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Home My WebLink About185-228CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF1 & CPF3 Subject:10-426 form for 3F-04 SI non-witnessed MIT-IA 6-7-25 Date:Sunday, June 8, 2025 9:56:03 AM Attachments:image001.png MIT KRU 3F PAD SI TEST 06-07-2025.xlsx Morning, Please see the attached 10-426 form from the 3F-04 SI non-witnessed MIT-IA that was performed on 6-7-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58) 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1852280 Type Inj N Tubing 930 940 935 935 Type Test P Packer TVD 5729 BBL Pump 2.3 IA 250 3300 3200 3190 Interval V Test psi 3000 BBL Return 2.1 OA 100 120 120 120 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3F Pad Non-witnessed Borge/Sheets 06/07/25 Notes:MITIA per AIO 2B.063 to maximum anticipatied injection pressure. Notes: 3F-04 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2025-0607_MIT_KRU_3F-04 9 9 9 9 999 99 9 9 9 9 -5HJJ MITIA per AIO 2B.063 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-04 KUPARUK RIV UNIT 3F-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 3F-04 50-029-21449-00-00 185-228-0 W SPT 5728 1852280 3000 2870 2870 2868 2868 140 140 140 140 REQVAR P Brian Bixby 6/4/2023 MIT-IA as per AIO 2B.063 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 3F-04 Inspection Date: Tubing OA Packer Depth 400 3325 3220 3200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607081728 BBL Pumped:2.2 BBL Returned:2.2 Wednesday, July 26, 2023 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 MIT-IA James B. Regg Digitally signed by James B. Regg Date: 2023.07.26 15:00:44 -08'00' Originated: Delivered to:14-Jan-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1A-05 50-029-20627-00 907568283 Kuparuk River Multi Finger Caliper Field & Processed 13-Dec-21 0 12 1A-19 50-029-22111-00 n/a Kuparuk River Plug Setting Record Field- Final 9-Dec-21 0 13 1E-31 50-029-22791-00 907551730 Kuparuk River Leak Detect Log Field- Final 7-Dec-21 0 14 1E-31 50-029-22791-00 907551730 Kuparuk River Multi Finger Caliper Field & Processed 6-Dec-21 0 15 1L-19 50-029-22049-00 907423896 Kuparuk River Multi Finger Caliper Field & Processed 27-Dec-21 0 16 1L-19A 50-029-22049-01 n/a Kuparuk River Multi Finger Caliper Field & Processed 10-Jan-22 0 17 2W-16 50-029-21255-00 907594924 Kuparuk River Plug Setting Record Field- Final 29-Dec-21 0 18 3B-16 50-029-21289-00 907292763 Kuparuk River Leak Detect Log Field- Final 28-Nov-21 0 19 3B-16 50-029-21289-00 907292763 Kuparuk River Multi Finger Caliper Field & Processed 3-Dec-21 0 110 3F-04 50-029-21449-00 907551131 Kuparuk River Multi Finger Caliper Field & Processed 4-Dec-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:01/14/2022Wd͗ϭϴϱϮϮϴϬͲ^Ğƚ͗ϯϲϮϯϴBy Abby Bell at 12:45 pm, Jan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y Samantha Carlisle at 5:00 pm, Jan 06, 2022 Jill Simek Digitally signed by Jill Simek Date: 2022.01.06 16:28:13 -09'00' '/% ; '6597/ '/% ; dts 1/12/2022 JLC 1/12/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.01.13 09:52:30 -09'00' RBDMS HEW 1/14/2022 ! " # $ ! 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The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϱϮϮϴϬͲ^Ğƚ͗ϯϲϭϰϮJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1H-11950029235910000 KRU WLIPROFFINAL FIELD24-Jun-211H-11750029236020000 KRU WLIPROFFINAL FIELD16-Jun-213H-31A50103202050100 KRU WLCUTTERFINAL FIELD31-Jul-213S-61150103207740000 KRU WLCUTTERFINAL FIELD11-Oct-211R-10150029214040300 KRU WLSAMPLINGFINAL FIELD30-Jun-213H-3750103208220000 KRU WLGLSFINAL FIELD29-May-213F-0450029214490000 KRU WLIPROFFINAL FIELD23-Feb-211J-10150029232860000 KRU WLPPROFFINAL FIELD2-Mar-211D-0250029204290000 KRU WLIPROFFINAL FIELD17-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD18-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD20-Feb-21MP-150029205730000 KRU WLSCMTFINAL FIELD28-Mar-211G-0250029208130000 KRU WLIPROFFINAL FIELD1-Apr-211C-19050029231360000 KRU WLIPROFFINAL FIELD30-Oct-212L-31850103206810000 KRU WLIPROFFINAL FIELD24-Jul-21 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3F-04 KUPARUK RIV UNIT 3F-04 Sre: Inspector Reviewed By: P.I. Supry 712— Comm Well Name KUPARUK RN UNIT 317-04 API Well Number 50-029-21449-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-228-0 Inspection Date: 6/15/2021 ✓ Insp Num: mitL01-210616090059 Rel Insp Num: Thursday, June 17, 2021 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-oa T e In w TVD 5728 Tubing 2305 _ 2305 -2305 - 2305 PTD 1852280 Type Test, SPT-1Test psi 3000 IA 700 3320 3210 3000 - BBL Pumped: 2 BBL Returned: 2 OA 160 165 165 - 165 - Interval REQVAR P/F P V, Notes: MIT -IA to the Maximum Anticipated Injection pressure per AIO 213.063. Thursday, June 17, 2021 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 12, 2019 TO: Jim Regg / / P.I. Supervisor �/ lol 131/G SUBJECT: Mechanical Integrity Tests -1 666 f I CONOCOPHILLIPS ALASKA, INC. 3F-04 FROM: Guy Cook KUPARUK RIV UNIT 3F -D4 Petroleum Inspector Sre: Inspector Reviewed By: P.1. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-04 API Well Number 50-029-21449-00-00 Inspector Name: Guy Cook Permit Number: 185-228-0 Inspection Date: 6/6/2019 ✓ Insp Num: miiGDC190607175733- Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Milt 60 Min Well 3F-04 "Type Inj W- TVD 5728 - Tubing 2006 - 2006 - 2005 - 2004 - PTD 1852250IType Test i SPT Test psi 3000 - IA 1260 3300 3240 3230 - BBLPumped:2 'BBL Returned: 16 OA 170 —170 ' 170 170 " IntervalREQVAR 1P/F P Notes: MIT -IA to maximum injection pressure per AIO 2B.063. Job was completed with a Little Red Services pump truck and calibrated gauges. Wednesday, June 12, 2019 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,June 15,2017 Jim Regg P.I.Supervisor I �lr' ( r ill 7 SUBJECT: Mechanical Integrity Tests f CONOCOPHILLIPS ALASKA INC 3F-04 FROM: Lou Laubenstein KUPARUK RIV UNIT 3F-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Ogg-- NON-CONFIDENTIAL } ' —NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-04 API Well Number 50-029-21449-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-228-0 Inspection Date: 6/6/2017 Insp Num: mitLOL170607162407 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-04 Type Inj W- TVD 5728 Tubing 2640 _ 2640 - 2640 - 2640 • PTD 1852280 - Type Test SPT Test psi 3000 , IA 1365 3400 - 3310 - 3310 - BBL Pumped: 1.7 BBL Returned: 1.5 - OA 180 . 180 180 - 180- Interval REQVAR P/F P ✓ Notes: MITIA per AIO 2B.063 to MAIP SCANNED SEP 0 520i? Thursday,June 15,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg n DATE: Tuesday,June 16,2015 P.I.Supervisor lcef i (o(Ilk SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-04 FROM: John Crisp KUPARUK RIV UNIT 3F-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Lit2— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-04 API Well Number 50-029-21449-00-00 Inspector Name: John Crisp Permit Number: 185-228-0 Inspection Date: 6/5/2015 Insp Num: mitJCr150607062814 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-04 • Type Inj N TVD T 5728 Tubing 1040 • 1040 1040 1040 -I 1 PTD 1 1852280 • (Type Test SPT Test psi 1500 - I IA 380 3310 • 3210 • 3200 • Interval REQVAR P/F P / OA 200 200 • 200 . 200 Notes: 3 bbls pumped for test.Numbers were good but well had been shut in fora few hours.MITIA to max anticipated injection pressure.Pass/Fail determination to be made by supervisor.Test determined to be"P"per J.Regg SCANNED JUL II 3 201 Tuesday,June 16,2015 Page 1 of 1 • • uny o[F A02,2[1(KA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 2B.063 Corrected Ms. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 ly: ff °;fa Anchorage, AK 99510 -0360 RE: KRU 3F -04 (PTD 1852280) Request for Administrative Approval Kuparuk River Oil Pool Dear Ms. Loveland: In accordance with Rule 9 of Area Injection Order (AIO) 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTED ConocoPhillips Alaska Inc. (CPAI) request for administrative approval to continue water injection in the subject well on September 6, 2011. This document corrects the specified maximum outer annulus (OA) pressure from 300 to 500 psi. No other change has been made to conditions of approval. Kuparuk River Unit (KRU) 3F -04 exhibits a subsidence related surface casing leak at about 838' below pad surface. The AOGCC finds that CPAI does not intend to perform repairs at this time, deferring until a rig workover can be justified. Reported results of CPAI' s diagnostic procedures and wellhead pressure trend plots indicate that KRU 3F -04 exhibits at least two competent barriers to the release of well pressure. AOGCC's administrative approval to continue WATER INJECTION ONLY in KRU 3F -04 is conditioned upon the following: I. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MITIA every 2 years to the maximum anticipated injection pressure; 4. IA pressure not to exceed 2000 psi. 5. OA pressure not to exceed 500 psi. 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; • AIO 2B.063 Corrected September 21, 2011 Page 2 of 2 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8. The MIT anniversary date is June 5, 2011, DONE at Anchorage, Alaska and dated September 21, 2011. • r' ,241 Daniel T. - , ount, Jr. Cathy ' . Foerster Chair, Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within l0 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. III • • ITE E [F ALASEA II SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 2B.063 Ms. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 "..,VOIED S E P . ` 201 RE: KRU 3F -04 (PTD 1852280) Request for Administrative Approval Kuparuk River Oil Pool Dear Ms. Loveland: In accordance with Rule 9 of Area Injection Order (AIO) 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI) pP request for administrative approval to continue water injection in the subject well. q Kuparuk River Unit (KRU) 3F -04 exhibits a subsidence related surface casing leak at about 838' below pad surface. The AOGCC finds that CPAI does not intend to perform repairs at this time, deferring until a rig workover can be justified. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 3F -04 exhibits at least two competent barriers to the release of well pressure. AOGCC's administrative approval to continue WATER INJECTION ONLY in KRU 3F -04 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MITIA every 2 years to the maximum anticipated injection pressure; 4. IA pressure not to exceed 2000 psi. 5. OA pressure not to exceed 300 psi. 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and AIO 2B.063 • • , September 6, 2011 piL AND Page 2 of 2 I 8. The MIT anniversary date is June 5, 20 , -- 2 DONE at Anchorage, Alaska and dates Setember ., 2011. % o S 'kVAT 7' ; ‘ 0 4°- IO4 G .C a � Daniel T. Seamount, Jr. o IF.r Cathy P Foerster Chair C s i o • er Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • I • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED' August 28, 2011 AUG 3 0 2011 N ks O% & Gas Gent. Commission Commissioner Dan Seamount Ancttera9e Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing well 3F-04(PTD 185 -228) to be online in water only injection service with a known surface casing leak. ConocoPhillips intends to pursue repairs should MI injection be desired in the future. If a successful repair is achieved we will request the well be returned to normal status and resume the ability to inject MI. If you need additional information, please contact myself or Martin Walters at 659 -7043, or Brent Rogers / Kelly Lyons at 659 -7224. Sincerely, Tf MJ Loveland Well Integrity Supervisor ConocoPhillips Alaska Inc. Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 3F -04 (PTD# 185 -228) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with a known OA X Formation leak for Kuparuk injection well 3F -04. Well History and Status Kuparuk River Unit well 3F-04 (PTD# 185 -228) was drilled and completed in 1983 as a service well in October 1985. 3F -04 was reported to the Commission on 04/24/2011 with a suspected subsidence related surface casing leak. Diagnostics were conducted which verified the surface casing to formation leak to is approximately 838' below the surface (conductor shoe is at 110' RKB). A passing MITIA was conducted on 05/02/2011 and a State Witnessed MITIA was conducted on 06/05/11. A Gyro log was run on 07/08/11. The results suggest it is possible for the leak to be subsidence related, however they did not give clear indications as to the exact cause of the leak. Considering that the leak is too deep to access via excavation, the well will require a workover or an alternate repair technology to remediate. ConocoPhillips requests an AA to continue water only injection until the well can be repaired. Barrier and Hazard Evaluation Tubing: The 3 -1/2" 9.3# L -80 tubing has integrity to the packer @ 6167' MD based upon a passing MITIA to 3000 psi on 05/02/11 and 2400 psi on 6/05/11. Production casing: The 7" 26# J -55 production casing has integrity to the Packer @ 6167' MD based upon a passing MITIA to 3000 psi on 05/02/11 and 2400 psi on 6/05/11. The production casing is set at 6862' and has an internal yield rating of 4980 psi. Surface casing: The well is completed with 9 -5/8" 36# J -55 surface casing in the upper portion of the hole with an internal yield pressure rating of 3520 psi. The surface casing is set at 3035' MD and was arctic packed in 1985. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T /IO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Well Integrity Supervisor 8/28/2011 • • Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed). 2. Perform a passing MITIA every 2 years as per AOGCC criteria (0.25 x TVD @ packer, 1500 psi minimum). 3. IA pressure not to exceed 2000 psi (40% internal yield). 4. OA pressure will be maintained as low as hydrostatic pressure allows. 5. Submit monthly reports of daily tubing & IA pressures, injection volumes, and any pressure bleeds on any annuli. 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. 7. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification Well Integrity Supervisor 8/28/2011 2 KUP 9 3F -04 ConocoPhillips We Attributes Angle & MD TD Alaska Inc Wel!bore APIIUWI Field Name Well Status Inc! ( MD (RKB) Act Btm (ftKB) ,., 500292144900 KUPARUK RIVER UNIT INJ 38.68 4,500.00 6,913.0 Comment H23 (ppm) Date Annotation End Date KB - Ord (R) Rig Release Date Well coots. - 3F - 04, 7/202010 2.0058 PM - SSSV: NIPPLE Last WO: 2/21/1997 36.80 10/14/1985 Schematic - Actual Annotation Depth (1668) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,624.0 3/6/2010 Rev Reason: QC Casing/Tubing Tallies Imosbor 7/20/2010 0 - - Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 110.0 110.0 62.58 H - 40 WELDED HANGER, 33 • Casing Description String 0... String ID ... Top (8868) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37.0 3,034.6 3,033.7 36.00 J - 55 BTC .� Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 35.0 6,862.2 6,299.4 26.00 J -55 BTC Tubing Strings I I Tubing Description String 0 ... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 3.5x2.875" I 3. 1/2 I 2.992 I 33.1 I 6,487.1 I 5,991.7 9.30 L-80 I ABM EUE Completion Details Top Depth (TVD) Top Inc! Noml... Top (1568) (RK 8) ( °) Item Description Comment ID (In) UC 6 -77 CONDTOD R, 33 33.1 0.15 HANGER FMC GEN III HANGER 3.500 3 522.8 522.8 0.27 NIPPLE CAMCO DS NIPPLE 2.812 6,114.4 5,686.5 35.81 NIPPLE CAMCO W -1 SELECTIVE PROFILE NIPPLE 2.812 NIPPLE, 523 6,152.9 5,717.8 35.57 PBR BAKER 10' strock PBR 3.000 6, 166.6 5,728.9 35.49 PACKER BAKER FHL PACKER 3.000 6,286.7 5,827.1 34.59 BLAST JT 2.992 6,453.4 5,964.2 35.12 NIPPLE AVA BPL NIPPLE 2.697 6,462.2 5,971.3 35 .11 X CROSSOVER 3112 x 2 7/8 2.992 O REDUCING SURFACE, J L 6,462.9 5,971.9 35.11 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.406 37 - 8035 6,464.0 5,972.8 35.11 PACKER BAKER DB PERMANENT PACKER 3.250 • 6,467.7 5,975.8 35.10 SBE BAKER SEAL BORE EXTENTION 3.250 GAS LIFT, ) iia 6,478.7 5,984.8 35.09 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,069 6,486.4 5,991.1 35.08 SOS BAKER SHEAR OUT SUB 2.441 - Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth NIPPLE, 6,114 III (TVD) Top Inc' Top (R103) (RKS) ( °) Description Comment Run Data ID (In) I 6,453 5,963.8 35.12 SLEEVE -O 2.75" AVA BPC 3/6/2010 2.310 6,664 6,136.6 34.69 FISH 1 1/2" DV Dropped 2/21/1997 PBR, 6,153 1 Perforations & Slots PACKER, 8,787 i Top (TVD) Btm ITVD) Shot Dens Dent FR Top (1tK6) Btm (RKB) (RKB) (RKB) Zone Date Ith ^• Type Comment 6,290 6,360 5,829.9 5,887.4 C-4, 3F -04 2/19/1997 3.0 APERF REPERF; 120 deg. phasing; SWS 4 1/2 "51BHJ INJECTION, 6,360 6,410 5,887.4 5,928.7 C-4, C-3, C-1, 2/19/1997 12.0 SQZ 120 deg. phasing; 5" HJ 11 Csg Gun 6,210 UNIT B, 3F-04 6,572 6,612 6,061.2 6,093.8 A-4, A-3, 3F-04 12/3/1985 4.0 IPERF 90 deg. phasing; 4" HJ II Csg Gun 6,632 6,670 6,110.3 6,141.5 A -2, 3F-04 12/3/1985 4.0 IPERF 90 deg. phasing; 4" HJ II Csg Gun APERF, 6.290 -6,360 Cement Squeezes 5 Top Btm Depth 8,360 -6,10 2 (TVD) VO) (TVD) Hamblin, 6,290 Top (Po(B) atm (RKB) (R103) MRS) Description Start Date Comment 6,290.0 6,410.0 5,829.9 5,928.7 Cement Squeeze 2/14 /1997 Notes: General & Safety End Date Annotation 7/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SLEEVE -0, 6453 NIPPLE, 5,453 SEAL ASSY, 6,463 PACKER, 5,464 SBE, 6,468 - - °= ME • NIPPLE, 6,479 50S, 6,486 Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run IPERF, ■ ■ Stn Top MKS) MKS) 11 Make Model (in) Sent Type Type (in) (psi) Run Date Com... 6'572 - 6'672 1 6,068.6 5,649.4 36.09 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/21/1997 2 6,210.1 5,763.9 34.43 CAMCO MMM 1 1/2 INJ DMY RK 0.000 0.0 2/21/1997 PERF, 6, I ,670 FISH, 6,664 PRODUCTION, 35.5,862N • TD, 6,913 Well Name 3F -04 Notes: Administrative Approval Application Start Date 5/21/2011 Days 90 End Date 8/19/2011 Annular Communication Surveillance 3000 WHP 1.2 IAP OAP WHT 2500 1 2000 0.8 • Q 1500 0.6 • 1000 0.4 500 - - 0.2 0 0 May -11 Aug -11 • DGI MGI -PWI SWI o •BLPD u 0.4 0.3 0.2 0.1 May -11 Jun -11 Jul -11 Aug -11 Date Page 1 of Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Monday, August 01, 2011 5:22 PM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv Subject: RE: 3F -04 (PTD# 185 -228) Report of Suspected Surface Casing Leak Tom, We have a Passing MITIA conducted 6/5/11 and a gyro on 7/8/11 that has not been analyzed yet. After the gyro analysis we should be able to rule out subsidence. The suspected, but unconfirmed leak is below 800'. The well is still shut in and an AA most likely will be the next course of action. