: KRU DS2T Suspected Surface Casing Leaks Jim, Recently CPAI conducted MITOA's on 12 wells on Drillsite 2T as a part of a program investigating subsidence. Of the 12 wells tested, there were 11 failures, 7 of which are injectors. The second phase of our diagnostics included injecting gas down the OA while using an Echometer to monitor the fluid level. The 7 injectors exhibited fluid levels which could not be depressed below 300' - 348'. We suspect that the reflection is possibly due a hole in surface casing or a mechanical obstruction and is consistent with data collected in the region. We began conducting MITIA's today (3/31/09) on all 11 wells and will follow up with tubing and inner casing packoff tests. Provided we can demonstrate the existence of 2 barriers, CPAI requests permission to continue water only injection in the subject wells (2T-02, 2T-04, 2T-09, 2T-10, 2T-11, 2T-15, and 2T-16) until administrative approval can be obtained within a reasonable amount of time. 2/23/2010 RE: KRU DS2T Suspected Surfac~asing Leaks Page 3 Qf 3 Attached are 90 day TIO plots and Wellbore schematics. « File: 2T-02 TIO Plot.pdf» « File: 2T-04 TIO Plot.pdf» « File: 2T-09 TIO Plot.pdf» « File: 2T-10 TIO Plot.pdf» « File: 2T-11 TIO Plot.pdf» « File: 2T-15 TIO Plot.pdf» « File: 2T-16 TIO Plot .pdf» « File: 2T-02 Wellbore Schematic.pdf» « File: 2T-04 Wellbore Schematic.pdf» « File: 2T-09 Wellbore Schematic.pdf» « File: 2T-10 Wellbore Schematic.pdf» « File: 2T-11 Wellbore Schematic.pdf» « File: 2T-15 Wellbore Schematic.pdf» «File: 2T-16 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ?/23/2010 ~~_ ~, ~ `"~ Cana~aP~illi~s Alaska I~Ic. ~2T-11 API: 501032006500 SSSV Type: TRDP sssv Annular Fluid: Last W/O: imp-t na, I OD:3.500) Ref Lo Date: 6463' TD: 6789 ftKE 1/28/2007 Max Hole An le: 42 de a - ALL STRI NGS Size To Bolton ;TOR 16.000 0 110 SING 9.625 0 2973 USING 7.000 0 6170 S 5.000 5976 6789 TUBING Top I Bottom TVD I ~0~ 5804 5382 Perforations Summar Interval TVD Zone 6331 - 6352 5789 - 5805 C-4 6429 - 6435 5864 - 5869 A-4 6446 - 6484 5877 - 5906 A-3 Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V 1 5665 5274 Otis LBX In'ection MandrelsNalves St MD TVD Man Mfr Man Type V 2 5763 5350 Camco KBUG Other lu s e ui .etc. - COMPLE' De th TVD T e 1777 1777 SSSV Camco TRDP-1 5711 5310 PBR Baker 5725 5320 PKR Baker'FHL' ~~~ ,~ 6373 5822 PKR Baker' 6387 5832 NIP Camco 6395 5838 SOS Camco 6396 5839 TTL i ~- - 'General Notes KRU 2T-11 Angle @ TD: 40 deg @ 678! Rev Reason: PULL BPC, Se BPI. TAG FILL t 38 I 4 X10/11/19841 IPERF 190 deg Ph' 3 3/8" H yperJet V Type V OD Latch I Port ~ ~ TRO Date Run Viv Cmnt DMY 1.5 RO-5 0.000 0 6!17/1987 V Type V OD Latch Port TRO Date Run Viv Cmnt DMY ~ 1.0 BK 0-000 0 10/12/198 • • To: AC~CC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 11) Caliper Report 19-Apr09 2T 10 1 Report / EDE 50-103-2006400 2) Caliper Report 15-Ap-~09 2T-02 1 Report / EDE 50-103-20072-00 ~~ ~ 1 ~Cp ` t ~l ! ! ~-~3 v3 r y~~ l~Co - c~`3~ Cady ~ ~ , . ~, ~ Signed : ~ Date- °---_ Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8981 FAX: (907)245-88952 E-MAIL : WEBSITE C:\Documents and Se[ta~gs\Owner\Desktop\Transmit_Conoco.docr • Memory IVfutti-Finger Caliper Log t~esults Suer Company: ConocoPhillips Alaska, Inc. Well: 2T-10 Log Date: AprfF 49; 2009 Field: Kuparuk Log No.: 7320 State: Alaska Run No.: 1 API No.: 50-103-20064-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 EUE 8RD AB-MOD Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 7,925 Ft. (MD) Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD AB-MOD Top Log dntvl2.: 7,925 Ft. (MD) Pipet Use: Tubing Tail Bat. Log Intvl2.: 7,951 Ft. (MD) Inspection Type : Buckling & Corrosive ~ Mechanical Damage lnspection ~ COMMENTS ; ' This caliper data is tied into the Tubing Tail ~ 7,S5t' (Drillers Depth). This log was run to assess the condition of the tubing with respect to buckling and corrosive and mechanical damage. Although not presenting a significant I.D. restriction, the caliper recordings indicate severe buckling from surtace to1,750', and slight to moderate buckling from1,750' to7,700'. A 3-D log plot of the caliper ' recordings from surtace to 1,750' highlighting the severe buckling is included in this report. The caliper recordings indicate the 3.5° tubing is in good condition with respect to corrosive damage, with no significant wail penetrations, areas of cross-sectionalwall loss or I.D. restrictions recorded. Although not presenting a significant I.D. restriction, the caliper recordings indicate light deposits throughout the 3.5 tubing. ''~~' The caliper recordings indicate the 2.875" tubing tail is in good condition with respect to corrosive damage, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. 3.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 16%) are recorded. 3.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wa11 loss (> 6%) are recorded. ' 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS No other significant I.D, restrictions are recorded. sr;~,~j~~ ~~~~ ~. ?~~= 2.875" TUBING TAIL -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 4%}are recorded. 2.875" TUBING TAIL -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No significant areas ofcross-sectional wall loss (> 3°~) are recorded. ProActive Diagndstic Services, Inc. J P.O. Box 1369, Stafford, Tri 77497 Phone: (281) or (888) 565-9Q85 Fax: (281) 565-1369 E-mail: PDS!~amemorylog.com Prudhoe Bay Field Office Phone: (907) 659-23Q7 Fax; (947) 659-2314 ' U~-i~ - r~s~o - o~ ~~ ~~ ~ • t~ 2.875" TUBING TAIL -MAXIMUM RECORDED ID RESTRICT1ONS No other significant I.D. restrictions are recorded. ~~ Field Engineer: Wm. McCrossan Analyst: HY. Yang Witness: S. Ferguson ~'~, ~ ProActive Diagnostic Services, Inc. / F.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDSLamemorylog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907} 659-2314 • PDS Multifinger Caliper 3D Log Plot ~, . , Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-10 Date : April 19, 2009 Description : Deatil of Caliper Recordings Across Severe Buckling Recorded in 3.5" Tubing Comments Depth Max I.D. (1/1000 in.) 1ft:600ft 350 4500 Min I.D. (1/1000 in.) 3500 4500 Nominal I.D. 3500 4500 Tree Pup Jts. Severe buckling 50 Joint 1 Joint 2 Severe buckling 100 Joint 3 Joint 4 150 Joint 5 200 Joint 6 Joint 7 Severe buckling 250 Joint 8 Joint 9 300 Joint 10 5 3 0 Joint 11 er) 3-0 0° (Off-Center) Image Map (Centered) In 0° 90° 180° 270° 0° 0° 90° 180° M;„, I~ >. r- __ 1 • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (9.3' - 7924.9') Well: 2T-10 Pipe 2 2.875 in (7924.9' - 7951.0') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 19, 2009 n A pprox. tool De viation A pprox. Borehol e Profil e 40 789 1568 2371 3159 3944 = t a a~ 4733 ~ 5521 6300 7079 GLM 1 IN)M ~ .6 . - 7951 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = .6 1 25 50 75 100 v E 125 Z ~ o 150 175 200 225 • • PDS Report Overview ~~ Body Region Analysis Well: 2T-10 Survey Date: April 19, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 EUE Srd ABMOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°,6 wall) ~ penetration body metal loss body 200 150 100 50 -- -- 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of 'oints anal se d total = 257 pene. 0 198 59 loss 98 159 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (°~ wall) ~ penetration body metal loss body 0 50 100 n ~~ u ~ IN)M 2 Bottom of Survey = 249.3 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf )-55 EUE 8rd ABMOD Well: 2T-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 19, 2009 Joint No. Jt. Depth (Ft.) I'r~n. Ulnc~t (ln..) Pen. Body (Ins.) Pen. % Vlc~t,rl I cuss ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 t? 0 O1 2 _' 2 7 PUP Severe bu klin . 13 U 0. 1 2 2. 5 UP .3 2 u 0.01 5 I .94 P P 4 30 r) 0.01 4 I 96 P P 1 40 a 0.01 4 ~ 2. 1 2 71 t) 0.01 7 2. 2 Seve e b cklin 3 103 U 0.0 '~ 2.91 Lt. De osits. 4 1 2 l) 0.02 £3 4 2.89 LL De osi 5 164 l) 0 0 i 4 Lt. De osits. 6 196 t ~ 0.0 £) t .91 7 224 t) 0.02 £3 _' 9 Severe uckl'n . 8 256 a 0.0 .92 Lt. e osi . 9 87 a 0.01 (~ (~ .92 10 318 a 0.0 7 2 92 11 50 U 0 2 ~~ -1 2.89 I_ . e its. 1 381 t) 0.02 2.89 Severe bucklin 13 412 a 0.01 5 2.92 14 (1 0.02 £~ ~ .93 15 475 t) 0 03 1 1 ~ 2 9 t. D its. 16 507 U 0.02 ~) 4 .91 Lt. e 17 539 a 0.0 ~) 3 2.92 S vere b cklin 18 570 U 0.02 i 4 .90 Lt. De o its. 19 601 U 0.02 £3 ~' 2.95 20 633 U 0.02 £3 -1 2.90 1 6 4 U 0 £i ' 22 696 U 0.01 (~ _' 2.94 Severe bucklin 2 7 t) 0 tt -1 2.92 24 758 a 0.02 9 ~ 2.91 Lt. De osits. 25 7 9 U .02 9 3 8 L. De i 26 821 t) 0.02 9 i 2.91 8 2 t) 0.02 £3 t .91 Lt. a osits. v re cklin . 28 884 tt 0.02 ( 2.91 Lt. De osits. 2 915 U 0.03 11 -( 90 Lt. De si 30 945 U 0.02 7 _' 2.93 31 976 U .0 9 ~1 2.92 t. De osits. 32 1006 U 0.02 0 4 2.91 Lt. De osits. Severe cklin . 33 1038 U .02 i 4 .89 34 1069 l) 0.03 1Z 2.93 Lt. D osits. 35 1101 U 0.0 ~~ 90 6 1132 t) 0.03 1 1 2.92 37 1163 a 0.0 £3 2. 1 Severe klin . 38 1194 a 0.02 £3 ) 2.91 39 225 U .0 t3 _' 2.8 Lt. a sits. 40 1254 a 0.02 £3 I 2.93 41 128 U 0.0 £i ' 2.9 42 1317 O 0.02 £3 _' 2.93 Severe bucklin . 43 1349 (~ 0.0 £3 I 2.94 44 1380 t) 0.02 £i 2.90 Lt. De osits. 4 1411 !) 0.01 5 ~ .90 46 1442 i ~ 0.02 t3 2.9 Severe bucklin . Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE Srd ABMOD Well: 2T-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 19, 2009 Joint No. Jt. Depth (Ft.) I'~~n. l ll~s<~t (Irri.j Pen. Body (Ins.) Pen. % :Vlclal I oss ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 147 t? 0.02 t3 a .9 48 150 t ? .01 5 .94 50 156 t? 0.01 6 I 2.94 S v bucklin . 51 1600 U 0.0 t3 2.93 52 163 U 0.02 ~ u 2.9 t. e si 53 1663 O 0.02 ~) 1 Lt. De osits. 54 1695 U 0.0 ti 2.93 55 1727 a .0 t3 I .88 S vere bucklin . 5 .1 1758 U 0.0 ti _' 2. PUP Buckli 55.2 176 t? 0 l) U Z. 1 o TRDP-1 A-SSA c ed Out 7 96 56 1773 U 0. 3 t U U 2.90 57 1805 U 0. 7 1 .9 58 18 6 t) .03 13 ' .89 t. D si 59 1868 a 0.0 t3 ~' .90 Bucklin . 60 1899 t) 0.03 I 1 2.89 t. De si . 61 1930 t) 0.02 '~ ~? .91 6 196 U 0.0 1 I ' 91 6 1993 t1 0. 4 14 I 2.90 Lt. its. 64 024 U 0.03 11 ? 2.87 Lt. De sits. 65 2055 t? 0.03 11 ~' .92 Bucklin . 66 2087 l? 0.03 1 1 ' 2.88 Lt. De si 67 2118 t) 0.01 5 1 2.93 68 2150 t1 0.03 It1 ? 2.91 Lt. D osits. 1 O 0.03 IU (? 1 70 2214 U 0.03 I U 2.91 Bucklin . 71 45 U 0.03 1 t) 2 0 t De os ts. 72 2276 O 0.03 1 Z U 2.90 73 30 U 0.01 i ~ .93 74 2339 It 0.03 11 2.91 Lt. D sits. 75 2371 U .02 ~ ,' .9 ckli 76 2403 a 0.03 13 2 2.92 77 24 4 t? 0.02 9 ~ .92 t. osits. 78 2466 t? 0.03 1O I 2.92 Lt. its. 79 2497 U 0. 8 I 2.94 80 2529 U 0.01 i _' 2.95 Bu kin . 81 25 9 U 0.03 12 n .91 82 2591 t) 0.03 13 I 2.91 Lt. De osits. 83 623 U 0.0 ~) I 2. 84 2655 O 0.04 14 _' 2.91 Lt. De osits. 85 687 t1 _- 0.0 9 O 2.94 ucklin . 86 2718 (? 0.03 12 _' 2.91 87 749 t) 0.02 9 I 2 92 88 2781 t) 0.04 15 _' 2.92 89 281 U 0.0 1 3 _' 2 8 ck' 90 2844 ~) 0.03 I ' I 2.91 Lt. De osits. 91 2876 t? 0.03 lt) .91 92 2908 U 0.03 1 U I 2.90 9 939 U ~) I 9 94 2969 U 0.02 9 _' .93 Bucklin . Penetration Body i Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf J-55 EUE Srd ABMOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 2T-10 Kuparuk ConocoPhillips Alaska, Inc. USA April 19, 2009 Joint No. Jt. Depth (Ft.) I'c~n. t)pset (In~.i Pen. Body (Ins.) Ne~n. %~ 1~te~t,rl I~~tis ,.~ Min. LD• (Ins.) Comments Damage Profile (°/a wall) 0 50 100 95 001 ~) .02 ~) .9 96 32 (~ 0.0 1 1 _' 2.88 97 3064 t) 0. 3 12 2 2.89 L e os' . 98 3096 U 0.03 11 ~' 2.91 99 3128 U 0.03 1 3 U 2 9 Buckli 100 3159 l) .03 13 2 2.90 t. o i . 101 3190 t) 0.03 12 U 2.90 102 223 n 0.0 1U 0 10 3253 U 0. 4 14 I .91 Lt. osits. 104 328 U .03 11 ~ 2.9 Bu kl~n . 10 314 0 0 9 I 1 106 3346 U 0. 3 10 1 2.90 t os' 107 3376 U 0.03 10 1 .91 108 3408 U 0.03 10 I 91 109 344 U 0. 3 10 1 .9 Lt: e its. 110 3471 U 0.03 1 U ~' 2. 9 ck i 111 3503 U 0.03 11 2.92 11 3534 a .04 l i I .90 t. e o its 11 35 7 U 0.0 1 1 1 93 11 597 U 0. ~) 1 .93 L . e sits. 115 62 U 0.03 13 U .88 uckli 116 3660 U 0.03 l.i 1 2.91 117 3691 U 0.03 1 ~~ ~ 2.89 118 3723 U 0.03 13 ? 2.92 Lt De osits. 119 755 ~) 0. 1 v I 2. 1 i 120 3786 U 0.03 I ~ 2.90 Lt. De osits. 121 381 U 0.0 I U 2 9 122 3849 U 0.02 t3 I 2.93 123 3881 U 0. 3 10 I 2.93 c in . 124 3912 U 0.03 11 2.88 Lt. De osits. 1 944 U 0. fi ~ ~ 7 126 3975 t~ 0.03 lU I 2.90 Lt. De osits. 127 4007 U 0 03 1 U I 3 Bu kli 128 4038 ~) 0.03 13 Z 2.90 1 9 4070 U 0.0 ~) .93 130 4101 ~~ 0.03 lU 1 2.91 Lt. De osits. 131 4133 ~ ~ 0. 4 I S I 2.91 Buc lin . 132 4165 ~) 0.02 ' ~ I 2.91 Lt. Ue osi ts. 1 3 4196 U 0.02 ~~ I 2.89 134 4228 U 0.02 ~~ I 2.89 Lt. De osits. 135 4260 U 0.02 ti I .9 Bucklin 136 4291 U 0.03 1 U ~ 2.90 Lt. De osits. 137 4323 U .03 1 ~) ? 8 t o 'ts. 138 4353 O 0.02 ~) ~' 2.91 139 4385 U 0. 3 12 Z 2.90 klin 140 4416 c) 0.04 1 ~ 2.92 14 4447 U 0.02 ~~ 2.87 142 4479 ~) 0.03 11) _' 2.83 Lt. D osits. 143 4511 ~) .02 t3 I .9 Bu klin . 144 4543 U 0.02 ~) I .9D Lt. D osits _ Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8rd ABMOD Well; 2T-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 19, 2009 Joint No. )t. Depth (Ft) I'c•n. t Il,.c~i (Ins.) Pen. Body (Ins.) Pe•n. `% ~1c•t.