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190-104
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, September 20, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-16 KUPARUK RIV UNIT 3G-16 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/20/2023 3G-16 50-103-20135-00-00 190-104-0 W SPT 5764 1901040 1500 2732 2732 2732 2732 190 190 190 190 4YRTST P Adam Earl 8/1/2023 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 3G-16 Inspection Date: Tubing OA Packer Depth 1330 2010 1940 1930IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230802194711 BBL Pumped:1.4 BBL Returned:1.3 Wednesday, September 20, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg '2„' l LYN, P.I. Supervisor 1�ff FROM: Adam Earl Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 6, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3G-16 KUPARUK RIV UNIT 3G-16 Sre: Inspector Reviewed By: P.I. Supry qBZ NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-16 API Well Number 50-103-20135-00-00 Inspector Name: Adam Earl Permit Number: 190-104-0 Inspection Date: 8/3/2019 ' Insp Num: mitAGE190805111015 Rel Insp Num: Tuesday, August 6, 2019 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-16 -TypeInj �N TVD 5764-jTubing '5 80 1580 - 2580 - 2sso - PTD 1901040— Type Test i SPT Test psi 1500 IA ago 810 1740 1730 BBL Pumped: 25 BBL Returned: 2.2 OA 200 200 zoo 200 - Interval 4vRTST - -� P/F P Notes: MIT/IA Tuesday, August 6, 2019 Page 1 of 1 MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Friday,August 21,2015 P.I.Supervisor c'�7 61 jS1 I5 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-16 FROM: John Crisp KUPARUK RIV UNIT 3G-16 Petroleum Inspector Src: Inspector Reviewed By:e P.I.Supry`Jt NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-16 API Well Number 50-103-20135-00-00 Inspector Name: John Crisp Permit Number: 190-104-0 Inspection Date: 8/15/2015 Insp Num: mitJCr150821101346 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min PTD 3G-16 IType Inj [ W =TVD 5764 - Tubing 2705 - 2702 - 2701 2701 Well] 1901040 + SPT T 1500 I 1040 2000 Type Test Test psi; IA - 1920- � 1910 Interval 4YRTST PAF i P -- OA 260 370 370 370 • Notes: 2.3 bbls pumped for test. • SCANNED _ - Friday,August 21,2015 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ?~-'/~z.~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~ [] TO RE-SCAN Bren Vincent Nathan Lowell Date:5.: ~ ~ ~)_/si~ Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd STATE OF ALASKA ' ALASKADL AND GAS CONSERVATION COMMIS /0N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other F SC Repair Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r / 190 - 104 3. Address: 6. API Number: Stratigraphic r Service J P. O. Box 100360, Anchorage, Alaska 99510 " 50 103 - 20135 - 00 '' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025548 % 3G - 16 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9653 feet Plugs (measured) None true vertical 6114 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 9087 true vertical 0 feet (true vertucal) 5764 Casing Length Size MD TVD Burst Collapse CONDUCTOR (Q 80 16 115 115' 1640 630 SURFACE (QC) 4341 12 4376 3047' 3520 PRODUCTION 9669 7 9650 611 -' 4980 4330 SLEEVE 46" patch fabbed from 10" .500 wall X65 pipe RECEIVED Perforation depth: Measured depth: 9130' - 9338'"t ' FEB 0 1 2012 ANSED FEB 'iu • True Vertical Depth: 5790' - 5913' Alaska Oil & Anchorage Tubing (size, grade, MD, and TVD) 3.5 ", J -55, 9204 MD, 5832 TVD Gas Packers & SSSV (type, MD, and TVD) PACKER - CAMCO 'HRP -I -SP' PACKER @ 9087 MD and 5764 TVD LOCKED OPEN - OTIS 'FMX' - LOCKED OPEN 10/29/2004 @ 1812 MD and 1627 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service P Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND WAG GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -264 Contact MJ Loveland / Martin Walters Printed Name Martin Walters Title Well Integrity Project Supervisor Signature . Phone: 659 - 7043 Date: 01/23/12 M i t t f , 7 Lt(t ■ ., FEB O 111i12 2 • N Z Form 10 -404 Revised 1 x/2010,7 Submit Original Only • • • Conoco Phillips W �- -- - -- - Alaska RECEIVED P.O. BOX 100360 ANCHORAGE; ALASKA 99510 -0360 ; FEB 0 1 2012 January 23, 2012 Alask; 'Oil & Gas Cons. Commission Anchorage Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 3G -16, PTD 190 -104, Sundry 311 -264 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, 1 ; v 7� , Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • 3G -16 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/30/11 Cut two 18 X 20" windows in wellhead conductor and chip cement. Buffed SC and found some major pitting. Awaiting Kakivik to inspect. 01/02/12 Cut 64 "of conductor off wellhead and chip cement. Buff SC for upcoming Kakivik inspection. Bad corrision at 17 ", with good pipe starting at 35" 01/03/12 (Notified stateman (Matt Herrera) of opportunity to inspect damaged SC. 01/15/12 Set and welded in place 46" long 10" .500 wall X 65 pipe, onto existing surface casing to complete repair. 01/16/12 Pressured up OA to 1835 psi in 300 psi increments with 1.2 bbls of diesel. Start MITOA, T /I /O= 925/40/1835,15 min T /I /O= 925/40/1770, 30 min T /I /O= 925/40/1730, Re- pressure OA to 1820 psi, T /I /O= 925/40/1820, 15 min T /I /O= 925/40/1793, 30 min T /I /O= 925/40/1778, 45 min T /I /O= 925/40/1767, 60 min T /I /O= 925/40/1755.Shot IA FL @ 618' (600 fps). Repressure OA to 1802 psi. Stung into IC PO with 0 +. T /I /0= 925/40/1802, 15 min T /I /0= 925/40/1753, IC PO at 0 psi, 30 min T /I /0= 925/40/1741, IC PO at 0 psi. Bleed OA to 0 psi. Final T /I /0= si 925/40/0. 01/20/12 (Insulators installed denso wrap over SC sleeve. 01/22/12 Welded 5' 8" long 16" .375 wall 62.58 # pipe, conductor extension onto existing conductor. J . v,,,- i ill - , ..i.- -, 1 Ftr 11 42 4 .*,,,,„,t s 4 - f f i 11 i ©Co o oPhillips Alaska, Inc is/ Z.. This photo is copyright by ConocoPhillips Alaska, Inc. and cannot be relz • _: r .. A 4 +04 . ►t tie published wit q . t 4, written conse ^° • (• oPhilli • s_ A as a , ` - • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, September 07, 2011 Jim Regg r---7, P.I. Supervisor �C (�it, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G -16 FROM: Jeff Jones KUPARUK RIV UNIT 3G -16 Petroleum Inspector Src: Inspector Reviewed By:7��, P.I. Supry y 1�� NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3G - 16 API Well Number: 50 - 103 - 20135 - 00 - 00 Inspector Name: Jeff Jones Insp Num: mitJJ110906083321 Permit Number: 190 - 104 - Inspection Date: 8/30/2011 1 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3G-16 ' Type Inj. W TVD -7 5764 , IA 980 2940 • 2870 2840 ' P.T.D! 1901 TypeTest SPT Test psi ) 1500 B OA 10 20 20 20 Interval 4YRTST p/ P - Tubing 2181 2184 2184 2184 Notes: 4 BBL diesel pumped. 1 well inspected; I exception noted: surface casing X conductor leaking into drum. Wednesday, September 07, 2011 Page 1 of 1 • • S 7 1,,EFE s SEAN PARNELL, GOVERNOR LaAsEA ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. % o Q ...- tbq P.O. Box 100360 ` � ,„-----'' Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3G -16 Sundry Number: 311 -264 Dear Mr. Walters: , Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, r� 0 ' Daniel T. Seamount, Jr. Chair n cJ DATED this Z day of September, 2011. Encl. • • ConocoPhillips RECEIVED Alaska 201 P.O. BOX 100360 3 ANCHORAGE, ALASKA 99510 -0360 GM IMISSW Rl�* Oil & Gas C M. Anchersge August 13, 2011 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3G-16, PTD 190 -104 surface casing inspection and repair. Please contact MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, /44, /4„ /Aees Ma in Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures ' II STATE OF ALASKA • RECEIVED ALASKA AND GAS CONSERVATION COMMISSION AUG 3 0 2011 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Mika off & Gas Cos. Commission 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Ai am r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:SC Repair R 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 190 -104 • • 3. Address: Stratigraphic r Service 17, 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20135 -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 F% 3G -16 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025548 • 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): 9653 ' 6114 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115' 115' 1640 630 SURFACE 4341 12 4376' 3047' 3520 2020 PRODUCTION 9669 7 9650' 6112' 4980 4330 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9130' - 9338' 5790' - 5913' 3.5 J - 9204 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO 'HRP -I -SP' PACKER MD= 9087 TVD= 5764 LOCKED OPEN - OTIS 'FMX' - LOCKED OPEN 10/29/2004 MD= 1812 TVD= 1627 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service P 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/1/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ F7 . GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland / Martin Walters Printed Name Martin Walters ����/.,'L/�_ ) Title: Well Integrity Project Supervisor t: Signature „i gai bda, .C�:' Phone: 659 -7224 Date: 08/15/11 Commission Use Only V6(1 Sundry Number: 3\ I- Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r - IVc3f ;Ch fns oe�br as .Znal:cc �P Other: TT'' r D I r eel ej I k.4 do C - 4 - 4., er. a1%0 bt c.71 Zeal £ rep 4 - 1 .I 4. • Subsequent Form Required: / 1 1 61 Y APPROVED BY 9 I Approved by:/ / COMMISSIONER THE COMMISSION Date: r SEP 0 7 2 g� 10 -403 Revised 1/2010 . 7.tl� p R 1 G 1 NA! . uplicate -- • • ConocoPhillips Alaska, Inc. Kuparuk Well 3G -16 (PTD 190 -104) SUNDRY NOTICE 10 -403 APPROVAL REQUEST August 13, 2011 This application for Sundry approval for Kuparuk well 3G -16 is for the inspection and repair of a surface casing leak. Currently part of the surface casing on this well is exposed to the atmosphere and it appears there is corrosion taking place. 3G -16 has shown visual signs of a surface casing leak and was reported to AOGCC in March 2011. During diagnostics the leak was estimated to be 18 inches below surface. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with a plug(s) and/or BPV. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Remove gravel around well head and build —9' working cellar. 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top off with sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plug(s) and/or BPV and return the well to injection. 12. File 10 -404 with the AOGCC post repair. Well Integrity Project Supervisor f KUP , 3G -16 COnOCOPhiliipS O Well Attributes Max Angle & MD TO Alaska. Inc. API /UWI Field Name Well Status Inc! (•) MD (ftKB) Act Btm (ftKB) L �,,,�. a ,,, p , 501032013500 KUPARUK RIVER UNIT INJ 63.90 3,800.00 9,653.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••• Well COnfp : - 3G IB8/1620116..36:14 AM SSSV:LOCKEDOPEN Last WO: 37.01 8/21/1990 Schematic - Actual Annotation Depth (ftKB)' End Date Annotation Last Mod By End Date Last Tag: SLM 9,408.0 6/14/2011 Rev Reason: TAG ninam 6/16/2011 Casing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description (in) (in) Top (ft013) (ftKB) (ftKB) (Ibs /ft) Grade String Top Thrd CONDUCTOR (QC) 16 15.062 35.0 115.0 115.0 62.58 )i-40 WELDED 7 , Ti SURFACE (QC) 9 5/8 8.921 35.0 4,376.4 3,047.0 36.00 J -55 BUTT PRODUCTION (QC) 7 6.276 -19.4 9,650.0 6,1124 26.00 J -55 BUTT AB -MOD Tubing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String CONDUCTOR Tubing Description ( Iin) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade String Top Thrd (0C), 115 TUBING 31/2 2992 0.0 9,108.0 5,777.3 9.30 J -55 EUE M OD -- TUBING 31/2 2.992 9,108.0 9,186.0 5,821.7 9.30 L -80 EUE MOD SAFETY VLV. O TUBING 27/8 2.441 9,186.0 9,204.0 5,832.2 6.50 J -55 EUE 1.612 Other In Hole (All Jewelry: Tubinc Run & Retrievable, Fish, etc.) Top Depth (TVD) Top Incl Top (ftKB) (ftKB) (1 Description Comment Run Date ID (In) 1,812 1,627.0 43.19 SAFETY VLV Otis'FMX' - LOCKED OPEN 10/29/2004 12/31/1990 2.813 GAS LIFT, 3,094 3,094 2,398.5 58.25 GAS LIFT MERLA/TMPD /1/DMYBKI // Comment: STA 1 8/31/1991 2.875 7,396 4,785.6 55.16 GAS LIFT MERLA/TMPD /1/DMYBK/ // Comment: STA2 8/31/1991 2.875 9,020 5,725.1 54.29 GAS LIFT CAMCO/MMG- 2/1.5/DMY/RK/ // Comment STA 3 5/11/1996 2.920 9,073 5,756.0 54.46 PBR Camco 10' stroke PBR 12/31/1990 2.937 + 9,087 5,764.1 54.51 PACKER Camco'HRP -lSP' PACKER 12/31/1990 3.250 s4Frnce___. 