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 (; �Ull From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, July 26, 2011 10:45 AM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj Subject: RE: 3F -04 (PTD# 185 -228) Report of Suspected Surface Casing Leak . Hi Kelly, I • . •' show that I got a response to this message? Any information on the determinations m- • - for this well? Thanks -•vance, Tom From: Maunder, Thomas E (DOA) Sent: Thursday, June 16, 2011 9:42 AM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Regg, James B (DOA); Sch - uy L (DOA) Subject: RE: 3F -04 (PTD# 185 -228) Report of Sus. ed Surfac- , - ing Leak All, Have there been any further determi - ons made on this well? Thanks in advance, Tom Maunder, PE AOGCC From: N •roblem Well Supv [ mailto :n1617 @conocophillips.com] Sent: unday, May 08, 2011 7:43 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; CPF3 DS Lead Techs; CPF3 Prod Engrs; Smith, Travis T; NSK Problem Well Supv 8/2/2011 �� Page lof � V Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.comj Sent: Wednesday, July 27, 2011 2:10 PM To: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 3F-04 (PTD# 185-228) Report of Suspected Surface Casing Leak Tom, As I recall we were unable to recreate a leak on this well, but I'm speaking from memory. I'll be back in the office next week and will provide a proper update. Regards MJ _ - �� From: NSK Problem Well Supv Sent: Wednesday, July 27, 2011 10:56 AM To: 'Maunder, Thomas E(D(]A)'; NSK Problem Well Supv Cc: NSK Well Integrity Proj Subject: RE: 3F-04 (PTD# 185-228) Report of Suspected Surface Casing Leak Tom, I'll have to defer to MJ on this one (she's out on vacation right now). We'll keep you updated when we know more. Thanks Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr 909 _ _ From. ^' nder, Thomas E(DOA) [mai|to:tonn.nlaunder@a|aaka.00v] Sent: Tues"a`, I 26, 2011 10:45 AM To: NSK Problem We "v Cc: NSK Well Integrity Proj Subject: RE: 3F-04 (PTD# 185-338 ' ' sort ofSuspected Surface Casing Leak Hi Kelly, I don't show that I got a response to this message? Any in* tion on the determinations made for this well? Thanks in advance, Tom From: Maunder, Thomas E va ^) Sent: Thursday, Jun ",Z0119:42A»4 To: NSK Pnob|'"^ ''eUSupv Cc: NSK ^ - Integrity Proj; Regg, James B (DOA); Schwartz, Guy L (DOA) Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, July 26, 2011 10:45 AM To: 'NSK Problem Well Supv' Cc: 'NSK Well Integrity Proj' Subject: RE: 3F -04 (PTD# 185 -228) Report of Suspected Surface Casing Leak Hi Kelly, I don't show that I got a response to this message? Any information on the determinations made for this well? Thanks in advance, Tom From: Maunder, Thomas E (DOA) Sent: Thursday, June 16, 2011 9:42 AM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: 3F -04 (PTD# 185 -228) Report of Suspected Surface Casing Leak All, Have there been any further determinations made on this well? Thanks in advance, Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Sunday, May 08, 2011 7:43 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; CPF3 DS Lead Techs; CPF3 Prod Engrs; Smith, Travis T; NSK Problem Well Supv Subject: RE: 3F -04 (PTD# 185 -228) Report of Suspected Surface Casing Leak Tom, The IA pressure is due to a bleed event done by the DHD crew while performing diagnostics. Please let me know if you have any more questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, April 25, 2011 9:38 AM To: NSK Problem Well Supv; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; CPF3 DS Lead Techs; CPF3 Prod Engrs; Smith, Travis T Subject: RE: 3F -04 (PTD# 185 -228) Report of Suspected Surface Casing Leak Looking at the TIO, there is a substantial increase in the volume of fluid injected into the well about early April. 7/26/2011 Page 1 of 1 S • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.comj Sent: Monday, July 25, 2011 9:07 AM To: Maunder, Thomas E (DOA); NSK Problem Well Supv Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: RE: June 2011 monthly failed MIT report 07 -24 -11 Tom, vb 5 g We have added 2L -305, 3F -04, and 3K -11. 3H -09 was removed because it was getting a RWO. I will be sending in a cancellation notice for 3H -09 in the coming days. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, July 25, 2011 8:46 AM To: NSK Problem Well Supv Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: RE: June 2011 monthly failed MIT report 07 -24 -11 Hi Kelly, I am just starting to review the document. Can you provide a list of any wells added or removed? That helps focusing my review. Thanks, Tom Maunder, PE AOGCC From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Sunday, July 24, 2011 8:33 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: June 2011 monthly failed MIT report 07 -24 -11 All, Attached is the monthly failed MIT report for the month of June 2011. Please call if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 7/26/2011 • 0 ConocoPhillips Well 3F -04 Injection Data \ • Water Injection • Gas Injection 4000 - 3500 3000 . 2500 o. • • ' a 2000 - ?� 1500 - 1000 500 0 0 2000 4000 6000 8000 10000 12000 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected Pressure (mscfpd) (psi) (psi) (bwpd) (psi) 30- Jun -11 0 0 2818 350 125 29- Jun -11 0 0 2815 350 125 28- Jun -11 0 0 2813 350 125 27- Jun -11 0 0 2787 300 125 26- Jun -11 0 0 2806 350 125 25- Jun -11 0 0 2810 350 125 24- Jun -11 0 0 2807 350 125 23- Jun -11 0 0 2806 350 125 22- Jun -11 0 0 2799 350 150 21- Jun -11 0 0 2784 350 150 20- Jun -11 0 0 2779 425 150 19- Jun -11 0 0 2775 425 150 18- Jun -11 0 0 2780 425 150 17- Jun -11 0 0 2774 425 150 16- Jun -11 0 0 2744 425 150 15- Jun -11 0 0 2755 425 150 14- Jun -11 0 0 2776 425 150 13- Jun -11 0 0 2787 425 150 12- Jun -11 0 0 2786 425 150 11- Jun -11 0 0 2794 425 150 10- Jun -11 0 0 2793 425 150 9- Jun -11 0 0 2793 425 150 8- Jun -11 0 0 2793 425 150 7- Jun -11 0 0 2792 425 150 6- Jun -11 0 0 2794 425 150 5- Jun -11 0 0 2803 600 150 4- Jun -11 0 0 2801 600 150 S ConocoPhillips Well 3F -04 Injection Data • Tbg Psi • IA Psi • OA Psi I 4000 - 3500 - 3000 - _ .y 2500 - a 2000- 1500- 1000 - -u =o 500 - 0 `'y'"' • 03/11 04/11 05/11 06/11 07/11 Date J PTD# 185 -228 Reason: SC leak Well lasted injected 4/24/11 4/22/11 SCLD with echometer showed a leak at —838' 6/5/11 state witness MITIA pass 7/8/11 gyro survey run • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, June 14, 2011 Jim Regg fl P.I. Supervisor L. en. L ( 4 11( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F -04 FROM: John Crisp KUPARUK RIV UNIT 3F -04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry \ I :IVO-- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3F -04 API Well Number: 50- 029 - 21449 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110605213130 Permit Number: 185 - 228 - Inspection Date: 6/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 3F -04 ' IT Inj. N TVD 5728 - IA 600 2400 2350 2350 .- P.T.D{ 1852280 TypeTest SPT Test psi 1500 - OA 140 140 140 140 Interval 4YRTST p/F P - Tubing 1775 1775 1775 1775 Notes: 1.7 bbls pumped for test. Well shut in at the time of test. Supervisor will determing tests validity with well shut in; "P" per J. Regg. :4s JUN 1 i 0l 1i Tuesday, June 14, 2011 Page 1 of 1 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 25, 2011 9:38 AM To: 'NSK Problem Well Supv'; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: 'NSK Well Integrity Proj'; 'CPF3 DS Lead Techs'; 'CPF3 Prod Engrs'; 'Smith, Travis T' Subject: RE: 3F -04 (PTD# 185 -228) Report of Suspected Surface Casing Leak Looking at the TIO, there is a substantial increase in the volume of fluid injected into the well about early April. While the temperature of the water (I presume produced water by the 120 degree temperature) does not substantially change, the heat input (mass rate x temperature) into the system more than doubles and appears evidenced by the increase in the IA pressure. Is the sharp IA pressure drop related to a bleed event or did a leak develop in the IA? Thanks in advance. Tom Maunder, PE w ti .ANNE AP r 6 2[]1`;i AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, April 25, 2011 9:28 AM To: 'NSK Problem Well Supv'; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; CPF3 DS Lead Techs; CPF3 Prod Engrs; Smith, Travis T Subject: RE: 3F -04 (PTD# 185 -228) Report of Suspected Surface Casing Leak Please keep us advised of the diagnostic progress. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Sunday, April 24, 2011 10:50 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 DS Lead Techs; CPF3 Prod Engrs; Smith, Travis T Subject: 3F -04 (PTD# 185 -228) Report of Suspected Surface Casing Leak Jim/Tom /Guy, Kuparuk WAG injector 3F -04 (PTD# 185 -228) is suspected of having a surface casing leak based upon a failed MITOA and Echometer diagnostics. The well will be shut in and freeze protected until approval is obtained to continue injection. CPAI plans to perform additional diagnostic tests and will submit plans for corrective action as necessary. Attached are a wellbore schematic and TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 4/25/2011 ■ I Well Name 3F -04 Notes: Report Surface Casing Leak to AOGCC Start Date 1/1/2011 Days 120 End Date 5/1/2011 Annular Communication Surveillance 3500 — — - 140 WHP IAP OAP 3000 - WHT -- a - 120 V . 1 t – - -- 100 • 2000 80 LL 1500 60 1000 - 40 %O 500 - - – 20 r 0 0 Jan -11 Feb -11 Mar-11 Apr -11 12000 ...DGI • • 10000 1 ■MGI o 8000 ��PWI 5 " a 0000 •BLPD - Fr"ViLmrr 0 V f 4000 2000 mmTh Jan -11 Feb -11 Mar -11 Apr -11 Date • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 29, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 3F -04 Run Date: 12/23/2010 • 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 3F -04 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 21449 -00 Injection Profile Log 1 Color Log 50- 029 - 21449 -00 %WINED FEB 01 2011 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 0� klinton.wood@halliburton.com Dater ry 1 Signed: . AV 3 ' 3 JVIEMORA..NDUM . State of Alaska . 'Iaska Oil and Gas Consenation Commission [0: J ¡rn Regg P.I. Supenisor -;::)7./.. I',/;d/¿¡ [ l ) \ I [: TlêSclél\ June 12.2011" '7 I SlB.JEC f: \1echal~!ca! In'~é!:r!t\ fests [\iC FROM: John Crisp Petroleum Inspector KiJPARiJK RIV U]\;[T 3F·04 . ç,cJ /ð- -yCÖ \ Reviewed Bv: ~-., '? P.I. Suprv .~~ Comm Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3F-04 Insp Num: mitJCr0706121l0947 Rei Insp Num: API Well Number: 50-029-21449-00-00 Permit Number: [ 85-228-0 Inspector Name: John Crisp Inspection Date: 6/8/2007 Packer Depth WeIl13F·04iType Inh W~TVD--,-m . 5729~; IA i- 65Ö-~ _...~. ----~--- . ~.T.DJ~2280;TypeTe~SP~ Te~s~_1500_ OA_~_ 160 . 200 ..Lnterv~'tRTST~..XI£.... __!_m~__ Tu~inffi~13=-=-_ 1365 Notes: 19 bbl's pumped for test Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. . -29~0'-¡'-;-9;0-T'--:;-9)O'-;- .---~-- . , - - i "- , ----·--~i--- -- ---" ~- 200 200 ---I ___.... .._____. '~M" _____ _..__ ___ 13ìO l380 __..__....__.____~_ ____.___._~_ ..___n_______ ._~ SCANNED JUN· ! 1 Z007 Tuesday, June 12, 2007 Page 1 of [ . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ;S(;ANNEDi SEP 0 8 2005 ~}.J6 \ßS"'~ Dear Mr. Maunder: '" Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top- fill operation was completed on August 14, 2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043,;1(YOU have any questions. /' Sincerely, 4 /11 j// 1" ;t' l / í~~~ ~/~~' ð l if .[,./'~ // I M.J.loveland ConocoPhillips Well Integrity Supervisor Attachment " . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date '. 3F;'O~1.... '," ·-18;~2.::25.. .:. .. . NA . .' .' , . '. . ! . '8ff:tlltJ:íJß· . . 3F-02 1 85-226 24' 7.0 8/14/2006 7.5 8/21/2006 ~f~~3 ' .':~ ,1:afi;t~1. ' '~'. ' 1'3'~n ' . '.'. ',... .... '.' . ' .- '. " . . '81:1;ítl2;Û(l)ß)' :··:6f2ifl~Ø.Ji~"' 3F-04 185-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 . ,3f~0$:~: ~4 . ;;. ·5.1 . ;' '. ,'. .' d~"Ì1ê4(2.º66;. ;.¡ .-. , ',11S:-·' " '. ;.i8F~~¥:2tl'~-'" .--' 3F-06 Did~OdifY . 3f-l;()7; . ,,':;J~tZ45 ",' - " .', 6;6 , 8J1:4k2.QO:Ð ..'-~ .;' 7:5 . " " . . ß/2~'¡2f¡Q6· . 3F-08 1 85-246 1 1 '4" 2.6 8/14/2006 6.6 8/21/2006 3F~Jl~;. '. ,la~2'1iO' Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21/2006 '3~f11. ':'_i "1t{5f'2fl2 " ..~. , ." ";' ';NÄ·, .. '. . , '. , 1.7 ;a'f2;J12l.1ß: , 3F-1 2 185-273 7'4" 1 .8 8/1 4/2006 6~1 8/23/2006 ~ ~ .' . '" , ~. fWO\·'·····' ..... . .c'L··--' " ';"·~/2JJff)Q:6' :' ~ Did n~ ~ ".~.".~; ,.ii· ····..··1!t5M~:::';· ; ......:..: '..' 2j~£. ... ;',.. . ':.' .' .: ::,8'/j1~f2~Ø6~::;' :fIr' f Ðõ6 : ;~3,J.2!'. '. --.- 3F-1 6 196-151 6" NA NA 2.7 8/23/2006 __ '.a.E-'1) .' ' . ~.; ..' '. ·1 ~, ' . "3l '.; : . .-: " ". '>8t1"4/2:ØQtS::' ~c--c8. .. .- ,>,; SÎ2ö~qjÐ6.: '. , '. '.' , ..,~, . . 3F-1 8 4' NA NA 28 8/23/2006 --3tr;'¡;11.9: z€t4ra1:6':·i.. '. ':,'-' . '; I\fÀ" . ,8'" , -- . (2. . · .,\. 1r2~I~øø6; '. --c .~-- 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F~21- ' ZPÓ:f203 . . "45'" . NA. -- NÄ __ - ·31 . ". sJ1f¡:2Ù€l6 . MEMORANDUM e TO: Jim ReggZ,dli 'C. IZ~/C¡-.-. P.I. Supervisor' r -l j - / ~ l FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 3F-04 Insp Num: mitCS060515060125 ReI Insp Num Packer Wcll I' 3F-04 !Type Inj. I w i TVD Ii' ~i 1852280 ¡TypeT~~T: Test psi Interval 4YRTST P/F P ~.. Notes Pretest pressures were observed and found stable. Monday, May 22, 2006 State of Alaska e Alaska Oil and Gas Conservation Commission DATE: Monday, May 22, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-04 KlTPARUK RIV UNIT 3F-04 \ £¡¡ '5 ~ Ôo 'J-- q, Src: Inspector Reviewed By: P.I. Suprv ,~ Comrn NON-CONFIDENTIAL API Well Number 50-029-21449-00-00 Inspector Name: Chuck Scheve Inspection Date: 5/14/2006 Permit Number: 185-228-0 Depth Initial 15 Min. 30 Min. 45 Min. 60 Min. Pretest I IA i 720 I ! I i . OA' 280 i ~---+----_! Tubing ¡ 1350 I 5729 2130 2100 2100 I 280 280 i : 1500 280 1350 -,-- 1350 ! 1350 - Well demonstrated good mechanical integrity. . '!t"" NAiE~- .. '''1 ;j"", d'! L' .,)!j r~ 1. D 200S Page I of I Re: 2006 witnessed MITIA's 'Vi I still have some concerns about KRU ~/ C} \CfJ V Thanks for the clarification about KRU 3F-04 pressures. 2K-03 (PTD 1881200). AIO 2B, Rule 7 requires: "Whenever operating pressure observances or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action, and when an USDW is not endangered, obtain Commission approval to continue injection." I have reviewed our well files and find no notice of pressure communication or leakage, and no record of a waiver for KRU 2K-03. Please send a no plot for KRU 2K-03, well schematic, and copy ofthe internal waiver you are using to allow continued water injection in the well. Jim Regg AOGCC NSK Problem Well Supv wrote: Jim, Yes 3F-04 casing pressure after 30 minutes should read 2100 psi. It appears I omitted a zero when transposing the data. My apologies. I've attached a corrected MITIA form. With regard to 2K-03, is a waivered well for IA x OA communication and has been limited to water injection since 2/1/04. The well is most likely not on your monthly monitoring list because it hasn't failed a MIT. Sorry for the confusion regarding 3F-04. Let me know if you have any other questions. Sincerely, ~~\Nl'Ì·EL; Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 .state.ak.us lof2 5/16/20061:50 PM Re: 2006 witnessed MITIA's e To: NSK Problem Well Supv Subject: Re: 2006 witnessed MITIA's e 3F-04; casing pressure @ 30 minutes should be 2100 psi? 2K-03; test report shows 1250 psi on the OA; an explanation would be in order; well is not on our monthly monitoring list Jim Regg AOGCC NSK Problem Well Supv wrote: All, Enclosed are the MITIA forms from yesterdays testing. Sincerely Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 «MIT KRU 3G-20 05-14-06.xls» «MIT KRU 2K PAD 05-14-06.xls» «MIT KRU 2G-03 05-14-06.xls» «MIT KRU 3F-04 05-14-06.xls» «MIT KRU 2W PAD 05-14-06.xls» «MIT KRU 1C-22 05-14-06.xls» «MIT KRU 1R-36 05-14-06.xls» «MIT KRU 3K-08 05-14-06.xls» > 2 of2 5/16/2006 1 :50 PM Schlumberger NO. 3429 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: <~·lt·¡·r\F'~'~, t·=¡= (\ .;':¡ "'00= r~\dIMJ,,\~t'.Lj ,) r_ ¡) V \] ¿ 15 Field: Well Job# Log Description Date BL ~ 2G-02 11> '{ -j). f 11047334 BHP SURVEY 06/30105 1 , 2G-13 (~:¡ - i)'~1 11047336 BHP SURVEY 07101/05 1 J. 2G-11 If'" -if7 11047337 BHP SURVEY 07101105 1 y 1Y-14)3~~ 01\ 11022907 LEAK DETECTION LOG 06/30105 1 'J 3H-19/87 .1)) 11022907 PRODUCTION PROFILE 06/28/05 1 \/, 1J-03 ~~Gí - c). <t 11022893 PRODUCTION PROFILE 06/17/05 1 .J 1L-09 ItjD.