~l I iris Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4575 U .0 9 I 1 Lt e o its 146 4606 t t 0.0 £3 I .9 147 4638 U 0.02 8 I 2.90 uc li 148 4669 a 0.02 ~) I 2. 0 149 701 tt .0 £3 I 2.93 150 47 3 t) 0.02 ~~ ~ 2.9 uckli 151 4 5 U 0.03 1 t Z 2.89 Lt. a sits 152 4797 U 0.02 ~~ 1 2.91 t De osits. 153 4828 tt .03 I 1 I 2 91 Lt. De osi 154 4860 (t 0.0 ~) I 4 15 4891 (t .0 8 4 .93 6 lin . 156 49 O 0.0 ti O 2.9 Lt. De i 1 7 4954 t t .03 11 ' 2.93 158 4986 t) 0.02 £3 I 2.92 Lt D osits. 159 01 t) 0 03 1 I _' .93 L . e o ' 160 504 u 0 02 7 ~ 2.93 B c li 161 5080 t) 0.0 £3 ~ 2 94 162 5112 U 0.0 £3 ~ .9 1 5143 tt .02 ~) tt 2.93 164 517 t1 0.03 1(1 2 2.94 B kin . 165 5207 t) 0.0 9 I .9 166 5 38 t? 0.0 8 1 2.94 167 5 70 t) 0.03 13 ~ 2.89 a s'ts. 168 5301 U 0.02 8 2.93 16 3 tt 0.01 (~ ~ .93 k 170 5364 U 0.02 i ' 2.91 Lt. De osits. 171 539 t t 0.03 11 .94 172 542 7 t t 0.02 7 _' 2.94 17 5459 U .02 9 I 1 174 5490 l1 0.03 1 I ~' 2.93 Bucklin . 1 5 5521 U 0.0 t3 I 2. t D 176 5552 t) 0.02 £i t t 2.91 177 55 3 t t 0.03 12 3 178 5615 t) 0.04 15 Z 2.91 Lt. De osits. 179 5646 a 0.0 E ' 2 92 t. e 'ts 180 5677 tt 0.02 £3 2.92 Bucklin . 81 57 (t 0.02 ~t I 2 9 182 5737 a 0.02 £3 2.93 1 5769 U 0.0 I ~ I 92 184 5800 t) 0.03 It) ~ 2.93 Lt. De osits. 1 5 5832 U 0.0 ~? .9 uckl' 186 5864 U 0.01 6 I 2.89 Lt. D osits. 187 5895 t t 0.03 1 U 2.94 188 5926 tt 0.03 11 I 2.92 189 5958 t t 0.0 ~~ t .9 c lin 190 5990 t t 0.03 1 t t _' 2.92 Lt De osi ts. 191 6022 U 0. 2 ') _' 93 Lt De osits. 192 6052 U 0.02 f3 I 2.91 Lt. D osits. 19 083 U 0. 1 5 ; Lt. De >osi ts. 194 6113 U 0.02 £~ _' 2.92 Bucklin . Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf )-55 EUE 8rd ABMOD Well: 2T-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 19, 2009 Joint No. Jt. Depth (Ft.) I'c~n. t )I »~~t Ins.) Pen. Body (Ins.) Pcn. `% Metal I oss `% Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 195 6144 t ~ 0.0 9 1 .95 196 6176 t~ 0.02 9 1 2.94 19 6 08 t ~ .0 ~) 2.91 198 623 tt 0.02 ~ 2. 3 19 62 8 U 0 0 ti ! 2.95 Bucklin . 200 6 00 t) .02 ~) U 2.8 2 1 63 1 O 0.0 t -1 2.9 202 63 3 U 0.02 ') .92 0 394 l) 0.03 1 U 2. 3 04 64 6 U 0.03 1 ~ .9 ucklin . 05 458 U 0.02 7 2 93 206 6489 U 0.02 ~) ~' .93 207 6520 t ~ 0.01 5 I 3 0 6551 t ~ 0.03 12 ~ 2.90 209 6581 t ~ 0.02 7 t .9 uckl' 10 6612 U 0.02 7 2.93 Lt sits. 211 6644 U .01 6 .94 1 6676 t~ 0.02 8 _' .90 213 6704 a 0.0 t3 2.94 2 4 6735 U 0.02 7 ~ .93 B cklin . 215 6765 U 0. 1 S 1 .93 216 6796 (~ 0.0 8 2 .93 217 6828 t) 0.02 i _' .9 218 6859 t) 0.02 £~ ? 2.96 Bucklin . 219 6891 a 0.0 l U 2 88 t. o f 220 6922 tl 0.04 I (, -1 2.94 2 1 6953 a 0.0 t3 2.90 . De i 222 6985 t) 0.02 Z3 ~ 2.94 223 7017 U 0 ~ 2.92 Bu klin . 224 7047 11 0.02 7 _' 2.93 25 7079 (t 0.03 1 1 I .94 226 7110 t ~ 0.02 7 I 2.94 27 71 U .02 7 1 .96 228 7174 f) 0.02 8 ? 2.94 Bucklin . 229 7205 U 0.02 ~) ~' 2.9 230 7236 t) 0.02 8 _' 2.94 231 7268 t~ 0.0 ti _' 2.94 232 7299 t) 0.02 7 1 2.92 Bucklin . 233 7331 t~ 0.03 tU 1 .9 234 7363 tt 0.02 £i U 2.93 235 7395 tt 0.0 11 I 2.91 236 7426 U 0.02 ti a 2.94 B cklin . 37 7458 U 0 0 7 96 238 7489 U 0.02 9 l 2.93 2 9 7521 U 0.01 i 1 2.9 240 7551 t~ 0.02 7 _' 2.93 Bucklin . 41 7583 t ~ 0.0 7 t t .94 242 7614 U 0.02 7 2.93 243 76 6 t) 0.0 i .94 244 7677 U 0.01 6 2.9 Bucklin . _ Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8rd ABMOD Well: 2T-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 19, 2009 Joint No. Jt. Depth (Ft.) I'~•n. t Il,u•i (Ins.) Pen. Body (Ins.) Pc~n. ~4~ ~lc•~al I Usti ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 244.1 7704 t~ 0 t~ U 2.91 GL 1 tc ~ 2:00 4 7714 t~ 0.03 I l l s 2.93 245.1 7747 U 0.01 5 ~~ 2.96 ak r P R 45.2 7751 U 0.01 ,' I 2.97 PUP 4 . 7762 ~~ 0 u ~~ 3.00 Baker FHL Packer 246 7772 a 0.02 8 + ~ 2.94 246.1 7802 ~ ~ 0 ~~ ~ ! .92 I M 2 Latc ~ 5:00 47 7813 t~ 0.01 E, ±~ .97 248 784 ~ ~ 0.01 o u 2.98 249 7872 ~ ~ 0.0 1(1 I 2.96 249.1 790 U 0 U (~ .3 AV Ported Ni I 2.75" VA TP I v 4 . 7920 ~ } 0.01 > 2.9 P _ Penetration Body Metal Loss Body Page 6 s • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf )-55 EUE 8rd ABMOmUell: 2T-10 Body Wall: 0.217 in Eield: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 19, 2009 Joint No. )t. Depth (Ft.) I'cn. Ulnc~~ (Ins.) Pen. Body (Ins.) I'en. % :~1ci.il lu<t ~~ Min. f.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 7925 ~~ .01 ~ I 2 43 UP .2 7927 ~l 0 0 ~~ 3.25 Baker D Packer w 5' S .3 7937 ~~ 0. 1 4 3 2 39 PUP .4 7944 ~) 0 i) ~ ~ 2.2 Camco Ni le NO GO 7945 a 0.01 3 I 6 PUP .6 79 1 ~~ 0 0 U SOS L Penetration Body Metal Loss Body Page 1 ` nvr ci-~v ConocoPhillips ' Wen Attrnwtes Max ~. ~ Nn ~ al,r,w, I. 6n w Ofe el eme YtelYe Type Ind ) 501032006400 KUPARUK RIVER UNR INJ PWI 50.88 5,600.00 8,256.0 - Commpt X Ipp~y a Entl B ekase 'CONDUCTOR, 170 SPFETY VIV, 1.778 SURFACE. 3.296 GPS LIFT. 7.702 PBR. 77d7 PAC1¢R. 7.76D IN.EC710N. 7 800 9'ERF, 7,851-7,899 NIPPLE. 7.802 SLEEVEC. 902 PAC10=R, 7.928 NIPPLE. 1.943 SOS, 7 957 rn. 7,95i RPERF, 7,968-8,018 IPERF, 7 988A 075 ].968A.025 TD, RE: KRU DS2T Suspected Surf~,~e Casing Leaks • Page 1 of 2 Regg, James B (DOA) K~ Z i - i c~ From. _Regg, James 8 (DOA) _ _ _ P:~ _ 1 `c~~- (i Q(o JJ Sent: Friday, April 03, 2009 3:47 PM ~~~ 4 l~~ To: 'NSK Problem Well Supv' Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks This is what we agreed to in phone conversation 3/31/2009. CPAI may continue to inject water only in the listed KRU 2T wells. Please add these 7 wells to the monthly injector integrity report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~c ~" ~ ~' ~ '~. From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, April 03, 2009 2:47 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks On 04/02/09, the last of a series of diagnostic tests on 7 injectors on Drillsite 2T (2T-02, 2T-04, 2T-09, ZT_10, 2T- 11, 2T-15, and 2T-16) to confirm the existence of 2 barriers was completed. The tests consisted of MITIA's and positive and negative tubing and inner casing pack off tests. All of the tests, without exception, passed and therefore we are continuing to inject water only and have designated each well as being incapable of conversion to miscible injectant (MI). CPAI plans to continue water only injection and begin drafting aDDlications for administrative approval to continue water only injection with a known surface casing leak (OAxForm). Please reply with your concurrence on the proposed plan of action. Martin From: NSK Problem Well Supv Sent: Tuesday, March 31, 2009 6:56 PM To: 'jim.regg@alaska.gov' Cc: 'tom.maunder@alaska.gov'; NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: KRU D52T Suspected Surface Casing Leaks Jim, Recently CPAI conducted MITOA's on 12 wells on Drillsite 2T as a part of a program investigating subsidence. Of 4/3/2009 RE: KRU DS2T Suspected Surf Casing Leaks • Page 2 of 2 the 12 wells tested, there were 11 failures, 7 of which are injectors. The second phase of our diagnostics included injecting gas down the OA while using an Echometer to monitor the fluid level. The 7 injectors exhibited fluid levels which could not be depressed below 300' - 348'. We suspect that the reflection is possibly due a hole in surface casing or a mechanical obstruction and is consistent with data collected in the region. We began conducting MITIA's today (3/31/09) on all 11 wells and will follow up with tubing and inner casing packoff tests. Provided we can demonstrate the existence of 2 barriers, CPAI requests permission to continue water only injection in the subject wells (2T-02, 2T-04, 2T-09, 2T-10, 2T-11, 2T-15, and 2T-16) until administrative approval can be obtained within a reasonable amount of time. Attached are 90 day TIO plots and Wellbore schematics. « File: 2T-02 TIO Plot.pdf » « File: 2T-04 TIO Plot.pdf » « File: 2T-09 TIO Plot.pdf» « File: 2T-10 TIO Plot.pdf » « File: 2T-11 TIO Plot.pdf » « File: 2T-15 TIO Plot.pdf » « File: 2T-16 TIO Plot .pdf » « File: 2T-02 Wellbore Schematic.pdf » « File: 2T-04 Wellbore Schematic.pdf » « Fife: 2T-09 Wellbore Schematic.pdf » « File: 2T-10 Wellbore Schematic.pdf » « File: 2T-11 Wellbore Schematic.pdf » « File: 2T-15 Wellbore Schematic.pdf » « File: 2T-16 Wellbore Schematic.pdf » Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 4/3/2009 Well Name ~?-? 0 Notes: End Date 4.1.2009 Days 90 Start Date 1/1/2009 wHP Annular Communicaton Surveillance IAP 2500 OAP - ~ _ 120 WHT 100 2000 - 80 1500 -- - -- <L _ N 60 d °- a 1000 40 500 20 0 0 Jan-09 Feb-09 Mar-09 Apr-09 2500 --, -- __ _-_..... - ----. ._---_. DGI I - -- ---------- ~MGI 2000 ~PWI o ~'~SWI ~ 1500 ~BLPD~ m 1000 U - 500 0 • • CMG ~ KUP ~ 2T-10 `, COIIOCOPI'IIIIlpS Max An le & MD Well Attnbutes TD AI;1tiL;f1 III, _ W Ilbore APIIUWI Field Nama Well Stat IProdll nj Typc Intl (°( ~ MD (fIK6( Act Btm (ftKB) ,,,. 50.88 01032006400 UPARUK RIVER UNIT INJ PWI ~ 5,600.00 8,256.0 _ i KB Grd 1771 Rig Release Date C t N2S (PPm) Dat A t tion End D t ~~~ - __ ... __ - wau c r zT 10 1 2 0 - 9 ~ SSSV: LOCKED OUT Lasl WO: 41.02 612011986 ~ _ I ~ -. - _ _ . ~5 h matt Acw.~l ~ - _-_ ____ A tatlon Depth IttKBI _ _ - - End Dat A notation End Date Last Tag: SLM 7,978.0 1/1/2009 iRev Reason: TAG FILL 1/2/2009 Casin Strln s String OD String ID _ Set Depth Set~Deptll ATV D) String WI String Casing Dascripti on (in( (in( Top (fiKB) IttKe( (ftKe) (lbs/ft( Grade String Top Thrd _ CONDUCTOR - 16 15.062 0.0 110.0 110.0 62.50 H-40 coNOUCroR. SURFACE 95/8 8.765 0.0 3.296.0 2,800.6 36.00 J-55 im PRODUCTION 7 6.151 0.0 6,232.0 6.097.4 26.00 J-55 Tubin Strin s String OD String 10 Set Depth Set Depth (TVD) String Wt Slring sAFETrvLV. Tubing Dascrlption _ (ln( NG 3112 TUB _ (i^) 2 992 Top (kK8) 0 0 (kKB( (kKB) 7 884 928 0 5 0 (lbs/k) 9 30 Grade String Top Thrd J-55 EUEBrdABMOC 1.ne I . , . . . . . TUBING ~ 2 7/8 2.441. 7.928.0 7.951.0 5.899.9 6.50 J-55 EUEBrdABMOC Other In Hole All Jew t e I~ Run 8 Retrievable, Fish, etc. SURFACE. . Top Depth, --- 3.296 (TVD) Top Intl ) (ftK8) Top (kK8 (") Description Comment Run Data ID (in _ 1,778 0 1.724.9 32.08 SAFETY VLV DP-IA-SSA'LOCked Out 3q/96' GAS LIFT - 7,702.0 -~ 5.733.3 49.07 GAS LIFT B OTIS/LBXn.S/DMY/RM///Comment: STA 1 7/23/1995 2.90 . zroz 7,747.0 5.762.4 48.64 PBR aker PBR 9/9 1966 3.00 PBR ] ]4] PACKER. ].]BO Top (kKB) Bbn (kKB) (kK8( (kKB( tons Dale to^~~~ Type Comment 7,852.0 7.898.0 5,832.6 5,863.5 C-4, UNIT B, 2T-10 9/10/1986 12.0 IPERF 5" HyperJet II: 90 Deg. Ph INJECTION 7,968.0 8,025.0 5.911.5 5.950.6 A-0. A-3. 2T-10 9/10/1986 1.0 IPERF 4" HyperJet II; 90 Deg. Ph ] soo 7.968.0 8,018.0 5.911.5 5,945.6 A-4, A-3, ZT-10 6/22/1988 4.0 RPERF 2 118" EnerJet 7,968.0 8,025.0 5,911.5 5.950.6 A-4, A-3. 2T-10 7/2/1991 4.0 RPERF 2 1/8" DynaStrip; 0 Deg. Ph IPERF. ] 852-].898 NIPPLE. ].902 SLEEVE-C. 7.902 f - ~~ - 1 ],g28 NIPPLE. 1943 505. I,BSi ~ TTL. ],851 RPERF. ].968-8.018 IPERF, 1988A,025~ ~ PRODUCTION, 8,232 TD, 8,258 C ~~-- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description s ~, a J ~~~ ~~,~ ? ' ' NO. 5056 • Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 01 /23/09 16-OS ANHY-0030 INJECTION PROFILE (~ 01/09/09 1 1 2L-325 ANHY-00031 LDL 01/10/09 1 1 3M-03A AZJZ-00011 SFRT - (~- 01/11/09 1 1 2T-10 ANHY-00033 INJECTION PROFILE - 01/11/09 1 1 2L-301 AZJZ-00013 USIT 01/12/09 1 1 2A-26 AZJZ-00010 SONIC SCANNER - 01/15/09 1 1 2A-26 AZJZ-00010 SFRT Cj / 01/17/09 1 1 1 R-16 ANHY-00039 INJECTION PROFILE (~ 01/19/09 1 1 2V-04 ANHY-00040 INJECTION PROFILE '~ 01/20/09 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. • l~ MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg Kelití 0(7/07 P.I. Supervisor l t DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-10 KUPARUK RIV UNIT 2T-10 \CðkOqt, FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed B~ P.I. Suprv:J? p...-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2T-IO API Well Number: 50-103-20064-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603 143606 Permit Number: 186-096-0 Inspection Date: 6/2/2007 ./ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-10 Type Inj. w TVD 5771 IA 1325 2540 2480 2480 P.T.D 1860960 TypeTest SPT Test psi 1500 OA 175 200 200 200 Interval 4YRTST P/F P /Tubing 1640 1640 1640 1640 I Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. .~ SCANNED JUN 2, 0 2007 Wednesday, June 06, 2007 Page 1 of I MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission ~ DATE: June 14, 2003 ~/'~/o~ ~.,~,.ig.i,~,~?~ SUBJECT: Mechanical Integrity Tests ~ Conoco/Phillips Kuparuk River Field 2T Pad FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL Kuparuk River Unit Packer Depth Pretest Initial 15 Min. 30 Min. vw,I ~T-~o IT~,~i.I s I~.v.~.I ~ I~u~,~l 2~o I~o 12~o 12~o I,~,1 4 I P.T.D.I 1860960ITypetestl P I Testpsil 3000 ICasingl ~$0 I 3080 I 3050 I 3040 I P/F I ~P I Notes: OA 160 psi. pretest & 170 psi. during test. 3.5 BBL. Pumped. I We,,I 2T-,S IType,nj.I S I T.V.D. I5760I Tubingl240012400 12400 12400 I,nter~a,I 4 P.T.D.I 1950170ITypetestl P ITestpsil 3000 I Casingl 1800 I 2970 I 2950 I 2940I P/F I ~P Notes: OA 760 psi. psi. during test. I pretest & 900 2 BBL. Pumped. w~,,I ~T-~ ITy,e,,i.I S I T.V.D. I~ I Tu~,~l 2330 1~30 12~0 I 2~0 I,,~,1 4 I P.T.D.I 1960820ITypetestl P ITestpsiI 3000 I Casingl ~020 I 3m0 I 3000 I 3000I P/F I _PI Notes: OA 0 psi. during test. 2 BBL. Pumped. We,,I ~T-~ I~,~,,i.I S I ~.V.