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183-094
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 29, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2C-04 KUPARUK RIV UNIT 2C-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/29/2023 2C-04 50-029-20973-00-00 183-094-0 W SPT 5618 1830940 3000 1450 1450 1450 1450 140 140 140 140 REQVAR P Guy Cook 8/9/2023 MIT-IA to maximum anticipated injection pressure per AIO 2B.091. Testing completed with a Little Red Services pump truck and calibrated gauges. 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 2C-04 Inspection Date: Tubing OA Packer Depth 520 3300 3200 3180IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230808102321 BBL Pumped:2.6 BBL Returned:2.6 Friday, September 29, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2C-04 KUPARUK RIV UNIT 2C-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 2C-04 50-029-20973-00-00 183-094-0 W SPT 5618 1830940 3000 1800 1800 1800 1800 140 140 140 140 REQVAR P Bob Noble 8/10/2025 MITIA to max injection pressure as per AIO2B.091 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 2C-04 Inspection Date: Tubing OA Packer Depth 700 3300 3230 3220IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250811104732 BBL Pumped:3.5 BBL Returned:2.9 Monday, September 22, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2C-04 KUPARUK RIV UNIT 2C-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/26/2023 2C-04 50-029-20973-00-00 183-094-0 W SPT 5618 1830940 3000 1440 1440 1440 1440 170 170 170 170 OTHER P Adam Earl 3/25/2023 MIT IA tested as per Sundry 323-085 post patch to max ant. Inj. Psi per AIO 2B.091 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 2C-04 Inspection Date: Tubing OA Packer Depth 750 3310 3230 3200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230329091514 BBL Pumped:2.3 BBL Returned:2.2 Wednesday, April 26, 2023 Page 1 of 1 9 9 9 9 9 9 99 9 9 99 9 9 Sundry 323-085 post patch James B. Regg Digitally signed by James B. Regg Date: 2023.04.26 13:51:50 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9190 feet N/A feet true vertical 6316 feet N/A feet Effective Depth measured 8177 feet 8150 & 8498 feet true vertical 5637 feet 5618 & 5858 feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3.5" J-55 8529' 5879' Packers and SSSV (type, measured and true vertical depth) Packer Camco HRP-1-SP 8450' 5618' Packer Backer FB-1 8498' 5858' SSSV Camco TRDP-1A 1831' 1739' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Oil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Dusty Freeborn dusty.freeborn@conocophillips.com 907-265-6218Well Integrity Specialist Gas-Mcf N/A N/AN/A N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 323-085 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A N/AN/A 16" 9.625" Size 102' 7" 8342-8455 & 8578-8619 feet 5751-5829 & 5913-5941 feet N/A Water-Bbl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 183-094 50-029-20973-00-00 P.O. Box 100360, Anchorage, AK 995103. Address: 5. Permit to Drill Number:2. Operator Name: 4. Well Class Before Work: ADL0025654 Kuparuk River Field/Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. KRU 2C-04 Plugs Junk measured N/A N/A N/A Length 70' 3579' 102'Conductor N/A measured true vertical Production 9134' Casing 6299'9162' Surface measured TVD 3610' 2845' Burst CollapseMD p k ft t Fra O s 183 6. A G L PG , h Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 9:44 am, Apr 17, 2023 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN= Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2023.04.17 09:18:53-08'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in KRU 2C-04 (PTD 183-094). Please contact me at 907-265-6218 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O= ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2023.04.17 09:18:24-08'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn Date Event Summary Executive Summary Reported to AOGCC for suspect IA pressure increase. Diagnostics suggested a tubing by inner annulus failure with a liquid leak rate of 0.1 gallons per minute at 3300 psi. An acoustic leak detect log suggested the leak was at the bottom of the SSSV at 1837'. A lower TTS patch packer was set and tested at 1845'. An upper TTS patch packer with spacer pipe was set at 1820'. A passing MIT-IA was perfromed to test integrity. The well was returned to injection and a passing AOGCC witnessed MIT-IA was performed. 03/25/23 (SW) State witnessed by Adam Earl, MITIA Passed to 3310 psi. Initial T/I/O = 1440/750/170, IA FL @ SF. LRS pressured IA with 2.3 bbl diesel to T/I/O = 1440/3310/170 15 min: 1440/3230/170 (-80 psi). 30 min: 1440/3200/170 (-30 psi). LRS bled 2.2 bbl diesel to T/I/O = 1440/750/170 Final T/I/O = 1440/750/170 03/06/23 SET LOWER 2.725" P2P @ 1845.5' RKB (ME @ 1848' / SN:CPP35327); RAN 3 1/2" TTS TEST TOOL DOWN TO 1845' RKB & CMIT TBG x IA TO 3000 PSI (PASS); SET UPPER 2.725" P2P (ME @ 1822' / SN:CPP35311), SPACER PIPE, & ANCHOR LATCH (CPAL35170) @ 1819.5' RKB; MITIA TO 3000 PSI (PASS). JOB COMPLETE. 02/13/23 Submitted 10-403 request for tubing patch installation. 01/20/23 CONVEY CALIPER W/ READ CASED HOLE, LOG FROM ABOVE RBP AT 8178' TO SURFACE. JOB COMPLETE & READY FOR PLAN FORWARD 01/19/23 CONVEY ACOUSTIC LDL W/ READ CASED HOLE, PUMPING DIESEL DOWN THE IA TAKING RETURNS UP TUBING TO AN OPEN TOP TANK. LOGGING PASSES MADE FROM ABOVE RBP AT 8178' TO SURFACE AND STATION STOPS PERFORMED OVER ALL JEWLERY, LEAK POINT IDENTIFIED AT 1837' AT BTM OF SUB SURFACE SAFETY VALVE JOB IN PROGRESS, READY FOR CALIPER LOG NEXT DAY 12/08/22 (AC EVAL) T X IA DDT PASSED 12/07/22 (AC EVAL) MIT-IA (FAILED) EST. IA X T LLR OF 0.10 GPM @ 3300 PSI, CMIT T X IA (PASSED) TO 3000 PSI, MIT-T (PASSED) TO 3000 PSI, DDT-T (IN PROGRESS) DDT-IA (IN PROGRESS) 12/06/22 CIRC OUT 240 BBLS INHIBITED SEAWATER & 75 BBLS DIESEL U-TUBE FREEZE PROTECT; SET DV @ 8083' RKB & MITT 2500 (PASS), DDT ON TBG (FAILED), PULLED 3 1/2 CATCHER ASSEMBLY @ 8180' RKB. READY FOR DHD. 11/29/22 (AC EVAL) IA DDT FAILED 11/27/22 (AC EVAL) T POT (Passed), T PPPOT (Passed), IC POT (Passed), IC PPPOT (Failed), MIT IA to 3300 psi (Passed), IA DDT (In progress). 11/23/22 REPORTED TO AOGCC FOR SUSPECT IA PRESSURE INCREASE Submit to: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1830940 Type Inj W Tubing 1440 1440 1440 1440 Type Test P Packer TVD 5618 BBL Pump 2.3 IA 750 3310 3230 3200 Interval O Test psi 3000 BBL Return 2.2 OA 170 170 170 170 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 / 2C Pad Adam Earl Beck / Borge 03/25/23 Notes:MITIA post patch per Sundry # 323-085 and to MAIP per AIO 2B.091 Notes: 2C-04 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 2C-04 03-25-23.xlsx Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,662.0 2C-04 11/3/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Patch 2C-04 3/6/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: T X IA ON MI water injection only 2/4/2015 lehallf NOTE: Tag of 5/26/14 is suspended hydrates 2/8/2014 hipshkf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 32.0 102.0 102.0 65.00 H-40 WELDED SURFACE 9 5/8 8.83 30.9 3,610.3 2,844.6 40.00 J-55 BTC PRODUCTION 7 6.28 27.7 9,162.0 6,298.9 26.00 K-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 21.4 Set Depth 8,528.5 Set Depth 5,879.1 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.20 Grade J-55 Top Connection EUE8rdABMO D ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 21.4 21.4 0.03 HANGER 8.000 FMC GEN II TUBING HANGER 3.500 1,831.2 1,739.3 34.81 SAFETY VLV 5.937 CAMCO TRDP-1A; Flapper Locked Out on 5/24/96; CL Sleeve Locked Out 3/26/96 CAMCO TRDP- 1A 2.812 8,083.8 5,573.2 47.30 GAS LIFT 5.940 OTIS LBX 2.907 8,127.9 5,603.2 46.94 PBR 5.625 CAMCO OEJ-10 PBR CAMCO OEJ-10 2.937 8,149.9 5,618.2 46.75 PACKER 5.937 CAMCO HRP-1-SP RETRIEVABLE PACKER CAMCO HRP- 1SP 2.867 8,352.0 5,757.7 46.42 BLAST JT 4.500 CAMCO BLAST JOINT PUPS (OAL = 59.17') 2.867 8,411.1 5,798.4 46.58 BLAST JTS 4.500 CAMCO BLAST JOINTS (2) 3.000 8,495.0 5,856.1 46.57 SEAL ASSY 4.500 LOCATOR SEAL ASSEMBLY 3.000 8,497.8 5,858.0 46.57 PACKER 5.875 BAKER FB-1 PERMANENT PACKER 4.000 8,501.2 5,860.3 46.58 SBE 5.000 BAKER 80-40 SEAL BORE EXTENSION 4.000 8,516.2 5,870.6 46.73 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 8,527.8 5,878.5 46.84 SOS 4.000 CAMCO SHEAR OUT SUB, ELMD TTL @ 8516 ON HES IPROF 