·~jC{ 11022895 PROD PROFILE W/DEFT 06/19/05 1 ./, 3S-10 ).0).-131 11001235 PROD PROFILE W/DEFT 06/14/05 1 .J 3F-04 ¡/j:J". ;1..18 11022891 INJECTION PROFILE 06/15/05 1 1Y-26A ¡33'lt~ 11022892 PROD PROFILE W/DEFT 06/16105 1 ;./ 1E-112Jyi..j -Ü11 11047339 INJECTION PROFILE U l (, 07/03105 1 j 1E-102 .Àv'1""¡31 11047340 INJECTION PROFILE vtC 07/04/05 1 SIGNED: vJ/~J Iii '. DATE: I. I ÔüJ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/08/05 \ C?5 / ;;l 'J-~ Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color .~ CD -' . I ';}, ("" \". L ~f- :¿ N. ,j" --.. _ ryV\¡ {j ij STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 6. Dalum elevation (DF or KB feet) Phillips Alaska, Inc. RKB 93 feet 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Loca§on of well at surface 56' FNL, 5184' FEL, Sec. 29, T12N, R9E, UM 5. Type of Well: Development Exploratory _ Strat~jrephic __ Servi~___X (asp's 508593, 5985765) 7. Unit or Property name Kuparuk Unit 8. Well number 3F-04 At top of productive interval 1196' FNL, 1124' FWL, Sec. 29, T12N, R9E, UM At effective depth 1455' FNL, 3914' FEL, Sec. 29, T12N, R9E, UM (asp's 509870, 5984367) 12_ Present well condition summary -i'otal depth: measured true vertical 6913 feet Plugs (measured) 6341 feet 9. Permit number / approval number 185-228 / 10. APl number 50-029-21449 11. Field / Pool Kuparuk Oil Pool Effective depth: measured ~ feet Junk (measured) true vertical feet Casing Lenglh Size Cemented Measured Depth CONDUCTOR 110' 1 6" 274 sx AS II 1 1 0' SURF, CASING 2942' 9-5/8' 800 sx PF E & 260 sx PFC 3035, PROD. CASING 6769' 7' 305 sx Class G & 250 sx PFC 6862' Packers & SSSV (type & measured depth) ............................................................................................................................... True vertical Depth 110' 3034' 6299' Alasl~a Oil & Gas Cons. Commi~ion Aritho'age 13. Stimulation or cement squeeze summary Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ~X OiI-Bbl Representative Daily Avera~qe Production or Injection Data Gas-Md Water-Bbl Casing Pressure Tublr ... ... 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sig. ed "',~~.__ ,~"~' Ti.e Production Engineering Supervisor Jeff A. Spencer Questions? Call Jeff Spencer659-7226 Prepared by Robert Christensen 659-7535 .. : . 3F-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary MEMORANDUM TO: David J o h'---h~o n? Chairman THRU: Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 9, 1997 FILE NO: acvlbied.doc FROM: John Spaulding, .%~. SUBJECT: Petroleum lnsp. BOPE Test Nordic #2 ARCO KRU / 3F-04 Kuparuk R. O~ PTD 85-228 Sunday February 9, 1997' i witnessed the BOPE Test on Nordic Rig 2 at ARCO's KRU well 3F-04. The AOGCC BOPE Test Report is attached for refence. Testing went quite well with no failures observed. The area around the rig was well laid out with good access to the rig from both sides. The Kelly valves will be ~ when picked up. Summary: I witnessed the BOPE Test on NORDIC Rig 2, 18 valves, 4 hour test time. Attachments: acvlbied X Unclassified Confidential (Unclassified if document removed) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial ARCO Workover: X NORDIC Rig No. 2 PTD # 85-228 Rep.: Rig Rep.: 6,862' Location: Sec. 3F-04 7" Set @ X Weekly Other DATE: Rig Ph.# Don Breeden 2/9/97 659-7115 Shane Mc Geehan 29 T. 12N R. 9E Meridian Umiat MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location yes Standing Order Posted yes BOP STACK: Quan. Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves '/ HCR Valves Kill Line Valves 2 Check Valve (Gen) Well Sign ok Drl. Rig ok Hazard Sec. yes Test Press. P/F 500/3,000 P 500/3500 P 5OO/35OO P 500/3500 P 500/3500- P 500/3500 P 500/3500 P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 500/3500 500/3500 2 500/3500 P 1 500/3500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 12 Test Pressure P/F 500/3500 P 36 500/3500 P I P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,000 P Pressure After Closure 2,400 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 19 Trip Tank ok ok System Pressure Attained minutes 45 Pit Level Indicators ok ok Blind Switch Covers: Master: yes Remote: Flow Indicator ok ok Nitgn. Btl's: 4 ea. @ 2150 avg. Meth Gas Detector ok ok . Psig. H2S Gas Detector ok ok sec. sec. yes :: i :~: :i :: ~ :i :~ :~ ~ TEST RESULTS Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 18 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File C- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X - NO Waived By: Witnessed By: FI-021L (Rev. 12/94) ACVLBIED.XLS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 5, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-04 (Permit No. 85-228) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent workover operations on KRU 3F-04. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad ~vl~iR 0 ~ 1997 Aiask~ Oii& ~gas Cons, Commission 'Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION C,.,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ' Class'ificati°n'0f S~r~i~e ~el'l "' [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 85-228 3. Address ............. 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-21449 - (~(~ ' 4. 'Location of well at surface ................................ ~" 9. Unit or Lease Name 59' FNL, 93' FWL, Sec. 29, T12N, R9E, UM ~ Kuparuk River Unit At top of productive interval ,,.~, ~.,,~.~ 10. Well Number 1196' FNL, 1124' FWL, Sec. 29, T12N, R9E, UM~ 3F-04 At total depth ,I ...... '~ i~ Field and pool " ' 1458' FNL, 1369' FWL, Sec. 29, T12N, R9E, UM Kuparuk River 5~---Eie~a~ior~ in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 93' RKBI ADL 25643 ALK 2574 i12. Date Spudded i13. Date T.D. Reached ! 14. Date Comp., Susp., or Aband,115. Water depth, if offshore 116. No. of Completions i 10/09/85 i 10/13/85 2/21/97 N/A MSLJ Two [17. Total Depth (MD+TVD) ! 18. Plug Back Depth (MD+TVD)~19, Directional Survey]20. Depth where SSSV set~21. Thicknes,s of Permafrost '. ............ _6__91_3~ .... 6340 F-~ 6772 6225 F~ I-lYes []No I N/A MD! 1650 (Approx.)_ !22. Type Electric or Other Logs Run __ _ 23. CASING, LINER AND CEMENTING RECORD (~SiNG '" i SETTING DEPTH i H~'~_E ........ SIZE VVT. PER FT. GRADE TOP BO'FrOM __ SIZE ._ CEMENTING RECOR_D ...... AMOUNT_PULL. ED 16" 62.5# H-40 Surf. 115' 24" 274 sx AS II 9.625" 36.0# J-55 Surf. 3035' 12.25" 800 sx PF 'E' & 345 sx PF 'C' 7" 26.0# J-55 Surf. '6862' -----~-~;~ ..... 320--~ O-f~S i2 8,-i75-~ PF-'-C-' , __ _ : ..... : ....... ..... , ......... ~ .......... ...... 24.'PerfOrations open to ProduCtion (MD+TVD Of Top ~d Bottom '25. - TUBING REC'ORD ..... and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" X 2.875" 6487' 6167' & 6464' MD TVD MD TVD ........................................................................... 6290'6360' 5829'-5887 .................... down-squeezed 26. Ac~D, FRACTURE, CEMENT SQUEEZE, ETC. and reperfed) ..... 2.5 spf DEPTH iNTERVAL (MD) AMouNT & K~ND OF MATER~^L USED 6572'-6612' 6060'-6093' 6290'-6410' down-squeezed perfs during workoverq 6632'-6670' 61 lO'-6141' 4 spf ........... 27:' ' pRoDucTioN TE ~-"1- .,' Date First ProduCtion :.~iMethod of OPeration (FIo'~ing, gas lift, etc.) <:? i Water Injection Date of Test iHours Tested PRODUCTION FOR OIL-DEL ~,~Mc~- ...... ~/A~-I~-B~- .... '(~'I~'(~KE SIZE J GAS'Oii~"RA'ri0 ......... ....................... i ................... _T~-ST_ _e~?_°~_; ..................................... I ! Flow TubinglCasing PressurelCALCULATED · i OIL-DEL .... (~As-M-~F ......... i'W-,~':I:[F[:-B-@I_' ......... [-Oi[-~-~,'~i~:~':'A'J~-I (-(~Siqi~i ..................................... pr..e..ss, i ... ~24-HoURRATE .. ....... J ........ i ............ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas ~)-i--water. Submit core chips. ,~t'~ 0~ 1997 ..................................... ~,~~,. n~ ~. r.~ Cons. commission Form 10-407 Rev. 07-01-80 Anchorage Submit In Duplicate 29. Geologic Mar!/~' 30. ~"'-' Formation Tests ,, Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. , ,, , 31. List of Atta~h'~ent~ ' Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge l ,.. _ ~...~r~___~.,,? .,,.~.,,..:~_.... .......... T!!.!e OIt,/.~.tt'¢..~C E~-EY.t~ Date Prepared By Name/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ~AR 0 7 ]997 Oil & Gas Cor~s. Commissior.., Anchorage Date: 3/5/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3F-04 RIG:NORDIC WELL ID: 998711 TYPE: AFC:--998711 AFC EST/UL:$ 762M/ 898M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:02/07/97 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21449-00 02/07/97 (C1) TD: 6913' PB: 6772' SUPV:DEB DAILY:$ 02/08/97 (C2) TD: 6913' PB: 6772' SUPV:DEB DAILY:$ 02/09/97 (C3) TD: 6913' PB: 6772' SUPV:DEB DAILY:$ 02/10/97 (C4) TD: 6913' PB: 6772' SUPV:DEB DAILY:$ 02/11/97 (C5) TD: 6913' PB: 6772' SUPV:DEB DAILY:$ 02/12/97 (C6) TD: 6913' PB: 6772' SUPV: DEB DAILY:$ 02/13/97 (C7) TD: 6913' PB: 6772' SUPV:DEB LEVEL RIG MW: 0.0 Move rig from 3F-08 to 3F-04. Accept rig @ 0530 hrs. 2/7/97. 31,383 CUM:$ 31,383 ETD:$ 0 EFC:$ 793,383 MONITOR WELL - LOADED W/S MW: 8.5 SW While connecting up hardline from rig choke to production flowline and upright tank, a serious incident occurred which caused the top of the tank to blow off. Secured well and shut down operation to evaluate incident and start SIR investigation. No injuries. Resume rig operations and start to kill well. 40,510 CUM:$ 71,893 ETD'$ 0 EFC:$ 833,893 TESTING BOPE - REMOVE CHO MW: 0.0 NACL Load tubing with brine to kill well. Monitor well, well dead. Test blowout preventer equipment. 50,075 CUM:$ 121,968 ETD:$ 0 EFC:$ 883,968 FISHING TUBING W/BLAST RI MW:ll.1 NACL Test BOPE. OK. POH 3.5" tubing and jewelry. RIH with fishing tool assembly %1. 34,900 CUM:$ 156,868 ETD:$ 0 EFC:$ 918,868 POH W/FTA %2 MW:ll.1 NACL Work overshot and latch onto fish. POH with fish. RIH with FTA #2 and pull fish free. POH with FTA %2. 85,779 CUM:$ 242,647 ETD:$ 0 EFC:$ 1,004,647 MONITOR WELL MW:ll.3 NACL POH with FTA %2 and fish. RIH with FTA %3. Mill out packer at 6450' Packer broke free, pushed down hole with kelly. Monitor ~ell. Flow slowing. Shut in well. Weight up Thixsal brine to 11.3 ppg. Circulate Thixsal around. Monitor well. Well dead. 43,184 CUM'$ 285,831 ETD.$ 0 EFC:$ 1,047,831 MW:ll.3 NACL Well dead, slow loss. Fill hole thru drillpipe & annulus. POH w/FTA %3. LD mill & boot baskets. MU FTA #4 (4" spear) RIH. Transfer brine from upright tank to pits & condition to 11.3 ppg. PU Kelly. Break circulation. Tag fish @ 6609' and engage spear into packer bore. Circulate Date: 3/5/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 DAILY:$ 02/14/97 (C8) TD: 6913' PB: 6772' SUPV:DEB DAILY:$ 02/14/97 (C9) TD: 6913' PB: 6772' SUPV:DEB DAILY:$ 02/15/97 (C10) TD: 6913' PB: 6772' SUPV:DEB DAILY:$ 02/16/97 (Cll) TD: 6913' PB: 6772' SUPV:DEB DAILY:$ 02/17/97 (C12) TD: 6913' PB: 6772' SUPV:DEB DAILY: $ 02/18/97 (C13) TD: 6913' PB: 6772' SUPV:DEB DAILY:$ 02/19/97 (C14) TD: 6913' ?B: 6772' SUPV'DLW DAILY:$ bottoms up, slow pump from 2 BPM to 1 BPM to minimize losses. Monitor Dead, well dead. Install head pin and pump slug. Hold safty meeting. POH w. FTA %4, slow to minimize swabbing. 75,679 CUM:$ 361,510 ETD:$ 0 EFC:$ 1,123,510 MW: 9.7 NACL Tripping in. RU circulating lines. Cleaning pits with seawater. Circulating with brine. Monitoring. 50,624 CUM:$ 412,134 ETD:$ 0 EFC:$ 1,174,134 MW:10.7 NACL Well shut in. Displace well to 9.9 ppg brine, 3.5 BPM. Pre-job safety meeting. Displace well to 11.3 ppg brine, 3 BPM. Monitor well. Establish injection rate. Pump 24 Bbls of batch mixed cement. Circulate. Close bag. Hesitatio squeeze. Cement only showed slight pressure increase. 118,339 CUM:$ 530,473 ETD:$ 0 EFC:$ 1,292,473 CIP IN 2ND STAGE SQUEEZE MW:10.7 NACL Bleed off pressure. Estimated TOC @ 6150'. Bread upper & lower Kelly valves. Service rig. Tag cement 6389' Drill firm cement from 6389' to 6417' Circulate hole clean. Test squeeze job. Safety meeting with both crews. Tag cement @ 6417' 32,710 CUM:$ 563,183 ETD:$ 0 EFC:$ 1,325,183 MW:10.7 NACL Pre-job safety meeting. Cement and then test lines. Squeezing. Pull wear ring. Set test plug. Tag cement 6160' Circulate out cement contaminated water spacers. Test casing. Drill out cement from 6160' to 6216' & drilling ahead. 54,634 CUM:$ 617,817 ETD:$ 0 EFC:$ 1,379,817 MW:ll.3 NACL Drill out cement from 6216' to 6415' Circulate. Test squeeze. Drill cement to 6423' Circulate hole clean. Load 230 Bbls Thixsal brine into pits. Drill cement to 6428'. Drill out CIBP from 6428' to 6430'. 42,681 CUM:$ 660,498 ETD:$ 0 EFC:$ 1,422,498 TRIP FOR BIT & SCRAPER MW:ll.6 NACL Continue to push CIBP down hole to 6500' well started to flow. Monitor well. Circulate on choke. Monitor well, well dead. Continue to push CIBP down well. Pump dry job, POOH slowly to minimalize swabbing. 132,283 CUM:$ 792,781 ETD:$ 0 EFC:$ 1,554,781 REPERF 'C' SAND 4-1/2" CS MW:ll.6 NACL POOH slowly to minimalize swabbing. RIH to 6610' Fluid loss about 8 BPH while circ. Monitor well, well dead. Rig floor safety meeting. Continue to L/D DP & BHA. 34,631 CUM:$ 827,412 ETD:$ 0 EFC:$ 1,589,412 1997 Date: 3/5/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 02/20/97 (C15) TD: 6913' PB: 6772' SUPV:DLW DAILY:$ RUNNING 3-1/2" COMPLETION MW:ll.6 NACL Pull wear ring. Rig floor safety meeting. SWS run gauge ring. Junk Basket to 6295'. Change gauge ring to 5.8" RIH to 6666' POOH recover small cement. Set PKR top @ 6464' correlate R/D SWS Lubricator, N/U flow nipple & flow line. Pre job safety safety meeting. Running 3-1/2" completion. 113,714 CUM:$ 941,126 ETD:$ 0 EFC:$ 1,703,126 02/21/97 (C16) TD: 6913' PB: 6772' SUPV:DLW DAILY:$ DISPLACE THIXSAL MUD W/SE MW: 8.5 Continue to run 3.5" tubing. Freeze protect well. SW 54,638 CUM:$ 995,764 ETD:$ 0 EFC:$ 1,757,764 02/22/97 (C17) TD: 6913' PB: 6772' SUPV:DLW DAILY:$ RELEASE RIG MW: 8.5 SW Test tubing and annulus to 2500 psi for 15 min. OK. Secure well. Move rig off hole. Released rig @ 1400 hrs. 2/22/97. 31,568 CUM:$ 1,027,332 ETD:$ 0 EFC:$ 1,789,332 End of WellSummary for We11:998711 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown~ Stimulate ~ Pull tubing Alter casing Repair well 2. Name of Operator I 5. Type of Well: Development ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service X 4. Location of well at surface 59' FNL, 93' FWL, Sec 29, T12N, R9E, UM At top of productive interval 1196' FNL, 1124' FWL, Sec 29, T12N, R9E, UM At effective depth 1402' FNL, 1311' FWL, Sec 29, T12N, R9E, UM At total depth 1458' FNL, 1369' FWL, Sec 29, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 6 91 3 feet true vertical 6340 feet Plugging Perforate Other X 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-04 9. Permit number/approval number 85-228/95- 1 87 1_.0. APl number 5o-029-21 449 11. Field/Pool feet Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 6772 feet true vertical 6225 feet Junk (measured) None Casing Length Size Cemented Structural Conductor 7 8' I 6" 274 SX AS II Surface 341 7' 9.625" 800 SX PF E & Intermediate 260 SX PFC Production 6827' 7" 305 SX Class G & Liner 250 SX PFC Cmt. Perforation depth: measured 6290'-6410', 6572'-6612', 6632'-6670' · _ _ true vertical 5830'-5928', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 6470' Packers and SSSV (type and measured depth) PKR: 6061 '-6094', 6110'-6141' Measured depth True vertical depth 115' 115' 3 4 5 4' 3450' 6862' 629~' Baker FHL @ 6186' & Baker FB-1 @ 6447'; SSSV: Camco TRDP-1A-SSAf'"~':":~ /~; ?;ii',~t'?!, 'i 13. Stimulation or cement squeeze summary 'C' sand Marcit profile modification. Intervals treated (measured) 6290'-6410' Treatment description including volumes used and final pressure Pumped 7420 bbl polymer, max conc. 6000 ppm, final pumping pressure - 960 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 4684 1000 843 Subsequent to operation 0 0 1129 250 825 15. Attachments Job Summary Copies of Logs and Surveys run __ Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service H20 Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendant Date 4//~£½~/ SUBMI'I~IN DUP~.ICATE Attachment 1 3F-0Zt Marcit Polymer Profile Modification Job started downhole 14:00 AST on November 9th, 1995. - 333 bbls - Sea water - 50 bbls - 3,000 ppm polymer - 3,400 bbls- 4,000 ppm/91 ppm polymer/xlinker (44:1) - 1,400 bbls- 4,000 ppm/100 ppm polymer/xlinker (40:1) - 570 bbls- 5,000 ppm/125 ppm polymer/xlinker (40:1) - 1,900 bbls - 6,000 ppm/150 ppm polymer/xlinker (40:1) - 100 bbls - 6,000 ppm polymer - 100 bbls - Sea water o 30 bbls - Diesel Finished 19:15 AST November 13th, 1995. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Tvoe of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well_ Plugging _ Time extension_ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Expioratory _ Stratigraphic _ Service X 4. Location of well at surface 59' FNL, 93' FWL, SEC.29, T12N, R9E, UM At top of productive interval 1196' FNL, 1124' FWL, SEC.29, T12N, At effective depth 1402' FNL, 1311' FWL, SEC.29, T12N, At total depth 1458' FNL, 1369' FWL, SEC.29, T12N, R9E, UM R9E, UM R9E, UM Present well condition summary Total Depth: measured 6 91 3' true vertical 6 3 4 0' 12. Effective depth: measured 6 7 7 2' true vertical 6 2 2 5' 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-04 feet feet feet feet feet Plugs (measured) Junk (measured) 9. Permit number/approval number 85-228 / 10. APl number 50-029-2144900 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 115' 1 6" Surface 3 5 3 5' 9 - 5 / 8" Intermediate Production 6 8 2 7' 7" Liner Cemented 274 SX AS II 800 SX PF E & 260 SX PFC 305 SX CLASS G & 250 SX P F C Measured depth True vertical depth 115' 115' 3454' 345O' 6862' 6299' Perforation depth: measured 6670'-6632', true vertical 61 41-6110', Tubing (size, grade, and measured depth) 3-1/2" J-55 w/TAIL @ 6470' 6612'-6572', 6094'-6061', 6410'-6290' 5928'-5830' OCT 2 b 1995 ;~,laska (J~l & Gas Cons. Commission Packers and SSSV (type and measured depth) BAKER FHL PKR @ 6186', BAKER FB-1 PKR @ 6447'/CAMCO TRDP-1A-SSA ~'~i~t:~e 13. Attachments Description summary of proposal Profile Modification using MARCIT Treatment. Detailed operation program BOP sketch 14. Estimated date for commencing operation November 1995 16. tf proposal was verbally approved Date approved 15. Status of well classification as: Oil Gas Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~,, ~ Title Wells Superintendent FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance __ Mechanical Integrity Test _ Subsequent form require Approved by order of the Commission Form 10-403 Rev 06/15/88 uav/r.l W. ,Johnston'., 10-_,~ved Copy Returned Commissioner Date IApprc/al._.No.,,-r~ SUBMIT IN TRIPLICATE Attached is Sundry application to inject MARCIT gel into the prolific watered out C1 interval in Well 3F-04. MARCIT is MARathon Oil 'Company's Conformance Improvement Treatment and consists of a polyacrylamide crosslinked with chromic acetate for treating a variety of conformance problems in both injection and production wells. The MARCIT gel technology was selected based on robust gel chemistry, controllable gellation rates and field successes in treating fractures, matrix or both. A successful Marcit treatment was pumped in 11/94 on Producing Well 3F-02 that increased the total oil production by 450 BOPD. The A Sand will be isolated during the treatment. The C Sand perfs open to the treatment are 6290' - 6410' MD-RKB. The goal of this treatment is a reduction in the water relative permeability of the C1 thief interval. If achieved, the treatment would reduce the amount of water entering the thief zone and divert the waterflood to unswept pore volume in the C34 Sand. STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed' Operation Shutdown__ Pull tubing Alter casing Stimulate M Plugging Perforate _ Repair well X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic ,Service 4. Location of well at surface 59' FNL, 93' FWL, Sec. 29, T12N, R9E, UM At top of productive interval 1196' FNL, 1124' FWL, Sec. 29, T12N, R9E, UM At effective depth 1398' FNL, 1313' FEL, Sec.29, T12N, R9E, UM At total depth 1458' FNL, 1369' FWL, Sec. 29, T12N, R9E, UM 12. Present well condition summary 6. Datum elevation (DF or KB) 93' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-4 9. Permit number/approval number 85-228 10. APl number 50-029-21449 11. Field/Pool Kuparuk River Oil Pool Total Depth: measured 6 91 3' feet true vertical 634 0' feet Effective depth: measured 6 7 7 2' feet true vertical 6 2 2 5' feet Casing Length Size Structural Conductor 8 2' I 6" Surface 3 5 0 2' 9 5/8" Intermediate Production Liner Perforation depth: 6829' 7" measured Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 274 Sx AS II 1 1 5' 1 1 5' 800 Sx PF E & 3535' 3529" 345 Sx PFC 250 Sx Class G & 6862' 6298" 180 Sx PFC 6290'-6410', true vertical 5829'-5928', 6572'-6612' 6061 '-6093' 6632'-6670' 6110'-6141' RECEIVED Tubing (size, grade, and measured depth) 3 1/2" J-55 w/ tbg tail at 6470' Packers and SSSV (type and measured depth) Baker FHL @ 6186', Baker FB-1 @ 6447', Camco SSSV @ 1805' 13. Stimulation or cement squeeze summary S E P 2 ? t 91 Alaska Oil & Gas Cons. Commisstan Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Inje(~tiQn Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure -0- 0- 5000 1800 -0- -0- 5000 650 Tubing Pressure 1400 1400 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .- Title ~A' ;~fi'~ ~~~'"~' ~'"SUBMIT ,~ DUPLICATE Form 10-404 Rev 09/12/90 ~ARCO Alaska, Inc. WELL IPBDT ~lf.q I ~777.. tRACTOR WELL SERVICE REPORT JFIELD - DISTRICT- STATE JOPERATION AT REPORT TIME SUMMARY CONTINUED ON BACK A~CO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 24, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following well. Well Action 3F-04 Repair Well Anticipated Start Date September, 1991 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer W. H. Carter ATO 1120 KOE1.4-9 w/o attachments RECEIVED SIP 2 ? 1991 Ab~ka 011 & 6as Cons, Commission Anchor-ace ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C STATE OF ALASKA 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 _ Re-enter suspended well _ ~x 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 Exploratory Stratigraphic Service 4. Location of well at surface 59' FNL, 93' FWL, Sec. 29, T12N, R9E, UM At top of productive interval 1196' FNL, 1124' FWL, Sec. 29, T12N, R9E, UM At effective depth 1398' FNL, 1313' FEL, Sec.29, T12N, R9E, UM At total depth 1458' FNL, 1369' FWL, Sec. 29, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 8 2' Surface 3 5 0 2' Intermediate Production 6 8 2 9' Liner Perforation depth: measured 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-04 feet 9. Permit number 85-228 10. APl number 5o-029-21 449 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 691 3' feet Plugs (measured) 6 3 4 0' feet None 6772' feet Junk (measured) 6 2 2 5' feet None Size Cemented Measured depth True vertical depth 1 6" 274 Sx AS II I 1 5' 1 1 5' 9 5/8" 800 Sx PF E & 3535' 3529" 345 Sx PFC 7" 250 Sx Class G & 6862' 6298" 180 Sx PFC 6290'-6410', 6572'-6612', 6632'-6670' true vertical 5829'-5928', 6061'-6093', 61 10'-6141' Tubing (size, grade, and measured depth) 3 1/2" J-55 w/ tbg tail at 6470' Packers and SSSV (type and measured depth) Baker FHL @ 6186', Baker FB-1 @ 6447', Camco SSSV @ 1805' RECEIVED S E P 2 ? t991 Alaska 011 & Gas Cons, C0mmtsst0n Anchorage 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch _ 15. 14. Estimated date for commencing operation ASAP 16. If..,,l~roposal ~{a..s ver~)ally approved Name of approveK. J' Date approved Status of well classification as: Oil Gas Suspended Service Water Iniector 17' ' h~/~b:rt/~Y.~)at~istrueand~rrectt°thebest°fmykn°wledge' ~~ Signed -tr(~r,/"~,g.~. Title ,,,-~l~J~ 0~.~/'7.~'~'~'~-'~ Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may Witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by order of the Commission ORIGINAL SIGNED BY LOIVNIE C_ SMITH lO-~o~eC~ C,,O~"J Form 10-403 Rev 09/12/90 IApprg.v~l No. SUBMIT IN TRIPLICATE Injection Well 3F-4 ARCO Alaska request permission to continue operating Well 3F-4 as is while we perform diagnostic work to determine the source of pressure communication between the tubing and 7" casing. Plans are to replace the packing on the 1-1/2" dummy valve (this is the only mandrel in the tubing string above the top packer). If this is not successful, we plan on shutting in C Sand injection, injecting A Sand only, and monitoring the 7" pressure to test the top packer. RECEIVED S E P ~ ? t991 Alaska 0il & Gas Cons. CommissIon Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 2, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 of Conservation Order No. 198, Kuparuk River Field Waterflood Rules, we are forwarding the blue line and sepia copies of the spinner logs referenced in our previous submittal of April 30. If you have any questions concerning the information reported, please contact me at 263-4978. Sincerely, S. E. Schmidt Operations Engineer SES:DLG Enclosure '~'~ ~ F ~ ARCO Alaska, Inc- is a Subsicl|Jry)of AllanticRichfieldCompany i //"). , ~ _...-,, -,.-'ir 'i. AR3B-6003-C ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-11 3H-12 3 O- 0 7 Kuparuk Well 3 F- 1 0 Kuparuk Well 3 F- 0 6 Kuparuk Well 3 F- 0 2 Kuparuk Well 3 F- 1 6 Kuparuk Well 3 F- 1 6 Kuparuk Well 3 F- 1 I Kuparuk Well 3 F- 0 4 Kuparuk Well 3 F- 0 5 Kuparuk Well 3 F- 1 3 Kuparuk Well 3 N- 1 0 Kuparuk Well 3 N - 1 0 Kuparuk Well 3 N - 0 4 Kuparuk Well 3 N - 0 9 Kuapruk Fluid 30-1 4 Kuparuk Fluid 3 O- 1 4 Kuparuk Fluid 3 M - 1 8 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 3 Kuparuk Fluid 3 F- 1 3 Kuparuk Fluid 3 F- 1 3 Kuparuk Fluid 3 F- 1 3 Kuparuk Fluid' 3 F- 0 8 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 3 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 6 Kuparuk Fluid 3 F- 1 4 Kuparuk Fluid Sub-Surface Pressure Survey Kuparuk Well Pressure Re3ort Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Pressure Re Level Report Level Report Level Report Level Report Level Re 30rt Level Re 30rt Level Re 30rt Level Re 30rt Level Re 30rt Level Re 30rt Level Re 30rt Level Re 30rt Level Re 30rt Level Re :)ort Level Re :)ort Level Re :)ort Level Re 30rt 10-06-88 #7-889 8 - 29 - 88 Amerada 3ort I 2 - 20 - 88 Sand 'A' 3orr 8 - 29 - 87 Amerada 3orr 8 - 29 - 87 Amerada 3oft 8 - 29 - 89 Amerada 3orr 8 - 1 7 - 8 7 Sand 'A' 3ort 8 - 17 - 87 Sand 'A' 3oft 8 - 2 9 - 8 7 Amerada :)od 6 - 26 - 87 Sand 'A' 3ort 12-12-88 3od 1 2-31 -88 3orr 6-1 I-87 3ort 6-11 -87 3orr 9- 01 - 87 5-04-87 2-13-89 2-1'0-89 2-10-89 6-05-87 6-09-87 6-18-87 6-16-87 6-21 -87 5-08-87 8-18-87 8-24-87 6-05-87 6-2/3-87 8-5-87 6-5-87 9-8-87 Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casing Anchorage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3No18 '3N-17 3N-07 3N-15 3N-05 3N-09 3N -04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Ku :)aruk Ku ~aruk Ku~aruk Ku,~aruk Ku~aruk Ku ~aruk Ku~aruk Ku ~aruk Ku ~aruk Ku~aruk Ku~aruk Ku~aruk Ku~aruk Kuaaruk Ku~aruk Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Acknowledged: Level Level Level Level Level Level Level Leyel Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Report Report Report Report Report Report Report Report Report Report Report Report Report Re ~ort Re ~ort Re ~ort Re ~ort Re~ort Re~ort Re ~ort Re ~ort Re :)ort Re ~ort Re aort Re ~ort Re ~ort Re aort Re ~ort Re aort Reaort Re )orr Re )orr Re )ort Report Report Report Report Report Report Report Report Report 9-1i-87 12-06-86 9-11-87 10-1 I -87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 I -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-01 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 .6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 6-17-87 6-20-87 5-07-87 8-24-87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing / Alaska Oil & Gas Conj. ....... ¢~r/c~o rag e DISTRIBUTION: D&M State of Alaska -- Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1987. The data is provided in the form of spinner logs or separate zone surveys as listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have an~ questions concerning the information reported, please contact me at (907) 263-4262. Sincerely, B. B. Berg Operations Engineer BBB/SPT:pg:O069 Attachments Naska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichlieldCompany ATTACHMENT 1 PAGE 1 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES FIRST QUARTER 1987 SUBMITTAL WELL APl DATE OF DATE OF DATA TYPE REASON FOR NUMBER NUHBER INITIAL PROFILE/ PROFILE/ PROFILE/ 50-029 INJECTION SURVEY SURVEY ~URVEY "~2C-03 20968 ~"'2C-O~ 20973 '?~'2D-05 21157 ">L~2W-05 21208 ";>~"2U-O8 21228 '"'~'~2X-O2 20982 "~.2X-O3 20987 "~--'~2X-O6 20988 ~3F-O~ 21~9 ~'~3F-07 21h63 12/12/85 11/09/85 11/09/85 11/22/85 11/15/85 11/19/85 11/04/85 11/04/85 05/04/86 05/06/86 02/03/87 02/01/87 02/04/87 03/05/87 03/06/87 02/07/887 03/02/87 03/04/87 02/08/87 O2/O9/87 SPINNER SP NNER SP NNER SP NNER SP NNER SP NNER SP NNER SPINNER SPINNER SPINNER WELL COMPLETION FOLLOWUP A&C S FOLLOWU P A&C S FOLLOWU P A&C SS FOLLOWUP A&C SS FOLLOWU P A&C SS FOLLOWU P A&C SS FOLLOWU P A&C SS FOLLOWU P A&C SS INITIAL A&C SS INITIAL A&:C SS ZONES TAKING WATER A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C INJECTION BWPD · Alaska 0il & Gas Cons. Commission Anchorage STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COiv,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVIC~ WATER INJECTOR , , , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-228 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21449 4. Location of well at surface 9. Unit or Lease Name 59' FNL, 93' FWL, Sec.29, T12N, R9E, UM Kuparuk River Unit , 10. Well Number At Top Producing Interval 1196' FNL, 1T24' FWL, Sec.29, T12N, R9E, UM 3F-4 At Total Depth 11. Field and Pool 1458' FNL, 1369' FWL, Sec.29, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6, Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 93' RKBI ADL 25643 ALK 2574 , 12. Date Spudded10/09/85 13. Date T.D. Reached10/13/85 14' Date C°mp" Susp' °r Aband' [ 1~' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°nsl 0/14/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20'. Depth where SSSV set 21. Thickness of Permafrost 6913'MD, 6340'TVD 6772'MD, 6225'TVD yES)~ NO[]I 1805 feetMD 1500' (approx) , 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL/GR, Cal, GR/CCL/CET/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6;" bZ.~ H-40 Surt 1i5" 2Z~',.' ' 274 sx AS II 9-5/8" 36.0# J-55 Surf 3535' "' i2-1/4" 800 Sx' pF "E" & 345 sx FF "C" 7" 26.0# J-55 Surf 6862' 8'-1/2" 320 sx Glass G & 175 sx PF "C" . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) . SIZE DEPTH SET (MD) PACKER SET (MD) 6670' - 6632' 2-1/2" 6470' 6186' & 6447' w/4 spf, 90° phasing 6612' - 6572' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6410' - 6290' w/12 spf, 120° phasing DEP:rH INTERVAL(MD) AMOUNT& KIN'DOFMATERIAI' USED See addendum attacl,ed to Well Compl'et'ion Report, dated 3/31/86. , , 27. N//~ .... PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) I ' . ~ Date of Test Hours Tested PRODUCTION FOR OILoBBL GAS-MCF WATER-BBL ~HOKE SiZE GAS-OIL RATIO TEST PERIOD ~ , , , Flow Tubing :Casing Pressure CALCULATED OIL-BBL GAS-MCF wATER-BIll O1'1' GRAVI:I'Y-API (corr) Press. 24-HOUR RATE ~ - ,, 28. CORE DATA Brief description of lithol°gy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips, JU !,.] 2 6 1986 Alaska .... Form 10-407 * NOTE: Tubing was run & well perforated 12/04/85. WCl/045 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC M'ARiK~:-~S~ ' : ..: , .''~: FORMATION TESTS ._. ~ : . : . :. . NAME Include inter~va~ tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH GOR and time%each phase. Top Kuparuk C 6286' 5826' N/A Base Kuparuk C 6409' 5927' · Top Kuparuk A 6562' 6052' Base Kuparuk A 6720' 6182' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~~~ TitleAss°ciate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA '" ALASKA OIL AND GAS CONSERVATION CON, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-228 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21449 4. Location of well at surface 9. Unit or Lease Name 59' FNL, 93' FWL, Sec.29, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1196' FNL, 1124' FWL, Sec.29, T12N, R9E, UM 3F-4 At Total Depth 11. Field and Pool 1458' FNL, 1:569' FWL, Sec.29, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 93' RKB ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/09/85 10/13/85 10/14/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 6913'MD, 6340'TVD 6772'MD, 6225'TVD YES ~(X NO [] 1805 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR, FDC/CNL/GR, Cal, GR/CCL/CET/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" Conductor report has rot been received. 9-5/8" 36.0# J-55 Surf 3535' 12-1/4" 800 sx PF "E" & 345 s~ PF "C" 7" 26.0# J-55 Surf 6862' 8-1/2" 320 sx Class G & 175 ,,x PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6670' - 6632' 3-1/2" 6470' 6186' & 6447' w/4 spf, 90° phasing 6612' - 6572' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6410' - 6290' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Add~;ndum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR :OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL !OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APR0 1986 ~ 0il & Gas ConS. ~0mmissi0n Anchore, ge Form 10-407 * NOTE: Tubing was run & wel 1 perforated 12/04/85. GRU13/WC12 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH TRUE VERT. DEPTH 6286' 6409' 6562' 6720' 5826' 5927' 6052' 6182' 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) FORMATION TESTS e interval tested, pressure data, all fluids recovered and gravity, GOR. dod time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- 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 ~:oreS taken, indicate "none". Form 10-407 /85 3F...4 Rn CET log f/6772 ,. f/6740 '-4 1/24/86 surf. 770, & 3050,.1800, Be~in frae @ ),,. ' Rn OCT - Frae K- -~ z / hfs, 1/24z._ gyro ? st uparuk ,,. ,, /o0. d~e_o~es Per ,~_ saad °cage I. ~Ulesel. ~esh & 20/~ Procedur. Oo32,.6670, Sta~e ~ z320 ps~ ~o bbls 5~. co 8800 h~'. Press 'dS- Eelled 3~', ',~z pres.~ ~ed df~ . ~age 2. ~ ~°ni~o~'' W9'5/~,,~ z/1530 ~.f~o ~ue Sta- s~age, uzu Ps~ ~=~4ed dies.e'~Cer 34 m~=ss ann to ~e. 3: ~9 b'- ' ~rZa~ rate ~ Pad ~ 2 b'ta~.. ' ~PM W/=. e aled d~- · I BpH ~ /Zlnal o= ~: 63 ~ZOal ur~ ~USel w~ ~ end of 8ta- ~v~ of l~ '~ ~elled ~. ~- L~ 19.8 ~ avg _- ~s ~e~' ',~ ~- /40, ~ ~ta ur 19 o ~aed . . ~ess o o pp Ee 7: ~..5 BpM ._ diesel .._ f 451n_ ~' Sand ~ual p~_ ~=~4ed d~_ - v Psi. - o pp~ =~s of 3970~esel flus~ ~ o~ sand psi. "~ avg of 20.4 Prop ' d 80"" 9235// 20/~'0 i00° mesh, o mesh, 8 ~,- ' o pp~ s-i-pp~ san.