~. I~0 I Tu~,,~I 2~20 12~20 12~20 I 2~20 I,,,e~,l 4 P.T.D.I 1960920 ITypetestl P Imestpsil 3000 I Casingl 1340 I 3050 I 3000 I 2980 I P/F I ,P-P Notes: OA 0 psi. during test. 3 BBL. Pumped. We,,I =T-=, IType,nj.I G I T.V.D. 157~4 I Tubingl 3650 13~50 13~50 13~50 IIntervall 4 P.T.D.I 1950750 ITypetestl P ITestpsil 3000 I Casingl 240 I 2950 I 2925 I 2910 I P/FI P Notes: OA 0 psi, during test. 5.4 BBL. Pumped. . Type I NJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details I travded to C/P's Kuparuk River Field to witness 4 year MIT's. No failures witnessed. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 5 Number of Failures: 0 Attachments: Total Time during tests: 4 hrs. CC: MIT report form 5/12/00 L.G. 2003-0614_MIT_KRU_2T-29jc.xIs 6~24/2OO3 5;CANNED' AUG 0 ~ 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/2T 06/14/03 Sauvageau/Brake - APC John Cdsp Well 12%t0 P.T.D. I1860960 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type Test Test psi I 1500 I Casing I 11501 30801 30501 30401 P/F Well 12%t8 P.T.D. It950170 Notes: TypeTest Test psiI 15oo I Casing I 18001 29701 29501 29401 P/F Well 12%26 P.T,D. It950820 Notes: Type Test TestpsiI 1500 I Casing I 10201 30101 30001 30001 P/F Well 12%28 P.T.D. 1195o92o Notes: TypeTest Test psiI 15oo I Casing I 13401 30501 30001 29801 P/F P.T.D..It950750 TypeTest Test psiI 15oo I Casing I 2401 29501 29251 29101 P/F Notes: Well 12T-36 P.T;:D; 1 t 951020 NoteS: Type Test Test psil 1500 I Casing I 13001 3050] 30001 30001 P/F P.T,D.It951220 Type Test Test psiI 1500 I Casing I 13501 29501 29201 28751 P/F Notes: Carried MIT out for one hour Pressure at 45 min 1100/2820 1 hr 1100/2800 Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form 'Revised: 05/19/02 2003-0614_M IT_KRU_2T-10_-18_-26_-28_-29._-36_-201 .xls 6/25/2003 KRU 4 yr MIT's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23-0800 From: "NSK Problem Well Supv" <nl 617@conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) [~MIT KRU 2T 06-14-03.xls MIT KRU 2T 06-14-03.xls '1~ Name: EXCEL File (application/msexcel) I' Type: Encoding: base64 ~_~MIT KRU 2K 06-14-03.xls Type: EXCEL File (application/msexcel) I Encoding: base64 I of I 6/25/2003 1:45 } STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate m Plugging Repair well Perforate Other X (CONV) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 152' FSL, 556' FWL, SEC 1, T11N, ;,R8E, UM At top of productive interval 1407' FNL, 1422' FWL, SEC 11, T~IN, R8E, UM At effective depth 1494' FNL, 1225' FWL, SEC 11, T11N, R8E, UM At total depth 1523' FNL, 1159' FWL, SEC 11, T11N, R8E, UM 12. Present well condition summary Total Depth: measured tru6 vertical 6 1 0 9' 8250' feet feet Plugs (measured) 6. Datum elevation (DF or KB) 117' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-10 9. Permit number/approval number 86-96 10. APl number 50-103-20064 11. Field/Pool Kuparuk River Oil Field/Pool Effective depth: measured true vertical 6 0 3 6' Casing Length Structural 8 0' Conductor Surface 3 2 6 6' Intermediate Production 8 2 0 3' 8148' feet Size 16" feet Junk (measured) cemented 225 SX CS II Measured depth True vertical depth 110' 110' 9 5/8" 1000 SX AS III 350 SX CLASSG 115 SX AS I TOP JOB 7" 920 SX CLASS G 3296' 2800' 8233' 6098' Perforation depth: measured 7852'-7898', 7968'-8025', 8018'-8025', 8052'-8081' true vedical 5831'-5862', 5910'-5950', 5946'-5951', 5968'-5989' Tubing (size, grade, and measured depth) 3 1/2", 9.3# J-55 @ 7951' Packers and SSSV (type and measured depth) PKR: BAKER FHL @ 7765', BAKER DB @ 7928', SSSV: Camco TRDP-~I.A-S$¢., ~i 1783' .. ,:', ", 13. Stimulation or cement squeeze summary Convert well from oil producer to WAG injector. Intervals treated (measured) 3 !995 Treatment description including volumes used and final pressure _.,~,r,~. Lie, ~-655 C0ft9, (}0~'$~'0~ 14. Representative DailY Average Pl"bi~ction or~__h~_'~t}[i~ Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1541 1564 2312 1410 34O Subsequent to operation 2650 5O 2240 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: WAG Injector X Oil __ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendent Date SUBMIT IN DU×PLICATE OPERATOR: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test FIELD I UNIT f PAD: DATE:~:?¥"~?'4'~ '~ COMMENTS: PRETEST PRESSURE OBSERVED FOR 30 MINUTES PRIOR TO CASi VG TEST. THIS WELL IS BEING CONVERTED FROM A PRODUCER TO A SEA WATER INJECTOR. , COMMENTS: TUBING TEST. COMMENTS: COMMENTS: III I 'COMMENTS: ...~, .~. II *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N: NOT INJECTING Distribution: orig - Well File c - Operator c- Database c -Tnp Rpt File c- Inspector ANNULAR FLUID: DIESEL GLYCOL SALT WATER · DRILLING MUD OTHER P.P.G. Grad. WELL TEST: /;./¢ ! 8.?.4' Initial ..Y t /Z/20 4 - Year J. Ll. Z?Z? Workover -- J ZF.Z?Z? Other AOGCC REP SIGNATURE OPERATOR REP SIGNATUR[ JBglGVCD.XLS B OBB Y D. FOSTER n . FI-051 (Rev. 3/93) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other X (CONV) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service -- 4. Location of well at surface 152' FSL, 556' FWL, SEC 1, T11N, R8E, UM At top of productive interval 1407' FNL, 1422' FWL, SEC 11, T11N, R8E, UM At effective depth 1494' FNL, 1225' FWL, SEC 11, T11N, R8E, UM At total depth 1523' FNL, 1159' FWL, SEC 11, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8250' feet Plugs (measured) 6 1 09' feet 6. Datum elevation (DF or KB) RKB 117 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-10 9. Permit number 86-96 10. APl number 50-103-20064 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth' measured true vertical 8148' feet Junk (measured) 6036' feet Casing Length Structural 8 0' Conductor Surface 3 2 6 6' Intermediate Production Perforation depth: Size Cemented 1 6" 225 SX CS II 9 5/8" 1000 SXAS III 350 SX CLASSG 115 SX AS I TOP JOB 920 SX CLASS G 8203' 7" measured 7852'-7898', true vertical 5831'-5862', Measured depth True vertical depth 110' 110' 3296' 2800' 8233' 6098' 7968'-8025', 5910'-5950', 8018'-8025' 5946'-5951' 8052'-8081' 5968'-5989' £C£1vED Tubing (size, grade, and measured depth) 3 1/2", 9.3# J-55 @ 7951' =ackers and SSSV (type and measured depth) PKR: BAKER FHL @ 7765', BAKER DB @ 7928', SSSV: Camco !13. Attachments Description summary of proposal X i CONVERT WELL FROM OIL PRODUCER TO WATER INJECTOR. Detailed operation program 14. Estimated date for commencing operation JULY 1 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas _ Suspended To be reclassified as: Service WAG INJECTOR 17. I hereby, certify that the foreaoinaJ~true and correct to the best of my knowledge. ¢ ~. Title Wells Superintendent Date ....FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP_.Test _ LoCation clearance _ Mechanical Integrity Test '"/ Subsequent form require Original Slgnea By Dawd W Johnston · ' Comber Date ~__~-'/~ Approved by order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE !, Attachment 1 'Conversion to Water Injection Kuparuk- Well 2T-10 ARCO Alaska requests approval to convert Well 2%10 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 5831' and 5989' TVD. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. ARCO Alaska, Inc. Date: August 19, 1994 TRANSMITTAL #9137 RETURN TO: ARCO Alaska, Inc. Attn: N. Sharlene Chang Kuparuk Operations File Clerk ATO-1263B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following pressure items. receipt and return one signed copy of this transmittal. ~ ~'~ (~2T-10 Fluid Level Report - 08-04-94 ~ ~.., Oc~ 2Z-12 Fluid Level Report ~.~ ./¢/ 08-03-94 Receipt Ack howl e g ~.~~¢_.~ · DISTRIBUTION' Please acknowledge Tubing Casing Date' BP Chevron D&M Mobil State of Alaska Unocal REEEIVE[) ,-' KUPARUK FLUID LEVEL REPORT WellZT-/0 Date cc. ~ NSK Files ~s sssv/7<~ 3 GLM DV or GLV Fluid Level Found @ 10ti 0 Ft Fluid'Level Shot Down: Casing :~ Tubing CSG Press During Shot = # TBG Press During Shot= ~70 # Reason For Shooting FL: To Determine Operating Valve Well Status: Comments: On Continuous GL Operating CSG Press = ~ GL Rate (If Available)= ~ On Intermittent GL On Time=~ Min. Off Time-- Hr. Min. D~lta Time From End Of On Cycle No GL # MCFD Min. Gas Cons. Comrnissio Anchors.,..,?, DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS ~ April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data WALTER d. HICKEL, GOVERNOR RO. BOX 107034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 ; _~[ , · .... ~;,- ..... / ' 2)~::5 .~. , - - . .. --% ~ :,.-.',.. [,,,'.,,0 ,. _- · '- " ' '.'-~; ' ~1 -.-- Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kupan~ River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in T11N R7E Umiat Meridian could be offered for lease. The unleased land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, ~~~.mes E. Eason 'JDirector cc: J. L. Dees, ARCO Alaska Inc. RE{EIVED APR 1 6 199t Alas~ Oil .& 6as Cons. commission Anchoraga ~'.~, ¢;rlr~fYU r)r~ r:;cvc:ed paper August 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wood: In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drillsite 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staff, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until further notice. Sincerely, /t ames E. Eason irector . cc' C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR ARCO Alaska, Inc_ Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 Transmittal #: 5936 RETURN TO: ARCO Alaska, Inc. -Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this-transmittal. 2A-12 CET. 3-8-86 6410-7007 · 3F-16 CET 1-13-86 7740-8443 2A-10 CBL 3-20-86 6500-7042 3N-4 CET 3-25-86 6690-7736 3N-3 CET 3-25-86 6587-8016 3Q-7 CBL 2-15-87 6698-8908 3Q-6 CBL 2-14-87 7494-9545 3Q-2 CBL '2-15-87 7843-9752 ___3Q-5 CBL 2-15-87 7809-9941 3N-5 CET 3-25-86 5590-7456 2T-17 CET 9-5-86 6947-8236 2T-13 CET 9-1-86 6900-7752 2T-lO CET 9-4-86 4700-8118 'Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC Unocal Vault ARCO Alaska, Inc, is a Subsidiary of AllanticRichlieldCompany STATE OF ALASKA ,, , ALASKA tjIL AND GAS CONSERVATION CC,,,;MISSION WELL COMI LETION OR RI=COMPLETION RE ORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .- 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-96 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20064 4. Location of well at surface 9. Unit or Lease Name 152' FSL, 556' FWL, Sec. 1, T11N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1407' FNL, 1422' FWL, Sec.ll, TllN, R8E, UM 2T-10 At Total Depth 11. Field and Pool 1523' FNL, 1159' FWL, Sec.ll, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 117' ADL 25569 ALK 2667 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 06/06/86 06/17/86 1 2/20/86* N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Dirtff-~ctional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8250'MD 6109'TVD 8148'MD 6036'TVD YES~' NO []I 1778' feetMD 1550' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/GR/SP, FDC/CNL,Cal ,CET,GCT 23. CASING, LINER AND CEMENTING RECORD , , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE iTOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 225 sx CS II 9-5/8" 36.0# J-55 Surf 3296' 12-1/4" 1000 sx AS Ill & 350 s~ Class G Performed top job w/11.3 sx AS I 7" 26.0# J-55 Surf 8233' 8-1/2" 920 sx Class G & 175 s.~ PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECO'RD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7951' 7760' & 7928' 7852'-7898'MD 5831'-5862'TVD w/12 sPf 7968'-8025'MD 5910'-5950'TVD w/1 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8052'-8081 'MD 5968'-5989'TVD w/4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Perforated w/90° phasing See attached AddenJum. dated 1-13-87 for Fra~t,~r~ , , 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 II~ I · _ Flow Tubing Casing Pressure CALCULATED,1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Anchorage ~Note: Dr'il]ed RR 6-20-86. ~e]] perforated & tubing run 6-20-86, Form 10-407 Rev. 7-1-80 WC2:02:DANI CONTINUED ON REVERSE SIDE Submit in duplicate// 29. i 30. GEOLOGIC MARINERS FORMATION TESTS : NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GaR, and time of each phase. Top Kuparuk C 78#9' 5829' N/A Base Kuparuk C 7900' 5863' Top Kuparuk A 7948' 5896' Base Kuparuk A 8145' 6034' 31. LIST OF ATTACHMENTS Addendum (dated 01/13/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge (~/~f~O/'ll ~ Associate Engineer Signed L~,~L/m../) ,, _ Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in*situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM 8/22/86 8/23~86 9/04186 12/2o/86 2T-10 RU CTU, displ diesel out of CT to brine, RIH to 100', fill hole w/brine. RIH to 500', circ 175° brine, press up on ann to 1500 psi. RIH to 1000' &circ 175° in/100~ out. RIH to 1500', circ, press on ann started to slowly bleed. RIH to 1900', circ, pressure on ann bleeding slowly. RU Hot Oil Serv, pmp hot brine dn ann @ 1BPM, 1500 psi. POOH to 200', dtspl CTU & top 200' to diesel, POOH, RD CTU. RU Hot Oil truck to ann, displ 9-5/8" x 7" ann w/50 bbls hot diesel @ 2 - 2.5 BPM, 1800 psi w/final pmp'g pressure @ 2.5 BPM, 1300 psi. Secure well. Arctic Pak w/29.3 bbls PF "C" & 59 bbls Arctic Pak. Rn CET log f/8118'-4700'. Rn GCT gyro f/8070'-surf. Rn GR/JB f/PBTD-surf. Frac'd "A" sand perfs 7968'-8025' & 8052'-8081' in 5 stages per 12/3/86 procedure using Musol, diesel, gelled diesel, 20/40 mesh sand. Press'd ann to 2520 psi w/diesel. Tst lns to 8000 psi; OK. Stage 1: Pmp'd 30 bbls diesel & 5% Musol @ 1.5 BPM, 3450 psi initial press & 3100 psi, 1.5 BPM final press Stage 2: 68 bbls diesel, 1.5 BPM, 3100 psi Stage 3: 16 bbls gelled diesel pad @ 3850 psi, 5 BPM Stage 4: 12 bbls gelled diesel w/10 ppg 20/40 mesh sand, 3550 psi Stage 5: 30 bbls gelled diesel @ 22 BPM, 6460 psi final press (2 bbls extra pmp'd on flush) Pmp'd 2520# 20/40 mesh in formation leaving 840# 20/40 mesh sand in csg. Load to recover 238 bbls of diesel & gelled diesel. Job complete @ 1455 hrs, 12/20/86. Alaska Oil & ~3as (;ans. Commission Anchorage ' Dril~ing--Shpervisor ' ' DaTe SUB-$ URFA CE DIRECTIONAL SURVEY [~UIDANCE [~ONTINUOUS r~OOL RECEIVED OCT - 2 -]986 Alaska Oil & Gas Cons. Commission Anchorage Company ~co ALASKA, INC. Well Name 2T-10 (152'FSL, 556'FWL, SEC.1,TllN,RSE,UM) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. Date 7'17'1.3 9/4/86 Lo_R,~;~L.