6J ► OG), 4 376 9,099 5771.1 54.55 INJECTION CAMCO /MMG- W /1.5/DMY/RKP / / /Comment: STA4 ' 12/31/1990 9,174 5,814.8 54.51 NIPPLE AVABPLNIPPLE 5/12/1995 2.750 9,174 5,814.8 54.51 SLEEVE -C AVA; BPI SLEEVE (4) x 1/4" ports 9/25/2009 2.310 9,186 5,821.7' 54.39 PACKER TIW 'SS' PERMANENT PACKER 12/31/1990 3.532 `' °s ` if 9,196 5,827.5 54.29 NIP Camco 'D' Nipple NO GO 12/31/1990 2.250 9,203 5,831.6 54.22 SOS Camco 12/31/1990 2.441 9,204 5,832.2 54.21 TTL 12/31/1990 2.441 919, rI` r - 9,453 5,983.6 50.44 FISH 1 1/2" DV Dropped in Rathole on 5/11/96 5/11/1996 0, 20 • 9,456 5,985.5 50.37 FISH 15' of DynaStrip Left in Hole; From Perf Job 8/10/91 8/10/1991 9,456 5,985.5 50.37 FISH 9 1/2' Strip Gun Left in Hole; From Perf Job 8/11/91 8/11/1991 Perforations & Slots Shot Oat 5 900 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eft.. Type Comment 9,130 9,150 5,789.7 5,801.0 C-4, 3G-16 12/29/1990 10.0 IPERF 60 deg. phasing; 41/2" HLS 9,235 9,275 5,850.5 5,874.1 A-4, A -3, 3G-16 8/11/1991 8.0 APERF 90 deg. ph; 2 1/8" Dyna Strip PACKER, 9.087 _ -- - 9,298 9,338 5,887.8 5,912.7 A -2, 3G-16 12/29/1990 4.0 IPERF 180 deg. phasing; 4 1/2" HLS Notes: General & Safety - 4 End Date Annotation INJECTION, _ _ 8/31/2010 NOTE: View Schematic w/ Alaska Schematic9.0 9,099 ■ IPERF, Ell 9,13 0 NIPPLE, 9,174 SLEEVE -C,� 9,174 1 / PACKER,9,186 - NIP, 9,196 - -� • SOS, 9.203 Z TTL, 9.204 APERF, 9,235 IPERF. . 9,288-9,330 FISH. 9,453 4 FISH, 9,456\ 9 FISH, 9,458 PRODUCTION (OC),9,850\ _ TO, 9,659 IA Well Name 3G -16 Notes: Surface Casing Repair 10-403 Start Date 9/1/2010 Days 365 End Date 9/1/2011 Annular Communication Surveillance 4000 180 WHP LAP OAP ^ ' — 160 3500 WHT ` 3000 ,I _ pl. 1 � 1 __ILA — 140 .. 1r �. ''T11 — 120 71F "" 2500 I — 10% Q 2000 d 80 1500 \ ri f id (I VL j—A-1141 60 40 1000 500 f� —20, 0 ' 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 • as DGI aof MG! 35 - PWI p 30 hig's 25 BLPD . AIM IW V � rL 20 15 •may�� , 1 1000 1000 500 0 . f 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 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 29, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 3G -16 `0 `O 4k C� Run Date: 6/23/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3G-16 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 103 - 20135 -00 Injection Profile Log 1 Color Log 50- 103 - 20135 -00 4,i40104E0 SF_P 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: � /Z 2a l l Sign AL, • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Sunday, April 03, 2011 2:50 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: CPAI Monthly Injector Report - March 2011 Attachments: CPAI Failed MITIA Monthly Data 03- 11.xis Jim/Tom /Guy, Attached for your records is the ConocoPhillips March 2011 monthly injector report. Wells added to the report: \0 `® �( 1 B -11 - OAxOOA communication - SC leak 3B -10 - TxIA communication on MI 3G -16 - OAxAtmosphere communication - SC leak Wells removed from the report: 2A -06 - P &A Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. ; APR 1 8 21.)i, Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 4/17/2011 • • ConocoPhillips Well 3G -16 Injection Data • Tbg Psi IA Psi OA Psi I 4000 3500 " •'ssw . s ,• M4«...1 3000 «w ; •».«0' .F2 2500 �► a • a 2000 1500 Ry�.� . . •... '•' 1h. 1000 •— 500 _ 0 12/10 01/11 02/11 03/11 04/11 Date J PTD# 190 -104 OAxAtmosphere 03/13/11 - MITOA failed • ill Conoco Phillips Well 3G -16 Injection Data ♦ Water Injection O Gas Injection] 4000 - 3500 <. 4> O 0 0 ° 3000 .°_I 2500 o. • 0 a 2000 • Y ♦♦ 1500 - W ♦ _♦. ♦♦ 1000 500 0 0 1000 2000 3000 4000 5000 Injection Rate, bwpd or mscfpd . J Date of Water Gas Injected Tubing IA Pressure OA Pressure Injected Pressure Injection (bwpd) (mscfpd) (psi) (psi) (psi) 31- Mar -11 1320 0 1648 900 30- Mar -11 1019 0 1526 1200 0 29- Mar -11 1392 0 1526 1200 0 28- Mar -11 1191 0 1721 1200 0 27- Mar -11 1513 0 1741 1200 20 26- Mar -11 1025 0 1747 1200 0 25- Mar -11 889 0 1747 1200 0 24- Mar -11 750 0 1740 1100 0 23- Mar -11 703 0 1740 1000 0 22- Mar -11 612 0 1579 1000 0 21- Mar -11 10 0 1579 1000 0 20- Mar -11 1 0 1587 900 0 19- Mar -11 769 0 1408 950 0 18- Mar -11 626 0 1608 950 0 17- Mar -11 416 0 1625 1150 0 16- Mar -11 601 0 1625 1200 45 1 15- Mar -11 630 0 1633 1200 50 14- Mar -11 498 3926 2204 1200 20 13- Mar -11 0 3926 3420 1200 20 12- Mar -11 0 3884 3384 1300 20 11- Mar -11 0 3960 3479 1300 20 10- Mar -11 0 4197 3571 1450 20 9- Mar -11 0 4165 3582 1500 20 8- Mar -11 0 4197 3585 1550 50 7- Mar -11 0 4152 3582 1550 50 6- Mar -11 0 4105 3542 1550 50 5- Mar -11 0 3985 3491 1650 160 e 0 Page I of 2 Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.comj Sent: Tuesday, March 29, 2011 2:35 PM To: Maunder, Thomas E (DOA): Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 3G -16 (PTD 1901040) Report of SC Leak Tom, There are additional wells where the surface casing has failed post placement of corrosion inhibitor in the OOA. As the number of total wells with sealant increases, 1225 treated YTD and roughly 1345 total wells, there are 120 wells remaining without sealant. We have observed a noticeable drop in the frequency of SC failures since instituting the sealant program as indicated by the graph below. year 2005 2006 2007 2008 2009 2010 2011YTD # wells treated 2 77 267 296 314 206 63 Sincerel ‘1.pNI Perry Klein pt hR 3 o Well Integrity Projects f`� +Y+ * OW 907- 907 - 659 -7059-70 34 Kuparuk & WNS Sealant Project Status 2.5 - 1300 w>. ` - 1200 . u - 1100 2 ♦A, A A • V we' — 1000 — 900 0 2 1.5 s 800 >. N * — 700 N = . - 600 Fs 1 • • • •• • • • Ai • ♦ ♦ •- 500 U o - 400 Q - 300 0.5 w .. - 200 - 100 0 I 1 I 1 I 1 I 1 I 1 1 I 1 1 I I 1 1 I co tJ (A CD ti tom. t•- tom- 00 co do co O a) a) a) O O O O r 0 1 0 0 0 0 O O O O O O O O O O T r T— N— T 1 i 4 1 ,L 1 1 L 4 1 1 i Y 1 d:+ 0- = U n = U Q 0 2 = 0 03 Q = 0 (G Q 4 Q -' O Q 0 Q D Q -) Q A Failures Per Month . Sealant Wells -+- Cum Repairs Cum Failures — Expon. (Failures Per Month) From: Maunder, Thomas E (DOA) [mailto:tom.maunder ©alaska.gov] Sent: Thursday, March 24, 2011 3:13 PM To: NSK Problem Well Supv Cc: Regg, James B (DOA); NSK Well Integrity Proj 3/29/2011 • • From: Maunder, Thomas E (DOA) Sent: Tuesday, March 15, 2011 10:02 AM To: 'NSK Problem Well Supv' Cc: Regg, James B (DOA); 'NSK Well Integrity Proj' Subject: RE: 3G -16 (PTD 1901040) Report of SC Leak Russ, et al, According to the well file, inhibitor was added to the conductor annulus (OOA) in mid February of this year and the cement top was determined to be at 16 ". It looks like the corrosion was well underway (not unexpected) prior to adding the inhibitor. Are there other wells that have experienced surface casing failures similar to this after placing the inhibitor in the OOA? Thanks in advance. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Monday, March 14, 2011 1:41 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv Subject: 3G -16 (PTD 1901040) Report of SC Leak Attention Jim / Tom WAG injector 3G -16 (PTD 1901040) was diagnosed with a SC leak on 03/13/11. The TIO at the time of testing was 3416/1260/0. Diagnostics indicate the leak to be around 18" below the outer annulus valve. A subsequent MITIA passed. The well has been wagged over to water, added to the monthly report, and will be added to the excavation and repair list. It is ConocoPhillips intention to apply for Administrative Approval for water injection until the well can be repaired. Attached is a schematic, 90 day TIO plot, and MITIA form. Please let me know if you have any questions Russ Colee PWS I • - CHOKE - FTP - -- FTT IAP - OAP TIIIO Plot - 3G -16 35a0 ................................ �.... ........... .................... 1 ................ , ............... , - -... 200 , \\ J., 3000 2500 = .......... - 150 r V It ft _ c6 Di — y f O "!- d J ' 100 0 a - f ..e 1500 _ _ U 1000 — — 50 500 _ 0 -. 14- Dec -10 27- Dec -10 09- Jan -11 22- Jan -11 04- Feb -11 17- Feb -11 02- Mar -11 Date • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(6alaska.aov; doa. aogcc.prudhoe.bav(dialaska.gov; phoebe.brooks(rtalaska.00v, tom.maunder(c.talaska.gov OPERATOR: ConocoPhillips Alaska, Inc FIELD / UNIT / PAD: Kuparuk / KRU / 3G DATE: 03/13/11 OPERATOR REP: Colee/Phillips AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3G -16 Type Inj. G TVD 5,764' Tubing 3,416 3,416 3,416 3,416 Interval 0 P.T.D. 1901040 Type test P _ Test psi 1500 Casing 1,260 3,000 2,943 2,933 P/F P Notes: Diagnostic MITIA OA 0 230 220 210 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 Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. _ Type test Test psi Casing P/F 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 Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MIT KRU 3G -16 03 -13-11 (2).xls • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 14, 2011 } Commissioner Dan Seamount FEB 17 2011 Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 bib al &Gas rms. fission Anchorage, AK 99501 Amsporoge Igo Commissioner Dan Seamount: i (D Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped February 10 -12, 2011.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • S ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 2/15/2011 1B,1D,1E,1Q,1Y / 3F,3G,3J PAD A r•` = Corrosion Initial top of VO I. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date _ _ ft _ bbls ft _ pal 1B -01 50029204650000 1800400 SF N/A 19" N/A 1.4 2/11/2011 1D-119 50029228360000 1972220 2" 't1"iAe 23" N/A 4.2 2/10/2011 1E -117 50029232510000 2050260 _ 12" _ N/A 12" N/A 4.2 2/12/2011 1E-121 50029232380000 2042460 6" N/A _ 18" N/A 4.4 2/12/2011 1Q-21 50029225910000 1951330 5' N/A _ 5" N/A 5.2 2/12/2011 1Q -22 50029225950000 1951400 5" N/A 5" N/A 3.2 2/12/2011 1Y -06A 50029209580100 1971340 6" N/A 6" N/A 5.2 2/12/2011 1Y-08 50029209440000 1830620 _ 6" N/A 6" N/A 3.3 2/12/2011 3F -19A 50029226800100 2040160 8" N/A 8" N/A 3.4 1 2/11/2011 3G -16 50103201350000 1901040 16" N/A 18" N/A 3 2/11/2011 3J -17 50029227000000 1961460 SF N/A 19" N/A 3.3 2/11/2011 ~~~ ~l~f~ 0 ~ 20G9 Schlumberger -DCS 2525 Gambell Street, Suite 400 s'~litzl'3~0 Anchorage, AK 99503-2838 ATTN: Beth '': ~;~ ~~~~? ':,~ ~~ ~~. ~.~~ ~~ 3 Well Job # Log Description Date NO. 5261 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 06/03/09 2U-15 AZCM-00012 GLS 03/28/09 1 1 3G-12 B04C-00047 INJECTION PROFILE - ~- j // 05/10/09 1 1 1C-172A B04C-00049 GLS 05/11/09 1 1 3G-11 B04C-00050 PRODUCTION PROFILE 05/12/09 1 1 2A-06 B14B-00048 DDL 05/15/09 1 1 2A-16 6148-00047 LDL /`: ~~~' 05/15/09 1 1 3G-16 B14B-00049 INJECTION PROFILE . i 05/16/09 1 1 3G-18 B14B-00050 PRODUCTION PROFILE 05/17/09 1 1 2D-05 AYS4-00072 INJECTION PROFILE 05/21/09 1 1 1 E-15 6146-00058 LDL 05/24/09 1 1 3H-33 B04C-00006 CH EDIT (PEX,SONIC SCANNER,CHFR) 02/09/09 4 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. j • KRU_3G-16_TIO_pressure_update_ 2008-0111.txt „J 3G-16 (PTD 190-104)From: NSK Problem Well Supv [n1617@conocophillips.com] ~ 1`Z`( Sent: Friday, January 11, 2008 10:00 AM ~~~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 3G-16 (PTD 190-104) Attachments: 3G-16 TIO Plot.jpg Jim , ~~- Attached is an updated TIO plot for the 3G-16 intend for 3G-16 to remain a "Normal" well. Martin Walters CPAI Problem wells Supervisor ~~~~~V~ Base upon this performance, we -------------------------------------------------------------------------------- From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] sent:. Wednesday, November 28, 2007 3:16 PM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) subject: RE: 3G-16 (PTD 190-104) Thank you for the update. I would like to see the IA pressure bled (to 500-1000 psi) and monitored for build up. Any concerns? with stable temp and presumably rate, if this were thermal the IA pressure should not build back significantly. If pressure does build, you will need an admin approval to continue injecting. Jim Regg AOGCC 333 w.