~ - ~u to Job C°mp~ece ~ 22~9 h~s, 1/24/86. [C[IV[D APRO 1986 ~ 011 & Gas Cons. Commission Anchorage ARCO Alaska, inc,'/-'~ . :: - · - Post Office b,,x 100360. Anct~orage. Alaska 99510-0360 Telephone 907 276 1215 RETUP~N TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Final Prints/ Schl/ CET or CBL's/ One * of each ~lQ-12 01-21-85 Run #1 3536-6934 ~_A-8 11-02-85 Run #1 6986-8362 ~D-13 12-17-84 Run ~1 5425-7488 ~2D-14 17-12-84 Run #1 6288-8136 ~2H-11 11-28-85 Run #1 4850-6642 ~2H-12 11-28-85 Run #1 5500-6776 ~W-15 02-02-85 Run #1 6500-8096 ~3A-4 11-03-85 Run #1 6792-8329 ~3F-4 11-12-85 Run #1 4770-6734 '~F-7 11-14-85 Run #1 4950-7876 DATE 03-11-86 TRANSMITTAL # 5595 Please acknowledge receipt and PT,RASE NOTE: These logs were received from the vender today 03-11-86. Receipt Acknowledged: ~0f ~AK*bl/se ,~-~:i~ Vault*~films NSK Clerk*bl 2 "--"' 0il & Gas Cons. C0mmlss~ ARCO Alaska. Irl¢. il · ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-4 Dear Mr. Chatterton- Enclosed is a copy of the 3F-4 Well History (completion details) to include with the Well Completion Report, dated 01/10/86. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L79 Enclosure cc' 3F-4 Well File Alaska 011 & 6,_% [:c:',i:;. Con'~r<:ssion ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO' Oil and Gas Company Well History - Initial Report- Dally Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only, District Alaska Field KuparUk River ]~un~, parish or borough North Slope Borough ILea ADL 25643 or Unit Title Completion Auth; or W.O, no. AFE AK0421 State Alaska lWell no. 3F-4 Nordic'i AP1 50-029-21449 Operator ARCO Alaska, Inc. Spudded_or W.O~ begun Complete Date and depth as of 8:00 a.m. 12/03/85 12104185 Complete record for each day reported 0300 hrs. ARCO W.I. Prior status If a W.O. 7" @ 6862' 6772' PBTD, Perf'g 9.9 ppg NaC1 Brine Accept rig @ 0300 hfs, 12/3/85. ND tree, NU &tst BOPE. Schl, tst lubr. TIH w/4" csg gun. The abo~e is correct 56.24% RU 7" @ 6862' 6744' PBTD, RU S/L 9.9 ppg NaC1 Brine Perf w/4" csg guns, 4 SPF, 90° phasing f/6572'-6612', 6632'-6670'. Perf w/5" guns, 12 SPF, 120° phasing f/6290'-6410'. TIH w/6-1/8" gage ring/JB to 6650'. TIH & set top Bkr FB-1 pkr @ 6447'. Rn 200 its, 3½", 9.3#, J-55. 8RD EUE IPC compl. Inst &tst SSSV, instl hgr, re-lnd tbg. Set pkr, shear PBR. Tst backside to 2500 psi; OK. Close SSSV, bled to 1000 psi. Press tbg, opened SSSV, press up, could not shear ball, close SSSV. Instl BPV, ND BOPE, pull BPV, tst pack-off & tree to 5000 psi. RU Otis S/L unit. SSSV @ 1805', FHL Pkr @ 6186', FB-1Pkr @ 6447', TT @ 6470' Signature For ~orm preparation andl~distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On Workovers when an official lest is not required upon completion, report completion and representative lest data in blocks provided. The "Final Report" form may be used for rbporting the entire operation if space is available. I Accounting Distr,ct ICounty or Parish JState Alaska North Slope Borough Field ~Lease or Unit · Kuparuk River I ADL 25643 Auth. or W.O. no. ~Title AFE AK0421 I Completion cost center code Alaska JWell no. 3F-4 Nordic 1 Operator ARco Alaska, Inc, Spudded or W.O. begun JA.R.Co. Date Complete Date and depth as of 8:00 a.ml. 12/o5/85 Complete record for each day reported 7" @ 6862' 6744' PBTD, RI{ Diesel .Shear SOS. AP1 50-029-21449 W.{. 56.24% 12/3/85 Iotal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well our ~Prlor atatus If a W.O. 0300 hrs. I Displ well to diesel. RR @ 1115 hrs, 12/4/85. Old TD Uew TO IP* Depth 6744~ PBTD I Released rig Date I Kind of rig 1115 hrs. 12/4/85 { Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected _. The above is correct Signature I Date I Title I For form preparation anc~listribution, see Procedurea Manual, Section 10, Drilling, Pagea 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Box J00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 10, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-4 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not yet received the Well History (Completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/mh GRU13/L170 Enclosures RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~- STATE OF ALASKA ,~. ALASKA£ 'ANDGAS CONSERVATION CO. ,'IISSION WI=LL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~3X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. 3. Address 8. APl Number P. 0. Box 100360~ Anchoraoe. AK 99510 50- 029_21~.~.9 _____~_--~. 9. Unit or Lease Name 4. Location of well at surface 't'T',.qCATiONS~. 59' FNL, 93' FWL, Sec.29, T12N, RgE, UM !i VERIF~ 1 K,,n~r,,l~ I~v~r ~ln~t At Top Producing Interval 10. Vv~-I~u-mb~r ....... At Total Depth 1 1. Field and Pool 1458' FNL, 1369' FWL. Sec.29. T12N. R9E_ UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKBI AD~ ?~,~ ~LK 257~. 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions * feet MSL 10/09/85 10/13IRF, I n/l~/R~ N/A 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+-I-VD)19.1~irec~i~)~al Survey I 20. DepthwhereSSSvset I21.Thickness°fPermafr°st 6913'MD, 6340'TVD 6772'MD. F, 2?~,,TVn YES qX NO [] 1805 feet MD 1500' (cpFrcx) 22. Type Electric or Other Logs Run I')11 /.&FI /_c,p/c,R. FlbC/('NI /C.P ('~1 r.p/r('l /("r:T/r. 23. ~ ........... ' --'' ..... ~S~I~,-I_-I~i=E~R 'A'I~'[~ ~I~I~=NTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" Conductor report has n,)t been received. 9-5/8" 36.0# J-55 Surf 3535' 12-1/4" 800 sx PF "E" & 345 sx PF "C" 7" 26.0# J-55 Surf 6862' 8-1/2" 320 sx Class G & 175 s;~ PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6670' - 6632' 3-1/2" 6470' 6186' & 6447' w/4 spf, 90° phasing 6612' - 6572' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6410' - 6290' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested IpRODUCTION FOR OILoBBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RF C[IV[D Alaska Anchnr~n,~ Form' 10-407 Rev. 7-1-80 * NOTE: Tubing was run & well perforated 12/04/85. CONTINUED ON REVERSE SIDE TEMP3/WC46 Submit in duplicate ....' . ~Eoi~OG~I(~ i~iARKEi~s . ', :. · ~:~._ .'.. '? ' ,': ~ . . ":~:i , [': FORMATION'~ ' TE~STS" ' "' · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6286' 5826' N/A Base Kuparuk C 6409' 5927' Top Kuparuk A 6562' 6052' Base Kuparuk A 6720' 6182' . 31. LIST OF ATTACHMENTS Cyrosc. onic Survey (2 eo~ies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~0j7~ _)~~ Title Associate Engineer Date Signed INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 1 Q-4CI7 TEMP3/WC46a ARCO Alaska, Inc. Post Office Bo^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 17, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3F-4 Dear Mr. Chatterton. Enclosed is an addendum to the 3F-4 Well History to include with the Well Completion Report dated ].1/14/85. If you have any questions, please call me at 263-4944.. Sincerely, d. ~ruber Associate Engineer JG/tw GRU12/L144 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ADDENDUM WELL: 11/14/85 3F-4 Rn CET log f/6740'-4770' & 3050'-1800' f/6772'-surf. Rn GCT gyro Drillin~ Superintendent Oil & Gas Cons. Co[nmission Date ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3F-4 Dear Mr. Chatterton: Enclosed is a copy of the 3F-4 Well Hi story to include wi th the Well Completion Report, dated 11/15/85. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L91 Enclosure cc: 3F-4 Well File RECEIVED ~ta~ka Oil & Gas CoNs. CommiSsion Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfJeldCompany ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily worl¢ prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0421 ICounty, parish or borough North Slope Borough Lease or Unit ADL 25643 Title Drill State Alaska IWell no. 3F-4 Doyon 9 AP1 50-029-21449 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded O,te 10/9/85 IH°ur Date and depth as of 8:00 a.m. 10/10/85 10/11/85 10/12/85 thru 10/14/85 Complete record for each day reported IARCO W.I. Prior status if a W.O. 56.24% 2230 hrs. 16" @ 115' 1533', (1418'), Drlg Wt. 9.6+, PV 28, YP 30, PH 8.5, WL 14.4, Sol 9 Accept rig @ 1630 hrs, 10/9/85. NU diverter sys. 2230 hfs, 10/9/85. Drl 12¼" hole to 1533'. Spud well @ 9-5/8" @ 3035' 3035', (1502'), NU BOPE Wt. 9.5+, PV 12, YP 15, PH 9.0, WL 13.6, Sol 8 Drl 12¼" hole to 3053', short trip, CBU, POOH. RU & rn 71 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 3035', FC @ 2946'. Cmt w/800 sx PF "E", followed by 345 sx PF "C". CIP @ 0110 hrs, 10/11/85. ND diverter sys. NU BOPE. 3023', 1.9°, S76.75E, 3022 TVD, 18 VS, 19N, 45E 7" @ 6862' 6913' TD, 6772' PBTD, (3860'), Cmt 7" csg Wt. 9.9+, PV 10, YP 12, PH 9.5, WL 4.8, Sol 11 NU & tst BOPE. RIH, tst csg to 1500 psi. DO flt equip, cmt + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 6913', short trip to 9-5/8" shoe, CBU, POOH. RU Schl, log DIL/SFL/SP/GR f/6896'-3035', FDC/CNL/GR f/6896'-6050', CAL f/6896'-3035', RD Schl. Make cond'g trip, POOH. RU & rn 161 its, 7", 26#, J-55 BTC csg w/FC @ 6772', ~ @ 6862'. Cmt w/320 sx Cl "G" w/.65 FDP-C344 & .25% HR-7. 3127', 2.~f~-3126 TVD, 21VS, 18N, 48E 3409', 9.6°, S43.75E, 3406 TVD, 51VS, 2S, 71E 3692', 13.9°, S34.75E, 3684 TVD, 104 VS, 43S, 106E 4037', 27.0°, S39.75E, 4006 TVI), 224 VS, 142S, 175E 4323', 34.4°, S39.75E, 4252 TVD, 369 VS, 254S, 268E 4794', 37.8°, S42.75E, 4625 TVI), 657 VS, 469S, 460E 5549', 35.8°, S40.75E, 5229 ~v'I), 1108 VS, 803S, 764E 6175', 35.4°, S41.75E, 5733 TVD, 1480 VS, 1084S, 1008E 6553', 35.0°, S44.75E, 6042 TVD, 1697 VS, 1243S, 1157E RECEIVED Alaska Oil & Gas Cons. Commission Anchorage The above is correct For form preparation ~nd di~'ibution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date I I- i ~ - Z~_~ Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operalion if space is available. I Accounting cost center code District County or Parish I Stale Alaska North Slope Borough I Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0421 Lease or Unit Title I Well no. ADL 25643 3F-4 Drill Doyon 9 Operator API 50-029-21449 A.R.Co. W.I. 56.24% ARCO Alaska, Inc. Spudded or W.O. begun Date Spudded 10/9/85 Date and depth Complete record for each day reported as of 8:00 a.m. 10/15/85 10/21/85 I otal number of wells (active or inactive) on this Dst cenler prior to plugging and I bandonment of this well I our J Prior status if a W.O. I 2230 hrs. 7" @ 6862' 6772' PBTD, (0'), RR 9.9 ppg NaC1 Displ cmt. CIP @ 0710 hrs, 10/14/85. Set slips, cut 7" csg, install packoffs. NU & tst tree. RR @ 0900 hrs, 10/14/85. Arctic packed well w/175 sx PF "C". Old TD Released rig 0900 hrs. Classifications (oil, gas, etc.) O±l Producing method New TD Date PB Depth 6913' TD 6772' PBTD 10/14/85 Kind of rig Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time ~-- I PVodd~o~a,~ Oil on test Gas per day ,~ I,,,, i ..... Pump size. SPM X length Choke size T.P. C.P. Water % G~~ ~JJ ~vij~ -, Allowable Effective date co.ea~, 00~ 'S. COrfl~Jssjoi The above is correct Signature For form preparatior~nd distribution, see Procedures Manual, Section 10, ' Drilling, Pages 86 and 87. Date [Title Ii-I~-~E Drillin~ Superintendent ARCO Alaska, Inc. Post Office Box 1'00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-4 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3F-4. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well completed. Also, I have not yet received the Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L84 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ---.. ALASKAC .AND GAS CONSERVATION COl ,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. (15-228 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21449 4. Location of well at surface 9. Unit or Lease Name 58' FNL, 93' FWL, Sec.29, T12N, R9E, UN Kvparuk River Unil; At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3F-4 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKBI ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore 116. No. of Completions 10/09/85 10/13/85 10/14/85J N/A feet MSL 17. Total Depth (MD+TVD) i18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6913'MD 6772'MD YES [] NO [~XI N/A feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR, FDC/CNL/GR. Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6;; 62.5~ H-~U Surf 115' 24" Conductor report has m~t been received. 9-5/8" 36.0# J-55 Surf 3535' 12-1/4" 800 sx PF "E" & 345 sx PF "C" 7" 26.0# J-55 Surf 6862' 8-1/2" 320 sx Class G & 175 s', PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corri Press. 24-HOUR RATE "IF 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~,~. ,. " < ECEi VED E0rm 10-407 TEMP2/WC56 Submit in duplicate R~ev. 7-1-80 CONTINUED ON REVERSE SIDE · · "- '" GEOI~OGIC-MARKERS' ;;?~ '';: :": ~' :'f~:';: i': "-:~'~ .':' '-. -'-: 'FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. : N/A N/A -- 31. LIST OF ATTACHMENTS · None · . 32. I hereby certify that the f°regOing is true and correct to the best of my knowledge Signed ~~ ~~L~ Title Associate Engineer Date_ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 O-407 8UB. SURFA DIREC~'IONAI. ~URVEY I~IUIDANCE I~ONTINUOU8 [~]OOL Company , Well Name Fleld/I.~atlon ARCO ALASKA INCORPORATED I 3F-4 (59' FNL, 93' FWL, S29, T12N, R9E, UM KUPARUK, NORTH SLOPE, ALASKA I 71102 I. oaaml I~v:. SA~S~/L~S~ZE RECEIVED Comauted BOLAM GCT DIRECTI3N.~L SURVEY , ,,." CUSTO~ER LISTZN2 FOR ARC3 ALASKA, INC. 3F-~+ KUP~qUK NORTH SLOPE,AL~,SKA SURVEY DATE: 13 NOV 85 ENGINEER: S&RSE~/LESNIE METHODS OF CSqPdTATiO~ TOOL LSCATI]N: TAN~ENTiAL- INTCRPS~ATI'2N: LINEAR VERTICAL SECTION: qORiZ. OiST. AVERAGED DEVIATION AND ~ZIMUTH PROJECT£D O~TO A TARGET AZIMUTH OF SOUTH 4~ DEG 12 MIN EAST ARCO ALASKA, INC. 3F-4 KUPARUK NORTH sLOPE,ALASKA COMPUTATI3N DATE: 19-0EC-85 PAGE O6TE OF SURVEY: 13 NDV 85 KELLY BUSHING ELEVATION: E54GINEER: SARBER/LESNIE TRUE MEASURED VERTICAL DEPTH DEPTH 0,00 0.00 100,00 100.00 200.00 200.00 300.00 300.00 400.00 400,00 500.00 500.00 500,00 600.00 700,00 699,99 800,00 799,99 900.00 89~.93 1000,00 999.97 1100,00 1099.97 1200.00 1199.95 1300.00 1299.94 1400.00 1399.93 1500.00 1499.93 1600.00 1599.93 1700.00 1699.93 1800,00 1799.91 1900.00 1899,88 2000.00 1999.33 2100.00 2099.76 2200.00 2199.59 2300.00 2299.51 2400.00 2399.51 2500.00 2499.41 2600.00 2599.32 2700.00 !699.24 2800.00 2799.17 2900.00 2899.12 3000.00 2999.05 3100.00 3099.00 3200.00 3198.91 3300.00 3298.50 3400.00 3397.23 3500.00 3495.~0 3600.00 3594.28 3700.00 36')1.89 3800.00 3788.11 3900.00 3832.05 IN'TERPOLATED VALUES FOR EVEN 100 SUB-SEA COURSE VERTICAL, DEVIATION AZIMVTH DEPTH', 9EG MIN D~G MIN -93.00 0 0 N 0 0 E 7 O0 0 8' S 71 42 c 107,00 0 6 S 3 2~ = 207.00 0 ? S 67 53 ~ 307.00 0 10 N 3.2 48 Vi 40?.00 0 11 N 4 17 E 507,00 0 34 N 5 29 E 606.99 0 33 N 28 :55 E 706.99 0 23 N 2.J 16 E 806.98 0 40 N 52 lZ ~ 906.97 0 43 N 60 20 E 1005,97 0 '51 54 49 27 E 1106.95 0 57 N 29 1! .= 1206.94 0 39 N 28 ~ S_ 1306.93 0 27 N 19 32 = 1406.93 0 19 N 21 40 ~ 1506.93 0 20 N 13 55 E 1605.93 O 30 N r, 27 E 1705.91 1 17 N 25 55 ~ iS06,8~ I ~4 N 41 44 E !906.~3 2 2 N 43 10 2 2006.76 2 6 N 51 24 E 2105.69 2 4 N 66 54 E 2105.6! 2 32 N 70 30 E 2306.51 2 ~2 N 76 58 E 2~05.41 Z 28 N ?9 51 ~ 2506.32 2 ZO N 80 2g E 2606.24 Z 13 N 86 5 E 2705,17 1 57 S ~5 25 =- 2805,12 1 49 S 81 21 ~ 2906.06 1 55 S 78 0 ; 3006.00 2 7 S 66 48 E 3105.91 2 55 S 63 10 ; 3205.50 7 32 S 46 32 g 3304.23 9 38 S 42 44 = 3402.80 9 48 S 42 3~ E 3501.28 10 36 S 41 18 ~ 3598.89 14 14 S 35 59 E 3695.11 17 ~8 $ 33 30 5 37~.06 21 ~3 S 32 10 5 VERTICAL SECTION FEET 0,00 0,05 0,26 0,29 0,09 -0,12 -0 ..62 -1,19 -1,34 -1.5O -1.17 -0.94 -1.17 -1.56 -1.95 -2.33 -2.67 -3.03 -3.71 -4.22 -4.44 -4.40 -3.56 -1.94 0.26 2,66 5.01 T .42 9.91 12.40 15.10 18.11 21.95 30.59 46.45 63.29 80.$4 102.12 123.93 162.40 FEET OF DOGLEG SEVERITY DEG/IO0 MEASURED RECTANG NORTH/S FEET DEPTH ULAR COORD OUTH EAST/ FEET INATES HDR WEST D 0.00 0.00 N 0.0 0.33 0.03 N . 0.1 0.24 0.11 S 0.25 E 0,18 0,26 S 0.15 E 0.17 0.17 S 0.05 W 0.41 0.07 N 0.09 W 0.32 0,79 N 0,08 W 0,41 1,83 N 0,18 E 0.36 2.48 N 0.63 E 0.70 3.22 N 1.16 E 0.16 3.83 N 2.25 E 0.51 4.51 N 3.39 E 0.44 5.83 N 4.32 E 0,95 7.18 N 5.14 E 0.31 8.15 N 5.58 E 0.37 8,8~ N 5.79 E 0,09 9°42 N 5.85 E 1,04 10,01 N 5,94 E 1.30 11,42 N 6.43 E 0.25 13.65 N 7.98 E 16,05 N 10.1~ 18.54 N 12.76 20,~3 N 15.90 21.75 N 19.59 23.04 N 24.06 23.99 N 28.48 24.70 N 32.60 25.20 N 36.56 25.27 N 40.21 24.96 N 43.45 0.32 0.43 0.60 0.68 0.45 0.19 0.16 0.26 0.58 0.41 0.20 0.53 2.47 5.21 0.37 0.27 3.04 3.02 5.01 3.46 24.33 N 46.68 E 23.31 N 49.96 E 21.66 N 53.76 E 15.36 N 60.71 E 4.83 N 71.59 E 7.51 S 83.05 E 20.31 S 94.79 E 37.24 S 108.18 E 59.76 S 123.47 E 88.54 S 141,89 E o E 1 E 0 DEPARTURE AZIMUTH DEG MIN ':'N 0 0 E 73 49 E 0,;2~,, SS 66 10 E 0,,'3. ,,..i" 29 43 E 0'!8 '$ 15 53 W 0'12" N 50 37 0.80 N 5 26 , / 1.84 N 5 29 6 Z. 56 N 16 11 E 3.42 N ]19 46 E 4.4,5 N 30 29 E 5.72 N 36 18 E 7.26 N 36 31 E 8.83 N 35 35 E 9.87 N 34 25 E 10.60 N 33 5 E 11.09 N 31 51 E 11,64 N 30 41 E 13.11 N 29 22 E 15.$1 N 30 19 E 18,99 N 32 16 E 22.51 N 34 32 E 25.89 N 37 54 E 29.27 N 42 0 E 3.3.32 N 46 14 37.23 N 49 53 40,90 N 52 50 . 44.~,1 N 55 25 47.~9 N 57 51 E 50.11 N 60 ? E 52.64 N 62 28 E 55.13 N 64 58 E 57.95 N 68 3 E 62.87 N 74 54 E 71.76 N 86 8 E 83.39 S 84 49 E 96.94 S 77 54 E 114,41 S 71 0 E 137,18 S 64 10 E 167.25 S 58 2 E ARCO ~LASKA, INC. 3F-4 KUP~RUK NORTH SLOPE~ALASKA T R U_: MEASURED VERTIC&L DEPTH DEPT~ 4000.00 3973.61 4100.00 4062.72 4200.00 3149.58 4300.00 ~234.35 4400.00 4316.53 4500.00 4395.5} 4500.00 ~473.55 4700.00 4552.15 4800.00 4630.97 4900.00 4710.2! 5000.30 4789.92 5100.00 4869.76 5200.00 4949.79 5300.00 5030.34 5400.00 5111.00 5500.00 5191.79 5600.00 5272.80 5700.00 5353.90 5800.00 5433.47 5900.00 5313.11 6000.00 5593.17 5100.00 5673.96 6200.00 5755.23 5300.00 5837.~1 5400.00 5919.52 6500.00 5001.50 6500.00 $083.37 6700.00 6165.