~,' Computed SARBER KRUWELL GCT DIRECTION4L SURVEY CUSTOMER LISTING FOR ARCO ALASKA~ INC. 2T-lO KUPARUK NORTH SLOPE,~LASKA SURVEY DATE: O~-SEPT-86 ENGINEER: S~RSER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH T1 DEG 57 MIN WEST COMPUTATION DATE: 22-S;P-86 PAGE 1 ARCO ALASKA~ INC. 27-10 KUPARUK NORTH SLOPE~ALASKA INTERPOLATED VALUES FOR TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -117.00 100.00 100.00 -17.00 200.00 200.00 83.00 300.00 300.00 183.00 400.00 399.99 282.99 500.00 499.99 382.99 600.00 599.93 482.93 700.00 699.84 582.84 800.00 799.77 682.77 900.00 899.65 782.65 1000.00 999.13 882.13 1100.00 1097.89 980.89 1200.00 1195.89 1078.89 1300.00 1292.63 1175.63 1400.00 1387.49 1270.49 1500.00 1479.96 1362.96 1600.00 1570.12 1453.12 1700.00 1657.93 1540.93 1800.00 1743.37 1626.37 1900.00 1826.16 1709.16 2000.00 1906.18 1789.18 2100.00 1983.05 1866.05 2200.00 2056.22 1939.22 2300.00 2126.13 2009.13 2400.00 2195.21 2078.21 2500.00 2263.72 2146.72 2600.00 2331.94 2214.94 2700.00 2400.10 2283.10 2800.00 2467.82 2350.82 2900.00 2534.75 2417.75 3000.00 2601.63 2484.63 3100.00 2668.85 2551.85 3200.00 2736.04 2619.04 3300.00 2802.90 2685.90 3400.00 2868.86 2751.86 3500.00 2935.35 2818.35 3600.00 3002.60 2885.60 3700.00 3070.02 2953.02 3800.00 3135.85 3018.85 3900.00 3201.47 3084.47 COURSE DEVIATION AZIMUTH OEG MIN DEG MIN 0 0 N 0 0 E 0 4 N 74 1 E 0 20 S 43 13 E 0 28 S 19 36 E 0 23 S 30 27 E 0 59 N 58 56 E 2 16 N 28 34 E 233 N 5 OW 1 50 N 63 42 W 4 0 S 82 OW 7 21 S 79 25 W 10 11 S 78 5 W 12 59 S 75 31 W 16 31 S 72 57 W ZO 26 S ?3 40 W 23 59 S 73 59 w 27 ? S 75 56 W 29 59 S 77 0 W 32 40 S 77 31 W 35 31 S 78 7 W 38 12 S 73 49 W 41 19 S 79 23 W 44 35 S 79 43 W 46 9 S 80 3 W 46 30 S 80 6 W 46 59 S 80 4 W 46 59 S 79 55 W 47 8 S 79 57 W 47' 44 S 80 36 W 48 4 S 80 48 W 47 55 S 80 50 W 47 39 S 81 4 W 47 59 S 81 1 W 48 18 S 81 17 W 48 41 S 81 35 W 48 0 S 81 40 W 47 36 S 81 51W 48 12 S 82 56 w 48 52 S 85 41 W 48 54 S 86 37 W DATE DF SJRVEY: 04-SEPT-86 KELLY 5USHING ELEVATION: 117.00 FT ENGINEER: SAR6ER EVEN 100 FEET OF MEA.SURED DEPTH VERTICAL DOGLEG RECTANGULAR CO SECTION SEVERITY NORTH/SOUTH EA FEET DEG/IO0 FEET F OR ST EE DINATES /WEST T HORIZ. DIST. FEET DEPARTURE AZIMUTH DEG MIN 0.00 0.00 0.00 N -0.13 0.62 0.07 N -0.41 0.18 0.13 S -0.60 0.15 0.73 S -0.64 0.27 1.45 S -1.25 2.29 1.56 S -3.92 1.12 0.88 N -6.03 1.37 5.06 N -5.61 2.76 8.33 N -1.24 3.42 8.39 N 0.00 E 0.12 E 0.47 E 0.87 E 1.14 E 1.82 E 3.84 E 4.69 E 3.18 E 1.43 W 0.00 0.14 0.49 1.14 1.85 2.40 3.94 6.90 8.92 8.51 N 0 0 E N 57 58 E S 74 53 E S 49 42 E S 38 16 S 49 30 N?7 1E N 42 50 E N 20 53 E N 9 38 W 8.71 ,3.05 6.54 N 24.24 1.68 3.47 N 44.00 3.25 0.94 S 69.26 3.86 7.99 S 100.79 4.65 17.06 S 138.80 3.14 27.67 S 181.96 2.75 38.89 S 229.63 2.65 50.00 S 281.34 2.81 61.42 S 337.12 2.66 73.25 S ! 2 4 7 10 13 17 22 27 33 1.29 W 6.63 W 5.97 W 0.24 W 0.45 W 6.96 W 8.71 W 5.22 W 5.89 W O.70 W 13.05 26.85 45.98 70.69 101.89 139.73 182.89 230.70 282.64 338.71 N 59 54 W N 82 34 W S 88 49 W S 83 30 W S 80 21 W S 78 34 W S 77 43 W S 77 29 W S 77 26 W S 77 30 W 396.67 3.00 85.22 460.11 3.21 97.25 527.65 2.96 109.58 598.46 0.47 122.13 670.03 0.24 134.51 742.14 0.17 147.03 814.52 0.18 159.70 886.99 0.40 172.53 959.78 0.80 184.91 1033.22 0.25 196.91 S 389.44 W S 452.24 W S 519.25 W S 589.64 W S 660.87 W 5 732.63 W S 804.64 W S 876.68 W S 949.20 W S 1022.53 W 398.65 S 77 39 W 462.58 S 77 51 W 530.69 S 78 4 W 602.15 S 78 17 W 674.42 S 78 29 ~' 747.24 S 78 39 820.33 S 78 46 ~ 893.49 S 78 51 W 967.05 S 78 58 W 1041.32 S 79 5 ~ 1106.68 0.30 208.76 S 1179.80 0.21 220.38 S 1252.93 0.10 231.91 S 1326.36 1.79 243.48 S 1400.45 0,82 254.45 S 1474.08 0.60 265.33 5 1547.00 0.37 275.92 S 1519.70 3.61 286.04 S 1693.22 2.16 293.52 S 1766.27 1.40 298.15 S 109 116 124 131 139 146 153 161 168 176 . 9. 2. 5. O. 3. 7. O. 5. O. 93 W O5 W 20 W 66 W 02 W 92 W I6 W 32 W 21 W 53 W 1115.63 1189.64 1263.67 1338.00 1413.12 1487.77 1551.73 1635.53 1710.58 1785.60 S 79 12 w S 79 19 W S 79 25 W S 79 30 w S 7'9 37 W S 79 43 W S 79 49 ~ $ 79 55 w S .50 7 W S 80 23 W COMPUTATION DATE: 22-SEP-86 PAGE 2 ARCO ALASKA, INC. DATE OF SURVEY: 04-SEPT-86 27-10 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SARBER 117.00 ET INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 4000,00 3267,25 3150,25 49 4 4100,00 3332,16 3215,16 49 56 4200,00 3397,30 3280,30 48 44 4300.,00 3463,21 3346,21 48 55 4400,00 3528,82 3411,82 49 2 4500,00 3594,30 3477,30 49 12 4600,00 3659,61 3542,61 49 14 4700,00 3T24,81 3607,81 49 20 4800,00 378g,76 3672,76 49 39 4900,00 3854,43 3737,43 49 47 S 81 15 W 1839.73 S 73 3 W 1915.39 S 65 39 W 1991.08 S 65 14 W 2065.78 S 65 15 W 2140.72 S 64 58 W 2215.77 S 64 50 W 2290.92 S 64 46 W 2366,16 S 64 46 W 2441,59 S 64 52 W 2517.28 6.16 7.15 1.44 0.28 0.32 0.46 0.10 0.17 0.18 0.75 305.25 S 1835.48 W 1860.69 S 80 33 W 321.98 S 1909.60 W 1936.56 S BO 25 W 349.49 S 1980.24 W 2010.85 S 79 59 W 380.89 S 2048.58 W 2083.69 S 79 28 W 412.49 S 2117.10 W 2156.91 S 78 58 444,25 S 2185.69 W 2230.38 $ 78 30 ,, 476.41 S 2254.25 W 2304.04 S 78 4 W 508,67 S 2322.86 W 2377.91 S 77 38 W 541.10 S 2391.63 W 2452.08 S 77 15 W 573.54 S 2460.67 W 2526.62 S 76 52 W 5000.00 3919.06 3802.06 49 38 5100.00 3983.70 3866.70 49 53 5200.00 4047.83 3930.83 50 14 5300.00 4111.62 3994.62 50 25 5400.00 4175.16 4058.16 50 40 5500.00 4238.38 4121.38 50 52 5600.00 4301.43 4184.43 50 53 5700.00 4366.29 4249.29 47 15 5800.00 4435.44 4318.44 45 $6 5900.00 4504.79 '4387.79 46 12 S 64 46 W 2593.01 S 64 44 W 2668.T0 S 64 43 W 2744.82 S 64 55 W 2821.23 S 64 57 W 2897.88 S 65 5 W 2974.79 S 65 4 W 3051.85 S 64 15 W 3127.36 S 63 38 W 319~.85 S 63 42 W 3270.14 O. 17 0.49 0.43 0.51 0.47 0.33 0.58 4.58 0.66 0.93 605.98 S 2529.74 W 2601.31 S 76 31 W 638.54 S 2598.74 W 2675.04 S 76 11 W 671.29 S 2668.13 W 2751.28 S 75 52 W 704.08 S 2737.81 W 2826.90 S 75 34 W 736.77 S 2807.77 W 2902.83 S 75 1T W 769.54 S 2877.98 W 2979.09 S 75 1 W 802.27 S 2948,37 W 3055.57 S 74 46 W 834.51 S 3017.28 W 3130.55 S 74 32 W 866.44 S 308Z.07 W 3201.54 S 74 1T W 898.42 S 3146.63 W 3272.37 S 74 3 W 6000.00 4574.28 4457.28 45 53 6100.00 4643.89 4526.89 45 56 6200.00 4713.34 4596.34 46 6 6300.00 4782.54 4665.54 46 14 6400.00 4851.68 4734.68 46 17 6500.00 4920.68 4803.68 46 26 6600.00 4989.42 4872.42 46 45 6700.00 5057.94 4940.94 46 35 6800.00 5126.57 5009,57 46 43 6900.00 5194.84 5077.84 47 10 S 63 40 W 3341.32 S 63 34 W 3412.35 S 63 25 W 3483.51 S 63 23 W 3554.91 S 63 4 W 3626.32 S 62 55 W 3697.82 S 62 48 W 3769.54 S 62 43 W 3841.43 S 62 38 W 3913.22 S 62 28 W 3985.32 0.22 0.22 0.26 0.52 0.57 0.18 0.17 0.51 0.60 2.55 930.27 S 3211.10 W 3343.14 S 73 50 W 962.17 S 3275.42 W 3413.82 S 73 37 W 994.27 S 3339.81 W 3484.66 S 73 25 W 1026.59 S 3404.37 W 3555.78 S 73 13 W 1059.13 S 3468.87 W 3525.96 S 73 1 " 1091.97 S 3533.36 W 3698.25 S 72 49 1125.11 S 3598.00 W 376'9.81 S 72 38 W 1158.42 S 3662.76 W 3841.58 S 72 26 W 1191.82 S 3727.38 W 3913.28 S 72 16 W 1225.46 S 3792,24 W 3985.33 S 72 5 W 7000.00 5262.60 5145.60 47 32 7100.00 5330.07 5213.07 47 36 7200.00 5397.37 5280.37 47 47 7300.00 5464.47 5347.47 47 53 7400.00 5531.27 5414.27 48 16 7500.00 5597.72 5480.72 48 28 7600.00 5663.92 5546.92 48 37 7700.00 5729.98 5612.98 48..:49 7800.00 5796.00 5679.00 48,': 8 7900.00 5863.41 5746.41 4%' 10 S 52 13 W 4057.82 S 62 4 W 4130.55 S 61 45 W 4203.39 S 61 24 W 4276.32 S 61 ? W 4349.45 S 61 3 W 4422.84 S 61 5 W .... 4496.45 S 61~ 6 W. · : ~.4570.18 S 63'52 S 66.'i~26 0.80 0.57 0.57 0.45 0.28 0.39 0.15 0.89 3.74 0.88 1259.61 S 3857.37 W 4057.82 S 71 54 W 1294.10 S 3922.62 W 4130.57 S 71 44 W 1328.90 S 3987.90 W 4203.48 S 71 34 W 1364.16 S 4053.11 W 4276.52 S 71 23 W 1399.96 S 4118.35 W 4349.79 S 71 13 W 1436.07 S W183.78 W 4423.38 S ?1 3 W 1472.31 S 4249.39 W 4497.22 S 70 53 W 1508.61 S 4315.10 W 4571.21 S ?0 43 W 1543.89 S 4381.39 W 4645.45 $ 70 35 W 1574.36 $ 4448.67 W 4719.03 S 70 30 W COMPUTATION DATE: 22-SEP-86 PAGE 3 ARCO ALASKA~ INC. 2T-10 KUPARUK NORTH SLOPE,ALASKA DATE OF SURVEY: 04-SEPT-86 KELLY BUSHING ELEVATION: ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH 117.00 FT TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 'FEET DEG/IO0 FEET FEET FEE'T DEG MIN 8000.00 5932.08 581'5.08 45,','?'58 S 667!27 ~"~'789.91 1.48 1603.37 S 4515.32 W 4791.55 S ?0 27 W 8100.00 6002.44 588.5.44 44.~749 .S 66...' 4 W~,,',,~,::,,-:'4860o60 0.00 1532.03 S 4580.34 W 4862.41 S ?0 23 W 8200.00 6073.37 5956.37 44,;'~49 S 66,:.' 4 W;":"4930.73 0.00 1660.63 S 4644.T8 W 4932.71 S 70 19 W 8250.00 6108.83 5991.83 44,~&49 S 66, 4 W""~;'4965.79 0.00 1674.92 S 4677.00 W 4967.86 S 70 17 W COMPUTATION DATE: 22-SEP-86 PAGE 4 ARCO ALASKA, INC. DATE OF SURVEY: 04-SEPT-86 27-10 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SARBER 117.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -117.00 0 0 1000.00 999.13 882.13 7 21 2000.00 1906.18 1789.18 38 12 3000.00 2601.63 2484.63 47 55 4000.00 3267.25 3150.25 49 4 5000.00 3919.06 3802.06 49 38 6000.00 4574.28 4457.28 45 53 7000.00 5262.60 5145.60 47 32 8000.00 5932.08 5815.08 45 58 8250.00 6108.83 5991.83 44 49 N 0 0 E 0.00 S 79 25 W 8.71 S 78 49 W 396.67 S 80 50 W 1106.68 S 81 15 W 1839.73 S 64 46 W 2593.01 S 63 40 W 3341.32 S 62 13 W 4057.82 S 66 27 W 4789.91 S 66 4 W 4965,79 0.00 3.05 3.00 0.30 6.16 0.17 0.22 0.80 1.48 0.00 0.00 N 0.00 E 0.00 N 0 0 E 6.54 N 11.29 W 13.05 N 59 54 W 85.22 S 389.44 W 398.65 S 77 39 W 208,76 S 1095.93 W 1.115.63 S 79 12 "! 305.25 S 1835.48 W 1860.69 S 80 33 605.98 S 2529.74 W 2601.31 S 76 31 930.27 S 3211.10 W 3343.14 S 73 50 ~ 1259.61 S 3857.37 W 4057.82 S 71 54 W 1603.37 S 4515.32 W 4791.55 S 70 27 W 1674.92 S 4677.00 W 4967.86 S 70 17 W COMPUTATION ARCO ALASKA, INC. 27-10 KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEG MIN DEG MIN 0 17 117 217 317 417 517 617 717 817 .00 .00 .00 .00 .00 .01 .02 .08 .18 .25 0.00 -117.00 0 0 N 0 0 E 17.00 -100.00 0 2 N 17 20 E 117.00 0.00 0 8 S 83 1 E 217.00 100.00 0 21 S 42 46 E 317.00 200.00 0 27 S 17 57 E 417.00 300.00 0 22 S 37 56 E 5IT.O0 400.00 i 21 N 50 42 E 617.00 500.00 2 20 N 23 16 E 717.00 600.00 2 29 N 9 54 W 817.00 700.00 1 59 N 75 29 N 917 1018 1119 1221 1325 1431 1540 1653 1768 1888 .40 .03 .43 .70 .49 .64 .75 .03 .82 .76 917.00 800.00 4 37 S 80 29 W 1017.00 900.00 7 59 S 79 18 W 1117.00 1000.00 10 33 S 77 58 W 1217.00 1100.00 13 39 S 74 41 W 1317.00 1200.00 17 28 S 73 3 W 1417.00 1300.00 21 45 S 73 46 W 1517.00 1400.00 25 20 S 74 41 W 1617.00 1500.00 28 41 S 76 37 ~, 1717.00 1600.00 31 46 S 77 22 W 1817.00 1700,00 35 13 S 78 2 W 2013 2145 2286 2431 2578 2724 2873 3022 3171 3321 .81 .74 .81 .68 .09 .86 .42 .93 .55 .26 1917.00 1800.00 38 37 S 78 54 W 2017.00 1900.00 42 49 S 7'9 34 W 2117.00 2000.00 46 6 S 80 0 W 2217.00 2100.00 46 36 S 80 6 W 2317.00 2200.00 46 57 S 79 59 W 2417.00 2300.00 47 11 S 80 5 W 2517.00 2400.00 48 4 S 80 44 W 2617.00 2500.00 47 51 S 80 53 W 2717.00 2600.00 47 53 S 81 1 W 2817.00 2700.00 48 35 S 8i 34 W 3472 3621 3771 3923 4076 4229 4381 4534 4688 4842 .54 .34 .42 .59 .43 .86 .97 .77 .01 .09 2917.00 2800.00 48 10 S 81 38 W 3017.00 2900.00 47 32 S 81 51 W 3117.00 30DO.O0 48 49 S 84 55 W 3217.00 3100.00 48 45 S 86 3 W 3317.00 3200.00 49 48 S 75 10 W 3417.00 3300.00 48 42 S 65 22 W 3517.00 3400.00 49 0 S 65 14 W 3617.00 3500.00 49 15 S 64 53 W 3717.00 3600.00 49 20 S 64 46 W 3817.00 3700.00 49 43 S 64 49 W DATE: EVEN 22-SEP-86 100 FEET OF VERTICAL SECTION FEET . --0. --0. --0. --0. --1. --4. --6. -0. 11. 27. 49. 76. 112. 155. 206. 264. 330. 405. .490. 589. 692. 798. 905. 1013. 1123. 1232. 1342. 1453. 1562. 1672. 1783. 1897. 2013. 2127. 2241. 2357. 