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~~o~~ JAS ~ ~ 200 From: NSK well Integrity Proj [mailto:N1878@conocophillips.com] sent: Monday, November 19, 2007 3:01 PM To: Regg, James B (DOA) Cc: NSK Problem well Supv Subject: RE: 3G-16 (PTD 190-104) Tim, Page 1 • • KRU_3G-16_TIO_pressure_update_ 2008-Olll.txt Here is the requested TIO plot from OlAUG07 to the present. It was wAG'd to water 27oCT07 on it's normal cycle. The IA was not bled during the wag swap. Please let me know if you would like any additional data. MJ Loveland Well Integgrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1687 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] sent: Monday, November 19, 2007 1:10 PM To: NSK Well Integrity Proj Subject: RE: 3G-16 (PTD 190-104) Please provide an updated TIO pressure plot for this well (pressures since August 1). Thank you. Jim Regg AOGCC 333 w.7th Avenue, suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK well Integrity Proj [mailto:N1878@conocophillips.com] sent: Thursday, August 30, 2007 12:58 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) CC: NSK Problem well Supv Subject: 3G-16 (PTD 190-104) Jim Page 2 C • KRU_3G-16_TIO_pressure_update_ 2008-0111.txt Per you phone message, here is the 6 month T/I/o. we don't have any reports of suspect problems or bleeds. It was wagged to MI 20APR07 It was bled after the MIT IA on 20A0007 all other pressure spikes are injection pressure or thermal related. MJ Loveland Well Integrity Project Supervisor ConocoPhiglips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 448-3114 Page 3 KRU 3 G-16 PTD 190-104 1~G ~ ~ ~~~ ~ `~~ C.~T7~ t /22 I ~J/ T/l/0 Plot - 3G-16 3000 z50o 2000 a 1500 1000 500 0 . _ ,~ __ ~, ~~ .~... .. ~~~~ _ .... ........Ef'~''. ........................ ......................f..1 ...........,.........:~:::......, :,?~................................................................. ~0 150 a. 100 0 s 50 01-Nc~v-07 01-Dec-07 Date u~-pan-uz~ 0 •i •i 3G-16 (PTD 190-104) • Regg, James B (DOA) • Page 1 of 3 From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Sunday, December 16, 2007 5:56 AM n tZI~~(;~ To: Regg, James B (DOA) ~~' Subject: RE: 3G-16 (PTD 190-104) ` Attachments: 3G-16 90 day TIO.jpg Jim, Please find the enclosed TIO plot. The operator bleed the well and it is maintaining with no signs of communication. `'~ Should the well exhibit any signs of communication we will notice and S/I per rule 7. Let me know if you have any questions. Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 ~~~~~~ .~~~ ~ ~ ~Q~~ ~ ~-i ~ ~~n_~,~ 3G-16 (PTD 19U-104j Page 1 of 3 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, November 28, 2007 3:16 PM To: 'NSK Well Integrity Proj' Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 3G-16 (PTD 190-104) '"-~,- Cf 11IZ~~C7 Thank you for the update. I would like to see the IA pressure bled (to 500-1000 psi) and monitored for build up. Any concerns? With stable temp and presumably rate, if this were thermal the IA pressure should not build back significantly. If pressure does build, you will need an admin approval to continue injecting. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 __.__a _ ,~ _~ ___ From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] ~ ~/~ ___,~~,_:., Sent: Monday, November 19, 2007 3:01 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 3G-16 (PTD 190-104) Jim, Here is the requested TIO plot from 01AUG07 to the present. • It was WAG'd to water 270CT07 on it's normal cycle. The IA was not bled during the Wag swap. Please let me know if you would like any additional data. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1687 11/28/2007 3G-16 (PTD 190-104) TIIfO Plot - 3G-16 3500 3000 2500 2000 N a 1500 1000 500 0 01-Sep-07 01-Oct-07 01-Nov-07 Date 200 150 a E as 100 y Y O r v 50 0 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, November 19, 2007 1:10 PM To: NSK Well Integrity Proj Subject: RE: 3G-16 (PTD 190-104) Please provide an updated TIO pressure plot for this well (pressures since August 1). Thank you Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Thursday, August 30, 2007 12:58 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv Subject: 3G-16 (PTD 190-104) Jim 11 /28/2007 Page 2 of 3 • • 3G-16 (PTD 190-104) Per you phone message, here is the 6 month T/I/O. We don't have any reports of suspect problems or bleeds. It was wagged to MI 20APR07 It was bled after the MIT IA on 20AUG07 all other pressure spikes are injection pressure or thermal related. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 448-3114 Page 3 of 3 • 11 /28/2007 • MEMORANDUM Toy Jim Re P.I. Supervisor ~~ ~~L~ ~ ~ I FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 22, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-16 KUPARUT{ RIV IJIvTT 3G-16 Src: Inspector NON-CONFIDENTIAL ~~o,~o~t Reviewed By: P.I. Suprv v~.`~ Comm Well Name• KUPARUK RN UNIT 3G-16 API Well Number: 50-1 03-20 1 3 5-00-00 Inspector Name: Chuck Scheve Insp Num• mitcso7os2ol72so2 Permit Number' 190-104-0 Inspection Date• s/2of2oo7 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well T 3G-16 ~'I`ype Inj, i G TVD ~ 5746 i IA 2450 i 1460 i I460 ~ 1460 1460 1460 P.T. ~ 1901040 ~TyheTeSt ~AM~ TOSt p Sl ~ 1500 I OA 330 ~ 120 ~ 120 1 120 ~ 120 j 120 Interval 4YRTST ~'~P~ P /~ Tuhing ; 3460 ~ 3460 i 3460 3460 ~ 3460 3460 NOteS' Pretest pressures observed for 30+ minutes and found stable with hi gh IA pressure. IA was bl ed off to 1460 psi and observed for 1 hour with no change noted. ~til~ c ppr~a~~ ~~L~~~,-- -~~- ~ t~~~, .~ ~°~s~~z~ ~~ ~vcv ~ ~ ~oa7 Wednesday, August 22, 2007 Page 1 of I 3G-16 (PTD 190-104) Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Thursday, August 30, 2007 12:58 PM To: Regg, James B (DOA); Maunder, Thomas 6= (DOA Cc: NSK Problem Well Supv Subject: 3G-16 (PTD 190-104) Jim Per you phone message, here is the 6 month T/I/O. We don't have any reports of suspect problems or bleeds. It was wagged to MI 20APR07 It was bled after the MIT IA on 20AUG07 all other pressure :pikes are injection pressure or thermal related. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 448-3114 t'a~e 1 of 2 • • 9/5/2007 3G-16 (PTD 190-104) Page 2 of 2 • l;(E'c}' l-v • - ;Ulu-7z-ll _. ~~~~o~zE~7 ~\CiI;SG~~\ 'fc~ (C'Sjl.l."E'_ to ~-,Q .? ~~Ch(L'~- -E-TVL'CA" WV Gl ~~a.CIC,I ~iG((,,~('-[~F/` C( rl~'IC.L~t-t~ 9/5/2007 ~ ` .Xl~~ I~' c 97c.~`~ ~~ L~.,L Jct,nc I - il-~,~~~t.s 1- ~ 3 t c! (~ ~, ~ r i. ~.t !~f-kL-c7 ~~ ~5 "` e wi~C~C',~t-ems 4~ za~~8 7 ~ ~~'t~~E_ ~~~ ~ D~ ~-~' i Q 11/10/06 Sc~luIIIbel'gel' NO. 4034 Schlumberger -DCS 2525 Gambel/ Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NCN :1 3 Z006 n, (,p,~ rJm1\\. Ç{)fnmiSSIDrl Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: {)I~¡;¡ UIO- 10o-ID¿/ Field: Kuparuk Well Job# Date BL Color CD Log Description 1 R·26 11416225 INJECTION PROFilE 10/23/06 1 1 R-22A 11416224 PROD PROFILE W/DEFT 10/22106 1 2K.28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE WIDEFT 10/24/06 1 3G..16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J·101 11445123 GLS 11/06/06 1 21='-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE WIDEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFilE WIDEFT 11/05/06 1 1R-19A 11416228 INJECTION PROFilE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28/06 1 1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N..305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GlS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 2L:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2Kr27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 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: ConocoPhillips Alaska Inc. ~./~ FIELD / UNIT / PAD: Kuparuk/KRU/3G DATE: 08/04/03 OPERATOR REP: Arend/Brake - APC AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. WelII3G-10 I Typelnj I S I T.V.D. I 5789 I Tubing I 20001 20001 20001 20001 Interval P-T.D-I1900840I ITypeTestP I Test psiI 1500 I Casing I 13501 24601 24201 24201 P/F Notes: 2 Yr MIT required by internal Waiver P.T.D. I1900730 Type Test Test psiI 1500 I Casing I 12501 2350l 23001 22801 P/F Notes: Well I3G-13 P.T.D. J1901160 Notes: Type Test TestpsiI 1500 I Casing I 11401 24001 23801 23801 P/F P.T.D. I1901210IITypeTestP I Test psiI 1500 I Casing I 12401 24501 2425] 24251 P/F Notes: A header pressure anonomile occurred right before the start of the test P.T.D. I1901040 Type Test Test psiI 1500 I Casing ] 13001 24001 24001 24001 P/F Notes: Well 13G-24 P.T.D. 11901340 Notes: Type Inj Type Test Test psiI 1500 I Casingl 12001 21001 21001 21001 P/F I P 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 MIT KRU 3G 08-04-03.xls 8/5/2OO3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner P.I. Supervisor DATE: August 4, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3G Pad KRU FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I WellI 3G-10 ITypelnj. I S I T.V.D. 15789 I Tubingl 2000 I~000 I~000 I~000 I,,ter~a,I 4I P.T.U.I 190-084 ITypetestl P ITestpsil 1447 I Casingl 1350I 2460I 2420I 2420I P/F I P [ Notes: WellI 3G-12 I Typelnj.I S J T.V.D. I 5686 I Tubing I 2350 I 2350 I 2350 I 2350 I lntervall 4 P.T.D.I 190-073 ITypetestl P ITestpsil 1422 I CasingI 1250I 2350I 2300I 2280I P/F IP Notes: WellI 3G-13 I Typelnj. I G I T.V.D. I,~ I Tubing I 3850 13850 I 3850 13850 I lntervall 4 I P.T.D.I 190-116 ITypetestl P ITestpsil 1445 I Casingl 1140I 240OI 2380I 2380 ] P/F I P I Notes: Well P.T.D. Notes: Well P,T.D. Notes: P~T.D. Notes: 190-121 ITypetestl P ITestpsil 1432 I Casingl 1240 I 24501 24251 24251 P/F I P I 3G-16 I Type,nj.I G I T.V.D. I~ I Tubing I 3100 I 3100 I 3100 I 3100 I lntervall 4 190-104 ITypetestl P ITestpsil 1441 I Casingl 1300I 2400I 2400I 2400I P/F I P 190-134ITypetestl P ITestpsil 1429 I Casingl 1200I 2100I 2100I 21ooI P/F I P Type INJ. 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 Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 36 Pad in the Kupamk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Number of Failures: O Attachments: Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. 2003-0804 MIT KRU 3G-24 cs.xls 8/15/2003 i STATE OF ALASKA I'." ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~;i operations'Performed: :Abandon [']' ' "SUsPe,d "[]] Operation shutdOWn ~ Perf0rate"~ ....... vadan(~e .... ~ 'Ann'Uiar Disp. []] '~i;~'~,~ Alter.Ga:sing · [] Repair Well F: Plug Perforations r'] Stimulate [--] . Time Extension r: · ' Other r'~ !;ii.. Change Approved Program [-] Puil Tubing' 'r-] 'Perforate New Pool El.. 'Re-enter Suspended'Well' 2. Operator Name: 4..' Cun'ent W. ell.!St.~tds:' : ~ 5. Permit to Ddll Number: · U ConocoPhillips Alaska, Inc. Development [] Exploratory 190-104 / 3. Address: Stratigraphic 'D ' Service .i['~ 6. APl Number: P. O. Box 100360 " .. 50-103-20135-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' 3G-16 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9653' feet true vertical 6114' feet Plugs (measured) Effective Depth , measured 9564 feet Junk (measured) true vertical 6056 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 4286' 9-5/8" 4376' 3047' PROD. CASING 9560' 7" 9650' 6112' Perforation depth: Measured depth: 9130 - 9338 JUN ~ 3 200.3 Tubing (size, grade, and measured depth) 2-7/8", J-55, 9204' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-I-SP'; TIW 'SS' PERM. pkr= 9087'; 9186' ~chorage SSSV= SSSV SSSV= 1812' 12. Stimulation or cement.sque'eze summary: .... ' . . · .. . Inte'rvals t~eate~l (measured) . ' N]A . " ' · . · Treatment descriptions including volumes used and final pressure: · ' : · ..... "1.3. ' ~'" ... ......... . RePresentative'Daily Ave¢age Production or..Injecti0n Data . ." · . , , ' ' ' :OiI-Bbl " Ga~:Mcf ... Wmer-Bbl Casin.q Pressure Tubing Pressu're · . . . .. . : Prior to wail'operation .. .. :. ' · 2543 '650 .. : 2067" ' · . Subsequent't0'operation .. ": . : ' '42R'9. '. ' . ...650'. .. 3744 . · · , 14. Attachments' .'" 