8/1/11 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,819.5 1,729.6 34.46 PACKER - PATCH - UPR 2.725" UPPER P2P (MID ELEMENT @ 1822'), SPACER PIPE, & ANCHOR LATCH (26.84' OAL) CPP3 5311 3/6/2023 1.650 1,823.5 1,732.9 34.58 ANCHOR LATCH ON SPACER PIPE SPACER PIPE & ANCHOR LATCH CONNECTED TO UPPER P2P. CPAL 35170 3/6/2023 1.600 1,837.0 1,744.0 34.98 LEAK LEAK OVER SSSV IDENTIFIED ON ACOUSTIC LDL RUN 1/19/23 1/19/2023 2.812 1,845.5 1,751.0 35.24 PACKER - PATCH - LWR 2.725" LOWER P2P (4.01' OAL / MID ELEMENT @ 1,848.0) CPP3 5327 3/6/2023 1.650 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,083.8 5,573.2 47.30 1 GAS LIFT DMY RM 1 1/2 0.0 12/6/2022 0.000 8,195.1 5,649.3 46.36 2 INJ DMY RM 1 1/2 0.0 10/2/2005 0.000 8,276.6 5,705.6 46.27 3 INJ DMY RM 1 1/2 0.0 10/2/2005 0.000 8,477.6 5,844.1 46.57 4 INJ DMY RM 1 1/2 0.0 12/8/2011 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,258.0 8,260.0 5,692.8 5,694.2 7/22/1983 4.0 SQZ DRESSER ATLAS 8,342.0 8,402.0 5,750.8 5,792.1 C-1, C-3, C-4, UNIT B, 2C-04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,363.0 8,364.0 5,765.3 5,766.0 C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,365.0 8,366.0 5,766.7 5,767.4 C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,371.0 8,372.0 5,770.8 5,771.5 C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,379.0 8,383.0 5,776.3 5,779.1 C-3, C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,387.0 8,389.0 5,781.8 5,783.2 C-3, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,395.0 8,399.0 5,787.3 5,790.1 C-1, UNIT B, 2C- 04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,433.0 8,440.0 5,813.4 5,818.2 UNIT B, 2C-04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,435.0 8,439.0 5,814.8 5,817.6 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 2C-04, 3/7/2023 7:48:33 AM Vertical schematic (actual) PRODUCTION; 27.7-9,162.0 RPERF; 8,609.5-8,619.5 APERF; 8,578.0-8,613.0 RPERF; 8,579.5-8,609.5 SOS; 8,527.8 Cement Squeeze; 8,520.0 ftKB SQZ; 8,520.0-8,522.0 NIPPLE; 8,516.2 SBE; 8,501.2 PACKER; 8,497.8 SEAL ASSY; 8,495.0 INJECTION; 8,477.6 IPERF; 8,454.0-8,455.0 IPERF; 8,452.0-8,453.0 RPERF; 8,448.0-8,456.0 IPERF; 8,450.0-8,451.0 IPERF; 8,435.0-8,439.0 RPERF; 8,433.0-8,440.0 IPERF; 8,395.0-8,399.0 IPERF; 8,387.0-8,389.0 IPERF; 8,379.0-8,383.0 RPERF; 8,342.0-8,402.0 IPERF; 8,371.0-8,372.0 IPERF; 8,365.0-8,366.0 IPERF; 8,363.0-8,364.0 INJECTION; 8,276.6 TUBING PUP; 8,270.6 Cement Squeeze; 8,258.0 ftKB SQZ; 8,258.0-8,260.0 INJECTION; 8,195.1 PACKER; 8,149.8 PBR; 8,127.9 GAS LIFT; 8,083.8 SURFACE; 30.9-3,610.3 PACKER - PATCH - LWR; 1,845.5 LEAK; 1,837.0 SAFETY VLV; 1,831.2 ANCHOR LATCH ON SPACER PIPE; 1,823.5 PACKER - PATCH - UPR; 1,819.5 CONDUCTOR; 32.0-102.0 HANGER; 21.4 KUP INJ KB-Grd (ft) 28.99 RR Date 7/12/1983 Other Elev 2C-04 ... TD Act Btm (ftKB) 9,190.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292097300 Wellbore Status INJ Max Angle & MD Incl (°) 59.10 MD (ftKB) 4,200.00 WELLNAME WELLBORE2C-04 Annotation Last WO: End Date 10/24/1987 H2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,448.0 8,456.0 5,823.7 5,829.2 UNIT B, 2C-04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,450.0 8,451.0 5,825.1 5,825.8 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,452.0 8,453.0 5,826.5 5,827.2 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,454.0 8,455.0 5,827.9 5,828.6 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,520.0 8,522.0 5,873.2 5,874.6 UNIT B, 2C-04 7/22/1983 4.0 SQZ DRESSER ATLAS 8,578.0 8,613.0 5,912.7 5,936.4 A-3, 2C-04 8/4/1983 12.0 APERF 5" Geo Vann 8,579.5 8,609.5 5,913.7 5,934.0 A-3, 2C-04 8/12/2012 6.0 RPERF 2" Millenium HMX, DP, 60 Deg Phase 8,609.5 8,619.5 5,934.0 5,940.8 A-3, 2C-04 8/9/2012 6.0 RPERF 2" Millenium HMX, DP, 60 Deg Phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,258.0 8,260.0 5,692.8 5,694.2 Cement Squeeze 5/20/2011 8,520.0 8,522.0 5,873.2 5,874.6 Cement Squeeze 2C-04, 3/7/2023 7:48:34 AM Vertical schematic (actual) PRODUCTION; 27.7-9,162.0 RPERF; 8,609.5-8,619.5 APERF; 8,578.0-8,613.0 RPERF; 8,579.5-8,609.5 SOS; 8,527.8 Cement Squeeze; 8,520.0 ftKB SQZ; 8,520.0-8,522.0 NIPPLE; 8,516.2 SBE; 8,501.2 PACKER; 8,497.8 SEAL ASSY; 8,495.0 INJECTION; 8,477.6 IPERF; 8,454.0-8,455.0 IPERF; 8,452.0-8,453.0 RPERF; 8,448.0-8,456.0 IPERF; 8,450.0-8,451.0 IPERF; 8,435.0-8,439.0 RPERF; 8,433.0-8,440.0 IPERF; 8,395.0-8,399.0 IPERF; 8,387.0-8,389.0 IPERF; 8,379.0-8,383.0 RPERF; 8,342.0-8,402.0 IPERF; 8,371.0-8,372.0 IPERF; 8,365.0-8,366.0 IPERF; 8,363.0-8,364.0 INJECTION; 8,276.6 TUBING PUP; 8,270.6 Cement Squeeze; 8,258.0 ftKB SQZ; 8,258.0-8,260.0 INJECTION; 8,195.1 PACKER; 8,149.8 PBR; 8,127.9 GAS LIFT; 8,083.8 SURFACE; 30.9-3,610.3 PACKER - PATCH - LWR; 1,845.5 LEAK; 1,837.0 SAFETY VLV; 1,831.2 ANCHOR LATCH ON SPACER PIPE; 1,823.5 PACKER - PATCH - UPR; 1,819.5 CONDUCTOR; 32.0-102.0 HANGER; 21.4 KUP INJ 2C-04 ... WELLNAME WELLBORE2C-04 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Plugs (MD): Junk (MD): 9190'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dusty Freeborn dusty.freeborn@conocophillips.com (907) 659-7224 Senior Well Integrity Specialist Tubing Grade: Tubing MD (ft): 8150' MD and 5618' TVD 8498' MD and 5858' TVD 1831' MD and 1739' TVD Perforation Depth TVD (ft): Tubing Size: J-55 8528' 2/25/2023 Packer: Camco HRP-1-SP Rtvbl Packer Packer: Baker FB-1 Perm Packer SSSV: Camco TRDP-1A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025654 183-094 P.O. Box 100360, Anchorage, AK 99510 50-029-20973-00-00 ConocoPhillips Alaska, Inc. KRU 2C-04 Kuparuk River Oil PoolKuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6316' 8177' 5637' 8177' MD 102' 2845' 102' 3610' 6299'9162' 16" 9-5/8" 70' 3579' Perforation Depth MD (ft): 8342-8455', 8578-8619' 9134' 5751-5829', 5913-5941' 3-1/2" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov MPSP (psi): 1987 psi By Samantha Carlisle at 8:33 am, Feb 13, 2023 323-085 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.comReason: I am the author of this documentLocation: Eagle River, AlaskaDate: 2023.02.13 08:22:54-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn DLB 02/13/2023 DSR-2/13/23 X 10-404 VTL 02/15/23 X X GCW 02/16/23JLC 2/16/2023 2/16/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.16 14:19:51 -09'00' RBDMS JSB 022123 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 13 February 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 2C-04 (PTD 183-094) to set a retrievable tubing patch over a known tubing leak to regain tubing by inner annulus integrity. Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.02.13 08:22:18-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn Well Work Justification & Objectives: 2C-04 has a tubing leak at 1837'. A tubing patch needs to be installed to regain TxIA integrity and resume injection. Risks/Job Concerns (Include Drift information on high deviation wells, or wells with tag issues): Do not perform Patch installation until approved sundry has been recieved. Waivered for known TxIA on gas injection Tubing leak at 1837' D&T has net been conducted since 2015' SSSV locked out Steps: S-line 1. Pull 3.5" P2P RBP from 8178'. 2. Brush and flush patch set area of ~1810'-1880'. 3. Drift with dummy 3.5" P2P with ~24' spacer pipe patch E-line 1. Set lower 3.5" P2P mid-element at 1848'. S-line 1. Set test tool in 3.5" P2P at 1848'. 2. Perform CMIT-TxIA to 3000 psi. Record initial, 15 and 30 min TIO pressures. 3. Pull test tool from 1848'. 4. Set anchor latch, spacer pipe and upper 3.5" P2P mid element at 1822'. 5. Perform MIT-IA to 3300 psi. Record initial, 15 and 30 min TIO pressures. 6. If MIT-IA passes return well to operations to resume injection. DHD to perform SW MIT-IA once online and IA has stabilized. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,662.0 2C-04 11/3/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Leak added at 1837' RKB (SSSV) 2C-04 1/19/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: T X IA ON MI water injection only 2/4/2015 lehallf NOTE: Tag of 5/26/14 is suspended hydrates 2/8/2014 hipshkf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 32.0 102.0 102.0 65.00 H-40 WELDED SURFACE 9 5/8 8.83 30.9 3,610.3 2,844.6 40.00 J-55 BTC PRODUCTION 7 6.28 27.7 9,162.0 6,298.9 26.00 K-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 21.4 Set Depth … 8,528.5 Set Depth … 5,879.1 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.20 Grade J-55 Top Connection EUE8rdABMO D ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 21.4 21.4 0.03 HANGER 8.000 FMC GEN II TUBING HANGER 3.500 1,831.2 1,739.3 34.81 SAFETY VLV 5.937 CAMCO TRDP-1A; Flapper Locked Out on 5/24/96; CL Sleeve Locked Out 3/26/96 CAMCO TRDP- 1A 2.812 8,083.8 5,573.2 47.30 GAS LIFT 5.940 OTIS LBX 2.907 8,127.9 5,603.2 46.94 PBR 5.625 CAMCO OEJ-10 PBR CAMCO OEJ-10 2.937 8,149.9 5,618.2 46.75 PACKER 5.937 CAMCO HRP-1-SP RETRIEVABLE PACKER CAMCO HRP- 1SP 2.867 8,352.0 5,757.7 46.42 BLAST JT 4.500 CAMCO BLAST JOINT PUPS (OAL = 59.17') 2.867 8,411.1 5,798.4 46.58 BLAST JTS 4.500 CAMCO BLAST JOINTS (2) 3.000 8,495.0 5,856.1 46.57 SEAL ASSY 4.500 LOCATOR SEAL ASSEMBLY 3.000 8,497.8 5,858.0 46.57 PACKER 5.875 BAKER FB-1 PERMANENT PACKER 4.000 8,501.2 5,860.3 46.58 SBE 5.000 BAKER 80-40 SEAL BORE EXTENSION 4.000 8,516.2 5,870.6 46.73 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 8,527.8 5,878.5 46.84 SOS 4.000 CAMCO SHEAR OUT SUB, ELMD TTL @ 8516 ON HES IPROF 8/1/11 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,837.0 1,744.0 34.98 LEAK LEAK OVER SSSV IDENTIFIED ON ACOUSTIC LDL RUN 1/19/23 1/19/2023 2.812 8,177.5 5,637.2 46.51 PLUG 2.725" RBP SET MID ELEMENT @ 8,180' RKB (7.97' OAL) TTS QUADC O P2P CPP3 5327/ CPEQ 35021 12/5/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,083.8 5,573.2 47.30 1 GAS LIFT DMY RM 1 1/2 0.0 12/6/2022 0.000 8,195.1 5,649.3 46.36 2 INJ DMY RM 1 1/2 0.0 10/2/2005 0.000 8,276.6 5,705.6 46.27 3 INJ DMY RM 1 1/2 0.0 10/2/2005 0.000 8,477.6 5,844.1 46.57 4 INJ DMY RM 1 1/2 0.0 12/8/2011 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,258.0 8,260.0 5,692.8 5,694.2 7/22/1983 4.0 SQZ DRESSER ATLAS 8,342.0 8,402.0 5,750.8 5,792.1 C-1, C-3, C-4, UNIT B, 2C-04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,363.0 8,364.0 5,765.3 5,766.0 C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,365.0 8,366.0 5,766.7 5,767.4 C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,371.0 8,372.0 5,770.8 5,771.5 C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,379.0 8,383.0 5,776.3 5,779.1 C-3, C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,387.0 8,389.0 5,781.8 5,783.2 C-3, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,395.0 8,399.0 5,787.3 5,790.1 C-1, UNIT B, 2C- 04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,433.0 8,440.0 5,813.4 5,818.2 UNIT B, 2C-04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,435.0 8,439.0 5,814.8 5,817.6 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,448.0 8,456.0 5,823.7 5,829.2 UNIT B, 2C-04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,450.0 8,451.0 5,825.1 5,825.8 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,452.0 8,453.0 5,826.5 5,827.2 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,454.0 8,455.0 5,827.9 5,828.6 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,520.0 8,522.0 5,873.2 5,874.6 UNIT B, 2C-04 7/22/1983 4.0 SQZ DRESSER ATLAS 8,578.0 8,613.0 5,912.7 5,936.4 A-3, 2C-04 8/4/1983 12.0 APERF 5" Geo Vann 2C-04, 2/9/2023 1:44:46 PM Vertical schematic (actual) PRODUCTION; 27.7-9,162.0 RPERF; 8,609.5-8,619.5 APERF; 8,578.0-8,613.0 RPERF; 8,579.5-8,609.5 SQZ; 8,520.0-8,522.0 Cement Squeeze; 8,520.0 ftKB PACKER; 8,497.8 INJECTION; 8,477.6 IPERF; 8,454.0-8,455.0 IPERF; 8,452.0-8,453.0 RPERF; 8,448.0-8,456.0 IPERF; 8,450.0-8,451.0 IPERF; 8,435.0-8,439.0 RPERF; 8,433.0-8,440.0 IPERF; 8,395.0-8,399.0 IPERF; 8,387.0-8,389.0 IPERF; 8,379.0-8,383.0 RPERF; 8,342.0-8,402.0 IPERF; 8,371.0-8,372.0 IPERF; 8,365.0-8,366.0 IPERF; 8,363.0-8,364.0 INJECTION; 8,276.6 TUBING PUP; 8,270.6 SQZ; 8,258.0-8,260.0 Cement Squeeze; 8,258.0 ftKB INJECTION; 8,195.1 PLUG; 8,177.5 PACKER; 8,149.8 GAS LIFT; 8,083.8 SURFACE; 30.9-3,610.3 LEAK; 1,837.0 SAFETY VLV; 1,831.2 CONDUCTOR; 32.0-102.0 KUP INJ KB-Grd (ft) 28.99 RR Date 7/12/1983 Other Elev… 2C-04 ... TD Act Btm (ftKB) 9,190.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292097300 Wellbore Status INJ Max Angle & MD Incl (°) 59.10 MD (ftKB) 4,200.00 WELLNAME WELLBORE2C-04 Annotation Last WO: End Date 10/24/1987 H2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,579.5 8,609.5 5,913.7 5,934.0 A-3, 2C-04 8/12/2012 6.0 RPERF 2" Millenium HMX, DP, 60 Deg Phase 8,609.5 8,619.5 5,934.0 5,940.8 A-3, 2C-04 8/9/2012 6.0 RPERF 2" Millenium HMX, DP, 60 Deg Phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,258.0 8,260.0 5,692.8 5,694.2 Cement Squeeze 5/20/2011 8,520.0 8,522.0 5,873.2 5,874.6 Cement Squeeze 2C-04, 2/9/2023 1:44:47 PM Vertical schematic (actual) PRODUCTION; 27.7-9,162.0 RPERF; 8,609.5-8,619.5 APERF; 8,578.0-8,613.0 RPERF; 8,579.5-8,609.5 SQZ; 8,520.0-8,522.0 Cement Squeeze; 8,520.0 ftKB PACKER; 8,497.8 INJECTION; 8,477.6 IPERF; 8,454.0-8,455.0 IPERF; 8,452.0-8,453.0 RPERF; 8,448.0-8,456.0 IPERF; 8,450.0-8,451.0 IPERF; 8,435.0-8,439.0 RPERF; 8,433.0-8,440.0 IPERF; 8,395.0-8,399.0 IPERF; 8,387.0-8,389.0 IPERF; 8,379.0-8,383.0 RPERF; 8,342.0-8,402.0 IPERF; 8,371.0-8,372.0 IPERF; 8,365.0-8,366.0 IPERF; 8,363.0-8,364.0 INJECTION; 8,276.6 TUBING PUP; 8,270.6 SQZ; 8,258.0-8,260.0 Cement Squeeze; 8,258.0 ftKB INJECTION; 8,195.1 PLUG; 8,177.5 PACKER; 8,149.8 GAS LIFT; 8,083.8 SURFACE; 30.9-3,610.3 LEAK; 1,837.0 SAFETY VLV; 1,831.2 CONDUCTOR; 32.0-102.0 KUP INJ 2C-04 ... WELLNAME WELLBORE2C-04 C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2023-01-20_15902_KRU_2C-04_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15902 KRU 2C-04 50-029-20973-00 Caliper Survey w/ Log Data 20-Jan-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 11:30 am, Jan 24, 2023 183-094 T37468 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.24 11:33:02 -09'00' C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2023-01-19_15901_KRU_2C-04_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15901 KRU 2C-04 50-029-20973-00 LeakPoint Survey 19-Jan-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 2:18 pm, Jan 23, 2023 183-094 T37458 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.23 14:20:50 -09'00' Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 32.0 Set Depth (ftKB) 102.0 Set Depth (TVD) … 102.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.835 Top (ftKB) 30.9 Set Depth (ftKB) 3,610.3 Set Depth (TVD) … 2,844.6 Wt/Len (l… 40.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 27.7 Set Depth (ftKB) 9,162.0 Set Depth (TVD) … 6,298.9 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 21.4 Set Depth (ft… 8,528.5 Set Depth (TVD) (… 5,879.1 Wt (lb/ft) 9.20 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 21.4 21.4 0.03 HANGER FMC GEN II TUBING HANGER 3.500 1,831.2 1,739.3 34.81 SAFETY VLV CAMCO TRDP-1A; Flapper Locked Out on 5/24/96; CL Sleeve Locked Out 3/26/96 2.812 8,127.9 5,603.2 46.94 PBR CAMCO OEJ-10 PBR 2.937 8,149.9 5,618.2 46.75 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.867 8,352.0 5,757.7 46.42 BLAST JT CAMCO BLAST JOINT PUPS (OAL = 59.17')2.867 8,411.1 5,798.4 46.58 BLAST JTS CAMCO BLAST JOINTS (2)3.000 8,495.0 5,856.1 46.57 SEAL ASSY LOCATOR SEAL ASSEMBLY 3.000 8,497.8 5,858.0 46.57 PACKER BAKER FB-1 PERMANENT PACKER 4.000 8,501.2 5,860.3 46.58 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 8,516.2 5,870.6 46.73 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,527.8 5,878.5 46.84 SOS CAMCO SHEAR OUT SUB, ELMD TTL @ 8516 ON HES IPROF 8/1/11 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 8,258.0 8,260.0 5,692.8 5,694.2 7/22/1983 4.0 SQZ DRESSER ATLAS 8,342.0 8,402.0 5,750.8 5,792.1 C-1, C-3, C-4, UNIT B, 2C- 04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,363.0 8,364.0 5,765.3 5,766.0 C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,365.0 8,366.0 5,766.7 5,767.4 C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,371.0 8,372.0 5,770.8 5,771.5 C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,379.0 8,383.0 5,776.3 5,779.1 C-3, C-4, 2C- 04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,387.0 8,389.0 5,781.8 5,783.2 C-3, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,395.0 8,399.0 5,787.3 5,790.1 C-1, UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,433.0 8,440.0 5,813.4 5,818.2 UNIT B, 2C- 04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,435.0 8,439.0 5,814.8 5,817.6 UNIT B, 2C- 04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,448.0 8,456.0 5,823.7 5,829.2 UNIT