2473. O0 O0 16 45 60 67 58 40 16 16 05 08 71 O1 71 18 76 67 79 64 19 50 04 78 66 05 68 49 06 05 94 53 33 45 37 37 20 92 14 44 PAGE 5 DATE OF SURVEY: 04-SEPT-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: SARBER SUB-SEA DEPTH DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG/iO0 FEET FEET FEET DEG MiN 0.00 1.11 0.45 0.19 0.08 0.37 2.36 1.54 1.26 2.24 3.70 3.94 2.20 3.08 3 · 56 3.41 3.64 3.20 2.83 2.73 3.20 3.41 0.60 0.63 0.41 0.72 0.44 0.57 0.62 1.48 0.69 0.36 2.41 2.81 6.68 0.19 0.23 0.32 0.21 0.26 . O. O. O. O. 1. 1. 1. 5. 8. O0 N 0.00 E 0.00 O0 N 0.00 E 0.00 07 N 0.15 E 0.16 21 S 0.54 E 0.58 87 S 0,91 E 1.26 54 S 1.21 E 1.96 35 S 2.10 E 2.50 50 N 4.14 E 4.40 81 N 4.59 E 7.40 52 N 2.65 E 8.92 N 0 0 E N 90 0 E N 64 25 E S 69 6 E S 46 22 r S 37 58 ,_ S 57 17 E N 70 4 E N 38 19 E N 17 15 E . 6. 2. 2. 10. 20. 32. 44. 57. 71. 19 N 2.72 W 8.63 10 N 13.64 W 14.95 74 N 30.04 W 30.17 24 S 50.81 W 50.86 18 S 77.37 w 78.04 25 S 111.39 W 113.22 28 S 153.31 W 156.67 75 S 202.79 W 207.67 81 S 259.66 W 266.02 91 S 324.32 W 332.20 N 18 21 W N 65 54 W N 84 46 W S 87 28 W S 82 30 W S 79 41 W S 78 6 W S 77 33 W S 77 26 W S 77 29 w 86. 102. 120 · 138. 156. 175. 193. 211. 228. 245. 87 S 397.85 W 407.22 84 S ~82.37 W 493.21 47 S 580.27 W 592.64 45 S 683.52 W 697.40 90 S 788.87 W 804.32 70 S 894.63 W 911.72 74 S 1003.01 W 1021.55 47 S 1112.72 W 1132.64 62 S 1221.33 W 1242.54 83 S 1331.40 W 1353.91 S 77 40 w S 77 57 W S 78 16 W S 78 32 W S 78 45 U S 78 53 l S 79 4 w S 79 14 W S 79 23 W S 79 32 W 262.36 S 1443.70 278.15 S 1552.76 291.77 S 1663.81 299.23 S 1778.25 317.06 S 1892.25 358.82 S 2000.65 406.80 S 2104.74 455.42 S 2209.55 504.80 S 2314.64 554.77 S 2420.67 W 1467.34 S 79 42 W W 1577.47 S 79 50 W W 1589.19 S 80 3 W W 1803.25 S 80 26 W W 1918.63 S 80 29 W W 2032.57 S 79 49 W W 2143.69 S 79 3 W W 2256.00 S 78 21 W W 2369.04 S 77 41 W W 2483.43 S 77 5 W COMPUTATION DATE: 22-SEP-86 PAGE 6 ARCO ALASKA, INC. DATE OF SURVEY: 04-SEPT-86 27-10 KUPARUK NORTH SLOPE,ALASKA KELLY 5USHING ELEVATION: ENGINEER: SARSER 117.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4996.82 3917.00 3800.00 49 38 5151.80 4017.00 3900.00 50 9 5308.44 4117.00 4000.00 50 27 5466.15 4217.00 4100.00 50 46 5624.65 4317.00 4200.00 50 34 5773.46 4417.00 4300.00 46 3 5917.62 4517.00 4400.00 46 6 6061.37 4617.00 4500.00 45 51 6205.27 4717.00 4600.00 46 7 6349.84 4817.00 4700.00 46 15 S 64 46 W 2590.60 S 64 44 W 2708.06 S 64 57 W 2827.68 S 64 59 W 2948.73 S 65 4 W 3070.82 S 63 39 W 3179.96 S 63 43 W 3282.71 S 63 35 W 3384.90 S 63 25 W 3487.27 S 63 14 W 3590.50 0.17 0.90 0.76 0.87 2.05 0.48 0.56 0.11 0.33 0.40 604.95 S 2527.55 W 2598.94 S 76 32 W 655.47 S 2634.63 W 271~.94 S 76 1 W 706.84 S 2743.70 W 2833.28 S 75 33 W 758.47 S 2854.19 W 2953.25 S' 75 7 TM 810.32 S 2965.70 W 3074.41 S 74 43 857.97 S 3064.96 W 3182.78 S 74 21 . 904.04 S 315~.02 W 3284.87 S 74 1 W 949.83 S 3250.57 W 3386.50 S 73 42 W 995.98 S 3343.20 W 3488.41 S 73 24 W 1042.75 S 3436.53 W 3591.25 S 73 7 W 6494.66 4917.00 4800.00 46 25 6640.27 5017.00 4900.00 46 47 6786.05 5117.00 5000.00 46 39 6932.66 5217.00 5100.00 47 17 7080.61 5317.00 5200.00 47 31 7229.26 5417.00 5300.00 47 52 7378.55 5517.00 5400.00 48 12 7529.10 5617.00 5500.00 48 29 7680.31 5717.00 5600.00 48 42 7831.35 5817.00 5700.00 47 46 S 62 55 W 3693.99 S 62 48 W 3798.51 S 62 38 W 3903.21 S 62 23 W 4008.96 S 62 6 W 4116.43 S 61 41 W 4224.74 S 61 9 W 4333.72 S 61 3 W 4444.25 S 61 5 W 4555.65 S 65 14 W 4667.22 0.18 0.08 0.50 0.39 0.96 0.34 0.52 0.46 0.35 3.14 1090.21 S 3529.92 W 3694.44 S 72 50 W 1138.52 S 3624.10 W 3798.73 S 72 33, W 1187.15 S 3718.37 W 3903.28 S 72 17 W 1236.57 S 3813.49 W 4008.97 S 72 2 W 1287.41 S 3909.96 W 4116.45 S 71 46 W 1339.17 S 4007.00 W 4224.86 S 71 31 W 1392.23 S 4104.33 W 4334.04 S 71 15 W 1446.63 S 4202.86 W 4444.86 S 71 0 W 1501.45 S 4302.15 W 4556.63 S 70 45 W 1553.89 S 4402.41 W 4668.60 S 70 33 W 7978.24 5917.00 5800.00 46 16 8120.52 6017.00 5900.00 44 49 8250.00 6108.83 5991.83 44 49 S 66 30 W 4774.28 S 66 4 W 4875.00 S 66 4 W 4965.79 1.2~ 0.00 0.00 1597.12 S 4500.93 W 4775.89 S 70 27 W 1637.90 S 4593.56 W 4876.84 S 70 22 W 1674.92 S 4677.00 W 4967.86 S 70 17 W ARCO ALASKA, INC. 2T-10 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION INTERPOLATED VALUES FOR MEASURED DEPTH BELOW KB 7849.00 7900.00 7948.00 8145.00 8148.00 8250.00 DATE: 22-SEP-86 CHOSEN HORIZONS FROM KB 5828.88 5863.41 5896.17 6034.36 6036.49 6108.83 ORIGIN: TVD PAGE 7 DATE OF SURVEY: 04-SEPT-86 KELLY BUSHING ELEVATION: llT.O0 ENGINEER: SARBER 152 FSL, 556 SUB-SEA 5711.88 5746.41 5779.17 5917.36 5919.49 5991.83 SURFACE LOCATION AT FWL, SEC 1, TllN, RSE, UM RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1559.27 S 4414.30 W 1574.36 S 4448.67 W 1588.38 S 4480.83 W 164~.90 S 4609.33 W 1645.76 S 4611.27 W 1674.92 S 4677.00 W FT COMPUTATION DATE: 22-SEP-86 PAGE 8 ARCO ALASKA, INC. 27-10 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD ~**~**~,~ STRATIGRAPHIC MEASURED DEPTH BELOW KB 7849.00 7900.00 7948.00 8145.00 8148.00 8250.00 DATE OF SURVEY: 04-SEPT-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: SARBER SUMMARY FROM ORIGIN: 152 TVD SUB-SEA FSL, 556 SU FWL, RECTA NORT RFACE LOCATION AT SEC 1, TllN, RSE, NGULAR COORDINATES H/SOUTH EAST/WEST 5828.88 5863.41 5896.17 6034.36 6036.49 6108.83 5711.88 5746.41 5779.17 5917.36 5919.49 5991.83 155 157 158 164 164 167 9.27 S 4414.30 W 4.36 S 4448.67 W 8.38 S 4480.83 W 4.90 S 4609.33 W 5.76 S 4611.27 W 4.92 S 4677.00 W UM FINAL WELL LOCATION TRUE MEASURED VERTICAL DEPTH DEPTH 8250.00 6108.83 AT TD: SUB-SE4 VERTICAL DEPTH 5991.83 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET OEG MIN 4967.86 S 70 17 SCHLUMBEROER O I REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC WELL 2T- i 0 FIELD KUPARWK COUNTRY USA RUN 1 DATE LOOOED 04 - SEP - 88 REFERENCE 000071?]3 WELL: 2T-10 (152'FSL, 5. FWL, SEC. 1, TllN,R8E, UM) 3RI ZONTAL PROJECTION NORTH 4000 9OOO 2000 IOO0 -1000 -ZOO0 -9000 SOUTH -4000 -6000 NEST REF 000071719 SCALE = 1/1000 IN/FT -SO00 -4000 -9000 -2000 -1000 0 1000 2000 WELL: 2T-10 (152'FSL, 556' SEC . 1, TllN, R8E, UM) ?ICAL PROJECTION 71. -2'000 -]000 0 0 ]OOO2000 3000 4000 SO00 B000 44-!-~-~j-&.L-~--.-~".; LL;--L;.4- -i-4--i4-4-~i i -&~-L.L~.J...!..-L ~..~--LLL!-.LL;-~ ...... LLLLL~...LL;.. 1--.~-.;-.:-.-~.-~---~. ;..~..:.-:--~- ~..L; 1.. ~ ....... ~..~.~ · -~--~-H---[-H--~----~ ...... ~--.P-~--+q-4-4--~--~..--~-4---~--+4--+-~--H--.-+4-+q---~.q-.-~---~-4-----~4-4---~4-4---;-4--4-.~-..~-..~...L.~...~..-~...;. 4..~ .-t-4- ~ ~-:.. ~. ~. 4.~. ~ .... :..-~..;-~-~: .~ 4--.: --L&..L.L.L~...~-~-.-~ ...... 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[-f-f-.~--f+.~--f-; .... f-?--~-.-?-~-.f-.f.-~..-~--,-.!--.~ ~: i ~"~"~"~' t ~ ~ :'"~ i"~";"~'f ~! ': ~~ :-"'~t II "fl PROJECTION ON VERTICAL PLANE ~Sl. - 71. SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/ 1000 IN/FT RECEIVED OGT '~ ~ !~B6 Alaska Oil & Gas Cons. Commission N-mhorage Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by.' ,l '- t ,. Required Date Received Remarks Completion Report S amp 1 e s Mud Log . -- , ~ , . . . Core Chips ~~.~ Core Description ~,~i~Registered Survey Plat Inclination Survey ~, .~ , .. ?"~ ,. . ....... Directional Survey 1 Drill Stem Test Reports Production Test Reports ~ ~-~v ~c': . .... . ,'-~ ~'~ ~.~ -..'j , . ~ ~ · . .. ~ ~ _ ' I.~. ._. ~ ~..~. ..... , ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 17, 1986 Transmittal #5832 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 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. Open Hole Final Logs' 3N-18~2" DIL-SFL-GR 6-2-86 2000-10608 ~5" DIL-SFL-GR 6-2-86 2000-10608 '2" FDC Porosity 6-2-86 8400-10582 .l FDC Porosity 6-2-86 8400-10582 FDC Raw 6-2-86 8400-10582 '5" FDC Raw 6-2-86 8400-10582 ~Cyberlook 6-2-86 9600-10550 3K-3-~2" DIL-SFL-GR 6-27-86 200-8894 ~5" DIL-SFL-GR 6-27-86 200-8894 2" FDC Porosity 6-27-86 4835-8869 ~5" FDC Porosity 6-27-86 4835-8869 2" FDC Raw 6-27-86 4835-8869 ~5" FDC Raw 6-27-86 4835-8869 ,-Cyberlook 6-27-86 8200-8869 2T-1~2" DIL-SFL-GR 6-18-86 1000-8248 ~ 5" DIL-SFL-GR 6-18-86 1000-8248 ~2" FDC Porosity 6-18-86 3300-8222 -~ ~5" FDC Porosity 6-18-86 3300-8222 ~ 2" FDC Raw 6-18-86 3300-8222 ~5" FDC Raw 6-18-86 3300-8222 ~ Cyberlook 6-18-86 7650-8200 Receipt Acknowledged' Distribution' NSK D & M Drilling Rathmell Vault (1 film) ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldComDany Date- State of Alaska (1 bl + I se) STATE OF ALASKA ALASF ,)IL AND GAS CONSERVATION COMr SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~: Stimulate .~ Plugging ~ Perforate ~ Pull tubing Alter Casing ~ Other ~ Complete 2. Name of Operator 3. Address P, O. Box 100360 Anchoracje~ AK 4. Location of well at surface 5. Datum elevation (DF or KB) RKB 117' 99510-0360 6. Unit or Property name Kuparuk River Unit 7. Well number 152' FSL. 556' FWL, At top of prod'uctive interval 1407' FNL, 1422' At effective depth 1494' FNL, 1225' At total depth 1523' FNL~ 1159' 11. Present well condition summary Total depth: measured true vertical Sec. 1, T11N, R8E, UM FWL, Sec. 11, T11N, R8E, UM FWL, Sec. 11, T11N, R8E, UM FWL, Sec. 11, T11N, R8E, UM Effective depth: measured true vertical Casing Length 8250 'MD 6109 'MD 8148'TVD 6036'TVD Size feet feet feet feet Plugs (measured) 2T-!0 8. Approval number 240 9. APl number 50--1 03 -20064 10. Pool Kuparuk River Oil Pool None Junk (measured) None Cemented Measured depth Feet True Vertical depth Conductor 80 ' 1 6" Surface 3262 ' 9-5/8" Producti on 8202 ' 7" Perforation depth: measured 7852 ' 7968' true vertical 5831 ' 5910' - Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail 8 7951' Packers and SSSV (type and measured depth) 225 sx CS II 1000 sx AS I I I & 350 sx Class G Top job w/115 sx AS 920 sx Class G 175 sx PF "C" - 7898'MD 8052' - 8081'MD - 8025'MD - 5862'TVD 5968' - 5989'TVD 5950'TVD FHL pkr @ 7760' "D" pkr ~ 7928' & TRDP-1A-SSA S$SV ~ 1778' 12. Stimulation orcementsqueezesummary I r~e/r~als treated (measured) Treatment description including volumes used and final pressure 1 lO'MD 110 'TVD 3296 'MD I 8233 'MD 2800'TVD 6096 ' TVD ' ~ RECEIVED OCT - 2 !986 N~ka 0il & Gas Cons. Commission Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History, w/Addendum, dated 9-02-86) Daily Report of Well Operations ~ Copies of Logs and Surveys Run~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate Engineer (DAM) Date bwu/~ ub Submit in Duplicate ARCO Oil and Gas Company Daily We~l History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after al!owab!e has been assigned or well is P!ugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are sus3enced for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, repeal completion and represen:ative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District County or Parish ~ State Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25569 Auth. or W.O. no. T t!e AFE AK0774 Completion Nordic 1 AP1 50-103-20064 cost center code Alaska IWell no. 2~-10 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 9/8/86 I otal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well our 0045 hrs. Prior stalus it a w.o. Date and depth as of 8:00 a.m. 9/08/86 9/09/86 9/10/86 Complete record for each day reported 7" @ 8233' 8149'- FC, Tst BOPE 12.2 ppg NaBr Accept ri$ @ 0045 hrs, 9/8/86. NU BOPE. 7" @ 8233' 8149' FC, Rn WL pkr 12.2 ppg NaBr Tst BOPE, displ diesel cap. RU Schl, perf w/4" gun, 4 JSPF f/8052'-8081', 1 JSPF f/7968'-8025', & 12 JSPF f/7852'-7898' RD WL. Rn gage ring/JB. RIH w/Bkr pkr. 7" @ 8233' 8148' PBTD, RR 6.8 ppg Diesel in tbg & ann Set pkr @ 7928' WLM, RD Schl. Rn 247 its, 3½", 9.3#, J-55 8RD AB Mod & 2 jts, 3½", BTC tbg & lnd w/SSSV @ 1778', FHL Pkr @ 7760' D WL Pkr @ 7928' WLM, Tailpipe @ 7951'. Tst ann & pkr to 2500 psi. Tst SSSV. ND BOPE, NU & tst tree to 5000 psi. Displ well to diesel. RR @ 0200 hrs, 9/10/86. Old TD Ne';,' TD PB Depth 8148t ?BTD Released rig Date Kind of rig 0200 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data 9/10/86 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing Iht .... , Oil or gas Test time Pr°du~nF C Oil on'~llt ~,~ L. ~as~er~y~ Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowabl~ I ~{fe~¢~e corrected ~,. Oil & Ancf[0rage The above is correct For form preparation and distribution, see Procedures Manual, Section I0, Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 8/22/86 8/23/86 2T-10 RU CTU, displ diesel out of CT to brine, RIH to 100', fill hole w/brine. RIH to 500', circ 175° brine, press up on ann to 1500 psi. RIH to 1000' & circ 175° in/lO0! out. RIH to 1500', circ, press on ann started to slowly bleed. RIH to 1900', circ, pressure on ann bleeding slowly. RU Hot Oil Serv, pmp hot brine dn ann @ 1BPM, 1500 psi. POOH to 200', displ CTU & top 200' to diesel, POOH, RD CTU. RU Hot Oil truck to ann, displ 9-5/8" x 7" ann w/50 bbls hot diesel @ 2 - 2.5 BPM, 1800 psi w/final pmp'g pressure @ 2.5 BPM, 1300 psi. Secure well. Arctic Pak w/29.3 bbls PF "C" & 59 bbls Arctic Pak. Drilling Supervisor RECEIVED OCT- 2 ]986 Alaska 011 & (]as Con~. Comrnission Anchorage Date MEMORAI'"3UM Stat- of Alaska AI~AS~ OIL ~.