15. Well ClasS after propoSed ·work: · · , · "copiesiof Logs and Surveys run --. '"' Exploratory E: . DevelOpment'. r~ Service ~] ' : .. · Dally Report of WelJ Opeiations ~x 16..Weil Status after'pi'oposed work: ... ' : Oil['-: Gas r-] WAG []~] GINJD WINJ F: WDSPL[] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: I Contact Jeff Spencer @ 659-7226 Printed Name ~;~~ ~ Title Producti0n Engineering Technician Signature .. ·Phone 659-7535 Date 6/19/03 JUN Form 10-404 Revised 2/2003 SUBMIT IN DUPLICATE 3G-16 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 6/17/O31.C6-~(~E~dW-K.Gi..EO,-Rlnje~fi0h - .. STATE OF N. ASKA ALASKA OIL AND GAS CONSERVATION COMM~ REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown _._ Pull tubing .,, Alter casing Stimulate Plugging Perforate ,,, Repair well , Other ;~ 2. Name of Operator ARCO Alaska. In¢, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 70' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1710' FSL, 1993' FWL, Sec. 25, T12N, R8E, UM At effective depth 1400' FSL, 2129' FWL, Sec. 25, T12N, R8E, UM At total depth 1337' FSL~ 2157' FWL~ Sec. 25~ T12NI ,R8E~ UM 12. Present well condil~on summary Total Depth: measured 9 6 5 3' feet true vertical 61 1 4' feet 5. Type of Well: Development Exploratory Stratigraphic -. Service X Plugs (measured) 6. Datum elevation (DF or KB) 9O' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-16 9. Permit number/approval number 90-1 04/91-221 , , 10. APl number 5o-103-20135 11. Field/Pool River Oil Pool Effective depth: measured 9564' feet true vertical 6056' feet Junk (measured) Casing Length Size Structural Conductor 11 5' I 6" Surface 43 76' 9 5/8" Cemented 216 Sx AS I 945 Sx AS III & Measured depth 115' 4376' True vertical depth 115' 3047' Intermediate Production Liner Perforation depth: 9650' 7" measured 9130'-9150', true vertical 5789'-5801 ', Tubing (size, grade, and measured depth) 570 Sx Class G 200 Sx Class G & 200 Sx Class G Tail 9235'-9275', 9298'-9338' 5851 '-5874', 5888'~5912' 9650' 6112' Stimulation or cement squeeze summary Converted from Producing Well to Water Injection Well Intervals treated (measured) 3 1/2" 9.3#, EUE, ABMOD, IPC, Bottom @ 9178, & 2-7/8" L-80, 6.5#, IPC, w/tail @ 9199' =ackers and SSSV (type and measured depth) SSSV:. Otis FaX Series 10 ~ 1808', Packer: TIW @ 9181', & Camco HRP-~~~}ii ~' !'~ Treatment description including volumes used and final pressure Reoresentative Daily Averaae Production or In_iection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure 14. Alask~ Oil & G~,~S ¢~OP~S~ (~Offl~t'~!!iSSi~ ;Anc, hnra~e Tubing Pressure Prior to well operation 7 3 6 4 0 0 - 0 - 1 1 0 0 163 Subse(luent to operation 0- -0- 5239 1025 2600 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run m Water Injector _~ Da!l,y Report of Well Operations _._ Oil __ Gas Suspended i7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title Service SUBMIT IN DUPLICATE STATE OF ALASKA - -~ ' AL'Aor(A OIL AND GAS CONSERVATION COMmiSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG r~ ~ ~'~ I Status of Well Classification of Service Well OIL ~] GAS r~ SUSPENDED r~ ABANDONED ~] SERVICE [---1 2 Name of Operator ' 7 Permit Number ARCO Alaska, Inc 90-104 3 Address ~ 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~'~-~., ~f,~' F .~ ~ V ,~~.~ 50-103-20135 4 Location of well at surface ~ ~;{~%T~? ~"" ~ 9 Unitor Lease Name 2538' FNL, 70' FEL, SEC 23, T12N, R8E, UM ~ /'~?,~ ;~ ~ ,;~ ~f~ i.~iii~d~7! KUPARUK RIVER Atmop Producing Interval ~ .... i~~... { ~ ~' ~ /¢.r~ ~ 10 Well Num~r 1710' FSL, 1993' FWL, SEC 25, T12N, R8E, UM~~:r~-'')' } "'~~ }' 3G-16 1337 FSL, 215~ ~L, SEC 25, T12N, RSE~ UM m,u-~,~- ~ ~Z~'~ KUPARUK RIVER FIELD 5 Elevation in f~t (indi~te KB, DF, etc.) I 6 Lea~ D~igna~on and ~Hal ~. KUPARUK RIVER OIL POOL RKB ~'I ADL 25~8 ALK ~62 12 Date Spud~ 13 Date T.D. Reach~ ;14 Date Comp., ~. or A~. I 15 Water D~, if offshore 116 ~. of Completions 8/13~90. 8/19/90. 1 ~31/~.I NA f~t MSLI 1 17 Total Dep~ (MD+~D) 18 Plug ~ck ~pth (MD+~D) 19 Dir~flo~l Su~ey !~ Dep~ where SSSV ~t 21 Thickness of permafrost 9653' MD, 6114' MVD 95~' MD, ~' ~D YES ~ NO ~I 1812' feet MD 1600' APPROX 22 Ty~ El~tric or Other Logs Run EWR/CN/SFD/DGR/CET/CBUGYRO 23 CASI~, LINER AND CEME~I~ RECORD SE~I~ DEPTH MD CASING SIZE ~. PER ~. GRADE TOP ~ HOLE SI~ CEME~ING RECORD AMOU~ PULLED 16" 62.5~ H-40 SURF 115' 24" 216 SX AS I 9-5/8" 3~ J-55 SURF 4376' 12-1/4" 945 SX AS III, 570 SX cLAss G 7" 26~ J-55 SURF 96~' 8-1/2" ~0 SX C~SS G & 2~ SX C~SS G TAIL .... 24 Pedoratiom o~n to Production (MD+~D of Top a~ ~om and 25 ~BI~ RECORD intewal, size and numar) SI~ IDE~ SET (MD) PACKER SET (MD) · 1/2" X2-7/8" TAIL 9~4' 9086', 9186' .... 913o'-91~' W/4-1/~ CSG GUN ~ 10SPF MD 5789'-~1' TVD I ~ ACID, F~CTURE, CEME~ SQUEEZE, ETC 9298'-9~8' W/4-1/2" CSG GUN ~ 4SPF MD ~'-5912' TVD DE~ I~ERVAL (MD) I AMOU~ & KIND OF MATERIAL USED SEE A~ACHED ADDENDUM 27 PROD~TION ~ST ,, Date First Production IMe~od of O~ration (Flowing. g~ li~ etc.) I Date of T~t Hours Test~ PRODUCTION FOR OIL-BBL ~AS-MCF WATER-BBL CHOKE SI~ I GAS-OIL RATIO I ~ST PERIOD ~ Flow Tubing Casing Pre.ute CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL G~VlTY-API (corr) Press. 24-HOUR RATE ~ 28 CORE DATA Brief description of lithology, ~rosi~, fractures, up.rent di~ ~d pres~ce of oil, gas or water. Submit core chips. B Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~9. 30. GEDL(~IC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, .... MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9132' 5790' NA KUPARUK C BOTTOM 9151' 5801' KUPARUK A TOP 9213' 5837' KUPARUK A BOTTOM 9421' 5963' · , :~'1. LIST OF ATTACHMENTS GYRO ~2. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~'~ ~ ~ Title ^REA DRILLING ENGINEER Date / / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent 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 ARCTIC PACK REPORT WELL: 3G-16 FIELD: Kuoaruk DATE: CSG SIZES: (Annular Dimensions)' 9 5/8" X 7" 8.921-7.0=1.~)21 TOTAL ACCUMULATED MUD VOLUME INJECTED: 15.814 9/21/90 WATER WASH VOLUME INJECTED: 300 bbls- RATE 8 SURFACE CSG DEPTH' 4376 feet CEMENT TYPE: Arctic Set 1 WEIGHT: 15.7 ppg VOLUME: 2~, bbls 17,5 ARCTIC PACK: WEIGHT: ppg VOLUME: ~ bbls DEPTH OF ARCTIC PACK/CEMENT INTERFACE: PUMP RATE: 6 pbm PUMP PRESSURE INITIAL: 560 psi FINAL: 6~0 psi CIP TIME: 1,.32,~ PRESSURE TEST: ~)/21/90 SX bbls DATE: 9/24/90 PRESSURE RESULTS' 100 .Dsi in on hr 1800 FEET BPM; 2000 psi Pmo 25 aal diesel to 1000 Dsi ~ 9:15 bled off -- REMARKS: Good test. Bled back 15 bbls of diesel SIGNATURE: ARCO Ok, .,,d Gas Company Well History - Initial Report- Daily Insimctiofle: Prepare and submit the '~l!~.J~' on the first Daily work prior tO s~d~d~.~-summaHzed District .: : ARCO A~S~ INC. ~.'~" Field KUpARUK RIVER UNIT Auth. or W.O. no. AK4991 Wednesday after a well is spudded or workover operstlone are started. on the form giving inclusive dates only. I County. parish or borough NORTH SLOPE Lease or Unit ADL:25548 ALK:2662 Title~ COMPLETION IState AK I Well no. 3G-~6 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m, 12/30/90 (9) TD: 0 PB: 9564 SUPV:DB/SK 12/31/90 (10) TD: 0 PB: 9564 SUPV:DB/SK IDate IHour 08/13/90 Complete record for each'day reported NORDIC I ARCO w.i. 55.2520721 IPr or status if a W.O, 21:00 RIH W/PKR MW: 0.0 NaC1/Br MOVE F/3G-17 TO 3G-16, ACCEPT RIG @ 12/29/90 10:00, ND MASTER VALVE & TBG HGR ADAPTER & NU HOPE, SET TEST PLUG, TEST HOPE, RU HLS, PERF "A" SANDS F/9298'- 9338' W/4 SPF 180 DEG & "C" SANDS F/9130'-9150' W/5 SPF 60 DEG, RIH W/ 6.07" GR & JB TO 9400', POH RECOVER SMALL PERF DEBRIS, MU PKR ASSY W/TAILPIPE ASSY & RIH DAILY:S37,713 CUM:$942,474 ETD:S942',474 EFC:$1,450,000 MU & TEST WELLHEAD MW:10.6 NaC1/Br RIH W/PKR & TAILPIPE ASSY & SET PKR @ 9181' WLM, RD HLS, NU FLOW NIPPLE, RUN 3-1/2" COMP ASSY, WELL FLOWING AFTER JEWELRY & 2 JTS RUN, SHUT WELL IN & BULL HEAD 3 BBL @ 1700 PSI, BLEED TO 400 PSI, BLEED OFF, RIH 5 JTS WELL FLOWING, CIRC ONE CIRC W/ll# BRINE, RIH 54 JTS & GLM#1, TOTAL 100 JTS MIX 115 BBLS 11.0# BRINE & CIRC AROUND @ 3191', WELL FLOW STOPPED, CONT TO RIH W/3-1/2" CONNECT & TEST SSSV CL, RIH TBG & LOCATE IN ON PKR, SPACE OUT & LAND, RILDS, PRESS TO 2500 PSI & SET PKR, PRESS ANNULUS TO 1000 PSI & HOLD FOR 10 MIN, PKR OK, BOLDS, PU & SHEAR PER @ 88K, RELAND TBG, RILDS, TEST TBG & SSSV OK, PULL LANDING JT, SET BPV, ND STACK NU 3~1/8,' WKM GEN IV 5KPSI TREE, PULL BPV, SET TP, TEST TREE & ~000PSI, OPEN SSSV & TEST CL TO 5000PSI, PULL TEST i:~.~;~i:.!~512- CUM:$1,009,986 ETD:S1,009,986 EFC:$1,450,000 The above is correct For o p elL/~lon~and dlstribuilon ~ ~ ~',"JhTe~'J'c''o" '0 ~ Date AR3B-459-1-D JNumber all dally well history forms consecutively as they are prepared for each well. Page no. ARCO (,.. and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the '~:~:~011' the first Wednesday after allowable has been assigned or well s Pugged, Abandoned, or So d "Fiaal Report" should be submitted ~~l'att~lle are suspended for an indefinite or appreciable length of t me On workovers when an offc a test is not required upon completion, report col~l~d:~rapre~entative test data in blocks provided. The "Final Report" form may be used for report ng the entire operation if space is available. ~!,~ ~!~' I Accounting cost center code District ICounty or Parish State ARCO ALASKA INC. I NORTH SLOPE AK Field ILease or Unit /Well no. KUPARUK RIVER UNIT I ADL:25548 ALK:2662 3~-16 Title COMPLETION Auth, or W.O. no. AK4991 OperatorARCO IA.R.Co. W.I. Spudded or W.O. begun ~Date SPUD I 08/13/90 Date and depth as of 8:00 a.m. 01/01/91 (11) TD: 0 PB: 9564 SUPV:DB/SK Iotal number of wells (active or inactive) on this. ost center prior to plugging and 55~. 252072 bandonment of this well our !Prior status if a W.O, '21: O0 Complete record for each day reported NORDIC 1 RELEASE RIG MW: 0.0 Diesel RU CIRC LINES, PRESS ANNULUS & TBG TO 2500 PSI F/15 MIN-OK, PRESS TBG & SHEAR OUT BALL @ 3300 PSI, REV CIRC 12 BBL DIESEL CAP INTO ANNULUS, 4 BBL DIESEL CAP INTO TBG, FORMATION BREAKDOWN @ 1700 PSI, CHECK VALVE IN GLM @ 9020' HELD, SITP=1200 PSI, SITP @ 10 MIN=400 PSI & FALLING, 3X7 PA=0 PSI, 7X9 PA=450 PSI, SECURE WELL & RELEASE RIG @ 12/31/90 07:30 DAILY:S208,634 CUM:$1,218,620 ETD:S1,218,620 EFC:$1,450,000 Old TD I New TD I Released rig I Date I Classifications (oil, gas, etc.) Producing method Potential test data IPB Depth Kind of rig Type completion (single, dual, etc.) Official reservoir name(s) Well no. Date !Reservoir Producing Interval Oil or gasTest time Production Oil on test I Gas per day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity AHowable Effective date corrected orrect ~'~C~...-~.