B, 2C- 04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,450.0 8,451.0 5,825.1 5,825.8 UNIT B, 2C- 04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,452.0 8,453.0 5,826.5 5,827.2 UNIT B, 2C- 04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,454.0 8,455.0 5,827.9 5,828.6 UNIT B, 2C- 04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,520.0 8,522.0 5,873.2 5,874.6 UNIT B, 2C- 04 7/22/1983 4.0 SQZ DRESSER ATLAS 8,578.0 8,613.0 5,912.7 5,936.4 A-3, 2C-04 8/4/1983 12.0 APERF 5" Geo Vann 8,579.5 8,609.5 5,913.7 5,934.0 A-3, 2C-04 8/12/2012 6.0 RPERF 2" Millenium HMX, DP, 60 Deg Phase 8,609.5 8,619.5 5,934.0 5,940.8 A-3, 2C-04 8/9/2012 6.0 RPERF 2" Millenium HMX, DP, 60 Deg Phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 8,258.0 8,260.0 5,692.8 5,694.2 Cement Squeeze 5/20/2011 8,520.0 8,522.0 5,873.2 5,874.6 Cement Squeeze 5/20/2011 Mandrel Inserts St ati on N o/ Top (ftKB) Top (TVD) (ftKB) Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 8,083.8 5,573.2 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 2/24/2000 2 8,195.1 5,649.3 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 10/2/2005 3 8,276.6 5,705.6 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 10/2/2005 4 8,477.6 5,844.1 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 12/8/2011 Notes: General & Safety End Date Annotation 9/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2/8/2014 NOTE: Tag of 5/26/14 is suspended hydrates Comment SSSV: LOCKED OUT2C-04, 11/4/2015 3:17:05 PM Vertical schematic (actual) PRODUCTION; 27.7-9,162.0 RPERF; 8,609.5-8,619.5 APERF; 8,578.0-8,613.0 RPERF; 8,579.5-8,609.5 SOS; 8,527.8 SQZ; 8,520.0-8,522.0 NIPPLE; 8,516.2 SBE; 8,501.2 PACKER; 8,497.8 SEAL ASSY; 8,495.0 INJECTION; 8,477.6 IPERF; 8,454.0-8,455.0 IPERF; 8,452.0-8,453.0 RPERF; 8,448.0-8,456.0 IPERF; 8,450.0-8,451.0 IPERF; 8,435.0-8,439.0 RPERF; 8,433.0-8,440.0 IPERF; 8,395.0-8,399.0 IPERF; 8,387.0-8,389.0 IPERF; 8,379.0-8,383.0 RPERF; 8,342.0-8,402.0 IPERF; 8,371.0-8,372.0 IPERF; 8,365.0-8,366.0 IPERF; 8,363.0-8,364.0 INJECTION; 8,276.6 TUBING PUP; 8,270.6 SQZ; 8,258.0-8,260.0 INJECTION; 8,195.1 PACKER; 8,149.8 PBR; 8,127.9 GAS LIFT; 8,083.8 SURFACE; 30.9-3,610.3 SAFETY VLV; 1,831.2 CONDUCTOR; 32.0-102.0 HANGER; 21.4 Annotation Last Tag: SLM Depth (ftKB) 8,662.0 End Date 11/3/2015 Annotation Rev Reason: TAG Last Mod By pproven End Date 11/4/2015 KUP INJ KB-Grd (ft) 28.99 Rig Release Date 7/12/1983 Annotation Last WO: End Date 10/24/1987 2C-04 H2S (ppm) Date ... TD Act Btm (ftKB) 9,190.0 Well Attributes Wellbore API/UWI 500292097300 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 59.10 MD (ftKB) 4,200.00 Notes: General & Safety End Date Annotation 2/4/2015 NOTE: T X IA ON MI water injection only 2C-04, 11/4/2015 3:17:07 PM Vertical schematic (actual) PRODUCTION; 27.7-9,162.0 RPERF; 8,609.5-8,619.5 APERF; 8,578.0-8,613.0 RPERF; 8,579.5-8,609.5 SOS; 8,527.8 SQZ; 8,520.0-8,522.0 NIPPLE; 8,516.2 SBE; 8,501.2 PACKER; 8,497.8 SEAL ASSY; 8,495.0 INJECTION; 8,477.6 IPERF; 8,454.0-8,455.0 IPERF; 8,452.0-8,453.0 RPERF; 8,448.0-8,456.0 IPERF; 8,450.0-8,451.0 IPERF; 8,435.0-8,439.0 RPERF; 8,433.0-8,440.0 IPERF; 8,395.0-8,399.0 IPERF; 8,387.0-8,389.0 IPERF; 8,379.0-8,383.0 RPERF; 8,342.0-8,402.0 IPERF; 8,371.0-8,372.0 IPERF; 8,365.0-8,366.0 IPERF; 8,363.0-8,364.0 INJECTION; 8,276.6 TUBING PUP; 8,270.6 SQZ; 8,258.0-8,260.0 INJECTION; 8,195.1 PACKER; 8,149.8 PBR; 8,127.9 GAS LIFT; 8,083.8 SURFACE; 30.9-3,610.3 SAFETY VLV; 1,831.2 CONDUCTOR; 32.0-102.0 HANGER; 21.4 KUP INJ 2C-04 ... CAUTION: 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Kuparuk injector 2C-04 (PTD #183-094) report of IA re-pressurization after IA bleed. Date:Wednesday, November 23, 2022 12:08:30 PM Attachments:image001.png AnnComm Surveillance TIO for 2C-04.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, November 23, 2022 11:22 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Kuparuk injector 2C-04 (PTD #183-094) report of IA re-pressurization after IA bleed. Chris- Kuparuk injector 2C-04 (PTD #183-094) was reported by operations as having IA re-pressurization after IA bleed attempts. Currently the well operates under AIO 2B.091 water injection only due to TxIA communication while on gas injection. CPAI intends to leave the well on injection to conduct the initial set of diagnostics. If the testing proves integrity the well will be placed on a 30 day monitor period. If the well fails the initial diagnostic testing, the well will be shut in and freeze protected for additional diagnostics. The proper paperwork for continued injection or repair will be submitted as required. Please let me know if you have any questions or disagree with the plan. Attached is a well bore schematic and 90 day TIO plot. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Matt Herrera Petroleum Inspector I Well Name KUPARUK RIV UNF4 2C-04 Insp Num: mitMFH210818075437 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 20, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2C-04 KUPARUK RIV UNIT 2C-04 Src: Inspector Reviewed By: P.I. Supry Jl� Comm API Well Number 50-029-20973-00-00 Inspector Name: Matt Herrera Permit Number: 183-094-0 Inspection Date: 8/15/2021 ' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2C-04 Type Inj W 'TVD 5618 Tubing' 1850 1850 1835 - 1830 - PTD 1830940 SPT'iTest sl 3000 IA 840 3300- 3150 3115 Type Test' p BBL Pumped: 3.2 BBL Returned: li 3.1 OA 140 140 140 140 Interval REQVAR P/F P �I Notes: MFF -IA Performed to MAIP Per A10 2B.091 Friday, August 20, 2021 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Sim Regg fes`DATE: Tuesday, December 10, 2019 P.I. Supervisor , I7 (jol tq SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2C-04 FROM: Adam Earl KUPARUK RIV UNIT 2C-04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Sup" NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2C-04 API Well Number 50-029-20973-00-00 Inspector Name: Adam Earl Permit Number: 183-094-0 Inspection Date: 12/7/2019 - Insp Num: miWGE191207201954 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2C-04 Type Inj W 'TVD 5618 Tubing 1700 1700P-31fj 1700 ' PTD 1830940 Type Test SPT Test psi 3000 IA 1130 3280 3160 " BBL Pumped: 22 ' IBBL Returned: 21 OA 120 120 120 120 Interval I REQVAR P/F P Notes: Tested as per A10 2B.091 to max anticipated inj. Pressure. Tuesday, December 10, 2019 Page 1 of 1 II • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,January 22,2018 Jim Regg ((z I� P.I.Supervisor 1` I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2C-04 FROM: Guy Cook KUPARUK RIV UNIT 2C-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvs-33Q-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2C-04 API Well Number 50-029-20973-00-00 Inspector Name: Guy Cook Permit Number: 183-094-0 Inspection Date: 1/21/2018 Insp Num: mitGDC180121161410 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2C-04 'Type Inj 11 W 'TVD 5618 " Tubing 1225 - 1225 1225 1225 PTD 1 1830940 "Type Test SPT Test psi i 3000 IA 20 3300 " 3160 - 3120 ' - BBL Pumped: 4.5 , BBL Returned: 4 ' OA 150 155 155 " 155 - Interval REQVAR P/F P - : —--- Notes: MIT-IA per AIO 2B.091 to maximum anticipated injection pressure. Little Red Services pump truck used for testing. SCAN F{,.r. hf U R i" Monday,January 22,2018 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, December 24, 2017 3:38 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 2C-04 (PTD# 183-094) Report of suspect IA pressurization update 12-24-17 Attachments: 2C-04 180 day TIO 12-24-17.JPG; MIT KRU 2C-04 Diagnostic 8-28-17.xlsx Hi Chris, KRU injector 2C-04(PTD#183-094,AIO 2B.091)was reported earlier this year because of an unknown IA pressure increase while the well was shut in. The well has been shut in since 3-31-16 for reservoir management reasons. On August 28,2017, a passing MITIA and tubing packoff tests were obtained where a significant amount of gas was found to be in the IA. Because the well is already waivered for known TxIA communication on gas injection, it is believed a gas slug was passing through the reservoir while the well was shut in allowing the gas to migrate into the annulus/near- wellbore area,thus causing the pressure to spike. In order to confirm this theory,CPAI intends to return the well to water injection and obtain a witnessed MIT once the well is stabilized (the MIT is currently past