~ GAS CONSERVATION COI-~i~'ION TO: C.V. Cha~,t~~O/ DATE: September 10, 1986 Chairman L/ F~LE NO.: D.EWS. 49 THRU: Lonnie C. Smith TELEPHONE NO.' Comanis s ioner FROM: Edgar W. Sipple, Jr. Petroleum Inspector SUBJECT: BOP Test ARCO Kuparuk 2T-10 Permit No. 86-96 Kuparuk River Field Sa~turday, September 7, 1986: I traveled this date from ARCO 2T-3, ~Ubjec~'0'~ anothe~ report, to ARCO Kuparuk 2T-10, Nordic Rig 1, to witness a BOP test. The drilling contractor was in the process of nippling up. Sunday, September 8, 1986: The BOP test commenced at 3:15 and was ~0ncluded at 3:45 p~m~ There were 3 failures. See Remark section on the report. I filled out the AOGCC BOP inspection report which is attached. In summary, I witnessed the BOP test on ARCO 2T-10, Nordic Rig 1. Attachment !02-001 A ( Rev 1 0-84) '~ ~-~" O&G #4 STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B,O.P.E. Inspection Report Inspector Operator Well Location: Sec.( Drillin~ Contractor Location, General General Housekeeping. Reserve Pit Mud Systems Ti! LI RS'efo, M ~O~t~r~ Ri8 # M~ Well Sign oA- ~ ~Rig O ~ Visual Audio Date Well Representative Permit # ~'-~- ?g '~' '~'" ,7" ~'¢ ~" Casing Set @ ft. Representative ACCU~ATOR SYSTEM Full charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig psig ~C~ O psig. 2- ~'~ ~ min~ ~ sec. Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack ~n~u~ar Preventer Pipe Rams 0 Blind Rams o Chok~~v~ Line Valves H.C.R. Valve ~ Kil~ ~ Line Valves Chec~ ~lve 0 Test Pressure "~ 0 o 0 0o0 ~OdO Full Charge~ressure Attained: / min Z~sec. N2' ~7 ~~ psig Controls: Master ~t~ ~4~ S~C'c~ Remote ~£0 BliHds switch cover~c$ Kelly and Floor Safety Valves Upper Kelly ~-~est Pressure . Lower Kell~ ~K~Test Pressure Ball Type ~ ~~Test Pressure Inside BOP..$ ~-~est Pressure ~ao 0 Choke Manifold ~.~ Test Pressure No. Valves // ~ ~ ~--~.~ No. flanges~ ~ Adjustable Chokes / ~ ~T c~ Hvdrauicall¥ operated choke I~!% ~ Test Time / ~ hrs. ~,~0 Aa ~'~ Test Results: Failures Repair or Replacement of failed equipment to be made within & days and Inspector/ Commission office notified. zstribution orig. - AO&SCC cc Operator .,, ?~ .... ARCO AlasKa. Inc. Post Office Box 100360 Anchorage. AlaSKa gg510-0360 Telephone 907 276 1215 DATE 07-Z2-86 TRANSMITTAL # 5702 RETURN TO: ARCO ~, INC. ATT~: 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. Open Hole LIS Tapes: Schl: O~e tape plus listinE for each ~2T-9 Edit LIS 06-22-86 Run #1 ~2T-10 Edit LIS 06-18-86 Run ~1 ~2T-11 Open Hole 06-05-86 Run #2 ~ 3K-1 Open Hole 06-10-86 Run #1 ~ 3K-2 Edit LIS 06-19-86 Run ~1 0067.0-2023.5 0995.0-8314.5 1441.5-6812.0 2992.5-9025.0 0994.0-9974.0 Receipt A~nowledged: State of AK Date: ARCO AIIIY. I. Inc. ~l · SUI:)I~(:}~Iry of Alllr~tlc~ltc~flelc~ComplnY STATE OF ALASKA ALAS~-,.. OIL AND GAS CONSERVATION COMI,...,SION APPLICATION FOR SUNDRY APPROVALS 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 ~Z Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P, 0. Box 100360 Anchorage~ AK 99510 4. Location of well at surface 152'FSL, 556'FWL, Sec.1, T11N, R8E, UN At top of Productive interval 1294'FNL, 1399'FWL, Sec.11, T11N, R8E, UM (approx.) At effective depth 1355' FNL, 1158'FWL, Sec.ll, TllN, R8E, UM (approx.) At lt~t~ ¢~ . , 1089'FWL, Sec.11, T11N, R8E, UN (approx.) 5. Datum elevation (DF or KB) 117'RKB 6. Unit or Property name Kuparuk River Unil; 7. Well number 2T-10 8. Permit number 86 -96 9. APl number 50_1 03 - 20064 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 8250 feet 6092 feet Casing Conductor Surface measured 81 48 feet true vertical feet 6025 Production Length Size 80' 16" 3262' 9-5/8" 8202' 7" Plugs (measured) N o n e Junk (measured) None Cemented Measured depth 225 sx CS II 110'MD 1000 sx AS III & 3296'1'4D 350 sx Class G Top job w/115 sx AS I 920 sx C1 ass G 8233 'MD ~ue Verticaldepth 110'TVD 2805'TVD 6081'TVD _. Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None feet 12.At. tachments. Well H1 Sl;Ory Description summary of proposal [] 13. Estimated date for commencing operation July, 1986 14. If proposal was verbally approved Name of approver Daf~;;al~Prov~d 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~,~ Title Associate Engineer Date "~' ~'8/-¢ Commission Use Only (DAM) SA/073 Conditions of approval Approved by Notify commission so representative may witness ,.~m Plug integrity [] BOP Test i.q Location clearance Commissioner J Approval No. ,.~.~; ~ by order of //-z:~.~ the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Rel~ort" on the first Wednesday atter a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty, parish or borough North Slope Borough ILease or Unit ADL 25569 ITitle Drill Kuparuk River IState Alaska IWell no. 2T-10 Auth. or W.O. no. AFE A~0774 Rowan 34 API 50-103-20064 OperatorI I IiARCO W.I. ARCO Alaska· Inc, Spudded or W.O. begun IDate IHour Prior status if a W.O. Spudded 6/6/86 1700 hrs. Date and depth as of 8:00 a.m. 6/06/86 thru 6/09/86 6/10/86 6/11/86 6/12/86 Complete record for each day reported 16" @ 110' 2242', (2137'), PU fsh'g assy Wt. 9.2, PV 12, YP 18, PH 10, WL 14.2· Sol 8 Accept rig @ 1200 hrs, 6/6/86. NU diverter. Spud well @ 1700 hrs, 6/6/86. Drl to 482', Pos,drill 12¼" hole to 1549', drl to 2242', POH. PU lock up assy, TIH, tight @ 1680', wrk stuck pipe. RU & rn freept. Rn APR BO shot, fire shot between 1507'-1510', POOH w/WL, circ hole cln; rec'd all HWDP. PU fsh'g assy. (TOF @ 1515'). 518', 2.2°, N59.8E, 517.99 852', 2.6°, S75.6W, 851.63 1003', 7.6°, S78.5W, 1001.94 1463', 23°, S73.6W, 1445.33 2150', 43.4°, S81W, 2019.37 56.24% TVD, - .54 VS, N 0.27, E 0.63 TVD, - 0.58 VS, N12.01, W 3.15 TVD, 12.47 VS, N 8.34, W 15.83 TVD, 129.45 VS, S22.97, W128.67 TVD, 497.78 VS, S99.17, W491.23 16" @ 110' 3086', (844'), Drlg Wt. 9.9+, PV 20, YP 27, PH 10, WL 9.6, Sol 12.2 RIH, tag fsh @ 1515', screw in & jar on fsh, POOH, RD Schl, POH. RIH to 1515', wsh & rm f/1515'-2242', drl to 3086". 2595', 47°, S80.8W, 2332.88 TVD, 809.65 VS, 149.10S, 802 97W 3004', 47.9°,S81.5W, 2609.46 TVD,1107 07 VS, 195 45S, 110~.68W 9-5/8" @ 3296' 3310' (224'), Tst BOPE , Wt. 10.2, PV 22, YP 16, PH 9.0, WL 9.8, Sol 14 Drl 12¼" hole to 3310' circ POOH. RU & rn 82 jts, 9-5/8" · · 36#, J-55 HF-ERW R-3 BTC csg w/FC @ 3214', FS @ 3296'. Cmt w/1000 sx AS III & 350 sx Cl G w/2% S-1 & .2% D-46. p~pR1 using rig pmps, bump plug. ND BOPE. Perform 115 sx AS 3ob. NU & tst BOPE. 3240', 47.8°, 880.8W, 2767.83 TVD, 1279.79 VS, 222.378, 1273.56W 9-5/8" @ 3296' 3795', (485'), Drlg Wt. 10.2+, PV 12, YP 11, PH 9.5, WL 9.2· Sol 17 TIH to FC, tst csg to 2000 psi. DO cmt & flt equip + 10' new Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole , SI well & raise mud wt to 10.3 ppg. Drl 8½" hole to , S85.3W, 3084 TVD, 1633 VS, 266S, 1630W hole. 3355' 3795'. 3719', 49.5° The, ab~p~',correct For form preparatj.e~nd'distribution, ~ see Procedures yan~al, Section 10, Drilling, Pages 8e--arid 87. IDate ,, Title Drilling Supervisor 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 ail 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 Field Alaska J County or Parish North Slope Borough ILease ADL 25569 or Unit Alaska Kuparuk River IWell no. 2T-10 Date and depth as of 8:00 a.m, 6/13/86 6/14/86 thru 6/16/86 6/17/86 6/18/86 6/19/86 Th~31~ve is correct For form preparatiq~-t'Jd-fdistribution ~.~-~.~ see Procedures M~nu_e,f Section 10, Drilling, Pages 86'a~d 87 Complete record for each day while drilling or workover in progress 9-5/8" @ 3296' 5278', (1483'), Drlg Wt. 10.5· PV 19, YP 13, PH 8.5· WL 6.2· Sol 15 Drl & surv 8½" hole to 5278'. 3875', 49.3°, S88W, 3185 TVD, 1747 VS, 272S, 1748W 4070', 49.8°, S82.7W, 3313 TVD, 1890 VS, 283S, 1895W 4382', 49.1°, S68.6W, 3515 TVD, 2126 VS, 354S, 2121W 4826', 49.6°, S67.6W, 3804 TVD, 2462 VS, 481S, 2432W 5142', 50.3°, S67.3W, 4007 TVD, 2703 VS, 574S, 2656W 9-5/8" @ 3296' 7896', (2618'), POOH Wt. 12.1, PV 25, YP 13, PH 8, WL 5.8, Sol 20 Drl & surv 8½" hole to 6765', .short trip, SS @ 4011'. Rotary drl to 7500', 10 std short trip, rm 7405'-7500', drl to 7726', TOH. Conduct formation tst to 10.6 ppg, TOH. TIH, rm undergauged hole 7597'-7726', drl 8½" hole to 7896', well flowing. Raise mud wt to 12.1 ppg, att to POOH, hole swabbing. RIH to 7896', spot 100 bbl pill on btm, POOH slow. 5452', 6042', 6691', 7094', 7425', 7650', 50.8°, S68.4W, 4204 TVD, 2942 VS, 664S, 2877W 46°, S65.3W, 4603 TVD, 3373 VS, 840S, 3274W 46.8°, S65.2W, 5051TVD, 3840 VS, 1037S, 3701W 47.7°, S64W, 5325 TVD, 4135 VS, 1164S, 3969W 48.5°, S64.1W, 5546 TVD, 4378 VS, 1272S, 4190W 48.7°, S64.4W, 5695 TVD, 4545 VS, 1345S, 4342W 7945' (49' Rm' , ), g to TD Wt. 12.1, PV 30, YP 10, PH 8.5, WL 4.2, Sol 19 " 8250'TIH' circ drl to 7945'wshout, POOH9_5/8,, @ 3296" ' . TIH, wsh & rm to TD.A~$~a 01!~~~~0 ~G , .,:, · (305'), TOH ~..L, .~. ', Wt. 12.2, PV 35, YP 15, PH 9.0, WL 4.8, Sol 19 Drl & surv 8½" hole to 8250', spot 150 bbl 13.2 ppg mud on btm, short trip, CBU. Wsh 8200'-8150', C&C hole, spot 150 bbls 13.2 ppg pill on btm, POOH to log. 9-5/8" @ 3296' 8250', (0'), LD 8½" BHA Wt. 12.1+, PV 25, YP 11, PH 8.5· WL 6.2· So1 20 RU Schl, rn DIL/GR/SP/SFL f/8256'-1000', FDC/CNL f/8256'-7650' 4000'-3301' & CAL f/8256'-3301'. Make cond'g rn, POH, LD DP. Drilling Supervisor 'ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or 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 County or Parish I State Alaska North Slope Borough I Alaska Field ILease or Unit [Well no. Kuparuk River ADL 25569 2T-10 Auth. or W.O. no. ~Title AFE AK0774 I Drill Rowan 34 API 50-103-20064 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Date 6/6/86 Complete record for each day reported Spudded or W.O. begun Spudded Date and depth as of 8:00 a,m. Old TD Released rig 6/20/86 6/21/86 I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well our J Prior status if a W.O, 1700 hrs. 7" @ 8233' 8250' TD, 8148' PBTD, Tst tbg spool Wt. 11.8+, PV 32, YP 19, PH 10.5, WL 10.2, Sol 16 RU & rn 202 jts, 7", 26#, J-55 HF ERW csg + mkr jt @ 7900', FS @ 8233', FC @ 8148'. Lost rtns @ 4800'. Pmp 77 bbl LCM pill & displ. Observe well; static. Pmp 720 sx 50/50 Pozz w/Healy ash w/8% D-20, .2% D-46 & .5% D-65, followed by 200 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Rtns after pmp'g 44 bbls cmt. Displ cmt w/12.2 ppg NaBr, bump plug. CIP @ 2245 hrs, 6/19/86. ND BOPE. Instl packoff. NU tbg spool & prep to tst. 7" @ 8233' 8250' TD, 8148' PBTD, RR 12.2 NaBr Unable to tst spool. ND & NU new tbg spool, tst to 3000 psi. RR @ 1200 hrs, 6/20/86. R CEiVEb J U L .! 0 ] ltG Alaska Oil & (~as Cons. New TD PB Depth 8250' TD 8148' PBTD 2245 hrs. Date 6/19/86 Kind of rg Rotary Type completion (single, dual, etc.) Single Classifications (oil, gas, etc.) 0±l 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 Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected ,. The ab~i,s correct see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor MEMORANPUM TH RU' Stat . of Alaska FROM: ^ " ' AS AL~_ S ¥~I OIL C. V. ~h to.,_ . DATE: June 24, Chair~:~ ~ F~LE NO.' D. EWS. 24 nonnie c. smit / TELEPHONE NO.: Co~issioner SUBJECT: BOP Test 1986 Edgar W. Sipple~' Petroleum Inspector ARCO KRU 2T-10 Permit No. 86-96 Kuparuk River Field Wednesday., June !1, 1986: I traveled this date from Conoco' s Milne Point, subject O2! anOther report, to ARCO's KRU 2T-10, Rowan Rig 34, to witness a BOP test. The drilling contractor was in the process of nippling up the casing. The BOP test commenced at 7:00 a.m. and was concluded at 10:30 a.m. There was one failure. The inside valve on the kill line was leaking. It was repaired and tested to 3000 pounds satisfactorily. I filled out an AOGCC BOP inspection report which is attached. In summary, I witnessed the BOP· test on ARCO's KRU 2T-10, Rowan Rig 34. 02 001 A ( Rev 10-84) i ' %O&G f/4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator ,~/C ~ ' Well ~7'-- /~ Location: Sec / · Drillin~ Contractor Location, General General Housekeeping . . Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors Well Sign Rig Visual Audio BOPE Stack ~n~u~r j~eventer ~)~ Blind Rams / ~/< ~o%; L~ine Valves ~ Date ~'n% Valves Valve Test Results: Failures D ET -c, -r- Representative Permit ~/ g~-- ~ ~/~ Casing Set Representative Rig ~/3(/ ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig psig 3~ ~ psig /~ OO O min ~.~O sec. ~// Full Charge Pressure Attained: ~ min.~--~sec. ! Controls: Master .-~ l~ Remote ~/~ Blinds switch cover~ { Kelly and Floor Saf Test Pressure ~0~ ~300 30~D o ~0oo --/_-- ety Valves Upper Kelly ~< Test Pressure Lower Kelly ~'~Test Pressure Ball Type ~ ~'fest Pressure Inside BOP ~/.