~5 6800.00 5247.56 6900.00 532'9.57 6913.00 5340.35 CCMPUTATION OAT~: i9-DEC-85 INTERPOL&TEO VAL3ES FOR 5VEN 100 SUE-SEA COORS~ VSRTICAL VERTI,CAL DEVI4T!ON AZIMUTH SSCTION DEPTH' DEG MIN O~$ MIN ~SET 3880.61 25 46 S 37 ,5 E 201.95 3969.72 28 6 S 38 6 E 247.06 4056.58 30 36 S 37 5 ~ 296.24 4141.35 33 50 S 37 50 '~ 348.84 ~223.63 35 55 S ,39 37 ~ 405.41 ~302.59 38 ~! S 41 ~ 5 455..$4 4350.$5 35 30 S 40 54 5 529.0~ ~459.15 38 8 S 40 45 = 590.88 4537.9? 37 53 S 40 39 ~ 653.31 ~617.2i 37 14 S 40 ~9 ~ 713.18 4696.92 37 3 S 40 41 E 773.47 4776.76 36 59 S 40 28 E 333.55 4856.79 36 30 S ~0 34 E 893.39 4937.34 36 13 S 40 3~ ~ '952.54 5015.00 36 10 S 40 29 E 1011.53 5093.79 36 3 S 40 21 ~ 1070.32 5179.80 35 45 S 40 14 5 1128.83 5260.'90 36 31 S 40 31 ~ 1187.19 53~J.4'7 37 20 S ~1 1 = 1247.65 5420.11 37 1 S 41 12 E '1308.03 5500.17 55 30 S 41 40 E 1367.87 5580.96 35 54 S 42 5 £ 1426.77 5662.23 35 17 S ~2 17 ~ 1435.00 5744.41 34 37 S ~2 31 ~ 1541.95 582~.6~= 34 50 S 42 43 ': 1598.85 590~.50 ]5 4 S 42 ~3 : 1656.25 5990.37 34 58 S 43 9 E 1713.65 5072.45 34 4~ S 43 31 ~ 1770.76 o15~.5~ 34 4.~ S ~3 31 ~ 18!7.84 623x.67 3* 43 S 43 31 ; 1884.91 5247.35 34 $8 S 43 31 5 1892.33 ~EET DOGLEG ,SEVERITY OEG/IO0 4.32 3.52 1.1~ 3.39 4.77 0.26 0.65 0.51 0.17 0.20 0.35 0.39 0.56 0.14 0.26 0.17 0.39 2.80 0.38 0.3~ 1.39 0.34 1.32 0.26 0.72 0.21 0.43 0.00 0.00 0.00 0.00 PAGE D~TE OF SURVEY: 13 NDV 85 KELLY 5O'SHING ELEVATION: ENGINEER: SARBER/LESNIE OF MEASUR6O DEPTH RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST FEET FEET 121.63 S 164.60 E 157.33 S 192.60 E 195.56 S 222.79 E 238.88 S 254.72 E 283.10 S 290.~0 E 329.66 S 330.34 E 376.84 S 371.33 E 423.68 S 411.87 ~ 470.36 S 451.97 E 516.56 S 491.79 E 562.28 $ 53{.24 E 608.02 S 570.39 E 653.61 S 609.34 E 698.60 S 647.91 E 743.54 S 686.32 E 788.39 S 724.53 E 833.11 S 762.46 E 877.74 S 800.28 E 923.55 S 839.89 E 969.14 S 879.63 E 1014.08 S 919.25 1057.90 S' 958.67 1101.04 S 997.83 1143.17 S 1036.20 1185.06 S 1074.74 1227.20 S 1113.73 1269.17 S 1152.90 1310.66 S 1192.17 1352.05 S 1231.48 1393.43 S 1270.79 1398.81 S 1275.90 93. O0 FT 2¢8'; s 2 9 7'";' '1 I S 349.21 S ~0'5.56 S ~66.69 $ 529.05 S 590.88 S 652.32 S 713.22 S 773.55 833.69 593.59 952.80 1011.87 1070.75 1129.34 1187.80 1243.35 1308.81 E 1358.71 E 1427.65 E 1485.92 E 1542.90 E 1599.82 E 1657.23 E 1714.64 E 1771.75 E 1828.81 E 1~85.88 E 1893.30 DEPARTURE' AZIMUTH OEG MIN 53 32 E '50 45 E 48 34 E 46 50 E 45 43 E 45 ' ] 44 3~ . / 44 11 E 43 51 E 43 35 E S 43 22 E S 43 10 E S 42 59 E S 42 50 E S 42 42 E S 42 34 E S 42 27 E S 42 21 E S 42 17 E S 42 13 E S 42 11 E S 42 10 E S 42 11E S 42 11 E S 42 12= S 42 1' S 42 15 ~ S 42 17 E. S 42 19 E S 42 21 E S 42 22 E ARCO ALASKA~ INC, 3F-4 KJPARUK NORTH SLDPE~ALASKA COMPUTATZDN DATE: 19-DEC-85 DATE OF SURVEY: 13 NOV 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE 3 93.00 TRUE MEASURED VERTICAL DEPTH DEPTH 0.00 0,00 1000,00 999,97 2000,00 1999,83 3000,00 2999,06 4000.00 3973.61 5000.00 4789.92 6000.00 3593.17 6913.00 5340.35 INTERPOLATED VALUES FOR SUB-SEA COURSE VERTICAL DEVIATION AZIMUTH DEP':'T~'~ DEG MIN DEG MIN -93.,00 0 0 N 0 0 906.97 0 ~3 N 50 20 1906,83 2 2 ' N 43 10 2906,06 1 55 S 78 0 3880,61 25 46 S 37 5 4696,92 37 3 S 40 ~1 5500.17 36 30 S 41 40 5247.35 34 ~8 S 43 31 EVEN 1000 VERTICAL S=CTIDN FEET 0.00 -1.17 -4.44 15.10 201.95 773.47 1367.87 1892.33 FEET OF MEASURED DEPT D~GLEG RECTANGULAR CODRD S~:VERITY NORTH/SOUTH EAST/ DEG/IO0 FEET FEET INATESM WEST D 0,00 0.00 N 0.00 E 0,15 3,83 N . 2,26 E 0,32 16,05 N 10,14 E 0,20 24.33 N 46.68 E 4.32 121.63 ,S 16¢.60 E 0,35 562,28 S 531,24 E 1.39 1014.08 S 919.25 E O.O0 1398.B1 S 1275.90 E 18~ 204. 773.55 1368.71 1893.30 DEPARTURE AZIMUTH DEG MIN 0 0 E ~0 29 E 32 16 E 62 28 E 53 32 E 43 22 42 11 / S 42 22 E CO'4PUT~Ti 3N ARCO ALASKA, INC. 3F-4 KJPARJK NORTH SLOPE,ALaSKA ME.~SU DEP 0 93 193 293 393 493 593 693 793 893 DAT~5:19-DEC-85 INTERPOLATED VALJES FOR ~VEN 100 FEET OF COURSE VERTICAL DOGLEG DEVI.~TIDN AZZMUTH SECTION SEVERITY WIN DEG MIN FEET DEG/IO0 SUB-SEA 0 N 0 0 E 0.00 0,00 9 S 79 3 =. 0,04 0,38 6 S 12 8 E 0,25 0,30 7 S 62 4 W 0.30 0,18 10 N 36 10 W 0,11 0,17 9 N 6 32 E -0,10 0.26 33 N ~ 50 ~ -0.56 0.24 34 N 26 25 E -1.17 0.50 22 N 30 1 E -1.33 0.22 38 N 49 23 E -1.51 0.69 TRUE RED VERTICAL VERTICAL TH DEPTH 0 E P ~,,,~',~, D'EG 9 10 11 12 13 15 16 17 93 93 93 93 93 93 93 93 93 93 · O0 0.00 -93~00 0 .00 93.00 0.00 0 .00 193.00 100.00 0 · 00 293.00 200.00 0 .00 393.00 300.00 0 .00 493.00 400.00 0 · O0 593.00 500.00 0 · 01 693,00 600,00 0 · 01 793.00 700.00 0 · 02 893.00 500,00 0 42 N 60 46 E -1.20 0.19 51 N 51 8 E -0,95 0,38 5.5 N 29 2~ ~ -1,14 0.33 ~2 N 29 24 E -1.54 0.82 27 N 21 44 ~ -1.93 0.18 ~0 N 22 46 E -2.32 0.38 20 N 12 57 E -2.65 0.09 26 N 2 57 = -3.00 0.85. 12 N 25 10 E -3.65 1.29 42 N 41 15 E -4.20 0.47 · 02 993.00 900.00 0 .03 1093.00 1000.00 0 .05 1193.00 1100.00 C · 06 1293.00 1200.00 0 .OT 1393.00 1300.00 0 .07 1493.00 1400.00 0 .OT 1593.00 1500.00 0 · 07 1693.00 1600.00 O .08 1793.00 1TO0.O0 1 · 12 1893.~0 l~OO.O0 1 1993.17 1993.00 1900.00 2093.23 ZO'~3.,)O 2000.00 ' 2193.30 2193.00 ZlO0.O0 2293.38 2293.00 2200.00 2393.49 2393.00 2300.00 2493.59 2493.00 2400.00 2593.68 25'93.00 2500.00 2693.76 2693.00 2600.00 2793.83 2793.00 2700.00 2893.88 2893.00 2S00.00 93.93 2993.00 2900.00 93.99 3093.00 3000.00 94.08 3193.00 3100.00 94.45 3293.00 ~200.00 95,71 3393.00 3300.00 97.15 3493.00 3400.00 98.70 3593.00 350~.00 01.14 3693.00 3600.00 05.13 3793.00 3700.00 11.7~ 3893.00 3800.00 2 1 Z 6 2 4 2 29 2 ~3 2 28 2 Z1 2 13 1 56 1 50 1 55 2 5 2 48 715 9 3B 9 48 10 34 14 16 18 3 22 6 N 42 55 ~ -4.43 0.37 N 50 ~7 E -4.42 0.31 N 5~ 52 : -3 5~ O 57 N 70 31 c -2.06 0,80 N 76 53 E -O.lO 0,26 N 79 35 E 2.50 0.23 N ~0 27 E 4.$7 0.15 N 85 43:5 7.27 0.25 S 88 52 ~ 9.76 0.49 S 81 45 E 12.24 0.37 S 7.3 9 =_ 14.93 0,19 S 67 16 : 17.91 0.77 S 63 56 E 21.68 2.07 S 47 7 E 29,88 5.28 S 42 40 -: 45.73 0.50 S 42 38 E 62.80 0.24 S 41 23 E 30.41 2.94 S 35 56 E 102.39 2.98 5 33 29 E 130.42 5.18 S 32 20 E 166.65 3.79 29 30 31 32 33 34 35 37 38 39 PAGE DATE OF SURVEY: 13 NBV 85 KELLY BUSHING ELEV4TION: ENGINEER: SARSER/LESNIE 93.00 SUB-SEA DEPTH RECTANGULAR COORO NORTH/SOUTH EAST/ FEET FEET 0.00 N 0,0 0,04 N 0,0 O, 10 S 0,2 0,26 S 0,1 0,19 S 0,0 0.05 N 0.0 0.72 N 0.0 1.77 N 0.1 2.44 N 0.6 3.17 N 1.1 INATES ':i,: WEST Bi 0 E 9 E 5 E 6 E 4 W 9 W 8 W 4 E 0 E O E 3.79 N 2.18 4.54 N 3.31 5.73 N 4.Z6 7.11 N 5.10 8.09 N 5.56 8.85 N 5.77 9.38 N 5.84 9.95 N 5.94 11.28 N 6.36 13.49 N 7.84 15,88 N 9,97 E 18.38 N 12,57 E 20,33 N 15,68 E 21,65 N 19.31 E 22.97 N 23.76 E 23.94 N 28.20 E 24.66 N 32.34 E 25.18 N 36.32 E 25.27 N 3'9.99 E 24.98 N 43.25 E 24.38 N 46.48 E 23.40 N 49.76 E 21.79 N 53.50 E 16.85 N 60.19 E 5.36 N 71.11 E 7.16 S 82.73 E 20,13 S 94,53 E 37.46 S 108.35 E 61.03 S 124.32 E 92.23 S 144.20 E DEPARTURE AZIMUTH MIN 0 E 23 E 43 E 20 E ) 36 E 54 E OEG 0:,:. 10,.;,'::i, N 6 8 0 .' '2'7: ":' !:S 68 0'3,0 '":s 3;, 0.1'9, ',,S 11 , 0.11 '"N 59 0.73 N 6 1.78 N 4 Z. 51 N 13 3.36 N 19 4,3'7 N 29 56 E 5,62 N 36 2 E 7,14 N 36 38 E 8,75 N 35 39 E 9.82 N 34 29 E 10.56 N 33 7 E 11.05 N 31 54 E 11.59 N 30 48 E 12.95 N 29 25 E 15.61 N 30 10 E 18.75 N 32 8 E 22,27 N 3~ 21 E 25.68 N 37 38 E 29,01 N 41 43 E 33.05 N 45 57 c 36.99 N 49 4C ) 40.67 N 52 40 ~ 44.20 N 55 15 E 47.31 N 57 42 E 49.95 N 59 59 E 52.49 N 62 19 54.98 .~ 64 48 57.77 N 57 50 52.50 N 7~+ 21 71.31 N 85 41 83.04 S 85 3 96.75 S 77 59 114.64 S TO 55 138.49 S 63 51 171.17 S 5? 23 A~CO ~LASK~, INC. 3~-4 KUP~RUK N3RTH SLOPE,~L~SKA C~MPUTATI DN DATE: 19-D;C-~5 PAGE DATE OF SURVEY: 13 N3V 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE 93.00 TRU~ MEASU2ED V~2T!C4L 2EPTH DEPTH 4021.51 3993.00 4134.53 4093.00 4250.61 4193.00 4371.07 4293.00 4~96.69 4393.00 4624.7i 4493.00 4751.88 4593.00 4878.37 4693.00 5003.86 4793.00 5129.08 4893.00 5253.70 4'993.00 5377.70 5093.00 5501.49 5193.00 5624.89 5293.00 5749.04 5393.00 5874.80 5493.00 5999.78 5593.00 6123.50 5693.00 6246.11 5793.00 6367.60 5893.00 6489.62 5993.00 6511.75 6093.00 6733.55 6193.00 6855.34 $293.00 6913.00 6340.35 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA SOB-SEA COORSE VERTICAL DOGLEG RECTAN VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/ DEPTH DEG MIN DEl3 MIN FEET OEG/IO0 FEE 3900.00 '26 !'7 S 37 50 ~000.00 29 20 S 37 45 4100.00 31 58 S 35 53 4200.00 34 55 S 39 10 q300.O0 38. ~1 $ 41 4 4400.00 38 ZO S 40 54 4500,00 37 59 S 4,,3 39 4600.00 37 20 S 40 48 ~700.00 37 2 S 40 40 4800.00 36 59 S 40 29 211.43 253.55 322.05 388.79 464.57 544.37 622.79 700.i1 775.79 851.00 925.20 998.39 1071.20 1143.32 1216.73 1292.87 1367.74 1440.52 1511..42 1580.39 !550.29 1720.38 1789.91 185'9.42 1892.33 4900.00 36 20 S 40 36 5000.00 36 14 S 40 29 5100.00 36 3 S 40 21 5200.00 35 41 S 40 13 5300.00 37 25 S 40 50 5&O0.O0 37 7 S 41 8 5500.00 36 30 S 41 40 5600.00 35 ~5 S 42 8 5700.00 34 39 S 42 15 5800.00 34 43 S 42 39 2.~9 3.71 ~.77 2.69 0.24 0.65 0.32 0.61 0.36 0.39 0.34 0.36 0.17 0.35 0.59 0.58 1.38 0.65 1.58 0.59 0.25 0.50 O.O0 0.00 0.00 5900.00 35 5 S 42 53 6000.00 3~ 57 S ~3 i2 5100.00 34 ~3 S 43 31 6ZO0.O0 34 ~8 S 43 31 5247.35 34 48 S 43 31 129. 170. 217. 270. 328. 388. '~47 · 506. :564. 621 · 577. 733. 789. 844. 900. 957. 1013. 1068. 1120. 1171. 1222. 1274. 1324. 1374. 1398. OEPTH GULAR CDORD SOUTH EAST/ T FEET 18 S 170.4 40 S. 202.8 35 S 238.4 17 S 279.8 10 S 328.9 45 S 381.3 93 S 432.7 64 S 483.2 05 S 532.7 31 S 581.7 80 S 630.0 53 S 677.7 06 S 725.1 21 S 771.8 17 S 819.5 71 S 869.6 98 S 919.1 11 S 967.9 62 S 1015.5 50 S 1062.1 84 S 1109.5 08 S 1157.5 55 S 1205.3 95 S 1253.2 81 S 1275.9 INATES ~DR] DEPARTURE WEST D AZIMUTH F., PEG MIN 3 E 3 E 322'~,;~' i:S 47 38 E 5 E 388.98 S 45 0 E 8 E 464.,62 S 45 4 ; 8 E 544.~8 S 44 2~ 1 E 622.79 S 44 0 , / ] E 700.14 S 4~ 38 E 6 E 775.88 S 43 21 E 5 E 851.15 S 43 6 E 925.44 S 42 54 E 998.72 S 42 44 E 1071.63 S 42 34 E 114.3.86 S 42 26 E 1217.38 S 42 19 E 1293.63 S 42 14 E 1368.58 S 42 11 E 1441.42 S 42 10 E 151~.36 S 42 11 E 1581.35 $ 42 11 E 1651.27 S 42 13 E 1721.37 S 42 15 E 1790.89 S 4Z 18 E 1860.39 S 4Z 20 E 1893.30 $ 42 22 ~ A~CO 4LASK4, INC. 3F-~ KUPARUK NDRTM SLOPE,ALaSKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPA2UK ~ DBTD TO COMPUT ~T ! 3N INTERPOLATED VALU=S ;DR MEA,SURED DEPTH ~ELOW KB 6286.00 6309.00 3552.00 6720.00 6772.00 6913.00 O4TE: 19-DEC-85 CMOSEN HgRIZONS ORIGIN: TVD :ROM KB 5825.89 5927.01. 6052.26 6181.87 5224.57 6340.35 SUB-SEA 5732.89 5834.01 5959.26 6088.87 6131.57 5247.35 PAGE DATE OF SURVEY: 13 NOV 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE 93.00 FT Sj'RFAC FNL, 93' FWL, SEC RECTANGU NORTH/S 1137.3 1188.8 1253.2 1318.9 13~0.4 1398.8 O~T, 3 $ $ S ~ S 6 S 1 S 'ION , RgE~UM )INATES !~,ST~EST · .~ 1030.82 1078.2~ 1137.99 1200.03 1220.47 1275.90 ARCO ALASKA, INC. 3~-4 KUPARUK N3RTH SLOP~,ALASKA TOP SASE TOP BASE PBTD TD MARKER KUPARUK C KUPARUK C KUm~RUK ~ KUPARgK & COIqPUTATZOrq DATE: ., ,,--,--, .... ~ ......... N~- -,: ..,..,- S T R A T I G R A P H I C ~E~SURED DEPTH BELOW KB 5286.00 6409.00 5552.00 6720.30 6772.00 6913.00 19-DEC-85 PAGE DATE DF SURVEY: 13 NOV 85 KELLY !3USHING ELEVATIDN: E,NGINEER: SARBER/LESNIE 93.00 ORIGIN: 59' FNLs TVD FROM KB SJB-SEA 5825.8'9 5732.89 5927.01 5834.01 5052.26' 5959.26 618!.8? 6085.37 5224.57 6131.57 5340.35 5247.35 93' FW RE N ks CT OR 11 11 1Z 13 13 13 URFA SEC &NGU TH/S 37.3 88.8 53.2 18.9 40.4 98.$ LA'R OUT' 3 S 6 S 4 S 6 S 1 S ',/ION !Ns R9EsUM IN~TES T/WEST 1078.2~ E 1~37.99 F ) 1200.03 ~ 1220.47 E 1275.~0 E FT FINAL WELL LOC~TIJN UT TO: TRUE SUB-SEA MEASURED 'VERTICAL VERTZC&L DEPTH DEPTH DEPTH H~DRIZONTAL DEPARTURE D'IST~NCE i~ZIMUTH FEET DEG MIN 6913.00 5340.35 5247.35 181~3.30 S 42 22 E SCHLUMBERGER 01RFCT I ONAL SURVEY COMPANY ARCO ALASKA INC. 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ECTIDN~L SURVEY CU S Tl~i',1 E R LISTING ARC3 ALASKA, INC. 3F-4 NORTH SLDP:,ALASKA SURVEY DATE: 13 NOV 85 ENGINEER: S~RSER/LESNIE METHODS OF CSqPUTATIO~ TOGc LDC~TI]N: TANSENTiAL- AVERAGED DEVIATION AND AZIMUTH ZNT=RPDL~TIDN: LIN~R VERTICAL SECTION: qORiZ. DIST. PRDJECTED O~TO A TARGET AZIMUTH SOUT~ 4.4. DEG lZ MIN EAST ARCO ALASKA, INC. 3F-4 KUPARUK NORTH SLOPE,ALASK& COMPUTATI3N DATE: 19-0EC-85 PAGE O~TE OF SURVEY: 13 NOV 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE '93.00 'FT TRUE MEASURED VERTICAL DEPTH DEPTH 0.00 0.00 100.00 100.00 200.00 200.00 300.00 300.00 400.00 400.00 500.00 500.00 500.00 600.00 700.90 5~9.99 800.00 799.99 900.00 899.93 1000.00 999,97 1100.00 1099.97 1200.00 1199.95 1300.00 1299.94 1400.00 1399.93 1500.00 1499.93 1600.00 1599.93 1700.00 1699.93 1800.00 1799.91 1900.00 1899.98 2000.00 1999.33 2100.00 2099.76 2200.00 2199.59 2300.00 2299.51 2400.00 2399.51 2500.00 249'9.41 2500.00 2599.32 2700.00 2699.24 2800.00 2799.17 2900.00 2899.12 3000.00 2999.05 3100.00 3099.00 3200.00 3198.91 3300.00 3298.50 3400.00 3397.23 3500.00 3495.~0 3500.00 3594.23 3700.00 3691.89 3800.05 3788,11 3900.00 38B2.06 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA COURSE VERTICAL, DEVIATION AZZMdT~ DEPTH~'. D~G MIN DEG MIR -93.00 0 0 N 0 0 7.00 0 5 S 71 42 107.00 0 5' S 3 24 207.00 0 7 S 67 53 307.00 0 10 N 32 4~ 407.00 0 11 N 4 17 507.00 0 34 N 5 2~ 606.9~ 0 33 N 28 55 706.99 0 23 N 2,~ 15 806.95 0 40 N 52 12 MEASURED 905.97 0 ¢3 N 60 20 1005.97 O 51 N 49 27 1106.95 0 57 N 29 1! 1206.94 0 39 N 28 ~ 1305.93 0 27 N 19 32 1406.93 O 19 N 21 40 1506.93 0 20 N 13 55 1605.93 O 30 N 5 27 1705.91 1 17 N 25 55 1805.85 I ~4 N ~! 4~ VERTICAL DOGLEG RECTANG SECTION SEVERITY NORTH/S FEET OEG/iOO FEET !905.33 2 2 N 43 10 2005.75 2 6 N 51 24 2105.69 2 4 N 66 54 2205.61 2 32 N 70 30 2306.51 2 ~2 N 76 5~ 2~06.41 2 g~ N 79 51 2506.32 2 gO N ~0 2q 2606.24 2 i3 N 86 5 2705.17 1 57 S $~ 25 2805.12 1 49 S 81 21 2905.06 1 55 S 78 0 3006.00 2 7 S 56 48 3105.91 2 ~5 S 63 10 5205.$0 7 32 S 46 32 330~.23 9 35 S 42 44 3402.80 '9 4~ S 42 3~ 3501.2~ !j 36 'S 41 18 359~.59 1~ 14 S 35 59 3695.11 17 48 S 33 33 3759.06 21 43 S 32 10 0.00 0.00 0.0 0.05 0.33 0.0 0.25 0.24 0.1 0.29 0.18 0.2 0.09 0.17 0.1 -0,12 0.41 0.0 -0,,62 O, 32 O, 7 -1,19 0,41 1,8 -1.34 0.35 2.4 -1.50 0.70 3.2 -1.17 0.16 3.8 -0.94 0.51 4.5 -1.17 0.44 5.8 -1.56 0.96 7.1 -1.95 o.31 5.1 -2.33 0.37 8.8 -2.67 0.09 9.4 -3,03 1.04 10,0 -3.71 1.30 11.4 -4.22 0.26 13.6 ~ -4.44 0.32 16.0 5 -4.40 0.43 18.5 = -3.56 0.60 20.~ ~ -1.94 0.68 21.7 : 0.26 0.45 23.0 ~ 2 66 0 19 23 9 : 5.01 0.16 24.7 E 7.42 0-26 25.2 :- 9.91 0.58 25.2 _ 12.40 0.41 24.9 DEPTH ULAR COORDINATES HO OUTH E~S.T/WEST D: FEET 0 N 0.00 E 3 N. 0.11 E 1 S 0.25 E ,O 6 S 0.15 E 0,,~. 3, 7 S 0.05 W 0'18 7 N 0.09 W 0'12' 9 N 0.08 W 0.80 3 N 0.15 E 1.84 8 N 0.53 E 2.56 2 N 1.15 E 3.42 3 N 2.25 E 1 N 3.39 E 3 N 4.32 E 8 N $.14 E 5 N 5.58 E ~3 N 5.79 E 2 N 5.85 E 1 N 5.94 E 2 N 6.43 E 5 N 7.98 E 5 N 10.14 E 4 N 12.76 E 3 N 15.90 E 5 N 19.59 E 4 N 24.06 E 9 N 28.48 5 0 N 32.60 E 0 N 36.56 E 7 N 40.21 E 6 N 43.45 E 15.10 0.20 24.33 18.11 0.53 23.31 21.95 2.47 21.56 30.59 5.21 15.36 46.45 0.3? 4.83 63.29 O.Z? 7.51 80.54 3.0~ 20.31 102.12 3.02 37.24 123.93 5.01 59.76 162.40 3.46 88.54 N 45.68 E N 49.96 E N 53.76 E N 60.71 E N 71.59 E S 83.03 E S 94.79 E S 108.15 E S 123.47 E S 141.89 E OEPARTUrRE AZIMUTH DEG MIN ::::N 0 0 E 73 49 E ',S 66 lO E S 29 43 E S 15 53 W N 50 37 N 5 26 '7 N 5296 N 14 11 E N 19 46 E 52.54 N 62 28 E 55.13 N 64 58 E 57.95 N 68 3 E 62.87 N 74 54 E 71.76 N 86 8 E 83.39 S 84 49 E 96.94 S 77 54 E 114.41 S 71 0 E 137.18 S 64 10 E 167.25 S 55 2 E 18.99 N 32 16 E 22.51 N 34 32 E 25.89 N 37 54 E 29.27 N 42 0 E 3.3.32 N 45 14 E 37.23 N 49 5' 40.90 N 52 5,.! 44.41 N 55 25 E 47.~9 N 57 51 E 50.11 N 60 7 E 4.~+5 N 30 29 E 5.72 N 36 18 E 7.26 N 36 31 E 8.83 N 35 35 E 9.87 N 34 25 E 10.60 N 33 5 E 11.09 N 31 51 E 11.64 N 30 41 E 13.11 N 29 22 E 15.81 N 30 19 E ARCO ALASKA, INC. 3F-4 KUP~RUK NORTH SLOPE,ALASKA CCMPUTATIJN DATE: ig-DEC-85 PAGE D~TE OF SU'RVEY: 13 NOV 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE 93.00 'FT TRUE MEASURED VERTICAL DEPTH OEPT~ 4000.00 3973.61 4100.00 4062.72 4200.00 4149.58 4300.00 4234.35 4400.00 4315.$3 4500.00 4395.5'; 4500.00 4473.55 4700.00 4552.15 4800.00 4630.97 4900.00 4710.Z! 5000.00 4789.92 5100.00 4869.76 5200.09 4949.79 5300.00 5030.34 5400.00 5111.00 5500.00 5191.79 5600.00 5272.80 5700.00 5353.90 5800.00 5433.~7 5900.00 5513.11 6000.00 5593.17 5100.00 5673.96' 6200.00 5755.23 6300.00 5837.~1 5~00.00 5919.52 6500.00 5001.50 6500.00 5083.37 6700.00 6165.~5 6800.00 5247.56 6900.00 5329.57 INTERPOLATEg VAL3ES FOR EVEN 100 SUE-SEA COORSE VERTICAL VERTIC.~L O,EVI~TION AZIMUTH S=_CTION DEPTH~'' DEG ~IN DEG FIN ~:ET 3s o.a 3969.72 28 6 4056.58 30 36 ~141.35 33 50 ~223.63 35 55 ~302.59 38 41 ~380.65 38 30 ~459.15 38 8 453?.9'? 37 53 4617.21 3'7 14 S 37 5 E S 38 5 E S 37 5 S 37 50 S 39 37 ~. S 41 ~ E :5 40 54 .~ S 40 45 5 S 40 39 E 4696.92 37 3 S 40 ~1 E ~776.76 36 59 S 40 28 E 4856.79 '3.5 30 S ~0 34 = 4937.3~ 36 13 S 40 3~ ~ 5018.00 35 10 S 40 29 ~ 5098.7~ 36 3 S 40 21 E 5179.80 35 ~5 $ 40 14 E 5260.90 36 31 S 40 31 E 53~0,47 37 gO S ~1 I ~ 542~.11 37 1 5 41 12 5 5500.17 35 30 S 41 40 E 5580.9~ '35 54 S 42 5 E 566!.23 35 17 S 574~.~1 34 37 S 582~.62 34 50 S ~2 43 ': 5905.50 35 5990.37 34 58 S 507t.45 0152.56 34 6236.67 34 201.95 247.06 296.24 348.84 405.41 455.54 529.04 590.88 652.31 713.18 '173.47 333.55 893.39 952.54 1011.53 1070.32 1128.83 1187.19 1247.65 1308.03 1367.87 1426.77 1435.00 1541.95 1598.85 1656.25 1713.65 1770.76 1827.84 1884.91 FEET OF MEASURED DEPTH DOGCEG RECTANGULAR SEVERITY NORTH/SOUTH OEG/IO0 FEET 4.32 121.63 S 3.52 157.33 S 1.14 195.56 S 3.39 238.88 S 4.77 283.10 S 0.26 329.66 S 0.65 376.84 S 0.51 423.68 S 0.17 470.36 S 0.20 516.56 S 0.35 562.28 S 0.39 608.02 S 0.56 553.61 S 0.14 698.50 S 0.26 743.54 S 0.17 788.39 S 0.39 833.11 S 2.80. 