[~,. -~1 ,~ < ~:~ ~. (~[? ( Drilling Supt. For form pro ap~rration~;~'~istri"butionC '~ ' ' see Procedures Manu~l, Section 10, ~ Drilling, Page~ 87. AR3B-459-3-C Number all daily well history forms I no as they are prepared for each well. consecutively I Page Dlvllion of AtlantlcRlchfteldComp~lny GREAT LAND Client · · · · · · Field ..... : Well ...... : Section at: Surveyor..: DIRECTIONAL DRILLING, ARCO ALASKA, INC. Kuparuk River Unit KRU 3G-16 (23-12-8) S,17.33,E MIKE NAIRN INCo HICROFILMED Computation...: Survey Date...: RKB Elevation.: Job Number .... : API Number .... : 10/12/90 RADIUS OF CURVATURE 09/24/90 90.00 ft AK0990G245 50-103-20135 SURVEY S MEAS INCLN C DEPTH ANGLE 7 100 0.25 7 200 0.20 7 300 1.07 7 400 5.83 7 500 11.23 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 100.0 10.0 -0.1 N 59.93 E 0.2 N 0.1 E 0.2 N 29.96 E 0.25 200.0 110.0 -0.1 S 87.42 E 0.3 N 0.5 E 0.6 N 60.43 E 0.05 300.0 210.0 0.7 S 34.09 E 0.2 S 1.4 E 1.4 S 79.98 E 0.87 399.8 309.8 6.6 S 21.28 E 5.6 S 4.2 E 7.0 S 37.05 E 4.76 498.6 408.6 21.4 S 18.09 E 19.5 S 9.2 E 21.6 S 25.22 E 5.40 7 600 12.89 596.4 506.4 42.3 S 16.99 E 39.4 S 15.5 E 42.4 S 21.44 E 1.66 7 700 14.23 693.6 603.6 65.7 S 14.08 E 62.0 S 21.8 E 65.7 S 19.34 E 1.35 7 800 15.99 790.2 700.2 91.7 S 15.61 E 87.2 S 28.4 E 91.8 S 18.06 E 1.76 7 850 17.78 838.0 748.0 106.3 S 15.60 E 101.2 S 32.4 E 106.3 S 17.73 E 3.58 7 900 21.29 885.1 795.1 123.0 S 14.98 E 117.3 S 36.8 E 123.0 S 17.40 E 7.02 7 1000 27.08 976.3 886.3 163.9 S 14.15 E 157.0 S 47.1 E 163.9 S 16.69 E 5.79 7 1100 32.82 1062.9 972.9 213.6 S 11.89 E 205.6 S 58.3 E 213.7 S 15.83 E 5.78 7 1200 34.26 1146.3 1056.3 268.5 S 10.11 E 259.8 S 68.8 E 268.8 S 14.84 E 1.55 7 1300 35.23 1228.4 1138.4 325.1 S 10.76 E 315.9 S 79.2 E 325.6 S 14.07 E 0.99 7 1400 37.59 1308.9 1218.9 384.2 S 12.45 E 374.0 S 91.1 E 384.9 S 13.69 E 2.44 7 1500 38.33 1387.8 1297.8 445.4 S 11.68 E 434.2 S 104.0 E 446.4 S 13.47 E 0.80 7 1600 39.09 1465.8 1375.8 507.7 S 12.03 E 495.4 S 116.8 E 509.0 S 13.27 E 0.77 7 1700 39.65 1543.1 1453.1 570.8 S 11.02 E 557.5 S 129.5 E 572.4 S 13.08 E 0.69 7 1800 42.95 1618.2 1528.2 636.5 S 13.22 E 622.0 S 143.3 E 638.3 S 12.98 E 3.45 7 1900 44.96 1690.2 1600.2 705.6 S 11.73 E 689.8 S 158.3 E 707.7 S 12.93 E 2.14 7 2000 49.81 1757.9 1667.9 779.1 S 16.18 E 761.2 S 176.1 E 781.3 S 13.02 E 5.50 ASurvey Codes: 7/GYRO (KRU3G16G) KRU 3G-16 (23-12-8) Page 2 10/12/90 S MEAS INCLN C DEPTH ANGLE 7 2100 50.50 7 2200 52.66 7 2300 51.29 7 2400 51.43 7 2500 56.34 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION BEARING 1822.0 1732.0 855.8 S 16.57 E 1884.1 1794.1 934.2 S 15.94 E 1945.7 1855.7 1012.9 S 15.17 E 2008.1 1918.1 1091.0 S 15.77 E 2067.1 1977.1 1171.7 S 18.63 E 7 2600 57.15 2121.9 2031.9 7 2700 56.91 2176.3 2086.3 7 2800 56.12 2231.5- 2141.5 7 2900 54.75 2288.2 2198.2 7 3000 54.26 2346.3 2256.3 7 3100 58.50 2401.6 2311.6 7 3200 57.90 2454.3 2364.3 7 3300 56.29 2508.7 2418.7 7 3400 55.94 2564.4 2474.4 7 3500 60.23 2617.3 2527.3 1255.3 1339.2 1422.6 1504.9 1586.3 1669.5 1754.5 1838.5 1921.5 2006.4 2094.7 2184.4 2274.1 2363.9 2452.4 7 3600 63.87 2664.1 2574.1 7 3700 63.73 2708.3 2618.3 7 3800 63.90 2752.4 2662.4 7 3900 63.84 2796.4 2706.4 7 4000 60.73 2842.9 2752.9 RELATIVE-COORDINATES FROM-WELL-HEAD 834.8 S 197.7 E 910.1 S 219.6 E 985.9 S 240.8 E 1061.2 S 261.6 E 1138.4 S 285.5 E S 17.81 E 1217.8 S 311.6 E S 16.69 E 1297.9 S 336.5 E S 15.97 E 1377.9 S 360.0 E S 15.77 E 1457.2 S 382.5 E S 15.20 E 1535.6 S 404.2 E S 19.11 E 1615.1 S 428.8 E S 16.99 E 1695.9 S 455.1 E S 17.47 E 1776.1 S 480.0 E S 16.61 E 1855.5 S 504.3 E S 18.44 E 1936.4 S 529.8 E 17.52 E 2020.4 S 557.1 E 17.18 E 2106.1 S 583.9 E 16.83 E 2191.9 S 610.1 E 16.50 E 2277.9 S 635.9 E 15.87 E 2362.9 S 660.5 E 7 4100 57.51 2894.3 2804.3 2538.2 S 16.18 E 7 4200 56.09 2949.0 2859.0 2621.9 S 18.10 E 7 4300 56.41 3004.6 2914.6 2705.0 S 17.91 E 7 4400 56.26 3060.0 2970.0 2788.2 S 18.12 E 7 4500 55.54 3116.1 3026.1 2871.0 S 17.95 E 7 4600 54.67 3173.3 3083.3 2953.0 2445.4 S 684.2 E 2525.3 S 708.9 E 2604.4 S 734.6 E 2683.6 S 760.3 E 2762.3 S 785.9 E S 16.71 E 2840.6 S 810.4 E CLOSURE DL DISTNCE BEARING /100 857.9 S 13.32 E 0.73 936.2 S 13.57 E 2.20 1014.9 S 13.72 E 1.45 1093.0 S 13.85 E 0.39 1173.6 S 14.08 E 5.29 1257.0 S 14.35 E 1.00 1340.8 S 14.53 E 0.82 1424.2 S 14.64 E 0.93 1506.5 S 14.71 E 1.38 1587.9 S 14.75 E 0.62 1671.1 S 14.87 E 5.10 1755.9 S 15.02 E 1.64 1839.8 S 15.12 E 1.64 1922.8 S 15.20 E 0.69 2007.6 S 15.30 E 4.51 2095.8 S 15.42 E 3.71 2185.5 S 15.49 E 0.31 2275.2 S 15.55 E 0.33 2365.0 S 15.60 E 0.27 2453.5 S 15.62 E 3.15 2539.3 S 15.63 E 3.23 2622.9 S 15.68 E 1.94 2706.0 S 15.75 E 0.35 2789.2 S 15.82 E 0.21 2871.9 S 15.88 E 0.73 2953.9 S 15.92 E 1.20 'Survey Codes: 7/GYRO KRU 3G-16 (23-12-8) S MEAS INCLN C DEPTH ANGLE 7 4700 53.29 7 4800 53.58 7 4900 55.50 7 5000 55.77 7 5100 56.17 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 3232.1 3142.1 3033.9 3291.7 3201.7 3114.2 3349.7 3259.7 3195.6 3406.1 3316.1 3278.1 3462.1 3372.1 3360.8 7 5200 56.28 3517.7 3427.7 7 5300 56.55 3573.0 3483.0 7 5400 56.44 3628.2 3538.2 7 5500 56.61 3683.3 3593.3 7 5600 56.45 3738.5 3648.5 7 5700 56.50 3793.7 3703.7 7 5800 56.62 3848.8 3758.8 7 5900 54.46 3905.4 3815.4 7 6000 53.87 3964.0 3874.0 7 6100 53.70 4023.0 3933.0 7 6200 53.70 4082.2 3992.2 7 6300 53.71 4141.4 4051.4 7 6400 53.34 4200.9 4110.9 7 6500 53.42 4260.5 4170.5 7 6600 53.54 4320.0 4230.0 7 6700 53.73 4379.3 4289.3 7 6800 53.92 4438.4 4348.4 7 6900 54.09 4497.1 4407.1 7 7000 54.25 4555.7 4465.7 7 7100 54.14 4614.2 4524.2 RECORD OF SURVEY 7 7200 54.48 4672.5 4582.5 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD 16.49 E 2918.1 S 833.5 E 15.72 E 2995.3 S 855.8 E 14.52 E 3073.9 S 877.0 E 14.78 E 3153.8 S 897.9 E 14.76 E 3233.9 S 919.0 E 3443.9 S 14.64 E 3314.3 S 940.1 E 3527.1 S 14.66 E 3394.9 S 961.2 E 3610.4 S 14.64 E 3475.6 S 982.3 E 3693.7 S 14.57 E 3556.3 S 1003.3 E 3777.0 S 14.64 E 3637.0 S 1024.3 E 3860.3 S 14.94 E 3717.6 S 1045.6 E 3943.7 S 15.11 E 3798.2 S 1067.2 E 4026.1 S 15.31 E 3877.8 S 1088.9 E 4107.1 S 16.60 E 3955.7 S 1111.2 E 4187.8 S 16.69 E 4033.0 S 1134.3 E 4268.4 4349.0 4429.4 4509.5 4589.8 4670.2 4750.7 4831.5 4912.5 4993.4 S 16.86 E 4110.2 S 1157.5 E S 17.16 E 4187.2 S 1181.1 E S 20.23 E 4263.4 S 1206.9 E S 20.59 E 4338.6 S 1234.9 E S 20.27 E 4413.9 S 1262.9 E S 20.75 E S 20.64 E S 20.54 E S 20.61 E S 20.79 E 4489.4 S 1291.1 E 4564.9 S 1319.7 E 4640.6 S 1348.1 E 4716.5 S 1376.6 E 4792.4 S 1405.3 E 5074.5 S 20.85 E 4868.3 S 1434.1 E Page 3 10/12/90 CLOSURE DL DISTNCE BEARING /100 3034.8 S 15.94 E 1.39 3115.1 S 15.94 E 0.58 3196.6 S 15.92 E 2.09 3279.1 S 15.89 E 0.32 3361.9 S 15.86 E 0.40 3445.1 S 15.84 E 0.14 3528.3 S 15.81E 0.27 3611.7 S 15.78 E 0.11 3695.1 S 15.75 E 0.18 3778.5 S 15.73 E 0.17 3861.9 S 15.71E 0.21 3945.3 S 15.69 E 0.17 4027.7 S 15.68 E 2.16 4108.8 S 15.69 E 1.03 4189.5 S 15.71 E 0.18 4270.1 S 15.73 E 0.11 4350.6 S 15.75 E 0.20 4430.9 S 15.81E 2.01 4510.9 S 15.89 E 0.25 4591.1 S 15.97 E 0.24 4671.3 S 16.05 E 0.37 4751.8 S 16.12 E 0.20 4832.5 S 16.20 E 0.18 4913.3 S 16.27 E 0.17 4994.2 S 16.34 E 0.16 5075.1 S 16.41E 0.34 Survey Codes: 7/GYRO KRU 3G-16 (23-12-8) RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 7300 54.76 7 7400 55.17 7 7500 55.40 7 7600 55.06 7 7700 53.90 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 4730.4 4640.4 5155.9 S 20.84 E 4944.5 S 1463.2 E 4787.8 4697.8 5237.6 S 21.04 E 5021.0 S 1492.4 E 4844.8 4754.8 5319.6 S 21.07 E 5097.7 S 1522.0 E 4901.8 4811.8 5401.6 S 21.30 E 5174.3 S 1551.6 E 4959.9 4869.9 5482.7 S 22.08 E 5249.9 S 1581.7 E 7 7800 54.31 7 7900 54.82 7 800O 55.O4 7 8100 54.94 7 8200 55.31 5018.5 4928.5 5563.4 S 22.22 E 5324.9 S 1612.3 E 5076.5 4986.5 5644.6 S 22.48 E 5400.3 S 1643.2 E 5134.0' 5044.0 5726.1 S 22.79 E 5475.8 S 1674.7 E 5191.3 5101.3 5807.6 S 22.90 E 5551.3 S 1706.5 E 5248.5 5158.5 5889.3 S 22.63 E 5626.9 S 1738.3 E 7 8300 54.22 7 8400 54.16 7 8500 54.34 7 8600 54.56 7 8700 54.86 5306.2 5216.2 5970.6 S 23.70 E 5702.0 S 1770.4 E 5364.7 5274.7 6051.0 S 25.08 E 5775.9 S 1803.9 E 5423.1 5333.1 6131.4 S 25.63 E 5849.2 S 1838.7 E 5481.3 5391.3 6211.9 S 25.93 E 5922.5 S 1874.0 E 5539.1 5449.1 6292.6 S 25.77 E 5996.0 S 1909.6 E 7 8800 54.77 7 8900 54.14 7 9000 54.22 7 9100 54.55 7 9200 54.25 5596.7 5506.7 6373.4 S 25.97 E 6069.5 S 1945.3 E 5654.8 5564.8 6453.9 S 25.45 E 6142.8 S 1980.6 E 5713.3 5623.3 6534.1 S 26.18 E 6215.8 S 2015.9 E 5771.6 5681.6 6614.4 S 26.16 E 6288.8 S 2051.8 E 5829.8 5739.8 6694.9 S 25.23 E 6362.0 S 2087.0 E 7 9300 53.26 7 9400 51.64 7 9500 49.38 7 9525 48.74 X 9653 48.74 5888.9 5798.9 6774.8 S 25.09 E 6435.0 S 2121.3 E 5949.8 5859.8 6853.4 S 24.49 E 6507.0 S 2154.5 E 6013.4 5923.4 6930.1 S 22.32 E 6577.8 S 2185.2 E 6029.8 5939.8 6949.0 S 21.35 E 6595.3 S 2192.2 E 6114.2 6024.2 7044.9 S 21.35 E 6685.0 S 2227.2 E 'Survey Codes: 7/GYRO X/EXTRAPOLATED Page 4 10/12/90 CLOSURE DL DISTNCE BEARING /100 5156.4 S 16.48 E 0.28 5238.1 S 16.55 E 0.43 5320.0 S 16.62 E 0.23 5401.9 S 16.69 E 0.37 5483.0 S 16.77 E 1.27 5563.6 S 16.85 E 0.42 5644.8 S 16.92 E 0.54 5726.2 S 17.01 E 0.30 5807.7 S 17.09 E 0.12 5889.3 S 17.17 E 0.41 5970.6 S 17.25 E 1.30 6051.0 8 17.34 E 0.91 6131.4 S 17.45 E 0.41 6211.9 S 17.56 E 0.30 6292.7 S 17.67 E 0.32 6373.6 S 17.77 E 0.16 6454.2 S 17.87 E 0.72 6534.5 8 17.97 E 0.49 6615.0 S 18.07 E 0.33 6695.6 S 18.16 E 0.68 6775.7 S 18.24 E 0.99 6854.4 S 18.32 E 1.66 6931.3 S 18.38 E 2.58 6950.1 S 18.39 E 3.37 7046.2 S 18.43 E 0.00 KRU 3G-16 (23-12-8) Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 5 10/12/90 SUBSEA DEPTH 0 100 200 300 400 5OO 600 70O 8OO 9OO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING 90 0.23 90 0 0 N 59.93 E 190 0.20 190 0 0 N 54.69 W 290 0.98 290 0 0 g 39.42 E 390 5.36 390 0 0 S 22.54 E 491 10.75 490 1 1 S 18.37 E 593 12.78 590 3 2 S 17.06 E 696 14.18 690 6 3 S 14.19 E 800 15.99 ~90 10 4 8 15.61 E 905 21.59 890 15 5 S 14.94 E 1015 27.97 990 25 10 S 13.80 E 1132 33.29 1090 42 17 S 11.32 E 1253 34.77 1190 63 21 S 10.45 E 1376 37.03 1290 86 23 S 12.05 E 1503 38.35 1390 113 27 S 11.69 E 1631 39.26 1490 141 28 S 11.71 E 1762 41.69 1590 172 31 S 12.38 E 1900 44.95 1690 210 38 S 11.73 E 2050 50.15 1790 260 50 S 16.37 E 2210 52.53 1890 320 60 S 15.87 E 2371 51.39 1990 381 61 S 15.60 E 2542 56.68 2090 452 71 S 18.29 E 2725 56.71 2190 535 83 S 16.51 E 2903 54.73 2290 613 78 S 15.75 E 3078 57.57 2390 688 75 S 18.25 E 3266 56.84 2490 776 88 S 17.31 E RELATIVE COORDINATES FROM WELL HEAD 0.15 N 0.08 E 0.48 N 0.12 E 0.13 S 1.29 E 4.69 S 3.81 E 17.93 S 8.66 E 38.05 S 15.06 E 61.14 S 21.55 E 87.18 S 28.44 E 119.19 S 37.26 E 163.89 S 48.78 E 222.85 S 61.85 E 289.41 S 74.21 E 359.92 S 88.05 E 435.89 S 104.32 E 514.67 S 120.87 E 596.98 S 137.66 E 689.60 S 158.29 E 797.89 S 186.79 E 917.48 S 221.76 E 1039.34 S 255.46 E 1171.24 S 296.46 E 1317.95 S 342.48 E 1459.57 S 383.16 E 1597.48 S 422.80 E 1749.17 S 471.52 E 2500 3447 57.95 2590 857 81 S 17.47 E 1893.10 S 515.81 E KRU 3G-16 ( 23-12-8 ) Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 6 10/12/90 SUBSEA DEPTH 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 420O 4300 4400 4500 4600 4700 480O 4900 5O0O MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING 3659 63.79 2690 969 112 S 17.32 E 3885 63.85 2790 1095 127 S 16.55 E 4092 57.77 2890 1202 107 S 16.16 E 4274 56.33 2990 1284 82 S 17.96 E 4454 55.87 3090 1364 80 S 18.03 E 4629 54.27 3190 1439 75 S 16.65 E 4797 53.57 3290 1507 68 S 15.74 E 4971 55.69 33.90 1581 74 S 14.71 E 5150 56.23 3490 1660 79 8 14.70 E 5331 56.52 3590 1741 81 S 14.65 E 5512 56.59 3690 1822 81 S 14.58 E 5693 56.50 3790 1903 81 S 14.92 E 5873 55.04 3890 1983 80 S 15.26 E 6044 53.79 3990 2054 71 S 16.64 E 6213 53.70 4090 2123 69 S 16.90 E 6382 53.41 4190 2192 69 S 19.67 E 6549 53.48 4290 2259 68 S 20.43 E 6718 53.76 4390 2328 69 S 20.73 E 6888 54.07 4490 2398 70 S 20.55 E 7059 54.19 4590 2469 71 S 20.72 E 7230 54.56 4690 2540 71 S 20.85 E 7404 55.18 4790 2614 74 S 21.04 E 7579 55.13 4890 2689 76 S 21.25 E 7751 54.11 4990 2761 72 S 22.15 E 7923 54.87 5090 2833 72 S 22.55 E RELATIVE COORDINATES FROM WELL HEAD 2070.67 S 572.87 E 2265.32 S 632.12 E 2438.92 S 682.34 E 2583.57 S 727.82 E 2725.94 S 774.14 E 2863.03 S 817.10 E 2993.11 S 855.16 E 3130.89 S 891.87 E 3274.23 S 929.62 E 3419.79 S 967.69 E 3566.05 S 1005.84 E 3712.17 S 1044.16 E 3856.73 S 1083.13 E 3989.84 S 1121.35 E 4120.28 S 1160.60 E 4249.64 S 1201.89 E 4375.85 S 1248.80 E 4502.96 S 1296.29 E 4631.39 8 1344.66 E 4761.08 8 1393.42 E 4891.22 S 1442.88 E 5023.88 S 1493.55 E 5158.51 S 1545.50 E 5288.28 S 1597.32 E 5417.98 S 1650.58 E 5100 8098 54.94 5190 2908 74 S 22.90 E 5549.55 8 1705.80 E KRU 3G-16 (23-12-8) Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 10/12/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE 5200 8272 54.52 5300 8443 54.24 5400 8615 54.61 5500 8788 54.78 5600 8960 54.19 TVD BKB 5290 5390 5490 5590 5690 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD. 2982 75 S 23.40 E 5681.31 3053 71 S 25.32 E 5807.62 3125 72 S 25.91 E 5933.53 3198 73 S 25.95 E 6061.00 3270 72 S 25.89 E 6186.73 1761.38 E 1818.83 E 1879.40 E 1941.16 E 2001.70 E 5700 9132 54.45 5790 5800 9302 53.23 5890 5900 9464 50.20 5990 6000 9616 48.74 6090 3342 72 S 25.86 E 6311.99 3412 70 S 25.08 E 6436.36 3474 62 S 23.11 E 6552.24 3526 53 S 21.35 E 6659.24 2063.09 E 2121.92 E 2174.49 E 2217.19 E KRU 3G-16 (23-12-8) Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 10/12/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING DL/ 100 1000 27.08 976 886 164 S 14.15 E 157 2000 49.81 1758 1668 779 S 16.18 E 761 3000 54.26 2346 2256 1586 S 15.20 E 1536 4000 60.73 2843 2753 2452 S 15.87 E 2363 5000 55.77 3406 3316 3278 S 14.78 E 3154 47 E 164 S 16.69 E 5.8 176 E 781 S 13.02 E 5.5 404 E 1588 S 14.75 E 0.6 661 E 2453 S 15.62 E 3.1 898 E 3279 S 15.89 E 0.3 6000 53.87 3964 3874 4107 S 16.60 E 3956 7000 54.25 4556 4466 4912 S 20.61 E 4717 8000 55.04 5134 5044 5726 8 22.79 E 5476 9000 54.22 5713 5623 6534 S 26.18 E 6216 1111 E 4109 S 15.69 E 1.0 1377 E 4913 S 16.27 E 0.2 1675 E 5726 S 17.01 E 0.3 2016 E 6535 S 17.97 E 0.5 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 10/12/90 Client .