~cTest Pressure Choke Manifold ~~Test Pressure No. Valves ,~ ~~~~ No. flanges ~ Adjustable Chokes ! ~.f Hvdrauically operated choke I--!4~]~ Test Time ~ hrs. ~0/~ /~ Repair or Replacement of failed equipment to be made within Commission office notified. ~/~days and Inspector/ May 15, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 2T-10 ARCO Alaska, Inc. Pemit No. 86-96 Sur. Loc. 152;FSL, 556'F~,~L, Sec. 1, TllN, RSE, UM. Btmhole Loc. 1391'FI,FL, I103'F~fL, Sec. 11, TllN, R8E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern~,-ental agencies prior .to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~ tru~urs, g. v. g~-tter~on Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO~iMISSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C,...,,1MISSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work Drill ,~ Redrill ~1 lb. Type of well. Exploratory [] Stratigraphic Test ~ Development Oil Re-Entry ~ Deepen[]1 Service ~ Developement Gas [] Single Zone ;~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 117', PAD 82' feet ,Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25569 ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 152'FSL, 556'FWL, Sec.1, T11N, RaE, UN Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,mber Number 1294'FNL, 1399'FWL, Sec.11, T11N, RaE, UN 2T-10 #8088-26-27 At total depth 9. Approximate spud date Amount 1391'FNL, 1103'FWL, Sec.11, T11N, RaE, UM 05/28/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD} property line 8123 'MD 1103 feet 2T-11 25'@ surface feet 2560 (6089'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure Isee 20 AAC 25.O35 lell2/I Kickoff depth 500 feet Maximum hole angle 46 0 Maximum surface I 620 psig At total depth (TVD) 3523 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ~4" 16" 62.5# ~-~,n w,~a 80' ~5' 35' !!5' !!5' _+200 cf 12:~" 9-R/R" '&C~.(~¢ .I-~5 RTC ~.~,R' R~,' RS' ~,'~7'~' ?P, rll , q~f~ ~× AF, 111 HF-EFW 350 sx Class G 8~z" 7" 26.0# J-55 BTC 8089' 34' 34' 8123' 60~)' 300 sx Class C HF-EFW 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor .~,O~,,!E!~!-~ i:- Surface "' ' ~" Intermediate ~ ~? ! '"'}! !!~' :-" . ,. Production ~ ~' :''~ *': '. " Liner Perforation depth: measured true vertical 20. Attachments Filing fee ,~ Property plat ~ BOP Sketch '~. DiverterSketch ..~ Drilling program Drilling fluid program ~ Timevs depth plot ~ Refraction analysis % Seabed report ~ 20AAC 25.050 requirements 21. I hereby Cesigned/r/~t the foregoing is true and correct to the best of my knowledge/~ ,~~' -~--~"~~Title Rag i on a 1 D r i 11 ing Eng i nee r Dat e.,,$---'//,~ ~ /__/(./ // Commission Use Only (LWK) PD/PD260 PermitNuml:::~r .~ I API numberI Approviy ? e I Seecover letter I50-- / C.-~ .2_ c c C~-/, /86, for other requirements Conditions of approval Samples required [] Yes i~LNo Mud Icg required =~ Yes ~ No Hydrogen sulfide measures C Yes © No Directional survey required ~Yes '~ No Other:Required workin~~~ure r ~12 · , 3M; [] 5M; ..~ 10M; ~ 15M by order of Approved b Commissioner the commission Date Form 10-401 Rev-7". 12-1-85 riplicate ! -< h 7 6 5 1 4 AC~ATOR CAPAC'rTY TEST 2 I. OEO< A,",,D FILL ACQ.M_LATCR ~OIR 'i'0'~ L~ ~ITH HY~LL~.C P,.UID, 2. ~ THAT ACQ. M..LATCR F'~~ IS _3,COO__ PSI 15C:O PSi ~TRF_.A~ CF' 'r,,-,E ~,_..GU_ATC:R. 3. ~VE TINE., T'~F_N CLCS?_ ALL LJN~TS ALI. UN]TS ~ Q_~ WiTH C~IN3 ~ CF'F. 4. F~Q::7:~ ~ NAD~ t::F/_PCRT, Tr-F_ ACC:ISP'TABLE L~ 13-5/8" BC:P STACX TEST FILL ~CP STAO< AN:) C~ MANIFCLD W"iTN DI~. ~ ~T ~ L~ ~ ~ IN ~~ ~Y ~RA~. ~T ~T ~ ~N BLm~ ~~ TO 0 ~!. L~ VALVES. ~ T~ PIPE ~ ~ ~ V~VE$ 6. TES~ TO 2~ PSi ~ ~ PS~ ~ ~N S~ 4. ~, ~I~ TESTI~ ALL V=VES, L]~S, ~ ~S w,~ A ~ PSi L~ *~ ~ PS] H]~. T~T AS-]N ~Y TEST ~.~P~PS ~ ~o ~ ~ ~ ~ ~. .. PSI. II. ~ ~I~ ~ ~ ~~ %ST ~. ~ ~UID. ~ ~ VALVES tN ~!~]~ P~ITI~ - I~ TEST ST~I~ VALV,., ~Y, ~ty ~S, PI~ S~ vALVE, ~ I~]~ B~ TO ~ PSI 3~ PSI. T% ! ~J ,, .. ~.,~ .~-,, ~ ..~ ,.', ',: . ' 510064001 REV. ' KUPARUK R I VER UN I T 20" D I VERTER SCHEMAT I C L_ DE SC R I PT I ON ll 16'' CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI DRILLING SPOOL H/10" OUTLETS. 7. 10" HCR BALL VALVES N/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DONNNINB DIVERSION. $o 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S . 03S (b) MAI NTENANCE & OPERAT ION I. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLON AIR THROUGH DIVERTER LINES EVERY !2 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DONNNIND DIVERSION. DO NOT SHUT IN NELL UNDER ANY CIRCUMSTANCES. RI( GENERAL DRILLING PROCEDUT KUPARb~ RIVER FIELD DEVELOPMENT WELLS 1o Move in rig. 2 Install Tankco diverter system. .3 Drill 12¼" hole toI 9-5/8" surface casing point according to directional plan. 4. Run'and~cement 9-5/8" casing. ~ .52 Install and'test blow out'preventer. Test casing to 2000 psigo 6. Drill out cement and t0' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open.hole logs. 9. Continue drilling 8½" hOle to provide 100' between plug back total depth and bottom of KuparUk sands. 10o Run and cement 7" casing.__ Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. ,,Run cased hole logs. - _ 15r Move in workover rig. Nipple up-blow out preventer. _16~ Pick up 7" casing scraper and _$ubing, trip in hole to plug back total --- depth, Circulate hole-With-~clean brine and trip out of hole standing tubing back. - , 17. Perforate and run completion assembly. 18. Nipple down blow out preventer and install Xmas tree. 19. _Change over to diesel and Sei packer. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate,. _ . _ LWK4/ih CENTRIFU&Ei 7'YPIC~L r~uD .~¥$T~r~ sCHEr~a'rl:: DRILLING FLUID PROGRAM Density PV Viscosity Initial Gel 10 Minute Gel Filtrate API pH % Solids Spud to 9-5/8" Surface Casing 9..6-9 8 15-30 20-40 50-100 5-15 o 2O 9-10 10+ Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 ¸4 -8 10-20 9.5-10.5 4--7 ~ Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid~practices will'be in accordance with the appropriate regulations stated in 20 AAC 25.033. .Maximum anticipated surface pressure is calculated using a surface casing leak-off'of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .-11 .psi/ft. This shows that formation breakdown, would occur before .a.-surface pressure of 3000 psi could be reached." Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 'Psi. After 200' of departUre, there ar'e no well bores within 200' of this proposed well. L~r~C5 / fh -'~ ARco- AL:ASKA, -- i Nc PAD 2T, WELL NO; lO PROPOSED ..... KUPARUK_~_I ELD ,.. N ORT H_SLO.P_E,_~ALASK^ - ~ - ~ ...... .-I-i~2:--~---B^SE PERt,I^FROST--TVt:)==1561---Tt'ID=1625 DEP==322 · ' : ':- -- - 1' --"'~'"39 TOP UGNU SNDS ::TVD 1701 TI'ID=IT99 DEP 425 ........ . " ' TVD~2601 .'-TMD~3084 'DEP= 1 341 m ~ ' '~' 9 5/8'' CSO PT - ' . - ~ TVD=2801 TMD=3373 DEP=1550 " _. .- : - . ........... ~ . ~ .--.. ................... . ................. ~ - . . - . -. ~ ~zS' TVD=4301 THD=5539 DEP=~I 1 ~ - _ - . . : . . .... - - - AVERAGE AN LE - ' _ . _ . . _ . : ..... j .- . . . _. : . ....... ::-~: .......... -/T/:ZON E,-C-::: TVD~SZO-T_-T~Da.7692-: DEP:~ 4666 - ~ ......... T/ ZONE~A 1VD=5846 1~D=7771 DEP~4724 " ' ~ ' :TAROET. CNTR :TVD=5871' TMD=7807 DEP=4750:-. '~', ' _:':-T ' ' .TD (LO0 PT).--TVD=6089-/MD='8123 DEP=4978:-- ~ " ........ - .. . _ : .... · ' ". O. - 000-: :::. : 2000:-~: 3000 :-. 4000~,~ ~ ~,~ - ,.~' h'~ ....... ~ ........... } :-'-- : ~ A -SECT,~,, . ~ ~,,.:~ ..... ~ - - _ ~: ..... ..... ; · '". ,.~ ' : , ~ ; ~ .~ '. ......... .............. . .......................................... _HOR ! ZONTAL PROJECII SCALE 1.', IN. ~= 1000 FEET ARCO ALASKA. INC. ~PAD 2T,.WELL NO~ I O'~PROPOSED KUPARUK FIELD, ~ NORTH ~ SLOPE. EASTHAN' ; WHIPSTOCK,"" INC~ .......... . ~ ...... '-' ~, .......... ...... ............... :2000 .., TARGET LOCATION~ 1320' FNL. 1320' FWL SEC. I1. TIIN. RBE TD LOCATION~ 1391' FNL. 1103' FWL SEC. 11. TIIN. RSE 2000 5000 4000 I 2000' ;1 000 0 , 1 ' ' 0 0 0 m, ~ .................. !_: ........... :..L ~ ~ .... SURFACE LOcAl' I ON ~ 152', FSL. , 556' FWL SEC. I. TI IN. ROE · . -T'~~-'-,'- ;' ................. ,~ . -'-'-~- .- I - ..... )0. )0 )0. 200 ' ' 300 ~4.00 500 i ~.. ' ' ~'~'! '.' t ' · ~ " .................... i . ..................... ~..~ .... ~.~-~ ................. ........ , ., ~ 2337 , ~ .... ~ : ., 1~,, : ~ , ................ ::j..,LL_'_L.:_j._~.,.~ ..... '-L~.-:..~z...~._. ~._ ~,...,;..,.'. :, " '~ .... .,"'~ ..... ' ':'-~'o:'-~''''2~:, "'~ . ' ' '~ ' t : ......... I .................... i"" '""/' ............... : ........ : , I', .~:/ ~ '" O0 .. _ 7'00. ~oo,,. I 9,00 "I~ ooo ~ ..... ~'~ .... ;'-~w,-,:-W-~ ...... :-:':-:'-~ ........ ~-:- ' .............. ~' .......... i .... · .~ . .. ~....;..L .... ; ............... ] .. : .., .. J 7oo ~f., .~1,~..1. . ........................ ~ ........... ~ ....... ~:, ~~~:-~.~-'-~: ..... : ...... ~.~::~_.: ....... ,..~ .... .:::~,..~::--~:-~. . , .~.. .... . ........ . ~.-.:.-~:. ,~... . . .... . , · .... . ..~,,~6o ~ '...:.:.:..i.i._.~.~...'....~ ...... ~..:__'.L'.._.:...~ .... : :..:..' :~.1~,: .... ._.~ --~ ~' , , ~: '~ , ' ............... i.~._~ ..... : ..... : ..... J .......... , 1U4~ . . ~ ' : ' ' : ~ ' ' I ~ ' ' ; :': : ' ' I ' ' ~ ' ' ' : I' I 829 X. ,. . < ~.., ,, I ..... ':,,, ~':' ~'" ~'' " ' .. ~,.'.~~.:'_": ~'~239'' I:": :' ~ .',' ','~ ~t ~.,,~ .,: . , ., .... ~._~_~.._, ....... : ....... ~, ~ .... ~ T: '"~ .... ?-~ '-' I ..... l,.'ii, ~_ ' X" 't , ' ~',f,,:,i ' ~"'~, <~",""r"~'"i'" 1~ ...... ': '"~'~'~"""t ~'" ' : : i : ~ ~ , i . . ~, ~ ~ '..'. .... . ...... ~; ' ' , ' · i . ~ : , ~ ', ,., . ~ ~ ~t ": I , ' ' .... '..:X,..; ?,,: ........ ~ ..... L.: .......... '_L,I :, ..... ' ....... ~.. ....... :...:...:: , .-i~ . ;: ' ': ~ I t ' I ,. ' ~ '~ ' " ' : I · ~Xi' ' * ~ i · '~ : ~t,. t ;' .~ i.~' I i ' ' ~ ,. , :, , ,, :, I , ,. , ', .... , ~ , , ~oo ~,oo, , I. iOOOi , ;~oo ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 -, _ January 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2T Pad (Wells 2- 17) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. If Sincerely, Gruber Associate Engineer JG/tw GRU13/L44 Enclosure RECEIVED Alack:.. Oil & Gas Co;:~. uo;:. ....... ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ~"~ ~ "\ LOCATED IN PROTRACTED LOCATED IN PROTRACTED SEC. I~ Ti I N~ RSE~ U.M. SEC. I ~ Ti I N~ RSE~ U.M. Z - Y = 5,970,38z.43 LAT. 70~19'49.~287'' ~0 - Y : 5,970,~32.65 LAT. Z0'19'46.67~9" X - 498,944.~3 LONG.~50~00'30.807'' X ~ ~98,945.27 LONG.150'00'30.796" ~2' FS1, 556' f~L 0G = 7~' PAD = 8Z.5 ZSZ'fSl, 556' F~L 0G = 76.0 PAD 3 - Y = 5,970,357.4~ ~T. 70~Z9'48.88~8'' ~l = 7 : 5,970,107.7~ LAT. 70~9'~6.~267'' ~ = 498,9~4.9] LONG. ~50~00"30.808'' X ~ 498,9~5. ~0 LONG. 150~00' 30.80~" 377' FSL, 556' ~L 0G = 77' PAD ~ 8~.5 ~7' FSL, 556' F~L 0G - 75.9 PAD = 81.7 4 - ~ = 5,970,33~.46 lat. 70~Zg'~.637Z" ~Z - Y = 5,970,08Z.58 1At. 70~Zg'46.Z794~ I X = 498,9~.84 LONG. ~50~00' 30.809" o ~ = 498,9~. 98 LONG. 150~00' 30.804" 35Z" fSl 556' ~L 0G = ~7' PAD = 8Z 6 ~ Z0Z' FSL, 556' f~L 0G = 75.~ PAD ' ' .~ I 5- ~ : 5,970,307.5Z ~T. 70'~9'48.39~9" ~ 13 - ~ : ~,970,057.59 ~t. 70~19'~.9336" I X ~ ~,9~4.9~ LON~'~50~00'S0'808", ~ o~ X :, 498,945.08 LONG.150'00']0.~0Z''. : " 327' FSL, 5~6' FUL 0G ~ 77 PAD = 8~.6 Z1 FSL, ~56' FUL 0~ Z5 5 PAD 6 - Y = 5 970 ~8Z.50 LAT. 70~9'~8 ~459" ~ ~4 - Y = 5 970,03~.60 LAT. 70~g'45.6879" ' = ~ ~ ~ 498,9~4.9~ LONG.~50'00'30.806" X = 498,944.95 LONG.ZS0~00 30.806" ~ o ~ 52' fSL 556' f~l 0G = 75 3 PAD = 8Z.7 302' FSL, 556' F~L 0G = 77' PAD : 8].7 ; : ~ ~ ~; , · ' ~ ~ ~5 -'Y : 5,970,007.69 LAT. 70~9'~5.44~8'' 7 - ~ = 5,970,257.54 LAt. 70~Z9 47.9O03" ~ O ~ ~ X ~98,944.93 10NG. ZS0~00'30.806'' X = ~98,944.95 LONG.{50"00'30.806" U ~ 27' FSL, 556' F~L 0G : 75.2 PAD : 8~ 6 277' FSL, 556' F~L 0G = 77' PAD : 8~.6 ~ · 8 - Y = 5,970,232.63 lat. 70~Z9'47.6553'' ~ Z6 - ~ = 5,969,98Z.85 LAt. 70~Z9'45.~985'' X = ~98,9~4.96 LONG. ~50~00' 30.806" ~ ~ ~ X = 498,94~. 88 LON~. 150~00' 30.80~" Z52' FSL, 556' F~L 0G = 76.9 PAD = 8~.6 ~ 2' FSL, 556' F~L 0G : ~5.~ PAD : 8~.7 9 - Y = 5,970.zoT.6z LAT. 70~Z9'47.~093" ~ LOCATED IN PROTRACTED x = 498,945.0Z LONG. ~50;00' 30.804'' ~ SEC.12, Tl l N~ R8E~ U.M. 227' fSl, 556' f~l 0G = 76.3 Pad = 8Z.6 Z7 - Y = 5,969,957.72 LAT. 70"zg'44.gSZ4'' NOTES ~ ~ '~'~"~' ~''' ~: ~ ~:: ':'":' :~ ~ I. ALL COORDINATES ARE A.S.R~ZONE4. ~" :~ 2. SECTION LINE DISTANCES ARE TRUE. i~r, .._: ' '- 5. horlz; PO~ITION~ BASED ON TEMR MON~ ~T- EAST, 2T- WEST & 2T - Middle PER -~'~ ~ ASSOC. 4. VERT. POSitiONS BASED ON tBM'= 2T-6 ~ N i9 +75, E I I+ 5~ PER F.r.b. ~ ASSOC. 5.C.g. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-~ 140 rev. ~, CERTIFICATE O~ SURVEYOR ' i ~E~EBY ~ERT;fY THat I ~M PROPERLY REGISTERED AND LICENSED tO ~RACTICE LAND ~ ~ SURVEYING IN THE STATE OF A~ASKA ~D THAT ~.~ Ur M~DE BY ME OR UNDER MY SUPERVISION, ~ND ~.ee' THAT AJL ~IMENSIONS ~ND OTHER DETAILS P -~ · ~ '~ SURVEYE~ FOR: ~ ARCO Alosko, lnc. ~ KUPARUK PrOJECt t~ ~ J D~TE 18 JAN 86 ~ ~ ~ M. 3fe~l D~ ~ DRILL SITE ~T CONDUCTOR ~,~'. ,o ,¢~ ~,~ ~K ~.~.~.~z~ AS- BUILT LOCATIONS ~ ¢~',~'-zZ-~ ' BSSOO, Arctic Boulevard, Suite 201, Anchorage, Alaska 29503 /isc~_E N.T.S. II-JOB NO. CHECK LIST FOR NEW WELL PERMITS ITEM AP~OVE DATE (2 'thru 8) (8)..., '.. / (9 thru 13),_ , '(10' and (3) Admin (14 thru 22) (5) BOPE (6) OTHER ,~/o (29 ~hru 31) (6) Add: me 3. 4. 5. 6. 7. 8. Company YES. Is the permit fee attached .......................................... / Is well to be located in a defined pool ............ Is well located proper distance from property ii=~ Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Lease & Well No. NO ® 10. 11. 12. 13. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 17. 