its anniversary due date). During the past several months,there has been minimal IA pressure recharge after the annulus was degassed in August. Pending a passing witnessed MIT after achieving stabilization,the well will be returned to its normally waivered status. Please let us know if you disagree with the path forward. Attached is the MIT data from August 28 and an updated 180 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 SCANNED w F Fr•-• : NSK Well Integrity Supv CPF1 and 2 Sent: • •day,August 27,2017 3:41 PM To:Wallace, • is D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyle '.Tyler.Senden@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips. : I > Subject: KRU 2C-04(PTD#183-.'4) Report of suspect IA pressurization Chris, KRU water injector 2C-04(PTD#183-094) regulates der AIO 26.091 for known TxIA communication on gas is exhibiting unexplained IA pressure increase. The well h. seen shut in since 12/01/16. DHD will perform initial diagnostics to include an MITIA, pack off tests, and draw do • the IA pressure. If diagnostics pass the well may be placed on a 30 day monitor period once brought on injection. An -quired paperwork for corrective action or continued injection will be submitted subsequent diagnostics or the ms .'tor period. Attached is a 90 day TIO trend and wellbore schematic. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday,August 27, 2017 3:41 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU 2C-04 (PTD# 183-Z41.Report of suspect IA pressurization Attachments: 2C-04.pdf; 2C-04 90 day TIO trend 8-27-17.PNG Chris, KRU water injector 2C-04(PTD#183-094) regulated under AIO 26.091 for known TxIA communication on gas is exhibiting unexplained IA pressure increase. The well has been shut in since 12/01/16. DHD will perform initial diagnostics to include an MITIA, pack off tests, and draw down the IA pressure. If diagnostics pass the well may be placed on a 30 day monitor period once brought on injection. Any required paperwork for corrective action or continued injection will be submitted subsequent diagnostics or the monitor period. Attached is a 90 day TIO trend and wellbore schematic. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 WELS TEAM SNE® SEP 1 5 2017. 1 y • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, January 23, 2016 3:05 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 2C-04 (PTD 183-094) Report of IA pressure anomaly update 1-23-16 Attachments: MIT KRU 2C-04 diagnostic MITIA 1-13-16.xls Chris, Diagnostics were completed on 2C-04 and there does not appear to be any problem beyond the known slow gas-only leak, for which the well is already waivered. The well was shut in this past summer/fall for an extended period of time from 06-25-15 to 10-23-15. It is believed that during this extended shut in period, a gas slug moved through the reservoir and entered the tubing/near wellbore area and migrated into the inner annulus. After a passing MITIA was completed on 01-13-16, it took several days of bleeding in order to degas the IA. The final bleed down to —100psi was performed on 01-19-16, and the IA has not shown any buildup in pressure since then. The well has now been shut in since 01-11-16. ConocoPhillips intends to return 2C-04 to water injection in the near future and return it to its normally waivered status, operating under A10 26.091. If any future indications of communication present themselves, it will be re-reported at that time. Please let us know if you disagree with the plan forward. Attached are the most recent 90 day TIO plot and MITIA data. SCANNED MAY 2 6 X016; 1 • Well Name 2C-04 Notes: Start Date 10/2512015 Days 90 End Date 1/2312016 3CCO — - 1! WHP Annular Communication Surveillance A _ P -�/��--�' vv -...t "�� - 1 25CC - •WHT 1: 1: 2000 1' 1E CC 11 Q"1CCC 114 1111 71 SCC — si Oct-1E Oct-1` No':-15 Nov-1E Nov;-1E Dec-1E Cec-1s Cec-1E Jan-1e Jan-1"e Jan-le Jan-1e r Oct-1` Oct-15 Nov-15 Nov-1E Nov-1E Dec-1E Cec-1S Dec-15 Jan-1v Jan-16 Jan-16 Jan-1F Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 From: NSK Problem Well Supv Sent: Tuesday, January 12, 2016 9:59 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R. Tyler Subject: KRU 2C-04 (PTD 183-094) Report of IA pressure anomaly 2 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday,January 12, 2016 9:59 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R. Tyler Subject: KRU 2C-04 (PTD 183-094) Report of IA pressure anomaly Attachments: 2C-04 schematic.pdf Chris, Kuparuk water injector 2C-04 (PTD 183-094) was reported with an IA pressure anomaly. The well is currently operating under A10 26.091 for TxIA communication on gas only. The well has been SI. Initial diagnostics will include an MITIA and an IA drawdown test if the MIT passes. Pending the results,further diagnostics may be performed by Slickline, E-Line, Digital Slickline as needed. An update and the appropriate paperwork will be submitted as needed for repair or request for continued injection and monitoring. Please let me know if you disagree. A 90 day TIO plot and wellbore schematic are attached for reference. SCANNED MAY 0 2 2016 • • 14.9 55t WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. ;. December 10, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 ' DATA LOGGED Anchorage, Alaska 99501 i /201 G K BENDER RE: Oxygen Activation Log with TMD3D: 2C-04 Run Date: 11/5/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2C-04 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-20973-00 Oxygen Activation Log with TMD3D (Field print) 1 Color Log 50-029-20973-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari SCASHEKi 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: P.9,,Adza.ozoLde4cedie • • 15S3 -t,rt WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2C -04 Run Date: 9/5/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2C -04 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 20973 -00 Injection Profile Log 1 Color Log 50- 029 - 20973 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: Signed: a at- \ �0 2 2 �'� g &It STATE OF ALASKA ALAI, OIL AND GAS CONSERVATION COM.ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell j"' Rug Fbrforations r Perforate 17 Other r Alter Casing r Rill Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 183 - 094 3. Address: 6. API Number;, �(� P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50- 029 - 20973 -00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25654 ' '''' 2C - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9190 feet Plugs (measured) None true vertical 6317 feet Junk (measured) None Effective Depth measured 9078 feet Packer (measured) 8150, 8498 true vertical 6243 feet (true vertucal) 5618, 5858 Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 102 102 SURFACE 3579 9.625 3610 2845 PRODUCTION 9134 7 9162 6299 /1� y}j �F- `,„ E/ 0 .Loh. 1 ® 2 Sc) G � Perforation depth: Measured depth: 8342 -8402, 8433 -8440, 8448 -8456, 8520 -8522, 8578 -8620 Q0 ac- O True Vertical Depth: 5751 -5791, 5812 -5818, 5823 -5829, 5873 -5874, 5913 -5937 0 Tubing (size, grade, MD, and TVD) 3.5, J -55, 8528 MD, 5879 TVD Packers & SSSV (type, MD, and TVD) PACKER - CAMCO HRP -1 -SP RETRIEVABLE PACKER @ 8150 MD and 5618 TVD PACKER - BAKER FB -1 PERMANENT PACKER @ 8498 MD and 5858 TVD SSSV - CAMCO TRDP -1A @ 1831 MD and 1738 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service' P Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations _XXX GSTOR r WINJ WAG GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce a 265 -6471 Printed Name John Peirce Title Wells Engineer Signature /74. W Phone: 265 -6471 Date g/28/1Z V L- C-: A .9 '/O Form 10 -404 Revised 11i DNIS AUG 2 9 13/ /t om Submit Original Only 2C -04 Well Work Summary DATE .SUMMARY 7/23/12 ATTEMPTED TO PERFORM AORATIONS UISNG 2.5" X 20' GUN. COO NOT GET PAST A DEPTH OF 2040' AFTER MULTIPLE ATTEMPTS. JOB CANCELLED AS PER CPAI. SLICK LINE WILL RETURN TO DRIFT WELL. 7/25/12 TAG ICE PLUG @ 2054' SLM; ATTEMPT TO MOVE ICE PLUG BY PRESSURING AND DEPRESSURING UNSUCCESSFUL. RDMO 7/29/12 JETTED ICE FROM 2089' TO 2310' CTMD, USING 140 DEGREE DIESEL. ENCOUNTERED HARD TAG AT 8691' CTMD UNABLE TO JET ANY DEEPER. NO SOILDS SEEN IN RETURNS. WELL FREEZE PROTECTED. READY FOR SLICK LINE. 7/31/12 TAG @ 8699' SLM (8701' RKB, EST 88' RATHOLE) ATTEMPT TO DRIFT W/ DUMMY PERF GUN DRIFTS AND UNABLE TO MAKE IT PAST 8214' SLM, IN PROGRESS. 