877.74 S 0.38 923.55 S 0.39 969.14 S 1.39 1014.08 S 0.34 1057.90 S 1.32 1101.04 S 0.26 1143.17 S 0.72 1185.06 S 0.21 1227.20 S 0.43 1269.17 S 0.00 1310.66 S 0.00 1352.05 S 0.00 1393.43 S COORDINATES ~Z. DEPARTURE EAST/WEST AZIMUTH FEET ~, !iOEG MIN 164.60 E 2 53 32 E 192.60 E 24, !. .S 50 45 E 222.79 E 29~ 1 $ 48 34 E 254.72 E 34'9.21 S 46 50 E 290.40 E 405.56 S 45 43 E 330.34 E 466.69 S 45 3 \ 371.33 E 529.05 S 44 34 411.87 E 590.88 S 44 11 E 451.97 E 652.32 S 43 51 E 491.79 E 713.22 S 43 35 E 531.24 'E 773.55 S 43 22 E 570.39 E 833.69 S 43 10 E 609.34 E 8'93.59 S 42 59 E 647.91 E 952.80 S 42 50 E 686.32 E 1011.87 S 42 42 E 724.53 E 1070.75 S 42 34 E 762.46 E 1129.34 S 42 27 E 800.28 E 1187.'50 S 42 21 E 839.89 E 1243.35 S 42 17 E 879.63 E 1308.81 S 42 13 E 919.25 E 1358.71 S 42 11 E 958.67 E 1427.65 S 42 10 E 997.83 E 1485.92 S 42 11 E 1036.20 E 1542.90 S 42 11 E 1074.74 E 159'9.82 S 42 12 E 1113.73 E 1657.23 S 42 1' 1152.90 E 1714.64 S 42 It 1192.17 E 1771.75 S 42 17 1231.48 E 1828.81 S 42 19 E 1270.79 E 1~85.88 S 42 21 E 6913.00 5340.35 5247.35 34' ~8 S 43 31 E 1892.33 0.00 1398.81 S 1275.90 E 1893.30 S 42 22 E 3F-4 KJPARdK NORTH SLOPE,ALASKA TRUE MEASURED VERTICAL 3EPTH DEPTH 0.00 0.00 1000.00 999.97 2000.00 1999.83 3000.00 2999.06 4000.00 3973.51 5000.00 4789,92 6000.00 5593.17 6913,00 6340,35 COMPUTATION INTERPOLATED VALUES FOR SOB-SEA VERTICAL DEPT~ DEG MIN -93.00 0 0 906,97 0 ~3 1906,83 2 Z 2906.06 1 55 3880.61 25.46 46~6.92 37 3 5500.17 36 30 6247.35 34 48 CDU2S,5 DEVIATION AZIMUTH DEG MIN N 0 0 N 60 20 N 43 10 S ?$ 0 S 37 5 S 40 ~1 S 41 40 S 43 31 DATE: EVEN VERTIC S~CTI FEE O. 15, 201. 773, 1367. 1892. 19-DEC-85 1000 AL DN T O0 17 44 10 95 47 87 33 FEET OF DAGLEG SEVERITY DEG/IO0 MEASU RECTA NORTH F E PAGe 5. ' OATE OF SURVEY: 13 NOV 85 KELLY BUSHING ELEVATI2N: 93.00'FT · ENGINEER: SARBER/LESNIE REDDEPT 0.00 0.00 N 0.00 E 0.15 3.83 N . 2.26 E 0.32 16.05 N 10.14 E 0.20 24.33 N 46.68 E .4.32 121.63 S 164.60 E 0,35 562.28 S 531.24 E 1,39 1014.0~ S 919,25 E 0,00 1398,81 S 1275,90 E NGULAR CODRDINATES HDR 'DEPARTURE /SOUTH EAST/WEST DJ AZIMUTH ET FEET F! DEG MIN 0 4,,~'",5:i:'.:"N 30 29 E 18.99 ~N 32 16 E 52.64 ,N 62 28 E 204,67 S 53 32 E 773.55 S 43 22 1368.71 S 42 11 . 1893.30 S ~.2 22 E ARCO ~LASKA, INC. 3F-4 KJP&RUK NORTH SLDP~,AL~SKA CO:qPUT&TI3N DATE: 19-DEC-85 PAGE DATE OF SURVEY: 13 NOV 85 KELLY BUSHING ELEVATION: ENGINEER: S~RBER/LESNIE 93.00'FT TRUE MEASURED VERTICAL DEPTH DEPTH O.OO 0.00 93.00 93.00 193.00 193.00 293.00 293.00 393.00 393,00 493.00 4'93.00 593.00 593.00 693.01 693.00 793,01 793,00 893.02 893.00 993.02 993.00 1093.03 1093.00 1193.05 1193.00 1293.06 1293.00 1393.07 1393.00 1493.07 1493,00 1593.07 1593.00 1693.07 1693.00 1793.08 1793.00 1~93.12 1893.00 1993.17 1993.00 2093.23 2093.00 2193.30 2193,00 2293.38 2293.00 2393.49 2393.00 2493.59 2493.00 2593.68 2593.00 2693.76 2693.00 2793.B3 2793.00 2893.88 2893.00 2993.93 2993,00 3093,99 3093.00 3194,08 3193.00 3294.45 3293.00 3395,71 3393.00 3497.15 3493.00 3598.70 3593.00 3701.14 3693,00 3805.13 3793.00 3911.7~ 3893.00 INTERPOLATEO VALUES FOR ~V6N 100 SUB-SE~ VERTIC~ OEP -93~00' ~' 0 0 0.00 0 8' 100.00 0 6 200.00 0 7 300.00 0 10 400.00 0 g 500.00 0 33 600.00 0 34 700.00 0 22 800.00 0 38 COURSE VERTICAL EVIATION AZIMUTH SECTION MIN OEG MIN FEET N 0 0 S 79 S 1Z S 62 N 36 10 N 6 &2 N ~ 50 N 2625 N 30 N 49 23 0.00 =_ 0.04 E 0.25 W 0.30 W 0.11 E -0.10 -0.58 -1.17 5 -1.33 E -1.51 900.00 0 42 1000.00 0 51 1100.00 C 56 1200.00 0 42 1300.00 0 27 1400.00 0 ZO 1500.00 0 20 1500.00 O 25 1700.00 i 12 1800.00 1 42 N 60 46 N 51 8 N 29 2~ N 29 24 N 21 44 N 22 46 N 12 57 N 2 57 N 25 10 N 41 15 E '1.20 E -0.95 -1.14 -1.54 -1.9.3 E -2.32 L-' -2.65 -3.00 5 -3,65 E -4,20 1900.00 2 1 2000.00 Z 6 2100.00 2 4 2200.00 2 29 2300.00 Z ~3 2400.00 2 28 2500.00 2 21 2600.00 2 13 2700.00 1 58 2S00.00 1 50 N ~2 55 N 50 ~7 N 65 52 N 70 3T N 76 53 N 79 35 N 80 27 N 85 4~ S 88 32 S 81 45 -4.43 -4.42 -3.6.% -2.06 -0.10 2.50 4.87 7 . 2? 9.76 12.24 2900.00 1 55 3000.00 2 5 3100.00 2 48 3200.00 7 15 3300.00 9 3~ 3400.00 9 &~ 3500,00 10 34 3600.00 14 16 3700.00 18 3 3800.00 22 6 S 78 9 S 67 16 S 53 56 S 47 T S 42 40 S 42 38 S 41 23 S 35 56 S 33 29 S 32 20 14.93 17.91 21.68 29.88 45.73 62.80 80.41 102.39 130.42 165.65 FEET OF SUB-SEA DOGLEG RECTANSULAR SEVERITY NORTH/SOUTH DEG/IO0 FEET COORDINATES EAST/WEST FEET O.O0 0.00 N 0.00 0.38 0.04 N . 0,09 0.30 0.10 S 0.25 0.18 0.26 S 0.16 0.17 0.19 S 0,04 0.26 0.05 N 0.09 0.24 0.72 N 0.08 0.50 1.77 N 0.14 0.22 2.44 N 0.60 0.69 3.17 N 1.lO 0.19 3.79 N 0.38 4.54 N 0.33 5.73 N 0.82 7.11 N 0.18 8.09 N 0.38 8.85 N 0.09 9.38 N 0.85 9.95 N 1,29 11.28 N 0,47 13.49 N 2.18 E 3.31 5 4.26 E 5.10 E 5.56 E 5.77 E 5.84 E 5.94 E 6.36 E 7.84 E 0.37 15.88 N 9.97 0.31 18.38 N 12.57 0.57 20.33 N 15.58 0.80 21.65 N 19.31 0.25 22.97 N 23.76 0.23 23.94 N 28.20 0.15 24,66 N 32.34 0.25 25.18 N 36.32 0.49 25.27 N 39.99 0,37 24.9~ N 43.25 0.19 24.38 N 46.48 E 0.77 23.40 N 49.76 E 2.07 21.79 N 53.50 E 5.28 16.85 N 60.19 E 0.50 5.36 N 71.11 E 0.24 7.16 S 82.T3 E 2..94 20.13 S 94.~3 5 2.98 37.46 S 108.35 E 5.18 61.03 S 124.32 E 3.79 92.23 S 144,20 E DEPARTURE AZIMUTH G MIN 0 0 E 58 23 E 0 68 43 E 0 32 20 E O' g $ 11 0 W O. 1I ,N 59 55 0.73 N 6 27 ,, ; 1.78 N 4 36 E 2..51 N 13 54 E 3.36 N 19 4 E 4.37 N 29 56 E 5.62 N 36 2 E 7.14 N 36 38 E 8.75 4 35 39 E 9.82 N 34 29 E 10.56 N 33 7 E 11.05 N 31 54 E 11.59 N 30 48 E 12.95 N 29 25 E 15.61 N 30 10 E 18.75 N 3_7 8 E 22.27 N 3~+ 21 E 25.68 N 37 38 E 29.01 N 41 43 E 33.05 N 45 57 E 36.99 N 49 4F 40.57 N 52 4b 44.20 N 55 15 E 4?.31 N 5? 42 E 49.95 N 59 59 E 52.49 N 62 19 E 54.9B N 64 48 E 57.77 N 57 50 E 62.50 N 74 21 E 71.31 N 85 41 E 83.04 S 85 3 E 96.75 S 77 59 E 114.64 S 70 55 E 138.49 S 63 51 E 171.17 S 57 23 E 3F-4 KUPA~U~ N3RTH SLOPE,fiL~SKA CCMPUTATI3N OATE: PAGE DATE OF SURVEY: 13 NAV 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE ,. 93,00 FT TRUE ~EASURE2 VERTICAL 3EPTH DEPTH 4021.61 3993.00 4134,53 4093,00 4250.61 4193.00 4371.07 4293.00 4496.69 4393.00 4624.71 4493.00 4751.83 4593.00 4878.37 4693.00 5003.86 4793.00 5129.08 4893.00 5253.70 4993.00 5377.70 5093.00 5501.49 5193.00 5624.89 5293.00 5?49.04 5393.00 5874.80 5493.00 5999.78 5593.00 6123.30 5693.00 6246.11 5793.00 6367.60 5893.00 6489.62 5993.00 6611.75 6093.00 6733.55 6193.00 6355.34 6293.00 6913.00 6340.35 INTERPOLATED VALUES FOR SUB-S EA C OURS ;~ VERTICAL' DEVIATION AZIMUTH D;PTH DEG MIN DEG MIN 3900.00 '26 27 S 37 50 4000.00 29 ZO S 37 45 4100.00 31 58 S 35 53 4200.00 34 56 S 39 10 ~300.00 38 41 $ 41 4 4400.00 38 gO S 40 54 4500.00 37 3~ S 40 39 ~600.00 37 20 S 40 48 &TO0.O0 37 2 S 40 40 4800.00 36 59 S 43 29 4900.00 36 20 S 40 36 5000.00 36 14 S 40 29 5100.00 36 3 S 40 21 5200.00 35 ~1 S 40 13 5300.00 37 25 S 40 50 5400.00 37 7 S 41 8 5500.00 36 30 5 41 ~0 5600.00 35 45 S 42 5700.00 34 39 S 42 15 5800.00 3~ 43 S 42 39 5900.00 35 5 S 42 33 6000.00 3w 57 S ~3 1Z 5100.00 34 ~'~ ~ 43 31 6200.00 34 ~8 S 43 31 5247.35 34 48 S 43 31 EVEN 100 VERTICAL SECTION FEET 211.43 253.55 322.05 388.79 464.57 544.37 622.79 700.1I 775.79 351.00 925.20 998.39 107!.20 1143,32 1216,73 1292.87 1367.74 1440.52 1511.42 1580.39 1650.29 1720.38 1789.91 1859.42 1892.B3 FEET OF DOGLEG SEVERITY DEG/iO0 2.~9 3.71 ~.77 2.69 0.24 0.65 0.32 0.81 0.36 0.39 0.34 0.36 0.17 0.35 0.59 0.58 1.38 0.65 1.58 0.59 0.25 0.50 0.00 0.00 0.00 SUB-SEA OEPTH RECTAN NORTH/ FEE GULAR COORDINATES HDRI SOUTH EAST/WEST O T FEET F 129.18 S 170.43 E 170.40 S. 202.81 E 2!7.35 S 238.43 E 270.17 S 279.85 E 328.10 S 328.98 E 388.45 S 381.38 E ~47.93 S 432.71 E 506.54 S 483.23 E 56~.05 S 532.76 E 621.31 S 581.75 E DEPARTURE AZIMUTH :i:i~,.:','OEG MIN 577.80 S 630.09 733.53 S 677.77 789.06 S 725.10 844.21 S 771.84 900.17 S 819.58 957.71 S 869.63 1013.98 S 919.16 1068.11 $ 967.90 1120.62 S 1015.59 1171.50 S 1062,19 925.44 S 42 54 E 998.72 S 42 44 E 1071.63 S 42 34 E 1143.86 S 42 26 E 1217.38 S 42 19 E 1293.63 S 42 14 E 1368,58 S 42 ll E 1~41,42 S 42 10 E 1512.36 S 42 11 E 1581.35 S 42 11 E 1222, 1274. 1324. 137~+. 1398, 94 S 1109.57 08 S 1157.51 55 S 1205.35 95 S 1253.23 81 S 1275.90 E 1651.27 S 42 13 E E 1721.37 S 42 15 E E 1790.89 S 42 18 E E 1860.39 S 42 20 E E 1893.30 S 42 22 E ) 21 52 50 E 264 ~',.'S 49'57 E 322.63' ,$ 47 38 E 388' '98"' S 45 0 E 464,62 S 45 4 E 5~4'38 S 44 28 '~ 52~,79 $ 44 0 .. 700,14 S 43 38 E 775,88 $ 43 ~1 ~ 851,15 S 43 6 E ARCO aLASKA, INC. 3F-4 KUPARUK NORTH SLOPE,ALaSKA TOP BAS E TOP BASE PBTD TO MARKER KUPARUK C KUP&RUK C KUPARUK A KUPARUK ~ C3MPUT~TIDN INTERPOLATED VALUES FOR MEASURED DEPTH ~ELOW KB 6286.00 6~09.00 6720°00 6772.00 6913.00 D~TE: 19-DEC-85 PAGE DATE OF SURVEY: 13 NOV 85 KELLY BUSHING ELEVATION: ENGINEER: SARBER/LESNIE 93.00 CHOSEN H3RIZONS FROM KB 5825. :~9 5927.01 6052.26 6181. ~7 5224.57 6340.35 SjRF~ ORIGIN: 59' FNL, '93' F'WL, SEC TVD RECTANGU SUB-SEA NORTH/S 5732.89 1137.3 5834.01 1188.8 5959.26 1253.2 6088.87 1318.9 5131.57 1340.4 6247,35 1398.8 L , 0 S, 3 S $ S 4 S 6 S 1 S ON m R9E,UM )INATES ,T/WEST 1030.82 1078.24 1137.9'9 1200.03 1220.47 1275.90 ARCO ALASKA, INC. 3F-4 KUPARUK NORTH SLOPE~ALASKA TOP EASE TOP DBTD TD MARKER KUPARUK C KUPARUK C KUP&RUK 4 CO!4PUTATZOr~ OAT:: MEASURED DEPTH 6256.00 6409.00 5552,.00 6720,00 6772°00 6913.00 19-D;C-85 P~GE DA'TE DF SURVEY: 13 NOV 85 KELLY )USHING ELEVATION: ENGINEER: S~RBER/LESNIE 93.00 ORIGIN: 59' FNL~ 93' FWL TVD FROH KB SJB-SEA 5825.8'9 5732,89 5927.01 5834,01 5052.26' 5959.26 6181.87 6088.87 6224.57 6131.57 6340.35 6247.35 REC NO SURFACE'?', , SEC T&NGULAR R TH/S DI~Tt't, 1137.30 S 1188.83 S 1253.26, S 1318.94 S 1340.46 S 1398.81 S ION !N, RDE,UM IN~TES T/WEST 78.24 E ,, 1137.99 E ) 1200.03 5 ~ 1220.47 E 1275,90 E FINAL MEASURED DEPTH WELL LOCATIJN ~T TO: TRUE SJB-SEA VERTICAL VERTICAL DEPTH DEPTH 5913.00 5340.35 5247.35 HORIZONTAL DEP6RTURE DIST,&NCE AZIMUTH FEET DEG MIN 1893.30 S 42 22 E SCHLUMBERGER O '[ RECT TONAL SURVEY COMPANY ARCO ALASKA INC. WELL 3F-4 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOGGED REFERENCE O0007110Z WELL NAME: 3F-4 SURFACE LOC~iTION: f FNL, 93' FWL, S29, T12N, R9E, - ! 000 -~00 0 0 ~ ! 000 ! SOO ~- [ ! ': F! ~ i I i ! i : .... ]:il: : : ..' : : : : ': .............. I ................ -~-..~ -4--i.-.i--.i.- ,-;..--4-~-.~.4--4....I- [ [ ~ [ 4-+4-HH-4.'-~H~?--H-4-~1 i ] ~ ~ [ ~ [ i [ [ [ {4---Hb4-~:~. 4 ~ -:- ~- ~- { { .-H-4-~- -; i-Hi ~ ~:+.+ i: { .]--b'.- ...+...HH} -+~...-F~fi---F.." ~-+J--{--~,,-F." -~f-~.--:4--~~- :. 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Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 11-13-85 TRANSMITTAL NO: 5441 RETUi~iq TO: · ARCO ALASKA, INC. KU PARDK 'OPE RATIONS ENGINEERING RECORDS -CLERK ATO- 1 l15B 'P.O. bOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEPJ~qITH APE THE FOLLOWING ITF~iS. PLEASE ACKNOWLEDGE PJ~CEIPT AlqD RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. IN S/ SCHL/ ,~-~ DIL/SFL ~:~ DEN/NEU PORO \ 5 "~ DEN/NEU PORO DEN/NEU RAW k CYBE~OOK ~5" 3 DIL/S~-GR 3F-3 ~2" DEN/NSU PORO DEN/NEU ~W ~- ~2 ~DEN/NEU ~W ~ ~YBE~OOK 3C-15 ~5 "~ DiL/SFL-GR ~2~ DIL/SFL-GR ~5 DBN/NEU-GR PORO ~ "~ DEN/NEU-GR PORO ~ 5.V · .__ DEN/NEUrGR ~W ~2 DSN/NEU'GR ~W ~YBE~OOK ~ 3C214~"~ DIL/SFL-GR ~ "-- DEN/NEU PORO " ~ DEN/NEU ~W ~ DEN/NEU ~~W ~YBE~OOK~ OPEN HOLE/ ONE * OF EACH 10-13-85 RUN' #1 3031-6888 10-13-85 RUN #1 3031-6888 10-13-85 RUN #1 6050-6860 10-13-85 RUN #1 6050-6860 10-13-85 RUN #1 6050-6860 10-13-85 t{UN #1 6050-6860 10-13-85 RUN #1 6200-6700 10-08-85 RUN #1 3446-7926 10-08-85 RUN #1 3446-7926 10-08-85 RUN #1 7100-7900 10-08-85 RUN #1 7100-7900 10-08-85 P~N 91 7100-7900 10-08-85 RUN #1 7100-7900 10-08-85 RUN #1 7100-7877 10-08-85 RUN 91 3842-7831 10-08-85 RUN #1 3842-7831 10-08-85 ~UN 91 7060-7806 10-08-85 RUN #1 7060-7806 10-08-85 RUN ~1 7060-7806 10-0~-85 RUN #1 7060-7806 10-08-85 RUN 91 7060-7831 10-15-85 t~UN #1 4062-8383 10-15-85 RUN 91 4062-8383 10-15-85 RUN 91 7650-8357 10.-15-85 }(UN ~1 7650-8357 10-15-85 RUN 91 76'50-8357 10-15-85 RUN 91 7650-8357 . 10-15-85 RUN RECEIPT ~CKNO%4LEDGED: BPAE B. CURRIER CHEVRON D & M*BL DISTRIBUTION: DRILLING*BL W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL 'NSK C]~ERK*BL J. RATHMELL*BL ..... u~ & (~a~,.,~r~s STATEsoHiO OF ALASF~%c~e .Cor.,,m,ssior' UNION VAULT/ ANO* F I LMS ARCO Alaska, Inc. is s Subs[oiar)' O! AllanticRichfie~dCompany ARCO Alaska, Inc. ~ Post Office £ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 11-07-~5 TF~ANSMITTAL NO: 5431 ~'TURN TO: ARCO ALASKA, INC. KUPARUK OPE}cATIONS ENGINEERING RECORDS CLERK ATO- 1 l15'B P.O. BOX 100360 ANCHORAGE, AK 99510 _qANSMITTED JCEIPT AND ?IN H.~QLE LIS TAPES PLUS LISTING/ 53--8-- i0-16-85 RUN ~1 2188 ~.T-7~/~ 10-09-85 RUN ~1 1748 3~-5~' 10-20-85 RUN ~1 1994 3~--4 --"" 10-13-85 RUN ~ 1 3030 3e-16~'~ 09-29-85 RUN ~1 3692 Z~- 15-'" 10- 08- 85 RUN ~1 3816 ~- 1~---~ 10-15- 85 RUN ~1 4050 Z~-.~ 10-24-85 RUN ~1 !948 ~/~-~.~'" 10-!8-85 RUN ~1 3410 3/~-5~''' 10-11-85 RUN ~i 3952 HER~TWITH AttE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SCHL/ ONE COPY OF EACH .5-7344· o~oa7~z~-$-~Fen~ ~1 ~- 73~x~ · 0-7585. O~'d~7~4-4~5-~e~- /~- .0-8647. ~~ T~-J-~fe~-/~-~7 .5-6851 55~7 .0-7864. ~~730--3- ~ e~ -3 ~/ ~- .0-8425. O~d~7~J-5-E~e~- .0-7269. o$~a7~-S-~fe~- /~ -~ 0-7617.5~74~--j~~-3 ~/~ - CEIPT ACKNO%~LEDGED: _z~ CURRIER' EVRON M DRILLING L. JOHNSTON P~O5IL NSK CLERK DISTRIBUTION:., -- EXXON SOHIO PHILLIPS OIL UNION J. ~~LL VAU LT/~O ARCO Alaska. Inc. i~. a Subsio~ar¥ of AtianlicRichf~elc:'C-ompany ARCO Alaska, Inc. ,~"', post Ottice 1~, )00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1965 Mr. C. ~/- chatterton commi ss ioner State of Alaska Alaska Oil & GaS Conservation commission 3001 Porcupine Drive Anchorage, Ai~ 99501 SUBJECT' State Reports lls' Dear Mr. ChattertOn: Enclosed are the October monthly reports for the following we L2-3 1B-1 (workover) 3A-7 3C-15 3J-6 9-24 L2-13 3A-8 3F-3 3J-7 9-36 L3-5 2A-8 3C-6 3F-4 3J-8 16-17 L3-11 2D-12 (w°rk°ver) 3C-13 3F-5 4-21 16-1B 3A-5 3C-14 3F-6 4-22 18-6 {workover) · 3A-6 If you have any questiOnS, please call me at 263-4944 S i ncerel Y, · Gruber Associate Engineer jG/tW GRUlZ/LSO Enclosures RECEIVED NOV 1 5 1 85 Alaska Oil & Gas Cons. Conim!ssion Anchorag~ ARCO AlaSka, Snc. is a Subsidiary o! Atlantic~ichtieldC°mP~n¥ · '-~ STATE OF ALASKA ,-.--. ALASKA O.. AND GAS CONSERVATION COk..,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellX~-] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-228 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21449 4. Location of Well at surface 58' FNL, 93' FWL, Sec.29, T12N, RgE, UM I 6. Lease Designation and Serial No. ADL 25643 ALK 2574 For the Month of October , 19 85 5. Elevation in feet (indicate KB, DF, etc.) 93' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3F-4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2230 hfs, 10/9/85. Drld 12-1/4" hole to 3053'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 6913'TD (10/13/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 6772'. Secured well & RR @ 0900 hfs, 10/14/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests · 16", 62.5#/ft, H-40, weld conductor set ~ 115'. Conductor Report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3035'. Cmtd w/800 sx PF "E" & 345 sx PF "C". 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 6862'. Cmtd w/320 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/6896' - 3035' FDC/CNL/GR f/6896' - 6050' Ca1 f/6869' - 3035' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repor~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10A04 TEHP2/HR21 Submit in duplicate ARCO Alaska, Inc-,~-' ' Post Office ~- ..~-100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001. Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3F Pad - Wells 1-16 . Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUll/L22 Enclosure If RECEIVED OCT 2 5 I985 Alaska Oil & G~s Corts. Commission Anchorag9 ARCO Alaska, InC. is a Subsidiary of AtlanticRich[ieldc°mpany '~'~ AS BIJ~'-' CONDUCTORS I-~ IN SECTION ~'9 1- ¥=5 , :,85 , 734. 98 LAT=70°22,20.0858,, X= 508,662.35 LONG=t49°55,46. 549'' 89 FNL, 162 FWL, 52 C.G., 56.1 PAD- 2- Y=5,985,745.10 LAT=70°22 ' 20. 1856,, X= 508,638.99 LONG=149°55' 47.233'' 78 FNL, 139 FWL, 52 C.G., 56.3 PAD 3- Y=5,985,754.79 LAT=70o22 ' 20. 2812" X= 508,616.29 LONG=149°55' 47.896'' 69 FNL, 116 FWL, 52 C.G. 56.3 PAD 4- Y=5,985,764.77 LAT=70°22 ' 20. 3796'' X= 508,593.66 LONG=149°55' 48. 558'' 59 FNL, 93 FWL, 52 C.G. 56.2 PAD 5- Y=5,985,774.87 LAT=70°22 ' 20. 4792'' X= 508,570.43 LONG=149°55' 49. 237 J 49 70 52 O'.G. 56.2 FNL, FWL, PAD 6- Y=5,985,784.84 LAT=70°22 ' 20. 5776'' X= 508,547.58 LONG=149°55'49 906" . NOTES 39 FNL, 48 FWL, 52 C.G. 56.1 PAD I. COORDINATES ARE A.S.R, ZONE4. 7- Y=5,985,794.93 LAT=70°22'20.6771'' 2. SECTION LINE DISTANCES ARE TRUE. X= 508,524.44 LONG.149°55 ' 50. 582'' 28 FNL, 24 FWL, 52 O.G.,55.9 PAD 3. HORIZONTAL AND VERTICAL POSITIONS ARE BASED 8- Y=5,985,804.81 LAT=70°22 ' 20. 7744'' ON MONUMENTS SF-MIDDLE & SF-EAST PER L.H.Q&ASSOC. X= 508,501.41 LONG=149°55'51.256'' 4. O. 6. ELEVATIONS INTERPOLATED FROM S/C DWG. NO. 18 FNL, 1 FWL, 52 0.G.,55.9 PAD CED'RIXX-3030 RE~V~.4,:~_It*.a,.. _ASy~=~II~T CONDUCTORS 9-'6 I" SECTIgN 19 ~ ~11 k~ 9 ,985,834.85 LAT=70o22 ' 2~..0708'' '- .~ ' ' "~/%'--- ~--~ -'.~Z''.. ' 12 FSL, 67 FEL, 51.2 C.G., 56.1 PAD "" ii;: ~ ~_~~ X= 508,410.73 LONG=149°55' 53.908" /:ii~ ::-.~ : a 21' FSL, 89 FEL, 51.2 C.G., 56.2 PAD ..;:;~:,-:~ ' : ',~; .ow^~.,~=--^- :.~' ' 11- Y=5 985,855 14 LAT=70°22'21 2708" ~ _%° 4~80-s ." ~:~ - X= 508 387 41 LONG=149°55'54 590" : . ~&.~,'........-"_~k'~_~ 32 FSL, 112 EEL, 51.20.G., 56.3 PAD '; - ~'kk?