18. 19. 2O 22. 23. 24 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 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 wellbore separation proposed ............................ Is a diverter system required .................................... Is the drilling fluid program, schematic and li;t of equipment'adeq~atez~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................' For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. REMARKS Geology: En giq, eering: HWKwvA3AL ~ LCSMTM~-~,., ~>~. 'BEWHJH ..... ~ rev: 04/03/86 6 ~11 POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks: / 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 VMRIFICATI'ON I,,ISTING ** REEl, NEADER SERVICE N AM {%] :EDIT DATE :86106125 9RIGIN ; CONTINUATION ~ :01 PREVIOUS REEL COMMENT'S :LiS LIBRARY TAPE ** TA, PE H~ADE[:{ ** SERVICE NAME :EDIT DATE :96/06/25 ORIGIN' :0000 TAPE NAME ;1549 CONTINUATioN ~, :01 PREVIOUS TAPE : COMMENTS :LIS LIBRARY TAP~ FILE NAME :EDIT ,O01 VERSION # OATE : ~AX1MU~ LENGTH : 1024 FILE TYPE : P~EVIO[,IS FIDE ** INFC3RMAT[ON RECORDS CN : ARCO ALASKA WN : 2T-lO FN : KUPAPUK TOWN: 1 1N SECT: 1 COUN: N, S[.,OPE STAT: ALaSKa CTRY: USA MNEM CD ,I'. EN T6 PRES: ** C{. M~I/]N IS {INIT . YPC CAT~ SIZE CODE; 000 000 018 065 000 000 0O6 065 000 000 008 065 000 000 ' 002 065 000 000 004 065 0o0 000 002 065 000 000 012 065 000 000 006 065 000 000 00~ 065 IINIT TYPE CATE SIZE CODE 000 000 001 065 "CAT ST bVP OlO,H02 VEF~],FI .... lOl'i bi', ING PAGE 2 * A~A6KA CO~PUT [~G CO~PA,.NY ~ ARCO ALASKA INC WELL = 2T'10 FIELD ; KUPARUK COUNTY = iqORT[,,I SbOPE STA ~., ; ALASKA JOB NUMOER AT ACC: 71549 5,DP: CK K,R~J~bL CASING TYPE FLUID DENSITY VISCOSITY =. 9.625" 0 3295' = WTD. NATIVE Ct, AY ~ 1~,2 LB/G -54 S = 9,0 : 6 C3 ~ATRIX SANDSTONE R~F ~ 3,06 0 65 DF -2,0! ~ 66 DF =.3,10 64DF = 1,459 0 144 DF bVP 010,~I02 V[CRiFiCATIOt:,i LISTING PAGE 3 *$*** THIS DATA ~AS N(]T BE~:~ DEP'T~ SHIFTED OVERLAYS IEhD PRINTS ***** *************************************************************~*~*~********* , * SC~{hUMBERGER bOGS INCbUOED , * DUAb INDUCTION SPHERICAhLY: FOCUSEO bOG (DIb) * D~T~ ~VAIbABbE: 8~48' TO 3300' * FOR:NATiON Dg~BITY COMPENSATED bOG (FDN) , COMP~NSA, TED M~;{]TRON LOG (FDN) * DATA ~V~IbABbE:~ * GA~IMA RAY IN CI~ING (GR,CSG TO * DATA AVAIbABGE: 3~ O' · 1000 , ** DATA FORMAT R~;CDRD *,* ENTRY BbOCKS TYP~ SIZE RCPR CODE ENTRY 2 ! 66 0 4 I 66 8 4 73 60 9 4 65 L, VP Ol(),H02 VERIFICATI,O.N LISTING PAGE 4 16 0 DATU~ SPE~CTFICATION BL, OCK~ ID ORDER ~ hOG S F L U D I L 0 H ~ ~ 00 IbD OI.b DH~ O0 SP D:I h ~V 00 G ~ D I L G A P 1 00 GR FDN GAPI O0 CALI FDN IN RHOB FO~ G/C3 O0 DRHO FDN G/C3 O0 NRAT FDN 00 RNRA PDN O0 NPHI FDN PLI O0 NCNb FON CPS O0 FC'NL FDN CPS O0 GR CSG GAPt O0 O0 0 '2 0 1 0 3!0 ~I0 280 ~50 000 890 3~0 33:0 310 DATA DEPT 83i4,5000 SFLO SP -50,2383 GR RHOB 2,3792 DRHO ~PHI 42,4805 NCNb 1, 80 4, O, 6. DEPT 8300 0000 SFLU $P -45:7383 GR. RHOB 2,3792 DRNO NPHI 41.,8457 NCNb 180 DEPI' 8200,0000 SFLU SP -]0.4482 GR RHOB 2,4358 DRHU NPH.[ 36,8164 NCNb '7 1~3 , 8. O, 6, 5 76: O, 2363, OEPT ~000. 0000 SFLU SP -'18 4727 ¢;R RHOB 2 ~ 2190 DRFIU ~P~I 29,345'1 NCNL 9O -0 2903'. DEP~' 7909,0000 SFLU SP -24,2451 GR RHOB ~,,4221 r)kHU ~PHI 33,9844 ~CNL 4 0 2311, 66 66 9143 9023 0151 6875 9143 9023 0.151 6875 APl: AP1 FiLE SIZE C[,~SS ~OD NO, O0 0 0 4 O1 0 0 4 4:6 0 0 4 44 0 0 4 Ol 0 0 4 Ol 0 0 4 Ol 0 0 4 01. 0 0 4 02 0 0 4 Ol 0 0 4 O1 0 0 4 O0 0 0 4 O0 0 0 4 31. 0 0 4 30 0 0 4 Ol 0 0 4 NRAT F C iq L 84 23 3 4:612 500 6406 SPb: REPR PROCESS CODE (OCTAb) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000~0000000 68 O0000~uO000000 68 00000000000000 68 00000000000000 68 00000080000000 68 000000 000,0000 68 '00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 000000:000:00000 68 00000000000000 IbM 2,8674 CAbI 8,50~0 RNRA ,3,60 7 GR '999,2500 IhD 2,8499 IbM 2,86t6 GR T 84,9023 CAbl 8,9316 NR~ 3,4612 RNRA 3,6077 FCNh 500,6.~06 GR -999,~500 91194 IL, D 2:;502 Ih" . 023 GR 78 023 CAbI 0361 NRAT 3,1936 RNRA 6875 FCNL 585,3125 GR ILD GR NRAT FCNL GR N R A T FCNL, 9929 4023 0132 5000 2148 1367 0210 500U 6,336'1 Ih~ 76,4023 CALl, 2,7971' RNRA 855,8125 GR 44,0805 IbM 38,1367 CALl 2,6311 RNRA 1006,3125 GR 5 3250 IbM 74:7148 CALl 3,0334 RNRA 726,8125 GR. 6570 7148 0034 5000 lbo GR N~AT FCNL ,8381 3,0020 .999 '1370 ,2500 2' 890 ,7600 -999,2500 50,5117 7,6453 '99 2500 5 1023 8i9316 3 1780 -999 2500 b ¥ P 01 (), ~{ 02 v E R I F 1 (7 a T j', 0 ~'~ L, I',, ,C I N G P A G E 5 DgPT SP D6;PT SP NPHI OEPT SP RHOB ~IpHI DEPT SP NPHI DEPT SP RHOB NPNI $P NPHI DBPT SP NPHI DEPT SP R H 0 B NPHI SP RHOB NPHi DEPT SP RNOB 7700 0000 -39 2383 2 3088 42 6270 SFLU N C M b 7600,0000 ~.FL'O -999,2500 DR['iO -999'~500 NCnb 75.00,0000 $ F b O '50,2383 GR -9:99,'2500 DRHO -999,250U N'CN[.., 7/00,00 SFLU " 3 GR .9~3,23~° 9,2500 O R ~] L3 -999,2500 NCNb 7300,0000 SFLU -66 ~227 UR -999~ 500 DRHO -q99~2500 NCNb 7200 0000 SFLU · , 72 .' 9727 G R -999~ 250(; DRNO -99q.2500 NCNb .. 00,0000 62,9883 GR 99 2500 NCNb 7.000 0000 SF[.U 58:7383 G~ -~99 2500 O~}-{O -9991250o NCNL bgo0.o00u SFLU -61 7383 GR -999:2500 DRHO -999,~500 !~CNL bS00 0000 SF!.,Li -56:q57u GR -999.2500 DR~.iG 2,'3167 IbD 104.~0273 GRT 0,0146 ~a 174]~6875 FCNL .8577 :I h D 0 5273 Gl{ 179 6875 FCNb 4,7000 153,3125 GR -999,2500 NRAT '999,'2500 FCML 2'7893 lbo 225,3125 GR -999,2500 NRAT -999.2500 FCNb 1 ,9327 104, 3,6995 RNRA 454 ,.6406 2':7327 Ib~i 100,5~73 CALl 3,6565 RNRA 448,6406 GR 3,9163 I la M -999'2500 ChbI -999,2500 RNRA .'999;2500 GR ~2 6096 -999 2500 -999 2500 -999 2500 CALl RNRA GR 4,05~4 IbD 3,6760 171 '9375 GR. -999,2500 CAL '999,2500 NR.AT '999,2500 RNRA -999,2500 FCNL "999.2500 GR I bi.) 4 6101 1.08 4048 -999 2500 -99q 2500 3.~682 71, 148 GR -999.2500 NRAT -099,2500 FCMb 4.8406 IbD 96,2')'73 GR :999,2500 NRAT 999, ~500 FCNh 4 8484 82.6523 GR -999,~500 ~RAT -999.2500 FCNL 3.6233 lbo 89.9023 GR -999,2500 NRAI -999.~500 FCNh 3,9417 IbM -999,2500 CAbI -999,2'500 RNRA -~99,2500 GR 3,5315 IbM '999,2500 CALl '999.2500 RNRA -999.2500 GR 4.6375 IbM :999,2500 CALl 990.2500 ~NRA -999.2500 Ga 4 8289 Ib~ -999:2500 CAGI -999.2500 RNRA -g9g,2500 GR 3.9280 -999.2500 CALl -999.2500 RNRA -q99,2500 GR 3,7327 -999.2500 CALl -999.2500 89i7773 GR -999 2500 N~AT 2,0608 8, I 113 3,8342 '999,'2500 2 *.8557 10,9629 4,0007 -999,2500 4,0671 999; 2500 ,.999. 2500 '999' 2500 ::7~70 2, -999,~ O0 - :500 999, -999,.2500 '99 , ~500 -999, 500 4,0554 -999,2500 -999,2500 -999,2500 3,6799 -999,2500 -999,2500 -999.2500 4,5828 -999,2'500 -999,2500 -999,2500 4,9226 '999,2500 '999,2500 -999,2500 3,9924 -999.2500 :999,2500 999,2500 :999,2500 999,2500 NPHI -999.2500 NCNL . E... it 0600,0000 SFI,U SP ','48,2383 ~R RHOB :999,~500 DRH[) NPHI , 999,~5,00 NCN~ EPr 6500,0000 SFbU SP '59,2e95 ~ RHOB ~999'2500 DRHO NPHI -999,~500 NCNL DEPT 6300 0000 SFbU SP -46 9570 GR RHOB -999 2500 DRH(3 NPHI -999 2500 NCNb DEPT b200 0000 SFLU SP '2'8,7451 GR RHOS -999,2500 DRH[3 NpH! -999,2500 NCNb DEPT ~lOOiO000 SFLU SP -27 9951 UR RH00 999 2.500 [')R HO NP~i -999.2500 NCNb DE, PT 600.0 0000 RI-lOB -999,250() NPHI -999,2500 NCNb DEP1' 5900.0000 SFLU SP i4, 9993 GR RH~B 9 9~2500 DRHO NPHI :9 9,250U NCNL DEPT 5800 0000 SFbI.} SP -519993 GR ~DB -999 25('i)0 DRHU NPH1 -999 2500 NCNb DEPT 5700.000U SP -5,g993 fir -999,2500 FCNL 2.9592 94,~023 GR ~999, NRAT -999,~500 FCNb ..,2273 IbD 108,6523 GR -999,2500 NRIT -999,2500 F'. tnb 4'0789 iLO 7~,'6523 GR '999'2500 NRAT -999,2500 FCN.L 3,18!9 'IhD .. 77,2148 GR T 999,2500 D.*RA -99'9,2500 FCNIa 2.9221 92,2773 GR '999,2500 :NRA. T '999,2500 5120 '3'9648 GR 117, '999,2500 '999,2500 FCNb 3,4651 113,0898 '999,2500 NRAT =999,~500 FCNb 2 6~'19 lbD 117' .99g,5273 GR .,2500 NRA'].' -999.2500 FCNL ¢,4163 135,56~5 GR '999.2500 '999,2500 FCN[. 1 5977 ILO 100i0273 GR -g99 ~500 NRA~ -999 2500 FCNL 1,7667 ILD 99.464~. GR -999.2500 GR 2,9846 IbM -999,2500 CALl '999'2500 RNRA '999,2500 GR 3,8206 I b" CAt, :999, .2500 .999. 2500 RNRA 999' 2500 GR 4.1023 I. hM '999,2500 CAt, I '999'~2500 RNRA -999,2500 GR 3,4709 .-999,2500 999,2500 .99~,7678 IbM -99 '2500 CALl ~:2500 RN.RA -99 2500 G'R '999, 0 CALl -999,2500 RNRA ,,999,2500 GR 3,6877 Ib~ -999 2500 CAbi -999' .999,2500 RNRA ,2500 GR 2 6C)t~ -999' .999,2500 CAb[ · ,2500 RNRA -999,2500 GR 2,4495 -999,2500 CALl -999,2500 RNRA '999,2500 GR 1,6944 i999,~500 CALI 999,2500 RNRA 999,2500 1,8458 IbM -999.2500 CALI -999.2500 . 3,I545 999,2500 ~999,2500 999,2500 3,9~0b :,99 9-2'50 o ,.999,250O 999 2500 4 4851 -999,2500 -999',2500 . 3,5510 999,25:00 -999,2}00 .,999, :2500 3. '7659 -999,2500 ,-999,2500 -999,2500 3,7463 -999,:2500 -999,2500 ,.999; 2500 3,6838 -999,2500 -999,2500 -999,2500 2 6252 -999:2500 -999 2500 -999:2500 2,4338 -999,2500 -999,2500 -999,2500 1,7237 '999,2500 '999,2500 -999,2500 1,8819 -999,2500 bVP OlO,g02 vERIFICATI["~!..i LI5T!NG PAGE 7 R HO $ -, 999.2500 D R lq 0 NPHI -999.25('}(.,) N C P,,!,k, DEPT 5.~00,0000 SFLU SP . 15,7480 ~R RHOB 999,~500 [)RHO NPHi -999,2500 NCNb OEPT 5200,0000 SFLU SP -15,7480 GR RHOB -999,2500 DRHO MPNI ~999,~500 NCNb OEPT 5100 0000 SFLU SP -15:4980 ~R RHOB -999.2500 DRHO NPH1 -999,2500 NCNb OEPT 4900.0000 SFLU SP 17 4951 RHOB -~99:~500 DRHO NPHI '999,2500 NCNb DEFT 4800 0000 S~'LU SP -14!49¢~ GR RHOB -999 ~bO0 DRHO NpHI -999,2500 NCNL DEPT 4700.0000 SFLU SP -16,~451 GR RHOB -999.2500 DHHO NPHI -9g9,250() NCNb DEPT 4600 - 999,2500 N R./% T -9'99,250(;) FCMb '999,2500 RNRA -9'99,2500 GR 1,8~4'~ ,lb!) 2,1'121 IbM 39~ Ga 99, 107 -9 2500 CALl -999~~500 NRAT -999,2500 RNRA -999,2500 FCNb -999,~500 GR 4,5671 IbD 1.86,9648 GR T "999,,2500 NRA, '999,~500 FCNb 2,4963 I50 I00;7773 GR -999,2500 NRAT -999,2500 FCML GR NRAT FCNL 2 8479 99 5898 -99'9 25:00 -999 2500 2 2991 ILO 109 4648 GR -999 2500 NRAT -999 2500 FCN5 2 3147 I L D 85i.t }98 C,R -999 2500 NRAT' -999,2500 FCNL 2,4670 IbD 80,4648 GR -999,2500 NRAT -999.2500 FCNb 2,9143 IUD 83,6523 GR '999 2500 NRA~" '999:2500 FCND 2,650~ 80.8']98 GR 2~99.2500 NRAT 99.2500 FCNL 2.8284 ILD 97,9~48 GR -999,2500 NRAT -999,2500 FCNL 2.4555 5.i218 IbM -999,2500 C~hl -999,'~500 R RA -999.~5()0 GR O0 CALl '999,2500 RNRA -999'2500 GR -999 2500 -9:99 ,25'00 -999 2500 IbM CALl RNRA. GR 2,5471 IbM '999'2500 CALl '999,2500 RNRA '999,2500 G'R 2 5002 -999 2500 GR 2500 CALl 99,2500 GR 3.2424 IbM -999 2500 CALl '999:2500 RNRA '999,2500 GR 2.8792 IbM -999 2500 CALl -999:2500 RaRA -999.2500 GR 3,1956 IbM -999 2500 CAbI -999!2500 RNRA -999~500 GR 3,0725 '999,2500 '999,2500 i 9 o .999,2500 999 ,.2500 5. 2546 999,2500 "9 99,2500 '999,2500 . 2,7092 999 ~.:2:500 -999,2500 -999,2500 3,213 ! -999~2500 2 5315 -999 2'500 -999 2500 -999 2500 2, ~866 '999,1500 soo 99,2500 -999, O0 -999,2500 '999,2500 ],1975 '999,2500 '999,2500 '999,2500 2 8049 -999,2500 -999,2500 -999,2500 3.025b :999,2500 999,2500 -999,2500 2,9807 LYP OlO,H02 VERIP',ICAT,£~I,~ L!t:,T!NG PaGE 8 SP ~13.4980 R H 0 ~ - 999..2 ...~ 00 D R H L..~ NPBi -9:99,2500 NCNb DEP~ 4500.0000 SFLU SP -15'7~0 GR RHO:8 -999,2500 DRHO NPHI -999,~500 NCNb DEPT 4200 0000 SFLU SP. ",,1.6~4951 GR RHOB '999 2500 DRHO NPHI "999' .2500 ~CN~ OEPT 4100,0000 SFLU SP ,-17,2764 GR RHOB 999,~500 DR~O ~PHI -999,2500 NCNb DEPT 4~00,000(.) 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GR CALl RNRA GR RNRA IbM CALl RNRA GR -999,2500 -999,2500 '999,2500 . 3,3049 999.~500 - 999,2 00 -999,2500 · ~ 2,9065 999'2500 '999;25O0 "999' 2500 ,,999, 0 999, 500 "999,2500 3,0920 -'999:,2§00 '999,2500 '999,2500 ~ ,1135 -999 2500 · '999 2500 -999 2500 3,3167 1~,4004 .5315 -999.2500 1~,4395 ,8301 3,1682 -999, 500 119,7148 15,5723 3,7737 '999.2500 70,2148 16.0518 2.8948 '999,2500 4.8367 12,1348 3,5959 -999.2500 bVP OlO,H02 V~PlFiCA. TION b,l.m.lNG PAgg 9 DEPT 3~00.:0000 SFDU SP 1.~.,.7559 GR RHOB ,5159 ORHO NPHI 53,9551 NCNb DEPT 2900 0000 SFLU SP -999:2500 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNb DEPT 2~00,0000 SFL. 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T -999 2500 RNRA NPHi ~999; 2500 NCNb -999,2500 FCNL -999:2500 GR DEPT II00,0000 8FLU SP '999,2500 GR RHOB -999'2500 DRHO NPHI -999,2500 NCNb -999 2500 ~999 2500 GR 999 2500 NRAT -999 ~500 FCN[, DEPT I000.0000 SFbO -999,2500 IhD SP 999,2500 G:R -999,2500 GR RHOB -999,2500 OREO -999,2500 NRAT gpMI -999,2500 NCNb -999;~500 FCNL .DEPT 995,0000 S[rLU -999.2500 ILO SP -999,2500 GR -999,2500 GR RH, OB .-999,250<) DR}{[3 ,,999 ~500 FCUl, NPHi 999,7500 NCNb -999:500 NRAT ** FILE TRAILER ** FILE NAME : E£',)I ~ ,001 SERVICE NAME 'VERSION # DATE : ~A.XiM[tM LENGTH : 1024 FILE TYPE : '~EXT KI:I.,E NA~E : ** TAPE TRAILE~ ** SEPvIcE NAME :EIDIT DATE :85106/25 ORIGIN :0000 TAPE b!~MF :1549 CONTINUATION ~ :01 ~EXT TAPE NA~E : COMMENTS II, IS [,IBRARY T~PE '999,2500 '999,2500 CAbI -9'99'2500 RNRA -999,2500 GR -999,2500 IbM -999,.2500 CALI -999,2500 RNRA ~999,2500 GR 36,2930 - 999,2500 -999~. 2500 -, 250 0 2'4,1~55 -999 2" 0 -999 -999 500 29 768 ':999,'2500 :500 -999, 500 ''999, 22,4893 -999,~00 '''999, "00 "999,~500 ~$4 · 9492 -999,:2500 ibm -999,2500 · ,999,2500 CAb][ -999,2500 -999,2500 RNRA --999,2500 .... 9893 -999,~500 (,R 31, ** REEl., TRAI!.,EP ** SERVICE NAME :EDIT DATE :86/06/25 ORIGIN : ~,VP 010,~02 VE~tF.:IC.A.TiOi¢ !~IST.[~G P&GE I2