8/1/12 DRIFT TBG W/ 10' X 2.5" BLR TO 8621' RKB, UNABLE TO TO DRIFT FREELY W/ 20' X 2.25 DIRFT. READY FOR E -LINE (2" GUNS X 10' ) 8/9/12 LOG CORRELATED TO GEARHART CEMENT BOND LOG DATED 27 JUL 1983. PERFORATE INTERVAL 8609.5'- 8619.5' USING 10' x 2" HSC LOADED 6 SPF, 60 DEG PHASED. 8/11/12 LOG CORRELATED TO GEARHART CEMENT BOND LOG DATED 27 JUL 1983. PERFORATE INTERVALS 8599.5'- 8609.5' AND 8589.5'- 8599.5' USING 10' x 2" HSC LOADED 6 SPF, 60 DEG PHASED. 8/12/12 LOG CORRELATED TO GEARHART CEMENT BOND LOG DATED 27 JUL 1983. PERFORATE INTERVAL 8579.5'- 8589.5' USING 10' x 2" HSC LOADED 6 SPF, 60 DEG PHASED. 8/12/12 Perform injectivity test. Pumped 135 BBLS diesel to tubing. Final rate was 4 BPM at 2300 psi. 8/14/12 T -POT (PASSED), T -PPPOT (PASSED) 8/16/12 (AC EVAL) MITIA (INCONCLUSIVE) @ 3000 PSI, IA LLR WAS ESTABLISHED @ .1 TO .14 GAL /MIN, 1 HOUR IA DD TEST 8/19/12 GAUGE TBG TO 2.78" TO D NIPPLE @ 8516' RKB, MEASURE BHP @ 8600' RKB, GRADIENT @ 8453' RKB. COMPLETE. f KUP 2C -04 Conoc 01$ Well Attributes Max Angles MD TD Inc Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Alaska. 500292097300 KUPARUK RIVER UNIT INJ , 59.10 4,200.00 9,190.0 • - Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: LOCKED OUT Last WO: 10/24/1987 28.99 7/12/1983 Well Config: 2C -04. 8/13/201210:46:24 AM Schematic -Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,699.0 7/31/2012 Rev Reason: ADD PERFS ninam 8/13/2012 HANGER. 21 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 15 32.0 e20 65.00 H WELDED lir \ ,,, VI Casing Description String g 0... String g ID ID ... Top (ftKB) Set Depth (f... Set Depth pth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 30.9 3,610.3 2,845.0 40.00 J BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 27.7 9,162.0 6,298.9 26.00 K -55 BTC Tubing Strings CONDUCTOR, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 32 - 102 TUBING 31/2 2.992 21.4 8,528.5 5,878.9 9.20 J -55 EUE8rdABMOD Completion Details SAFETY VLV, r �',. ( Top Depth 1,831 f (TVD) Top Inc! Noml... ..I Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 21.4 21.4 0.06 HANGER FMC GEN II TUBING HANGER 3.500 1,831.2 1,738.4 34.55 SAFETY VLV CAMCO TRDP -1A; Flapper Locked Out on 5/24/96; CL Sleeve Locked 2.812 SURFACE. - ■ Out 3/26/96 31 - 3,810 ( 8,127.9 5,603.3 46.94 PBR CAMCO OEJ -10 PBR 2.937 GAS LIFT, 8,149.9 5,618.3 46.75 PACKER CAMCO HRP -1 -SP RETRIEVABLE PACKER 2.867 8,084 8,352.0 5,757.6 46.42 BLAST JT CAMCO BLAST JOINT PUPS (OAL = 59.17') 2.867 i id: 8,411.1 5,797.4 45.70 BLAST JTS CAMCO BLAST JOINTS (2) 3.000 PBR, 8,128 8,495.0 5,856.0 46.52 SEAL ASSY LOCATOR SEAL ASSEMBLY 3.000 PACKER, 8,150 8,497.8 5,858.0 46.55 PACKER BAKER FB-1 PERMANENT PACKER 4.000 8,501.2 5,860.0 46.86 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 INJECTION, } 8,516.2 5,870.4 46.96 NIPPLE CAMCO D NIPPLE NO GO 2.750 sass i 8,527.8 5,878.4 47.04 SOS CAMCO SHEAR OUT SUB, ELMD TTL @ 8516 ON HES (PROF 8/1/11 3.000 8258-MN - a,zeo .5260 \ _ Perforations & Slots - Cement _= Shot Squeeze. 8,258 Top (TVD) Btm (TVD) Dens TUBING PUP, Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 8271 ' 8,258 8,260 5,692.7 5,694.1 7/22/1983 4.0 SQZ DRESSER ATLAS INJECTION, 8,277 1 I 8,342 8,402 5,750.8 5,790.9 C -1, C -3, C-4, 2/23/1985 4.0 RPERF 0 deg. Phase; 21/8" EnerJet UNIT B, 2C -04 III I 8,363 8,364 5,765.3 5,765.9 C-4, 2C-04 10/16/1984 1.0 IPERF 25/8" Hollow Carrie 1 8,365 8,366 5,766.6 5,767.3 C-4, 2C-04 10/16/1984 1.0 IPERF 25/8" Hollow Came IPERF, 8,371 8,372 5,770.8 5,771.5 C -4, 2C -04 10/16/1984 1.0 IPERF 25/8" Hollow Carrie 8,363 IPERF, 8,379 8,383 5,776.3 5,779.1 C C 2C 10/16/1984 1.0 IPERF 25/8" Hollow Carrie IPERF, 8,365 - 8,368 8,387 8,389 5,781.8 5,783.2 C - 3, 2C - 04 10/16/1984 1.0 IPERF 25/8" Hollow Carrie 8,371 -03 2" 8,395 8,399 5,787.3 5,790.1 C - 1, UNIT B, 10/16/1984 1.0 IPERF 25/8" Hollow Carrie RPERF, ,t, 2C-04 8,342 -8.402 IPERF, 8,433 8,440 5,812.9 5,817.8 UNIT B, 2C -04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8.379 - 8,383 8,435 8,439 5,814.3 5,817.1 UNIT B, 2C -04 10/16/1984 1.0 IPERF 25/8" Hollow Carrie IPERF, 8,387 8,448 8,456 5,823.4 5,829.0 UNIT B, 2C -04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,450 8,451 5,824.8 5,825.5 UNIT B, 20-04 10/16/1984 1.0 IPERF 25/8" Hollow Carrie IPERF, 8,395 8,452 8,453 5,826.2 5,826.9 UNIT B, 2C -04 10/16/1984 1.0 IPERF 25/8" Hollow Carrie --� 8,454 8,455 5,827.6 5,828.3 UNIT B, 2C-04 10/16/1984 1.0 IPERF 25/8" Hollow Carrie 8,520 8,522 5,873.0 5,874.4 UNIT B, 2C-04 7/22/1983 4.0 SQZ DRESSER ATLAS 8,433 -8 RPERF, r � 8 5 8 8 5 5 A - 2C 8/4/1983 12.0 APERF 5" Geo Vann ,440 IPERF, 8,580 8,609 5,913.7 5,934.6 A - 3, 2C - 04 8/12/2012 6.0 RPERF 2' Millenium HMX, DP, 60 Deg Phase - ---- 8.435 - 8,439 . ■ 8,609 8,620 5,934.6 5,941.2 A -3, 2C 04 8/9/2012_ __ 6.0 RPERF 2" Millenium HMX, DP, 60 Deg Phase Notes: General & Safety " IPERF, 1 End Date Annotation 8,4506.451 " ' r 9/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 RPERF. i = 8,448 -8,456 t IPERF. - i 8,452 -8,453 - IPERF, t• 8,454-8,455 INJECTION. 8,478 ) REAL ASSY, _ III 8,, 595 5 PACKER, 8,498 SBE, 8,501 init IF NIPPLE, 8,516 - .. O Mandrel Details sOZ, Top Depth Top Port 8.520-8,522 'N - (TVD) Intl OD Valve Latch SiZe TRO Run Cement Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... Squeeze, 8,520 1 8,083.8 5,573.2 47.32 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 2/24/2000 90S, 8.528 '.. 1--' 2 8,195.1 5,649.3 46.36 OTIS LBX 1 1/2 (NJ DMY RM 0.000 0.0 10/2/2005 i 3 8,276.6 5,705.6 46.17 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 10/2/2005 RPERF, 4 8,477.6 5,844.0 46.35 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 12/8/2011 .580$810 APERF, B-8,813 RPERF, II I 8,610 ,5]8 -8,620 PRODUCTION, 28- 9,162 . TD, 9,19 ■ • • z i.677 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 15, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2C-04 Run Date: 8/12/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2C-04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20973-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: l� �Q �� Signed: 6 6 STATE OF ALASKA • • ALASK.L AND GAS CONSERVATION COMMIS& REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations (-" Stimulate r Other ✓ Thief Sealing Alter Casin Rill Tubing Perforate New Pool Waiver Time Extension Treatment g g X STAt- Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r j " SF4L 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 183 -094 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 • 029 - 20973 - — 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25654 — . 2C -04 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9190 feet Plugs (measured) None true vertical 6317 feet Junk (measured) None Effective Depth measured 9078' feet Packer (measured) 8150, 8498 true vertical 6243 feet (true vertucal) 5618, 5858 Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 102 102 SURFACE 3579 9.625 3610 2845 PRODUCTION 9134 7 9162 6299 RECEIVED Perforation depth: Measured depth: 8342'- 8402', 8433'- 8440', 8448'- 8456', 8578' -8613' 1An\ True Vertical Depth: 5751'- 5791', 5813'- 5818', 5823'- 5829', 5913' LA t��a � l;tytrrn$gta�' t'ift�i't?f ^�° Tubing (size, grade, MD, and TVD) 3.5, J -55, 8528 MD, 5879 TVD Packers & SSSV (type, MD, and TVD) PACKER - CAMCO HRP -1 -SP RETRIEVABLE PACKER @ 8150 MD and 5618 TVD PACKER - BAKER FB -1 PERMANENT PACKER @ 8498 MD and 5858 TVD SSSV - CAMCO TRDP -1A @ 1831 MD and 1738 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8520' -8522' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut -in 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service - Ni Stratigraphic r 15. Well Status after work: Oil r Gas `- WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ WAG ' GINJ " SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -322 Contact John Peirce ( 265 -6471 Printed Name John Peirce Title Wells Engineer Signature t.,1/4_,J. Phone: 265 -6471 Date rLf 1-j1Z. ' 'it. ,. ‘ , B® S JAN ' v°7' Form 10 04 Revised 10/2010 ubmit Original Only P -6 ' i t .S /. (3. 9� Y 2C -04 Well Work Summary DATE SUMMARY . 12/8/11' GAUGED TBG TO 2.79" TO D NILE. SET 2.75" CAT SV IN D NIPPLE @ >' RKB. PULLED HFCV @ 8477' RKB (NO EROSION) & REPLACED WITH DV. MIT TBG 3000 PSI, PASSED. MIT IA 2075 PSI, PASSED. PULLED CAT SV @ 8516' RKB. TAGGED @ 8587' SLM. COMPLETE. 