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well · KRU 3G-16 (23-12-8) Section at: S,17.33,E Surveyor..: MIKE NAIRN Computation...: RADIUS OF CURVATURE Survey Date...' 09/24/90 RKB Elevation.: 90.00 ft Job Number .... : AK0990G245 API Number .... : 50-103-20135 INTERPOLATED MARKERS REPORT Surface Location: 2538 SNL 70 WEL S23 T12N R8E MARKER IDENTIFICATION KB 9-5/8" CASING. TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 7" CASING TD MEAS INCLN VERT-DEPTHS SECT DEPTH ANGLE BKB SUB-S DIST BEARING 0 0.00 0 -90 0 N 0.00 E 4376 56.30 3047 2957 2768 S 18.07 E 9132 54.45 5790 5700 6640 S 25.86 E 9151 54.40 5801 5711 6655 S 25.69 E 9213 54.12 5837 5747 6705 S 25.21 E 9421 51.17 5963 5873 9650 48.74 6112 6022 9653 48.74 6114 6024 DIRECTION REL-COORDINATES FROM-WELLHEAD ON 0E 2665 S 754 E 6312 S 2063 E 6326 S 2070 E 6372 S 2092 E 6870 S 24.03 E 7043 S 21.35 E 7045 S 21.35 E 6522 S 2161 E 6683 S 2226 E 6685 S 2227 E <KB>O 650 13oo t95o 26oo T 3250 ¥ D 3900 455O 5200 5850 65OO 7t50 7800 8450 9tO0 650 VERTICAL SECTION VIEW ARCO ALASKA. INC. ............ KRU3G-16 (23-12-8) Section at: S ~?.33 E TVD Scale · ! inch = t300 feet Dep Scale.' ! inch = t300 feet Drawn · 10112190 Marker Identification MD TVD ~ECTN ~} KB 0 0 0 A ........... B} TD 9653 6~4 7045 INCLN 0.00 48.74 0 650 i300 i950 2600 3250 3900 4550 5200 5850 6500 Section Departure Marker Identifica[ion MO N/$ E/N A) KB 0 0 N 0 E 8) TO 9853 8685 S 2227 E PLAN VIEW ARCO ALASKA. INC. KRU 35-~§ CLOSURE ..... : 7046 ft S iB.43 E DECLINATION.: 0.00 E SCALE ....... : ! inch = il00 feet DRANN ....... : 55O 0 55O ttO0 t650 220O 2750 33OO 3850 4400 495O 5500 6050 6600 7t50 550 0 550 tt00 <- NEST' EAST -> t650 2200 2750 3300 3850 4400 4950 5500 5050 COMPLETION Ofl~ /~ I ~/.. t. ~o CO, CONTACT ,~~ cieck'a'ff °r'ii~i~d'~t~ ~S it'i~ reCeivedTIist received dai~ ~or 4'07. ilnot required ..... list ~z'"l *z~/,,, X"'~/ I' d'rime nis~°W I ~ s~ev I" il' ~eH t~s~s W~. C~'re deSEri~tie~ cored intervals core analysis dnf ditch intervals digital data i1,11 ii ii i i ii i .............................. ~",/. ..... ,,"o ~) i ii ii i iiiiii i ii i i i ii ii i i i !111 ii i ii i ii i i i i i ii , i iii ii 111 I I '8) 9) 10} 111 i2] .... ~ ii i · i3! 14! ,, ,, , Il I , _ I I IIIIILr 'Il',,,.,.. il' . ,,, I IlllI I II IIII II I ~ , ii i i i i Illl I I II -- L~I]I I IIII ,,~l, ,..n ~AL~ j $,.,.ALE .. [to the nea?es,t, foot] I, [inchtl §0'1: STATE OF ALASKA AI_ASKA OIL AND GAS CONSERVATION COMMI~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate m Plugging Repair well ,,, 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 2538' FNL, 70' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1710' FSL, 1993' FWL, Sec. 25, T12N, At effective depth 1400' FSL, 2129' FWL, Sec. 25, T12N, At total depth 1337' FSL~ 2157' FWL, Sec. 25, T12N~ 12. Present well condition summary Total Depth: measured 96 true vertical 61 R8E, UM R8E, UM R8E~ UM 53' feet 1 4' feet Plugs (measured) Perforate Other ;~ , 6. Datum elevation (DF or KB) 90' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 36-16 g. Permit number/approval number 90-1 04/91-221 10. APl number 5o-lo3-20135 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 9564' true vertical 6056' feet Junk (measured) feet Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 43 76' 9 5/8" Intermediate Production 9 6 5 0' 7" Liner Perforation depth: measured 9130'-9150', true vertical 5789'-5801 ', Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 216 Sx AS I 1 1 5' 1 1 5' 945 Sx AS III & 4376' 3047' 570 Sx Class G 200 Sx Class G & 9 65 0' 61 1 2' 200 Sx Class G Tail 9235'-9275', 9298'-9338' 5851'-5874', 5888'-5912' 3 1/2" 9.3#, EUE, ABMOD, IPC, Bottom @ 9178, & 2-7/8" L-80, 6.5#, IPC, w/tail @ 9199' Packers and SSSV (type and measured depth) SSSV: Otis FMX Series 10 @ 1808', Packer: TIW @ 9181'~ & Camco HRP-1-SP @ .9.0~12~ 13. Stimulation or cement squeeze summary Converted from Producing Well to Water Injection Well. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaige Production er OiI-Bbl Gas-Mcf Water-Bbl Casing Pre~j~0~-3,.~bing Pressure Prior to well operation 736 400 - 0 - 1 100 163 15. 17. Signed Subsequent to operation - 0 - - 0 - 5 2 3 9 1 0 2 5 Attachments J 16. Status of well classification as: Copies of Logs and Surveys run ~ I Water Injector X Daily Report of Well Operations X Oil-.. Gas Suspended I hereby certify that the foregoing is true and correct' to the best of my knowledge. omv - Title 26OO Service Date Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ~ARCO Alaska, Inc,~'% Sul~icliary of Atlantic Richfield Coml~any WELL SERVICE REPORT WELL IPBDT ~ITRACTOR REMARKS FIELD- DISTRICT- STATE OPERATION AT REPORT TIME .... A;'(..~ qqv'9o I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots ~-~. WELL SERVICE REPORT ,r~,~ ~lasKa, inc. ~ Sut3s~chary of Atlantic RicnfielO Company ~6-/~ CONTRACTOR ~-, ,RKS ' IPBDT I FIELD - DISTRICT- STATE iOPERATION AT REPORT TIME I DAYS , DATE CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK '/eather Temp. Chill Factor Visibilify Wind Vel. :eport °F °F miles knots STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown, Pull tubing Alter casing Stimulate Repair well 2. Name of Operator ARCO Alaska. Ir~, 3. Address P. O. Box 100360, Anchorage, AK 99510 "4. Location of well at surface 2538' FNL, 70' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1710' FSL, 1993' FWL, Sec. 25, T12N, R8E, UM At effective depth 1400' FSL, 2129' FWL, Sec. 25, T12N, R8E, UM At total depth 1337' FSL~ 2157' FWL~ Sec. 25, T12N~ R8E, UM 12. Present Well condition summary Total Depth: measured 9653' feet true vertical 61 14' feet 5. Type of Well: Development X Exploratory _ Stratigraphic .- Service Plugging Perforate X Other 6. Datum elevation (DF or KB) 90' RKB 7, or Property name Unit Kuparuk River Unit 8, Well numl:~r 3G-16 9. Permit number/approval number 90-104/NA 10. APl number so-103-2013~; 11, Field/Pool Kuparuk River Oil Pool Effective depth: measured 9564' feet true vertical 6056' feet Plugs (measured) Casing Length Size Structural Conductor I 1 5' 1 6" Surface 4376' 9 5/8" Intermediate Production 9 65 0' 7" Liner Perforation depth: measured 9130'-9150', true vertical 5789'-5801 ', Tubing (size, grade, and measured depth) Junk (measured) Cemented Measured depth True vertical depth 216 Sx AS I 1 15' 1 15' 945 Sx AS III & 4376' 3047' 570 Sx Class G 200 Sx Class G & 9 6 5 0' 61 1 2' 200 Sx Class G Tail 9235'-9275', 9298'-9338' 5851'-5874', 5888'-5912' fee.~ 3 1/2" 9.3#, EUE, ABMOD, IPC, Bottom @ 9178, & 2-7/8" L-80, 6.5#, IPC, w/tail @ 9199' Packers and $SSV (type and measured depth) SSSV: Otis FMX Series 10 @ 1808', Packer: TIW @ 9181', & Camco HRP-1~.,P~9~38~ 13. Stimulation or cement squeeze summary ~,.~ ,.~ ~ [-~' ~ ~.,~ ~ I~ Perforated A3 interval of Kuparuk Formation. Intervals treated (measured) _ 9235'-9275' Treatment description including volumes used and final pressure Perforated interval using strip guns with a density of 8 SPF phased at 90°. ~4. ' Reoresentative Daily Avera(~e Production or Inie(~tion'"Data ' Oil Bbl ~-- .... - - ' - ,.~, s- MCr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 320 119 -0- 1100 163 15. 17. Signed Subsequent to operation 73 6 4 0 0 - 0 - 1 1 0 0 Attachments ! 16. StatUs of well' classification as: Copies of Logs and Surveys run ~ I Water Injector ~ Daily Report of Well Operations X Oil X Gas Suspended I hereby 'certify that the ~oregoing is true and correct to the best of my knowledge. Title 163 Service Date Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Su,bsidiaw of Atlantic Richfield Company ~-~..s. ,VELL -- C 'RACTOR o~',~ - ~,'IL~ REMARKS I=a=r FIELD- DISTRICT- STATE Z.,e. ~. .... OPER~T.~DN AT REP, OR]I'TIME DF& - , WELL SERVICE REPORT IDAYS i DATE · ¢ , ' /Pose , / _ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK _'eather 'Temp. !Chill Factor !Visibility "Wind Vel. Signed eport oF °F' miles, knots, ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company REMARKS WELL SERVICE REPORT OPERATION AT REPORT TIME ~/-E - ~ ~ q 715- I DAYS i DATE i ~-¢-¢1 _.j .' CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Yeather Temp. :leport i Chill Factor i Visibility Wind Vel. °F °F miles knots -ARCO Alaska, Inc/~) Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL l PBDT ',ITRACTOR REMARKS 'FIELD- DISTRICT- STATE OPERATION AT REPORT TIME ,4FE' iDAC, l DATE /~Z~' /1/o //2.3. 5.,A ot ~ CHEOK THIS BLQ~K IF SUMMARY OONTINUED ON BAOK Re~d °F °F miles knots 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 STATE Of ALASKA ~ OIL AND GAS CONSERVATION COMMI~ON APPLICATION FOR SUNDRY APPROVALS ~ i i 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well Alter casing _ Repair well_ Plugging _ Time extension _ Stimulate _ Change approved pro,,gra,rn _ Pull tubing _ Variance 5. Type of Well: Development .~. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 70' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1710' FSL, 1993' FWL, Sec. 25, T12N, R8E, UM At effective depth 1400' FSL, 2129' FWL, Sec. 25, T12N, At total depth 1337' FSL, 2157' FWL~ Sec. 25r T12N~ 12. Present well condition summ~ry "' Total Depth: measured true vertical Effective depth: measured true vertical Length 115' 4376' 9650' measured 9130'-9150', true vertical 5789'-5801 ', Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: R8E, UM _ Perforate _. Other 6. Datum elevation (DF or KB) RKB ~ 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-1(~ feet R8Er UM 9653' feet Plugs (measured) 61 1 4' feet None 9564' feet Junk (measured) 6 0 5 6' feet None Size Cemented 1 6" 216 Sx AS I 1 1 5' 9 5/8" 945 Sx AS III & 4376' 570 Sx Class G 7" 200 Sx Class G & 9 6 5 0 200 SX Class G Tail 9. Permit number 90-104 10. APl number sod 03-20135 11' Field/Pool Kuparuk River Field Kuparu,k River Oil Pqol , Measured depth True vertical depth Tubing (size, grade, and measured depth) 9298'-9338' 5888'-5912' 115' 3047' 6;1 1 2' :, 3-1/2" J-55 , 9.3#, AB Mod., IPC, Bottom @ 9178' & 2-7/8", J-55, 6.5#, IPC'~'W/T~ii'~'@ 9199' Packers and SSSV (type and measured depth) TIW Pkr. ~ 918.1', Camco HRP-1-SP Pkr. @ 9082'~ Otis FMX Series 10 SSSV ~ 1808' 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch _ Convert well from oil producer to water injector. 14. Estimated date for commencing operation 15. Status of well classification as: AUGUST 1991 oi~ X Gas__ Suspended_ 16. If proposal was verbally approved Service Date approved the fo. regoing is true and correct to the best of my knowledge. FOR OOMMISSION USE ONLY Notify Commission so representative may witness Location clearance Subsequent form require 10- Name of approver 17. I here. e_~zrt~y t~,~t Si~ned ~ 4,~'~ ~,.~. Conditions of approval: Plug integrity m BOP Test Mechanical Integrity Test /~ Commissioner Approved by order of the Commission Form 10-403 Rev 09/12/90 lAppr°va~°:- ~// SUBMIT IN TRIPLICATE Water Injection Conversion Procedure Well 3G-16 Procedure. · SI well to perform surface equipment modifications. Install catalytic heater, rotate check valve and choke, install 1.5" meter runs, and calibrate instrumentation· 2. MIRU slick line unit. RIH and tag fill. Replace all GLV°s with DV's. 3. Conduct MIT. Note: The state should be notified a few days prior to performing the MIT so they can witness the test. . After well has been shut in for at least 72 hours, contact Operations Engineering (x7525) to record wellhead pressure and shoot tubing fluid level. This information will be used for waterflood surveillance. . Begin injection, eventually working up to a flow rate of approximately 2500 BWPD. ARCO Alaska, Inc. Date: November 2, 1990 Transmittal #: 7940 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. signed copy of this transmittal. / '/3G- 14 Pulse Echo Cement Evaluation(PET) 9 - 2 /~G- 16 Pulse Echo Cement Evaluation(PET) 9 - 2 18 /-3;.G- 14 17 ..3'G- 18 Please acknowledge receipt and return one Pulse Echo Cement Evaluation(PET) 9-2 Pulse Echo Cement Evaluation(PET) 9-2 Acoustic Cement Bond Log 9 - 2 Acoustic Cement Bond Log 9 - 2 Acoustic Cement Bond Log 9 - 2 Acoustic Cement Bond Log 9 - 2 5-90 3308-6908 4-90 5820-9530 2-90 4668-7668 4-90 6500-9520 5-90 2992-6919 4-90 6500-9535 2-90 4668-7668 4-90 6500-9520 Receipt Acknowled . Date: DISTRIBUTION: Drilling NSK RECEIVED ~~f.'AlaSka(+sej3ia) Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA U [~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown X Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development .X__. Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 2538' FNL, 70' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1760' FSL, 1885' FEL, Sec. 25, T12N, R8E, UM At effective depth NA At total depth 1525' FSL, 1958' FWL, Sec. 25, T12N, R8E, UM (approx) (approx) 12. Present well condition summary Total Depth: measured 9650' feet (approx) true vertical 6128' feet Effective depth: measured NA feet (approx) true vertical NA feet Plugs (measured) None Junk (measured) None 6. Datum elevation (DF or KB) RKB 9O' 7. Unit or Property name Kuparuk River Unit 8. Well Number 3G-16 9. Permit number 90-104 10. APl number 50-103-20135 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 3021 ' 9 5/8" Intermediate Production 6 0 93' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented Measured depth 115' 945 Sx AS III & 4376' 570 Sx Class G 200 Sx Class G 96 5 0' & 200 Sx Class G tail R CEIVEO True vertical depth (approx) 115' 3058' 6128' 13. Attachments Description summary of proposal _ Detailed operation program X~ BOP sketch 14. Estimated date for commencing operation November, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as:., Oil X Gas __ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~, ~,, ~/~~~ Title Area Drilling Engineer / FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test w Location clearance__ Mechanical Integrity Test_ Subsequent form require JApproval No. ~ ~o - -7/~/ / Approved by.the order of the Commission Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED LONNIE C. $~TU Approved · 8etupe.~o Date q I'~r. I~ SUBMIT IN TRIPLICATE ARCO Oil a,,d Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Rel:,ort" on the first Wednesday after a well is spudded or workover operations are started. Dally Work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25548 Title DRILLING IState AK KUPARUK RIVER UNIT ALK: 2662 Auth. or W.O. no. AK4991 l;ell no. U 3G-16 Operator ARCO Spudded or W.O. begUnsp[iD IDate 08/13/90 1H°ur Date and depth as of 8:00 a.m. 08/14/90 (1) TD: 1268' (1268) SUPV:KSP 08/15/90 (2) TD: 3570'(2302) SUPV:KSP 08/16/90 (3) TD: 4400'( 830) SUPV:KSP 08/17/90 (4) TD: 4850' ( 450) SUPV:KSP 08/18/90 (5) TD: 8044' (3194) SUPV: KSP TD: 9107' (1063) Complete record for each day reported DO¥ON 14 21:00 IARCO W I 55.2521 Prio~ states if ~ W.O. DRLG MW: 8.9 VIS: 48 NU 20" ANNULAR PREV, RISER, FLOWLINE, DIVERTER SYSTEM. CDL. PU BHA. TEST DIVERTER SYSTEM. DRLD CMT. ORIENT TOOLS. SPUD @ 2100 8-13-90. DRLD TO 1268 DAILY:S64,887 CUM:$64,887 ETD:S64,887 EFC:$1,450,000 DRLG MW: 9.5 VIS: 55 DRLD F/1268-3446'. NAVIDRILL STALLED. PUMP HI-VIS SWEEP. DROP SURVEY. POH. CO NAVIDRILL. TIH - NO PROBLEMS. DRLG F/3446-3570' @ 90 FPH. DAILY:S53,016 CUM:$117,903 ETD:S117,903 EFC:$1,450,000 ND ANNI]LAR PREVENTOR MW: 9.8 VIS: 49 DRLD F/3570-4400'. PUMPED HI-VIS SWEEP. CIRC HOLE CLE~. 32 STAND SHORT TRIP. CIRC. TOH. LD BHA. RU AND RUN FS, 2 JTS 9-5/8" CSG, FC, AND 109 JTS 9-5/8" 36 PPF BTC CSG. SET CSG @ 4376'. CIRC CSG VOL. RU DOWELL AND CMT W/ 80 BBL FW SPACER, FOLLOWED BY 945 SX LEAD ARCTIC SET III CMT @ 12.1 PPG (326 BBL). TAILED IN W/ 570 SX CL G + ADDS @ 15.8 PPG (119 BBL). DISP W/ 333 BBL FW. HAD FULL RETURNS THROUGHOUT JOB. NO CMT RETURNS TO SURF. BUMPED PLUG W/2000 PSI. FLOATS HELD. ND DIVERTER FOR TOP JOB. DAILY:S153,858 CUM:$271,761 ETD:S271,761 EFC:$1,450,000 DRLG MW: 9.5 VIS: 38 ND DIVERTER. RU AND PUMP 80 SX CL G YOP JOB. MU STARTING HEAD, NU BOP. PU DC. WO CAMERON TO REPAIR VR PLUG. TIH TO FC. DRLD FC, CMT, FS, AND 10' OF NEW FORMATION. RAN LOT TO 12.5 PPG EMW - OK. DRLD F/4410-4802'. SURVEY. POH FOR BHA. PU PDC BIT, TURBINE, AND MWD. ORIENT TOOLS. TIH. DRLD F/4802-4850'. DAILY:S135,602 CUM:$407,363 DRLG DRLG F/4852'-8044'. DAILY:S58,966 CUM:$466,329 ETD:S407,363 EFC:$1,450,000 MW: 9.8 VIS: 38 ETD:S466,329 EFC:$1,450,000 TRIP FOR BIT MW:10.7 VIS: 42 DRLG F/8044-8800'. CIRC HOLE CLEAN. POH TO CSG SHOE. RAN LOT TO 11.3 PPG EMW. NO LEAK OFF. SLIP DRILL LINE. TIH. DRLG F/8800-9107'. ROP DROPPED TO 10 FPH FROM 90 FPH. DROP SURVEY. POH. DAILY:S79,707 CUM:$546,036 ETD:S546,036 EFC:$1,450,000 The above is .~rrect S,gnatu For form ~reparation~ ~ist~butionl '4 ~ - -- see Procedures Me~. ~ectJon 10, Drilling, Pages 86 ~ 87. AR3B-459-1-D JNumber all daily well history forms consecutively as they are prepared for each well. iPage no. ARCO Oil an~ ,~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ,IC°unty or Parish IState ARCO ALASKA INC. I NORTH SLOPE Field JLease or Unit KUPARUK RIVER UNIT I KRU 3G-16 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a,m. DOYON 14 7) 543', 08/20/90 ( TD: 9650'( SUPV:KSP LD DP MW:10.7 VIS: 38 LD TURBINE, MU BHA. INSTALL SOURCE IN MWD TOOL. TIH TO 9021' BREAK CIRC AND REAM 9021' - 9107' DRLG F/9107-9650'. CIRC. PULL 15 STAND SHORT TRIP. HOLE VERY TIGHT. WENT BACK TO BOTTOM W/ NO PROBLEMS. CIRC BOTTOMS UP. SPOT DIESEL PILL. POH AND LD DP. HOLE IN BETTER SHAPE. DAILY:S58,141 CUM:$604,177 ETD:S604,177 AK IWell no. EFC: $1,450,000. The above~s correct For form~rmpreparat o/~preparatio nd distribution Drilling, Pages 86 a'¥fd 87 J Date' /[Title ~ __ AR3B-459-2-B Number all daily well history forms consecutively as hey are prepared for each well. IPage no. ARCO O,, ,~nd Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also whe~l operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ALASKA ING. ICounty or Parish NORTH. SLOPE Lease or Unit ADL: 25548 Title DRILLING tAccounting State AK cost center code Field KUPARUK RIVER UNIT ALK: 2662 3G-16 Auth. or W.O, no, AK4991 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 08/21/90 ( TD: 9650'( SUPV:KSP 8) 0) A.R.Co. W.I. 55.2521 Date 08/13/90 !Complete record for each day reported DOYON 14 Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W,O. 21:00 ND BOP MW: 0.0 VIS: 0 POH, LDDP. LD BHA. PULL WEAR BUSHING. RU AND RUN 114 JTS 7" 26# J-55 BTC CSG AND 113 JTS 7" 26# J-55 AB MOD BTC CSG. SHOE @ 9650'. FC @ 9563'. RU DOWELL AND CIRC CSG VOLUME. BEGAN LOSING RETURNS. HOLE WOULD STAY FULL, BUT COULD NOT GET FULL RETURNS. PUMPED 5 BBL FW AND TEST LINES TO 3000 PSI. PUMPED 10 BBL ARCO PREFLUSH AND 35 BBL 11.6 PPG ARCO SPACER. PUMPED 200 SX CL G + ADDS @ 12.5 PPG (75 BBL). TAILED IN W/200 SX CL G + ADDS (42 BBL). DISP W/366 BBL 10.5 PPG BRINE. BUMPED PLUG W/3000 PSI. FLOATS HELD. HAD PARTIAL RETURNS MOST OF THE JOB, HAD NO RETURNS 10% OF THE JOB. PUMPED 100 BBL OF MUD DOWN BACKSIDE iauND FLOWED BACK 70 BBL. ND BOP, SET SLIPS, CUT CSG. INSTALL TBG HEAD AND PREPARE TO MOVE TO 3G-14. DAILY:S300,584 CUM:$904,761 ETD:S904,761 EFC:$1,450,000 Old TD New TD I PB Depth I Released rig Date IKind of rig I Classifications (oil, gas. etc.) Type completion (single. dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir I Producing I~terval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR; : ' 'Gra~vity Allowable Effective date corrected .... .... The abo~i.'s correct Sign~ ~ . ,Date/ -' For fZm prepar.~ and distribut,o~ see Proced~es ~nual, Section 10, DrilHnG, Pages 86 and 87. AR3B-459-3-C INumberall daily well history forms consecutively Page as they are prepared for each well. I ~ no, Dlvi~on of AtlanflcRIchfieldCompeny ARCO Alaska, Inc. Date: August 31, 1990 Transmittal #: 7874 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119' P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the OPEN HOLE following items. receipt and return one signed copy of this transmittal. 3 G- 19 Dual Gamma Ray Compensated Neutron Porosity Simultaneous Formation Density ,~3 G- 19 Dual Gamma Ray Electrmagnetic 8 - 1 2 - 9 0 Wave Resistivity ~3 G - 14 Dual Gamma Ray Compensated 8 - 2 5 - 9 0 Neutron Porosity Simultaneous Formation Density 3 G - 14 Dual Gamma Ray Electrmagnetic 8 - 2 5 - 9 0 Wave Resistivity Formation Exposure Time 3 G- 16 Dual Gamma Ray Compensated 8 - 2 0 - 9 0 Neutron Porosity Simultaneous Formation Density 3G- 16 Dual Gamma Ray Electrmagnetic 8 - 2 0 - 9 0 Wave Resistivity 8-12-90 Please acknowledge 3798-8200 3798-820O 3160-7040 3160-7040 4370-9653 4370-9653 Receipt Acknowledged' DISTRIBUTION: ~~-------~--- Date' .... SEF - 4 ]990 Alast~a.Oil .& Gas Cons. Commission Anchorage D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: August 31, 1990 Transmittal Ct: 7873 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the OPEN HOLE following items. receipt and return one signed copy of this transmittal. ~/ 3G-19 ~/3G-14 v3G-16 Receipt LIS Tape and Listing 8 - 9 - 9 0 LIS Tape and Listing 8 - 2 9 - 9 0 LIS Tape and Listing 8 - 2 9 - 9 0 Acknowledged: ~ ...... DISTRIBUTION: Lynn Goettinger Please acknowledge 900830 900834 .RE6Eiv u Date: .......... S _p - 1990 estate of Alaska August 1, 1990 Telecopy: (907)276-7542 A, Wayne McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 3G-16 A~RCO A!a~ka, 'Inc. Permit No. 90-i04 . L c 2538'FNL, . Sur ~o . 70'FEL, Sec. 23, T12N, RSE, Btmhole Loc. I525'FSL, 1958'FWL, Sec. 25, T12N, RSE, UM. Dear M~r. McBride Enclosed is the approved application for permit to drill the above referenced W~ll. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting dete~tnattons are made. The Commission will advise you of those BOPE tests that it wishes to witness. Very~ truly ' n of C~isszo ~r Alaska Oil and Gas Conse~ation Co~ission BY O~ER OF nE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Depar~ent of Environmental Conse~ation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,:.,,ON PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill X Redrill m I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 90', Pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Ancho. ra~le, AK 99510-0360 ADL 25548 ALK 2662 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25,025) 2538' FNL, 70' FEL, Sec. 23, T12N, R8E, UM .Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 1760' FSL, 1885' FWL, Sec. 25, T12N, R8E, UM 3G-16 #U630610 At total depth 9. Approximate spud date Amount 1525' FSL, 1958' FWL, Sec 25, '1'12N, R8E, UM 13-AUG-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-19 9455' MD 3322' @ TD feet 75' at SURFACE feet 2560 6072' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 3 00 feet Maximum hole angle 55° Maximum surface 1845 psig At total depth (TVD) 3400 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD lVD TVD (inc, lude stage data) 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' _+200 Cu. Ft. , ,, ! , ,, , 12.25 9.625 36.0# J-55 BTC 4274' 35' 35' 4309' 3115' 1833 Cu. Ft. AS III & ~F-~.RW 655 Cu. Ft. Class G , 8.5 7" 26.0# J-55 BTC 9420' 35' 35' 94~5' 6072' 210Cu. Ft. ClassG ~'-~.RW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical , , , , , 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I herebY, Certify that the foregoing is true and correct to the best of my knowledge ' ' Signed ,/~//~,~~_ ~' C°mm, issi°nTitle Areause Only'Drilling En~]ineer Dale Permit Number~c~(::~ ..,/~) ¢),/ ] APl number 50?/'~__~J~-., ,~.(::3//,~..~ !Appr°val date 08/01 /.~0N See c°ver letter f°rother requirements Conditions of approval Samples required --Y e s ~ N o Mud log required __ Ye's o Hydrogen sullide measures ~ Yes .~' N o Directional survey required ~ Yes ~ N o Required working pressure for BOPE ~2M; ..~ 3 M;~ SM; ~ 1 0M' __ 1 5 M [Approved by ,.'' Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DRILLING FLUID PROGRAM (3G-16) Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 8.6-10.0 8.6-9.3 11.0 PV 15-35 5-15 10-1 8 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4-8 4-8 APl Filtrate 10-12 8-1 0 4-5 pH 9- 1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and 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 and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1845 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-16 is 3G-19. As designed, the minimum distance between the two wells would be 75' at surface. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ~RCO ALASKA, !ne. Pad 3G, Well No' 16 Kuparuk Field, Nor th Proposed SI ope, Al asks ~ 1000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 - RKB ELEVATION~ 90' KOP I$ ~7 TVD=300 TMD=300 DEP=O BUILD 3 OEO PER I00 FT B/ PERHAFROST TVD=1605 TI'ID=IT37 DEP=515 T/ UONU SNDS TVD=1775 TI'ID=l g85 DEP=697 EOC TVD=1863 TI"ID=2131 DEP=812 T/ W SAK SNDS TVD=2420 TMD=3100 DEP-1606 B/ W SAK SNDS TVD=2915 THD=3961 DEP=2311 9 5/8" CSO PT TVD=3! 15 1'1"1D=4309 DEP=2595 K-!O TVD=3265 THD=4570 DEP=2809 K-5 TVD=4370 THD=6493 DEP=4383 AVERAGE ANGLE 54 DEG 55 HI N T/ ZONE C TVD=5815 THO=g008 DEP=6440 T/ ZONE A TVD=5840 THD=9051 DEP=6476 TAROET CNTR TVD=5899 THD=9154 DEP=6560 B/ KUP SNDS TVD=5957 THD=9255 DEP=6643 TD (LO0 PT) TVD=6072 THD=9455 DEP=6806 I 1 000 i i i 'l 2000 3000 4000 5000 VERTICAL SECTION I 6000 7000 P~'ZONTAL PROJECT !0~~ ~CALE 1 IN. = 1000 FEET 1000 SURFACE LOCATION, 2538' FNL, TO' FEL SEC. 23, T12N. RSE ~ 1000 - 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ ARCO ALASKA, Ino. Pad 3G, Well No, 16 Proposed Kuparuk Field. North Slope, Aleeke 1000 WEST-EAST 1000 .... ! 2000 3000 I I SURFACE S 17 DEG 20 MI N E 6560' (TO TARGET) TARGET CENTER TVD-$899 THD=91$4 DEP-6$60 SOUTH 6262 EAST 1955 TARGET LOCATION, 1760' FSL, 1885" FWL SEC. 25, TI2N. RSE TD LOCATION, 1525' FSL, 1958' FWL SEC, 25, T12N, R8E 200 150 100 50 0 50 100 150 200 2450 2500 . 255O 26OO 265O · 2700 2750 900 1100 1300 300 5oo '~roo 900 \ \ \ \ II100 \ 2450 / / / / y / , oo , oo 33020700 \ 500' ,,. 2550 I ! I I _ 2700 2750 200 150 100 50 0 50 100 150 200 ttUPARUK RIVER UN.~ 20" DIVERTER SCHEMATIC 5 6 4 I , HCR 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 7 , 6 ,I I3 13 5/8" 5000 ,'ol BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STAQK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BoTroM PIPE RAMS. TEST BOq-~OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" -2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3G PAD . . . , . . . , . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. II 1. ~$15 OF lOCATION ANO P. g£RVATION$ SHOWN $. COOROIbl;ar£$ SHOWN AR~ A$.R · . LOC&1"~O WI?b/IN PR~N&O?~D $R~'$. PS · ~4, ~. 18N.~ N. ~ ~.~U. M.~ AK. ¥1ClNI?Y M&P I"~ ~ Mt, /0 ~ A I". &ON$. ?0~ ~' 4 ?, ~" ' I§0 ~00 ~$9,~$$" 100°00'40. PO8" I00o00'0 I. ? I $" l~OoO0' 4P. 4 bO'' I00°00'45. lOI ' 1~0~0'45. I 0~0°00' 4 P'. Po4" F. W.&. O.O. 195' 40. P 84.0 IpO' 4p.O 140' 4?.g 854 lEO' 4~.8 8 ' 47,3 No. Y X 16 8,900~$~0.8~ 490~0~.00 I~ 8,000, 860.~0 400~ PO0. ?0 aO 8~00, $~0.~0 4~0~ POo. O0 SURVEYOR'S C~RTII~I CATK I b/EREBY CERTIFY rff4r I AM ~NO SURVffYIN~ IN AND ~AT THIS ~LAT ( ~ T~T A~L 01~N91~9 AND O THPO ~TAILS AR~ COROT AS OF 4R¢0 ALASKA,/NC. OW~. IVO. ' N$OK. $$00. CRA ~n~ ~£5T ~'OK NnW W£LL PEIlbfIT$ !T--~ APPROVE DATE (2 :hru 8) (S) (3) Aa=in ,, 7-27- ~ 1i. (10 ~d I3) 12.- 13. (~4 :h~ 22) (23 thru 28) Company _./~.r~_z~ Lease & Well No. YES NO Is the permit fee at:ached .......................................... ~ 2. Is well :o' be located in a defined pool ............................. /~ 3. Is well located proper distance from property line .................. ~ ,, , 4. Is well located proper distance from other wells ........ ~ ........... ~._ .... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is we!! :o be deviated and is we!!bora pla: included ................ 7. Is operator ~he oniy affected par~y ......... i ....................... , ...... 8. Can permit be approved before fifteen-day wait ...................... , Does operator have a bond in force .................................. ~ is a conservation order needed ...................................... -~- Is adm/~is=rative approval needed ................................... Is :he lease number appropriate ..................................... Z Does :he well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 2!. 22. 23. 24. 25. 26. 27. 28. Is cdnduc:or string provided ........................................ Will surface casing protect ail zones reasonably ex?ected ~o serve as am underground source of drinking water ..................... Is enough cement used :o circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known produc=ive horizons ..................... Will al! casing give adequate safety in collapse, tension and burs:.. '' Is this well :o be kicked off from an ez_isting we!lbore ............. Is old we!!bore abandonment procedure included on 10-403 ............ is adequate weilbore separation proposed ...................... Is a diver=er system required ....................................... ,,~,, Is the drilling fluid program schematic and list of equipment adequate__~ Are necessary diagrams and descriptions of diveruer and BOPE attached. Does BOPE have sufficien~ pressure rating - Test to Does =he choke manifold comply w/A. PI R~-$3 (May 84) .................. Is the presence of HZS gas probable ............................. ~... (6) Add: Geolo~':~ Engineering: DWJ~ LCS BEW rev: 01/30/89 6.011. ~or 29. 30. 31. 32. exploratory amd Strauigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Addi=ional requirements ............................................. " ' zszZ ' dso ufzz t 0N/o POOL CLASS STATUS AREA, NO. ,, SNORE ,> 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. T° 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. .o (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/08/24 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/08/24 ORIGIN OF DATA: 3G16 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ICROFILMED ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G16.MWD SERVICE NAME: RLL VERSION #: V2.40 DATE: 90/08/24 MAX. RECORD LENGTH: 1024 FILE TYPE: E1 PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-16// API: 50-103-20135// DATE: 20-AUG-90 LOCATION: 2538' FNL & 70' FEL, SEC. 23, TWP. 12N, RANGE 8E, KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA, U.S.A.// RIG: DOYON 14// CO. REP. KEN PRICE// RLL ENG.: BORWN & GALVIN// COMMENTS **>>>> NEUTRON & DENSITY LOGS ARE CALIPER CORRECTED. NO TOOL WEAR OR CALIBRATION SHIFTS OBSERVED DURING POST JOB CALIBRATION. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT EWR MWD FXE MWD ROP MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD GRC MWD CAL MWD DRHO MWD NPSC MWD RHOB MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 aPI 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY DESCRIPTION 4 1 66 255 LOG DIRECTION, DOWN 0 1 66 TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT EWR MWD FXE MWD ROP MWD NFO MWD NFl MWD NN0 MWD NN1 MWD GRC MWD CAL MWD DRHO MWD NPSC MWD RHOB MWD FT OHMM HOUR FT/H CTS CTS CTS CTS API INCH G/C3 P.U. G/C3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 1 1 4 4 4 4 4 4 4 4 4 4 4 4 4 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 1 1 68 68 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION DEPT NN1 4280.000 -999.250 4300.000 -999.250 4400.000 2408.000 4500.000 2576.600 4600.000 2509.523 4700.000 2441.621 4800.000 2600.000 4900.000 2536.000 5000.000 2584.000 5100.000 2488.000 5200.000 2536.000 5300.000 2639.208 5400.000 2511.019 550O.000 2680.000 5600.000 2664.000 5700.000 2568.000 5800.000 2632.000 5900.000 2651.350 6000.000 2760.000 6100.000 2536.000 EWR GRC (every 100 FT) FXE ROP CAL DRHO -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 8.350 .000 5.027 84.658 1.003 183.513 9.080 -.075 7.734 80.175 .641 101.904 8.820 .001 5.266 100.204 .950 80.000 8.600 -.004 3.884 89.714 .597 112.500 8.610 -.006 7.192 81.374 6.792 131.083 8.580 -.002 4.477 97.575 .431 400.000 8.720 .000 4.330 99.204 .432 305.713 8.410 -.053 4.818 102.562 .587 380.742 8.680 .000 4.092 104.192 .452 380.742 8.840 .001 4.068 106.617 .575 262.542 8.810 .000 3.665 88.646 .610 220.244 8.880 .007 4.525 79.154 .457 333.825 9.080 .016 3.396 106.679 .598 394.980 9.130 .001 3.534 97.488 .670 394.629 8.950 .009 3.941 106.629 .850 305.127 8.820 .009 3.420 87.143 .678 222.829 8.690 .000 5.861 66.111 .472 299.451 8.740 .000 3.461 114.900 .496 387.422 8.900 .001 NF0 NPSC -999.250 -950.387 -999.250 -950.387 469.000 27.901 539.900 23.623 544.746 25.576 506.318 27.916 591.000 23.113 551.000 26.407 591.000 25.874 591.000 26.210 575.000 22.644 561.376 22.642 555.752 24.593 575.000 20.600 583.000 20.792 559.000 21.527 591.000 23.257 562.256 21.852 575.000 19.647 631.000 23.508 NFl RHOB -999.250 -999.250 -999.250 .491 519.000 1.874 527.000 2.226 576.888 2.409 520.106 2.427 567.000 2.065 559.000 2.231 477.000 2.184 551.000 2.256 583.000 2.304 580.624 2.270 549.103 2.379 559.000 2.440 631.000 2.431 567.000 2.531 599.000 2.530 562.163 2.344 599.000 2.413 615.000 2.455 NN0 -999.250 -999.250 2312.000 2576.600 2571.777 2441.106 2728.000 2424.000 2568.000 2504.000 2696.000 2609.503 2531.510 2616.000 2584.000 2712.000 2552.000 2744.000 2840.000 2584.000 6200.000 2693.235 6300.000 2600.000 6400.000 2712.000 6500.000 2520.000 6600.000 2536.000 6700.000 2642.029 6800.000 2760.000 6900.000 2728.000 7000.000 2570.658 7100.000 2552.000 7200.000 2424.000 7300.000 2415.600 7400.000 2472.000 7500.000 2552.000 7600.000 2472.000 7700.000 2648.000 7800.000 2584.000 7900.000 2696.000 8000.000 2624.195 8100.000 2488.000 8200.000 2677.782 8300.000 2632.000 8400.000 2614.856 3.065 72.811 3.069 128.955 2.841 81.007 2.557 96.411 2.238 90.920 3.325 120.659 3.617 147.289 5.239 150.541 5.068 192.711 4.255 152.114 4.695 158.781 4.266 121.567 4.321 123.492 5.340 126.505 4.119 123.308 3.767 105.858 3.875 95.050 2. 174 123.259 4.450 90.199 4.214 103.358 6.640 95.187 4.222 100.719 4.305 124.030 .735 8.850 .689 8.860 .590 8.560 .735 8.800 .681 8.780 .545 8.970 .613 8.780 .774 9.320 .844 10.500 .684 9.210 .698 9.530 .544 9.160 .483 8.630 .878 8.790 .769 9.090 .823 8.710 .715 8.830 1. 187 8.460 .744 8.870 .672 8.620 .901 8.930 .821 8.760 .992 8.850 281.926 .011 366.680 .004 256.892 -.015 189.839 .004 224.780 .003 183.252 .018 203.711 .005 218.072 .014 139.002 .047 257.143 .059 245.393 .047 291.797 .024 266.912 -.003 257.645 .001 298.287 .027 229.285 .000 229.285 .003 208.311 -.029 262.165 .008 229.285 -.002 215.901 .008 104.435 .003 181.722 .000 550.161 20.899 638.208 22.592 599.000 20.840 575.000 24.650 575.000 24.192 617.985 21.075 671.000 19.862 695.000 17.010 733.133 12.889 687.000 22.519 599.000 24.228 557.800 24.311 591.000 27.005 575.000 24.682 535.000 22.727 599.000 22.688 567.000 21.851 623.000 22.831 598.414 21.868 591.000 24.352 612.228 20.621 615.000 20.809 635.857 21.999 545.765 2.496 620.010 2.393 607.000 2.215 567.000 2.384 599.000 2.383 624.912 2.414 743.000 2.536 719.000 2.712 719.430 2.701 695.000 2.612 599.000 2.676 582.600 2.659 615.000 2.455 607.000 2.543 575.000 2.623 591.000 2.415 615.000 2.405 615.000 2.236 618.121 2.348 591.000 2.454 593.217 2.486 623.000 2.403 605.857 2.314 2706.470 2621.624 2872.000 2552.000 2584.000 2664.233 2776.000 2760.000 2657.615 2504.000 2392.000 2530.800 2472.000 2520.000 2632.000 2648.000 2728.000 2728.000 2662.438 2696.000 2697.108 2824.000 2668.857 850O.OOO 2539.505 4.447 .950 133.217 630.746 150.566 9.010 .012 24.021 8600.000 2472.000 4.031 .724 207.227 136.505 8.690 .000 8700.000 2632.000 4.113 .970 197.784 226.825 8.770 .000 8800.000 2591.655 4.134 7.015 201.201 8.730 149.203 .001 8900.000 2382.669 2.770 1.018 111.199 8.470 146.169 -.083 9000.000 2344.956 2.674 2.118 114.805 8.590 124.138 -. 012 9100.000 2.449 12.670 2095.668 105.945 9.890 20.339 .031 9200.000 3.939 1.078 2632.000 89.050 8.730 50.879 .001 9300.000 9.964 .880 2841.746 82.142 8.920 64.944 .006 9400.000 4.361 1.284 2593.547 98.860 8.860 47.292 .005 9500.000 3.250 1.496 2462.937 98.571 8.790 48.745 .000 9600.000 -999.250 -999.250 2723.057 93.475 8.740 37.077 .001 9700.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 571 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: 3G16.MWD SERVICE NAME: RLL VERSION #: V2.40 DATE: 90/08/24 MAX. 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