~;~ll~;,,~~ 12- Y=5,985,865.19 LAT=70°22'21.3699'' - '~:~,~:~:'~"' X= 508,364.05 LONG=149°55'55.273,, I HEREBY'CERTIFY THAT I AM I~OI~RLY REQIITERED 42 FSL, 136 FEL, 51.1 0.G. 56.2 PAD AND LICENSED TO PRACTICE LAND II~¥[YIMO'I# 13- Y=5,985,874.97 LAT=70°22'21.4663'' THE.STATE OF ALASKA, THAT THII PLAT RIPtEIENT$ X= 508,341.36 LONG=149°55' 55.937" A SURVEy I~ADE UNDER MY DkqECT ~4~I~RVI~H~I AND 52 FSL, 158 FEL, 51.1 C.G., 56.3 PAD THAT CO#DUCTORE I ~ · AI~.C~H~CT Al ~ 14- Y=5 985 885.08 LAT=70°22'21 5660" SEPTEMBER 19,191E ANO.¢~TQtI't THRU 1~, ' ' ' ARE CORI~CT A~ OF ~PTIlIIER it, ltll. X= 508,318.27 LONG=149°55' 56.612" ' 62 FSL, 181 FEL, 51.1 O.G.,56.3 PAD ~F~=v ~S.3B - 15- Y=5,985,894.96 LAT=70°22'21.6635'' '19 ~ X= 508,295.72 LONG=149°55' 57.271'' -~~~ 72 FSL, 204 FEL, 51 O.G. 56.1 PAD D'S3F'/' 29~~~28 7~ ~~...~~_] /"~ .... ) ~)~" .16-Y:5,985,904.95X LAT:70°22'21'7619"° , 30 2. = 508,272.74 LONG=149 55 57.943" ' ~ J.' ' ......... ,r- ........ .~2 FSL~ 227 FEL~ 51 O.G. 56 PaD II - CONDUCTOR AS BUILT CONDUCTORS I THRU 8 LOCATED iN PROTRACTED " :* :ii · SEC.~9, T.I~N.,R. gE., U. MER. 111~1[ D.t-: October 11,1985 ,0,14: N.T.S. CONDUCTORS 9 THRU '16 LOCATED IN PROTRACTED SEC. 19, T. 12N.,R. 9E.,U. MER. --.-=~,~,,=, Drlft®~l by: Sydney2 Dwi. Ne. N~K85-26 L_~ S TA TE OF ;~Lh S ~0% AIA, SFF~ OIL & CAS OD~,]SERVATION CO':tLLc,SIO]: B.O.P.E. Ins!~ct ion Rcl>ort Well ~~t ~tion: Sec_~ q ~tion, ~ra~_~- We] 1 Si~~ Cenera 1 ~o'~e~9 ~se~e pit. . B;.t'E Stack. Tes't Pressure k unu]ar Preventer _ C~oke Line Val¥~s F .C.R. Valve } il 1 Line Va] %~s ._ Represemtative ,D~lq 0 [P ~q ~ _~Casin9 Set @__~ft. Re ~esentative~~ ~~J-'[.O~ ]~ff~IATOR SYSTEM ,~11 Charge Pressure_ Pressure After Closure '~ 700psig Ptmp incr. clos. pres. 200 psig.~__n~$%.-~_sec. Full Cha~e F~zesmn3£e ~ttained: . ?_ mir%~_~__sec. .. Controls: 5~ster_~_~K .. Kelly and Floor Safety Valves Upper Kelly. Lower Kelly_ Ins ide BOP__. Choke Manifold No. Val ves__J_~ _Test Fressu re__ ~3(~ Test Pressure__._. ~.00 Test Presm~re ...... ~2_~~------ Test Pres sire_.__ -_~/~__-- .Test Pressure ~_ ~=0~0 __ - Oi str ]but ion September 17, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3F-4 ARCO Alaska, Inc. Permit No. 85-228 Sur. Loc. 58'FNL, 93'F%~L, Sec. 29, T12N, R9E, UM. Btmhole Loc. 1501'FNL, 1496'~L, Sec. 29, T12N, R9E, UM. Dear ~. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very~ruty ryo~nrs, Lonnie C. ~smith Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 20, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3F-4 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to a $100 application fee o Diagrams showing the proposed projections of the wellbore o A proximity plot ° A diagram and description of system Drill Kuparuk 3F-4, along with horizontal and vertical the surface hole diverter ° A diagram and description of the BOP equipment We estimate spudding this well on October 7, 1985. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/HRE/tw PD/L158 Enclosures ~/a,~ka 0it ~ ~a~ Cone '~ncf~orage' Corarale$ion ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (JIL AND GAS CONSERVATION CO,v~MISSION PERMIT TO DRILL 20 AAC 25,005 lb. Type of well EXPLORATORY [] SERVICE [] ~TRATI~I~APH~ DEVELOPMENT GAS [] MULTIPLE ZONE [] 9. Unit or lease name Kuparuk River Unit la. Type of work. DRILL [~]X REDRILL [] DEEPEN [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 58' FNL, 93' FWL, Sec.29, T12N, RgE, UN At top of proposed producing interval 1229' FNL, 1232' FWL, Seco29, T12N, RgE, UN At total depth 1501' FNL, 1496' FWL, Sec.29, T12N, RgE, UM 10. Well number 3F-4 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 93', PAD 56' ADL 25643 ALK 2574 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 58' ~ surface feet 3F-3 well 25' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7001' MD, 6335' TVD feet 2560 10/07/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 3200 feet. MAXIMUM HOLE ANGLE 39 oI (see 20 AAC 25.035 (c) (2) 2677 psig@_~80° F Surface 3074 _psig@ 6027 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) Z4" 16" 62.5# H-40 Weld 80' 35' I 35' 115~, 115' :1:200 cf 12-1/4" 9-5/8" 36.0# 1-55/HF-EF',W BTC 3018' 35' I 35' 3053'1/ 3053' 800 sx PF "E" & ' I ~ I 345 sx PF "C" 8-1/2" 7" 26.0# . -55/HF-EF'.W BTC 6967' 34' II 34' 7001'1 6335' 320 sx Class G neat I I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7001' MD (6335' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole, A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will' be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2677 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3F~4 will be 25' away from 3F-3 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby~ that the foregoing is true and correct to the best of my knowledge SIGNED / /.~~~~~J TITLE Regional Drilling Engro T h e ,p aoe/~o~v ~ ~o~~n use' - CONDITIONS OF APPROVAL DATE Samples required I! Mud log required F-lYES ~4~O I []YES Permit number APPROVED BY Approval date 5 Directional Survey required I APl number ~ES F-IN(:) [ 50- OL-~-C-/'Y'¢¢ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE September 17; 1985 by order of the Commission (HRE) PD/PD158 Form 10-401 Submit in triplicate PERHIT TO DRILL 3F-4 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED Alaska Oil & G~,s b~c~s. Commission . ': 0 l 000 2000 YERTtCAL : ! 3000 'RECEIVED SEP ~ 0 ~Sb Alaska Oil & Gas Cons. COr;i/nJ..q.~lOi'/ .... Anchorage I{OP TVl)-320~O rtlD=; ~200 OEP-O - ...... :-i-':~: - "::-:'- ............. ' - , ...... ::~:-~-: ...... ~~ ~ rv~=-T~.~=- 0~.o,' ~ ...... '~ ...... A¢:E R-k~ _~ TOP zO~ c TVD-5873 THD-8404 ' ~'~__~XT .......... ' ~TOP:ZONE A TVD 6038 THD 661~ DEP 176g ..................... ~T-.-~TE-- TVD~27 T~-6~--D~ 17-~ .... : , ~ ~ BA~ KU~ SNDS TVD=6180 THD-6801 DEP-1886 TD .... ~ ' 1000 I oo0 I 2000 S 44 DEG 12 MINE i , t'7'80' ..... (T 0" T ~-RG~ T) ..... : .................. i .......... ::-': ........... : ,RECEIVED .'. ~ . -, ;ur6:,)8 . _ ,~ _ i, N.OF T.H ~00 . 400 . 500 . · I I 2141 22~ ......... t ....... ! ........ r ' 22?8 ~oo I KUPARUK RIVER UNIT -PO" DI VERTER SCHEMAT I C DE SCR I P T I ON I. 16 · CO~JCTOR. 2. TAI~O STARTER H[AD. 3. TANKO SAVER SU~. 4. TAI~O LO1M[R QUICK-C~CT ASSY. 5. TAI~O UPPER QUICK-COI~&[CT ASSY. 6. 20' 2000 PSI DRILLING SPOOL W/I0" OUTLETS. 7. I0' HCR BALL VALVES W/lO" . DIVERTER LI~[So VALVES Ol:q[N AUTOMATICALLY UPON C[.~ OF Af~ULAR PREVENTER. 8. 20' 2000 PSI A~JLAR PREVE~. 6 MAINTENANCE & OPERATION , I. UPON INITIAL INSTALLATION, CLOSE PREVENTER AI~) VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE N~MLAR PREVENTER AI~ BLOW AIR THROUGH DIVERTER LINE8 EVERY 12 HOURS. CLOSE A~LAR PREVENTER IN THE EVENT THAT AN I~FLUX OF FLUIDS OR GAS IS DETECTED. IF NECESSARY, M~d~IUALLY OVERRII~ AI~ CLOSE APPROPRIATE VALVE TO ACHIEVE DO~il~II~ DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUblSTANCE$. ll_amldO~l 114 7 6 DIAGRAM #1 13-5/8' ,5CX30 PSI RSRRA BOP STACX 5 4 2 14. RECEIVED Alaska 0il & Gas Cons. Commission A,~Chora.c~e 13-5/~' BOP STACX TEST I. FILL l~P SI'AQ( N~ ~ I~fl~FCI..D wITH 2. Q.ECI( TN4T ALL LOQ( ~ BCRS~ IN ~_~ ~D FLI.LY RL:-,~ACTED. SE. AT TEST PLUG IN WS. LJ-F. AD WITH Rl.~l~ JT ~ I~ IN I.~ ~. LIllE VALVES ADd~ TO ~ STN3(. ALL 4. PRESSI.I~E L~ TO 250 F~! ~ ~ F~R I0 MIN. IN.- CR~ P;~ TO ~ PSI ~ HI:I.D FCR I0 MIN. Liam=n PRE~'~___~E TO 0 PSI. LI~ VALVES. CL~ TCP PIPE ~ AN~ ~ VALVES C:N KILL. At~D ~ LIliES. 6. TEST 1'0 250 PSI AN~ ~ PSI AS IN STEP 7. 03qrIl~JE TESTING ALL VALVES. LI~E,~. AI~ (I-ICI<ES WITH A 250 PSI LOW ~ ~ PSI HI~H. TEST AS iN TEST 801'TC~ PIPE RN~B TO 250 PSI N~D ~ PSI. I0. CLO6E BLI~I:} RAM6 AN:) TEST TO '250 PSI AhD 5000 PSI. NIANIFCLD ~ LIliES ARE FULL CF N~ING FLUID. ~-r ALL VALVES IN DRILLING 12. 'T~ $]'AI',~IPE VALVES,, K~I_ [Yo K1:1! Y C013($. DRILL PIPE SAFETY VALVE. ~ INSIDE ~ TO 250 PSI 5000 PSI. 15. RECI~ TEST II~FC~TIC~ C~ B[.O~ PR~ TEST FCla~t. SION. A~D SF.~D TO DRILLIN~ VIEE)(LY TkF. RF_AF'r~ FI~I(:NALLY C~TE 8CPE DAILY. S 100~4001 REV.; I~Y I 5. 19,eS CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc /""'/'"x._ (,2' thru 8)' (~ ~ ~--~ru 12) ' 10. //J'/~/ :~/;z//:Kf'' 11o (10 and 12. (4) Casg~~.~, (13 thru 21)' (22 thruz 2~) 13. 14. 15, 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. YES NO 1. Is the permit fee attached ......................................... · 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line ................ 4. Is well located proper distance from other wells ............... 5. Is sufficient undedicated acreage available in this po2~'... 6. Is well to be deviated and is wellbore plat i.n.cluded ..~.~ 7. Is operator the only affected party .............. 8. Can permit be approved before ten-day wait ......... 27. Does operator have a bond in force .................................. ~_. Is a conservation order needed ........................................ Is administrative approval needed Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ................... ... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ................ Are necessary diagrams of diverter ~'~ ~quip~ .., Does BOPE have sufficient pressure rating - Test to ~~ psig ../~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. ,~_ , Additional requirements ............................................. ~ Additional Remarks: REMARKS o ~z Geology: Engi. neering: HWK ~_~ LCS ,/o~,'"~ -, WVA --- MTM ~ HJH ~. JAL ~..~ ............. 'x ........ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , , Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumUlated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. .o bVP OlO,HO~ VEPlFICATION LISTING PAGE ** REEL 8EADMR 8ERVYCM NA~E ~EDTT DA?E 185/10/19 RE~L NA~ ~,~92~7 CONTYNUATION # PR~V~Ol,~$ OR~GYN 10000 iAPE ONT'YNUATI~N # ~01 REVYOU$ TAPE COMMENTS :[,IBRRRY TAP~ ********** EOF ********** ** FYbM WE~D~R ** FILE N~M~' :~DYT ,001 SERVYCF ~A~E : VERSION # : DATE l ~I[,E TYP~ = PR£VIO~lS FTS~ : ** INFhR~ATION RMCOR~M MN~M CO~TWN~$ CN { ~RCO A[,ASKA TNC WN ~ IF-4 FN ~, wUPARU~ RANG~ qE TOWN! SMCT) COUNI STa. T{ ~L~SKA CTWYi USa PRMS~ ~ ** CO~£~T~ ** UNYT TYPE CATE SIZE CODE 000 000 0i9 065 000 000 004 065 000 000 008 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 0i2 065 000 000 006 065 000 000 00'] 065 TYPE CATE SIZE CODE 000 000 001 065 LVP OIO,NO~ VE~IFICAWlON 5ISTING PA~E 2 *' SCHtUMB~RGE~ ~. W£[,b = 3F-,4 FIELD = KUPARUK COUN?Y = NORTH St,,OPE BOROUGH STAT~ = ALASK~ JOB ~U~BER AT ACC: 708~6 RU~.#1~ ~ATE LOGGED: t, DP: L, m, CUD~E¥ CASING = 9.6~5" ~ 303~ VISCOSITY PH = 9,80 mLUID LOS8 c 5,8 C~ ~F R~C = 4 . oo s,~'o 58,0 .. 58,0 Die ~ ~.o83:~ la 142.' Die ~ATRIX SAND$~O~!E tVP OlO,HO~ VB~I~I~ATIDN ~I$?I~G ~A~E HOLE CORRECTT..O. = ~ALIPE~ ***** THT$ D IA HAS ********************************************************************************* NO~Ei TOP JO ~'~,, OF OIb '~0~ ~.V~IbABLE ON FTEt, D TAP~ , , , , · , , , , , , , · , , , · , , , , , , , , · SCHbUMBE~G~R bOGS %NCbUDMD ~TR TH~S MAGNETIC , · OUAb IMDUC?ION SPMMR~'CabLY FOCUSED LOG · DAT~,' ~VA~LABL~,~ 303i~ TO' 6~8~ · ~ORMAT~OM DE~I$'~TY COMP~NSATE~ LO~ {'F~N) · COMPMNSA?E~ NEUTRON bog · , DATA AV~ItAMb~:I 6050~ T0 ~9~0~ , , , , , , , , , , , , , , , , , , , $ , , **'DATA MNTRY BLOCKS · YPE SIZE ~EPR CODE ENTRY 2 1 ~6 0 4 i 66 610 8 9 4 65 LVP OIO,H02 VERIFICATION LTSTING PAGE 4 i. 6 ! 66 1 0 I 66 0 YNEM SERVICE $~RVICE UNIT API DEPT RNRA FDN C~L AP1 APl rT O0 000 O0 0 OHMM O0 220 01 0 OH~ O0 1.20 46 0 OHMM O0 ~.20 44 0 ~V O0 010 01 0 ~API O0 ].01 O1 0 ~API O0 ]10 O1 0 ~N O0 280 01 0 ~/C3 O0 ]50 02 0 ~/C3 O0 ]56 01 0 O0 42O O! 0 O0 000 O0 0 PU O0 890 O0 0 CPS O0 330 )I 0 CPS PO )30 ]0 0 NO. (O~TAb) 0 4 i $6 O00000000OO000' 0 4 1 ~8 00000000'000000 o oooo ,oo o o o " oooo oo o o8o 0 4 ~ · $8 0 4 Z8 00000000000000 0 4 68 000000000'000'00 0 4 I 68 00000000000000 0 ~ ~ ~ 00000000000000 '0 4 1 6B' O000000:OlO00'OOO 0 4 i ~8 000'0.0000000000 0 4 ~8 0000,0000000000 0 4 0 4 I ~ 0000000'0000000 00000000000000 0 4 '$8 O0'OOO0000000 0 4 I 68 .0000000000008~ DATA RHOB .OEOT RHOB NPHI RHOB OEPT OEVT SP RHOB ~P~I SP 6900 5000 ~Ft, U -66~97~7 gR 2,4065 DRHO 41,6504 ~CNL 6mO0.O000 5,9727 ~R '62,4143 DR~O 44,7266 NCNb 6700.0000 SFLU "70,6602 gR ~,42q9 DRMO 4].t5q4 ~CNL 6~000000 -79:47~7 6~00 0000 SFLU -7~:Q7~7 CR 2,3831 DRHO 3~.~754 NCNb 6400 oono SFLU 3' -t1~.7277 ~R .4475 DR~O 32.56~4 NC~L 3,2385 ILO 133,5625 0,~012 NRAT ~,4436 TLD 121.7773 0 0337 187~:6875 WCN~ 3 i057 1897:6875 69 7148 TLO 5]:7930 OR 0,0093 -0.0005 ~RAT 2~5).~000 rCNb .6055 GR ,n,o171 ~RAT 2561.~000 PCNL 200 68Z5 tb~ 2,,'7717 i3~'56z5 CALX 3:4163 RNRA ..9307 540,31~5 , 3 C~LI 8, 12~,6116 RNRA 4, 451,1406 1.03:33~8 CALl 3,5237 RNRA 3,6721 ~16,8125 40.0117 :TL, M .qO'7.t~125 57.0430 TbM 98,9023 51.6055 CALl 8,8691 2,94i7 R'NPA ],2815 78o,3125 RHOB RHOB .r).EPT ~pHI NPHI ~EPT Sp RHOB OEPT sp RHOB NpH! DEPT NPHI O£PT RHOB OEPT SP RHOB SP 37 6~00 -74 4~ 6~00, 999. '999, 5900 '999 5~00, -999, 5?O0 · '93, '~99, -Bg, '99q, 0000 ,~303 .2559 .~000 , 227 ,0000 2500 2500, 0000 72~7 25O0 ~500 0000 97~7 O0 0000 ~777 ~500 ~500 0000 mLO0 2500 SFLU 148 9375 )bD, 59.2305 TbM GR 65:~148 GR 65.2148 CALl DR~O O,~02 73 ~TRR T 3.2209 RNRR NC~ib 2097,5000 rCNb 590.~125 DRHO . ~NRA ~{C~'b 1721:85 FCNb ~26, ~R 254,8125 ~R '999,2500 CALl. ~RHO -099,2500 ~RA=T -999,2500 RNRA wCk~b -990.2500 ~CNi, ~R l 3~.0625 ~R -999"~500 CAbI ~RHO -999.2500 ~R~T -~99.~500 NC~b -999.2500 FCNb -999,2500 ~R 121 '2773 GR -999.~500 CRLI ~RWO -999,2500 ~RR~ -999.2500 RNRA. WCWb -U9~.~500 ~CNb -~9~,2500 ~R 11i.2773 ~R -999.2'500 CALl ~RWO -999.2500 ~RAT -999.2500 WNRA NCNb -g99.~500 FC~TL -qgq,~500 102 ~R 104,~ ~ -999,2500 ALI , -9 OR,O '2500250 -999.2~00 .~.~500 -~99 . . FCNL -q992500 500 ~C~b -ng9 5~00.00o0 SF[,U 3.4592 IbD 2.9924 ibm 88 0352 CE 104.5273 cR 999.{500 CALX -U99'2500 ~R~O -qgg 2500 ~R~T ~Q9~,2500 mNmA -~90~2500 ~CNb -~9~'2500. ~C,b.. .699,. .2500 2 29.0 ~ =,,, 4,000? 999, 4,28~9 "999, ],0862 -999,2500 -999,2500 i 45 '999, 500 5¥P 010,140~ VEPlFICATI. ON LISTING PAGE 6 0000 SF[.U DEPT 5~00, SP.. -86.47~7 RHOB -099.~500 DEPT 5100 0000 SP -~01 2852 RBOB -999 2500 DRHO NP~I -999 ~500 DEPT 5000,0000 SFLU P .... -70,0~52 HOB -99~,~500 DR~O NPMI -999,~500 SP 5~.~008 RHOB '~99,2500 DR~O NpH! -~99,~'500 DEPT 4~00.0000 SFLU RH~B -999.9500 NPHI -999,,~500 ~C~ DEPT 4~00 ~000 SF[,U ~P -57!5195 RHOB -9992500 DRHO NPHI -~99,~500 i oo.oooo srt,,,u SP, 49 ~008 aR RHOB ~901~500 ~p.~ .~99'~5oo ~c~ ~ux 4~oo oooo SF~,U SP -62:51q5 GR RHOB -999,2500 OReO NPH! -999,~500 OEPT 4]00 0000 SFLU SP. -60'76o5 GR ~HOB -99q:2500 OReO NPHI -99q,~500 ~CNL OEVT 4200 0000 SFLU SP -61'0195 26526 ILD 2,4475 ~26'7148 ~R -999,2500 CAtI- -999~500 NR~.T -999,~500 -990.2500 FCN5 -999,~500 35979 TLD 3, 7~2 ~M o 123:~648 ~R .-999.~50~ -999. 500 ~R~T -999, 500 -999.2500 PCNL -999~500 RN'~A 3.6819 tLD .3.3323 IbM 1.41,'625 ~R -999,,$00 -999'2500 ~RAT ~~5999, O0 ~NRA -999,~500 WCN4 .~9~,,.2500 5 OR '99 '.~500 I -999.~500 NR~T -~99.~500 -999.~500 FCNL -999.2500 1 9639 {LD t,~8t3 ibm 16~'06~5 ~R -~99,~500 fALl -999'~500 ~R!T -999,,~500 -999~500 ~CN5 -999.2500 141.11~5 ~R '999.2500 CALl 999 ~500 MRAT -999.~500 -999~ 500 gC~h -999'~500 1.9112 ?LO 1,?159 IbM 155.6875 GR -999.2500 CALl -999.~500 NRIT -999,2500 -990.2500 ~CN5 -999.2500 19737 !LO 1.9229 IbM i2413398 CR -999,9500 GAL! -999.2500 NR~T -999,2500 -999.~500 FCNb -999,~500 4553 ILO ~,4202 tlc 12 :9023 ~ -99~.~500 999.2500 rC~b -99 .2500 5452 ~bD 2,4807 IbM 10 ,5273 GR -999, -qgq 2500 N~T -999,2500 RNRA 100:~773 GR -999:2500 CALl, .-999.2500 NR~.T -999.2500 RNmA -q99, O0 -999;2:$00 ',~ -999. -q99,~'~00 $128 -999, ,9825 '99 .2500 -99 2,44?5 -999, . 2.4866 999.2500 -999,2500 2'!506 -999., 5'00 -999, 500 t, VP 01~,~0~ VErIFICAtION b!MTiNG PA~E ? SP~I -~99.~500 DEPT 4100,~000 SFLU SP.. -67, 852 RHO8 -q99..~500 DR~O NPH! -~99.'2500 RHOB -999,~500 D~P? '3~00.0000 SFLU RHOB '999.~00 DEPT 3~00 0000 SF[,U a~O,B -999.,9'500 DRHO ~EPT 3700 0000 SFt, U SP -71' ,2852 DEPT ~600.O000 ~FLU ~P. -73.97~7 NP~! -q9~ 500 NCNb DEPT 3500 0000 SFLU SP -73~T227 OR RHOB -999,~500 qPHI -999.~500 DEPT 3400 0000 ~FLU ~P -76~7852 RHOB -999,~500 ~R~O NPH! -q99,~500 DEPT 3200 0000 SFLU ' ~. nRHO SP 84:28~2 -999,~500 3 4417 114:~98 ~R -999.2500 NR~T -999'~500 FCNb 102i,2148 -q9~ 2500 NRAT -999,~500 2,60?7 ~09,7i48 -999.~500 NR.~T '999,2500 '6523 999.~500 WRiT '~99.2500 2 6760 94~7 .9~,25oo ~ 91n4 . 94,65~ ~R -099 ~500 NR~T . . . -999.2500 4.0476 109.4023 -999.~500 -999,2500 3 ~932 ~0!,3~98 '~99,2500 '999.2500 · 96,7~48 -999 ~5~0 .O9O' " - .~500 FC~Ib ~.3494 95.7773 -999.2500 3,2151 '999.2500 '~99,2500 '999'2500 2,9397 '999'2500 '999,2500 2,47'49 '999.2500 "999,2500 '999,2500 ~,0256 '~99.,.~500 '999.3'$00 -999.2500 2,7698 "999,2500 '999,2500 -999,2500 -999!2500 ~e99 2500 -999 ~500 2 5276 -~90!2500 -999 2500 -999 2500 4.0398 -999,2500 -999.~500 -099.2500 3,6077 -999.2500 -999.2500 -g9~.2500 ~,3312 -999.~500 -9'99.~500 -~99o 500 5 1375 -99q~2500 AL1 ~NRA ~N~A CALI RNRA ~NRA ~N~A RNRA CAbX ~NRA RN~A CAI~I WNRA ;,2620 '99.,2500 -999.2500 -999,2500 2'4983 -999,2500 -999,2500 -99 , 2 7307 '99 *~500 -999,2'$0'0 -999.~$00 . 2. 999.~ . ]. ?88 999.;500 -999.~00 . 999. -999, 0 4,0906 "999.~500 '999.2500 5,0164 -999,2500 -~99 ~500 MRAT ,,9~9,~500 ~IR~T ,-~99', ~500 WCML '099,2500 MC~L FILM TR~It, E~ **. ~ILE NAM~ {MD?T ,001 {E~VIC~ NA~E : )A?E t~ ~ZLE TYPr : ********** EOF ~* TAPM TRAILER ** {E~VIC~ NA~E :EDIT )ATE_ I'~5/!0/1, 9 3R~GTN lO000 CO~TTN~A?ZO~ # I01 ETTRP~ NA~E OMM~NTS :.LIbRarY TACE OA?E :85/i0/!9 OR~GIN : WE~L NRM~ :1.49217 CO~T~NT~ATI~N # :01 NEXT R~EL WA~E : COMMENTS :T,IRR~R¥ TAmE EOF EOF ********** .N~A -99~.25Oo -~99,~500 000,6875 IbM 299g'~500 CALI i 00,68?5 - 9,9.2500 -g99"~500 RNRA -999,2500