12/16/11 PLACED 3740 POUNDS OF 4MM MESH CRYSTAL SEAL IN 2% KCL WATER THROUGH LEAKY SQZ PERFS (TO FAULT) AT 8520'- 8522'. PRESSURES GRADUALLY INCREASED TO TARGETED MAXIMUM SAFE TREATING PRESSURE WITHOUT SCREEN OUT. FREEZE PROTECTED CT AND PUMPED DISPLACEMENT WHILE POOH. INTENTIONALLY DID NOT OVERDISPLACE. JOB COMPLETE. . _ F KUP 2C -04 Conoc �= ell Attributes ax Angle & MD TD l<1S,a, 11 h.; Welibor9APWWI Field Name Well Status Intl ( °) MD (ftKB) Act Btm (ftKB) CarocciPhe Ilps 500292097300 KUPARUK RIVER UNIT INJ 59.10 4,200.00 9,190.0 i Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: LOCKED OUT Last WO: 10/24/1987 28.99 7/12/1983 Well Confie - 2c -04, 12/9'2011 6.15 40 AM - scnematic- Actual Annotation Depth(ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM I 8,587.0 12/8/2011 Rev Reason: GLV C /O, TAG ninam 12/9/2011 HANGER. 21 . -r Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt.. String ... String Top Thrd CONDUCTOR 16 15.062 32.0 102.0 102.0 65.00 H WELDED Casing Description String 0... String 10 ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd g i r l SURFACE 95/8 8.835 30.9 3,610.3 2,845.0 40.00 J - 55 BTC Casing Description String 0... String ID ... Top MK 13) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 27.7 9,162.0 6,298.9 26.00 K -55 BTC r it alifF r Tubing Strings Tubing Description Str 0... ing ID ... Top (1108) Set Depth (f... Set Depth (TVD)... String Wt... String... String Top Thrd CONDUCTOR, TUBING 1 3 1/2 I Str 2.992 I 21.4 I 8,528.5 5,878.9 I 9.20 I J -55 I EUE8rdABMOD 32 -102 Completion Details Top Depth SAFETY VLV, I .o.) l Top (mk6) 1 ( N8) Top Intl Nom). 1,831 ) 1 ° I Rem Description commune ID (In) 7 ‘ 21.4 21.4 0.06 HANGER FMC GEN II TUBING HANGER 3.500 1,831.2 1,738.4 34.55 SAFETY VLV CAMCO TRDP -1A; Flapper Locked Out on 5/24/96; CL Sleeve Locked 2.812 Out 3/26/96 8,127.9 5,603.3 46.94 PBR CAMCO OEJ -10 PBR 3.000 SURFACE. 0 � 8,149.9 5,618.3 46.75 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 3.000 8,352.0 5,757.6 46.42 BLAST JTS CAMCO BLAST JOINTS 2.867 GAS LIFT, j 8,411.1 5,797.4 45.70 BLAST JTS CAMCO BLAST JOINTS 3.000 B,o84 �� 8,495.0 5,856.0 46.52 SEAL ASSY LOCATOR SEAL ASSEMBLY 3.000 8,497.8 5,858.0 46.55 PACKER BAKER FBA PERMANENT PACKER 4.000 PBR, 8,128 8,501.2 5,860.0 46.86 SBE BAKER 80-40 SEAL BORE EXTENSION 3.000 PACKER, 8,150 _ 8,516.2 5,870.4 46.96 NIPPLE CAMCO D NIPPLE NO GO 2.750 . 8,527.8 5,878.4 47.04 SOS CAMCO SHEAR OUT SUB, ELMD TTL @ 8516 ON HES'PROF 8/1/11 3.000 INJECTION, Perforations & Slots 6,195 Shot RE Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Oh... Type Comment SOZ, 8,258 8,260 5,692.7 5,694.1 7/22/1983 4.0 SQZ DRESSER ATLAS 8.258 - 8 280 - N - Cement - 8,342 8,402 5,750.8 5,790.9 C - 1, C - 3, C 2/23/1985 4.0 RPERF 0 deg. Phase; 21/8" EnerJet squeeze. 8.258 UNIT B, 2C TUBING PUP, 8,271 8,363 8,363 5,765.3 5,765.3 C 2C 10/16/1984 1.0 IPERF 25/8" Hollow Carrie INJECTION, 8,27 8,365 8,365 5,766.6 5,766.6 C-4, 2C-04 10/16/1984 1.0 IPERF 25/8" Hollow Carne 8,371 8,371 5,770.8 5,770.8 C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carne 8,379 8,383 5,776.3 5,779.1 C-3, C-0, 2C-04 10/16/1984 1.0 IPERF 25/8" Hollow Carrie 8,387 8,389 5,781.8 5,783.2 C-3, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie IPERF, 8,363 8,395 8,399 5,787.3 5,790.1 C -1, UNIT B, 10/16/1984 1.0 IPERF 25/8" Hollow Carrie IPERF, 8,385 2C IPER RPERF t , 8,433 8,440 5,812.9 5,817.8 UNIT B, 2C-04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8,342 - C402 8,435 8, 5,814.3 5,817.1 UNIT B, 2C -04 10/16/1984 1.0 IPERF 2518 "HdlowCarrie 1/8" IPERF, 8,379-8,383 8,448 8,456 439 5,823.4 5,829.0 UNIT B, 2C-04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 EnerJet IPERF, 8,450 8,450 5,824.8 5,824.8 UNIT B, 20-04 10/16/1984 1.0 IPERF 25/8" Hollow Came 8.387 - 8,389 8 8,452 5,826.2 5,826.2 UNIT B, 2C-04 - 10/16/1984 1.0 IPERF 25/8" Hollow Carrie IPERF. 8,454 8,454 5,827.6 5,827.6 UNIT B, 2C -04 10/16/1984 1.0 IPERF 25/8" Hollow Carrie 8,395 - 8,399 8,520 8,522 5,873.0 5,874.4 UNIT B, 2C -04 7/22/1983 4.0 SQZ DRESSER ATLAS 8,578 8,613 5,912.7 5,936.9 A -3, 2C -04 8/4/1983 12.0 APERF 5" Geo Vann Notes: General & Safety RPERF, == {_ End Date Annotation 8,433 - 9/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 IZ 11 B,4J59,438 n IPERF, 8,450 RPERF, 8.418 -0,450 N IPERF, 8,452 IPERF, 8,454 INJECTION,f 8,478 JJJ { SEAL ASSY. 8 .S5 . PACKER, 8.496 SBE, 8,501 in in Mandrel Details Top Depth Top Port NIPPLE, 8,518 (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... SOZ 1 8,083.8 5,573.2 47.32 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 2/24/2000 K520-8522 cement _ - Squeeze, 8,520 2 8,195.1 5,649.3 46.36 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 10/2/2005 SOS, 8,528 3 8,276.6 5,705.6 46.17 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 10/2/2005 4 8,477.6 5,844.0 46.35 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 12/8/2011 8.578 7.613 PRODUCTION, 28 -9,162 - - TD. 9.190 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 10, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2C -04 Run Date: 8/9/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2C -04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20973 -00 ,A. NF :! ' NW! r Z(11/ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com / /7) Date: N b \ Signed: � �/ ✓ - Page l of l • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, December 05, 2011 3:56 PM To: 'Peirce, John W Subject: RE: 2C -04 Crystal Seal Sundry Approval (PTD 183 -094) John, The change from fullbore to coil tubing (CT) placement of the sealant will not require a modification to the sundry. This email is sufficient to document the change to the procedure. Thanks , Guy Schwartz Senior Petroleum Engineer AOGCC •!'t,a °tt' 4U.la, 793 -1226 (office) 444 -3433 (cell) From: Peirce, John W [ mailto:J ohn .W.Peirce @conocophillips.com] Sent: Monday, December 05, 2011 3:38 PM To: Schwartz, Guy L (DOA) Cc: Soon, Andrew T Subject: Re: 2C -04 Crystal Seal Sundry Approval Guy, Per our phone conversation today, you requested an email notification rather than a 10 -403 resubmittal re: changes to pumping a 2C -04 Crystal Seal Treatment. As we discussed, I am planning to modify 2C -04 Crystal Seal full -bore pumping procedure AOGCC approved 10/24/1; Sundry Approval 311 -322. Rather than pump Crystal Seal full -bore as approved, we will be pumping Crystal Seal through coil tubing to treat the well. No other changes will be made from what has already been approved. Regards, John Peirce Wells Engineer CPAI Drilling & Wells (907)- 265 -6471 office 12/5/2011 ' • • SI faTIE CIF AILASEA 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 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 3-0 4- Re: Kuparuk River Field, Kuparuk River Oil Pool, 2C -04 Sundry Number: 311 -322 Dear Mr. Peirce: t' `l: i ` c` '7 t tOI) Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this Z rda of October, 2011. Encl. STATE OF ALASKA *II RECEIVED ALASK. AND GAS CONSERVATION COMMISSIOT APPLICATION FOR SUNDRY APPROV PICT 2 9 ?ill'' 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell °Ahs+;e( t* goot;ortoWliiseon infg Suspend r Rug Perforations r Perforate I® Full Tubing Ancf10O r Operational Shutdown r Re -enter Susp. Well r Stimulate After casing g ra Other:Thief Sealing TreatmOt , 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory E 183 - 094 - 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20973 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No J 2C -04 9. Property Designation (Lease Number): , 10. Field / Pool(s): ADL 25654 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9190 • 6317 • 9078' 6243' Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 102' 102' SURFACE 3579 9.625 3610' 2845' PRODUCTION 9134 7 9162' 6299' Perforation Depth MD ( 8342' 8402', Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8436- 8440', 8448' - 8456', 8578' -8613' 5751'- 5791', 5816- 5818', 5823'- 5829•, 5913' -5937' 3.5 J -55 8528 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO HRP -1 -SP RETRIEVABLE PACKER MD= 8150 TVD= 5618 PACKER - BAKER FB -1 PERMANENT PACKER MD= 8498 TVD= 5858 SSSV - CAMCO TRDP -1A MD =1831 TVD =1738 12. Attachments: Description Summary of Proposal rr 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory " Development r Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/20/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ TV GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature Phone: 265 -6471 Date . 11) /21:41 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ) 3//`" _' 3 --- Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: / U / O / APPROVED BY �I Approved by. COMMISSIONER THE COMMISSION Date: /o 12� I ' ■ Form 10 -403 Revised 1/2010 BQS OCT 2 4`LIJIi r ubmit in Duplicate 40 T • v �y hi ti . C OP 4::;': ;: , 1 Well llAtttributes Max Angle & MD TD ' _ _ Alask'i.,ric t , % d W Ilbore A (F N ame jWell Status Inc! C) IMD (ftKB) Act Btm (ftKB) tasnOC1111h)ts 500292097300 KUPARUK RIVER UNIT INJ 59.10 l l 4,200.00 9190.0 ' Comment H2S (ppm) (Date IAn otat End Date KB-Grd (ft) Rig Release Date "" SSSV LOCKED OUT I !Last WO 10/240987 [ 28.99 7/12/1983 .. 1 : X11 ]24:GS AM : "` _ "" " _ ShcNnetit 990101 - Annotation Depth (ftKB) IEnd Date Annotation (Last Mod ... !End Date Last Tag. SLM 8,606 0 7/27/2011 Rev Reason TAG ninam 8/12/2011 HANGER, 21- "*.". ' " Casin. Strin.S Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. 'String Top Thrd ... Wtlrp , „ � CONDUCTOR 16 15 - 062 32.0 102 - 0 102.0 65.00 H - 40 WELDED • r'; f Casing Description String 0... String ID -.. Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrtl li I SURFACE 95/8 8.835 309 3,610.3 2,845.0 40.00 J-55 BTC ID... - -_ - -- r. _-. Casing Description String 0... String Top (ftKB) Set Depth (f.. Set Depth (ND) ... String Wt... String String String Top Thrd PRODUCTION 7 6.276 27 -7 9,162.0 6,298.9 26.00 K -55 BIC Tubing Strings - .. 3. :Z' lifil Tubing Description String 0... String ID . Top (ftKB) Set Depth (f_. Set Depth (TVD) ... String Wt.. Siring ... String Top Thrd TUBING 3 1/2 2 992 21 4 8,528.5 5,878 9 9.20 J EUE8 dABMOD CONDUCTOR,_ 32 -102 Completion Details Top Depth (ND) Top Inc] Nomi... SAFETY VLV, o - Top(RKB) C) item Description _ ID (in) 1.831 21.4 21.4 0.06 HANGER FMC GEN II TUBING HANGER 3.500 1,831.2 1,738.4 34.55 SAFETY VLV CAMCO TRDP -1A; Flapper Locked Out on 524/96; CL Sleeve Locked 2.812 Out 3/26/96 8,127.9 5,603.3 46.94 PBR CAMCO OEJ -10 PBR 3.000 suRFACE,» 9,149.9 5,618.3 46.75 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 3.000 31 -3,610 8,352.0 5,757.6 46.42 BLAST JTS CAMCO BLAST JOINTS 2.867 GAS LIFT,. _ I. ; 8,411.1 5,797.4 45.70 BLAST JTS CAMCO BLAST JOINTS 3.000 8,084 ----- - ° - -- 8,495.0 5,856.0 46.52 SEAL ASSY LOCATOR SEAL ASSEMBLY 3.000 8,497.8 5,858.0 46.55 PACKER BAKER FB -1 PERMANENT PACKER 4.000 PBR, 8,128 -- 8,501.2 5,860.0 46.86 SBE BAKER 80-40 SEAL BORE EXTENSION 3.000 PACKER, 8,150 - - 8,516.2 5,870.4 46.96 NIPPLE CAMCO 0 NIPPLE NO GO 2.750 8,527.8 5,878.4 47.04 SOS CAMCO SHEAR OUT SUB 3.000 INJECTION, -- Perforations & Slots 8,195 o,. - - _..shot Top (T3/0) Btm (TVO) Dens ,_ _ -4. Top (ftKB) Btrn (ftKB) (ftKB) (ftKB) Zone Date ( Type Comment SQZ. 8,258 8,260 5,692.7 5,694.1 7/22/1983 4.0 SQZ DRESSER ATLAS - _ - -- 8,258 8,260 __ Cement . 8,342 8,402 5,750.8 5,790.9 C - 1, C - 3, C - 4, 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet Squeeze, 8,258 UNIT B, 2C TUBING PUP, _ Y _ - - -' -- 8,363 8,363 5,765.3 5,765.3 C 2C 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie INJECTION, - - ' - ' 8,277 8,365 8,365 5,766.6 5,766.6 C-4, 2C-04 10/16/1984 1.0 IPERF 25/8 Hollow Carrie 8,371 8,371 5,770.8 5,770.8 C -4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carne 8,379 8,383 5,776.3 5,779.1 C -3, C-4, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,387 8,389 5,781.8 5,783.2 C-3, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie IPERF, 6,363 °' 8,395 8,399 5,787.3 5,790.1 C - 1, UNIT B, 10/16/1984 1.0 IPERF 2 5/8" Hollow Genie IPERF,8,365 --- -- 2C-04 IPERF, 8,371 8,433 8,440 5,812.9 5,817.8 UNIT B, 2C-04 2/23/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet 8.342 - 8,402 8,435 8,439 5,814.3 5,817.1 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie IPERF, - - -- 8,379 .8,383 8,448 8,456 5,823.4 5,829.0 UNIT B, 2C-04 223/1985 4.0 RPERF 0 deg. Phase; 2 1/8" EnerJet !PEKE, 8,450 8,450 5,824.8 5,824.8 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,387 8,452 8,452 5,826.2 5,826.2 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie IPERF, 8,454 8,454 5,827.6 5,827.6 UNIT B, 2C-04 10/16/1984 1.0 IPERF 2 5/8" Hollow Carrie 8,395-8,399 8,520 8,522 5,873.0 5,874.4 UNIT B. 2C-04 7/22/1983 4.0 SO2 DRESSER ATLAS . : __ 8,578, 8 613 5,912.7 5,936 9 A -3, 2C -04 8/4/1983 12.0 APERF 5" Geo Vann Notes: General & Safety_ End Date Annotation 8,433 - 8,44 0 9/232010 ! NOTE: VIEW SCHEMATIC w /Alaska Schema! c9 0 IPERF, 8,435 - 8,439 yy � 5 1I IPERF,8,450�_� RPERF, 8,4488,456 IPERF, 8,/52 - IPERF, 8,454 i INJECTION, _ ._ 8,478 SEAL ASSY, .... 8,495 - PACKER, 8,498 -- - -. SBE, 8,501 - ' -- -' •r MB` Mandrel Details Depth Top - A . 4 , , . _... � ` " * .. :, Top Port NIPPLE, 8,516- - -- - - ' (ND) Inc! OD Valve Latch Sian TRO Run Stn Top (ftKB! (ftKB) 1 (") Make Model lint Sery Type Type ( (Pal) Run Date Cwn... 8,520.6,5522 22 s 1 8 5,573.2 47.32 OTIS LBX 1 12 GAS LIFT DMY RM 0.000 0.0 2242000 _ _ - cement 2 8,195.1 5,649.3 46.36 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 10/2/2005 Squeeze, 8,520 SOS, 0,520 : ? - 3 8,276.6 5,705.6 46.17 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 10/2/2005 4 8,477.6 5,844.0 46.35 OTIS LBX 1 12 INJ CV RM 0.250 0.0 6/25/2008 APERF, - «: - 8,578-8,613 ( PRODUCTION, 28 -9,162 TD, 9,190 . • . • 2C -04 Crystal Seal Treatment 2C -04 was drilled & completed in July 1983 as a Kuparuk A and C sand selective injector. A fault was crossed at 8552' RKB during drilling that caused lost circulation and problems getting a good primary cement job of 7" casing. Due to a poor primary cement job, squeeze perfs were shot at 8258 - 8260' RKB (75' above C Sd) and at 8520 - 8522' RKB (in middle of B Sd) to perform 3 cement squeezes before finally getting a good cement job placed behind 7" casing. IPROF's on 10 -14 -05 & 8 -1 -11 both show 75% of injection disappearing at the tubing tail, with 25% to the C Sd selective through a CV (0% enters A Sd). This indicates most injection is going out of zone, likely to a thief fault behind casing via leaky squeeze perfs at 8520 - 8522' RKB behind the tubing tail. A lower packer leak to C Sd matrix injection seems unlikely due to low WHIP even at high injection up to 8000 BWPD. In all likelihood, matrix injection has not existed to the A sand for at least 6 years, and only limited injection has been entering the C sand. CrystalSeal slurry (synthetic crosslinked crystalline swellable gel) will be fullbore pumped to ' place a gel plug into thief feature believed to be a fault, to seal the thief and restore greater injection splits to the A and C Sand for improved waterflood efficiency to the offset producers. Procedure: Slickline: 1) Pull CV from GLM at 8477' RKB and replace it with a DV. Place the well on injection to perform a pre job baseline injection test at low rate (500 BWPD) and a high rate (5760 BWPD). 2) Set a Plug in the D Nipple at 8516' RKB. Perform an MITT to 3000 psi & MITIA to 2500 psi. ./ Pumping: 3) Fullbore pump Crystal Seal in Seawater down the tubing at steady 4 bpm at 0.05 ppg initial Toad concentration gradually ramped up to 0.25 ppg, followed by 1 tubing volume (76 bbls) of Seawater flush, followed by Shutdown. Wait at least 6 hours for Crystal Seal to fully hydrate then return well to injection (at 500 BWPD initial rate), to evaluate the change in rate vs. WHIP. Pump another batch of Crystal Seal slurry if the injectivity change indicates a lack of success, otherwise rig down pumping equipment and leave well on PWI for further post -job evaluation. Coil Tubing: 4) RIH with a jetting nozzle to jet and shear break any excess Crystal Seal remaining in the wellbore to as deep as possible while taking returns to tanks. The main objective of this cleanout is to ensure that the A sand perforations at 8578 - 8613' RKB are not covered by fill or any CrystalSeal gel plug remaining stacked across the pert interval. POOH with CT. RD CTU. Slickline: 5) Pull DV from GLM at 8477' RKB and replace it with a CV with 0.25" port (same port size as pulled in step #1 above). Return well to injection. Compare pre- treatment baseline injection test to post- treatment injection results to evaluate success of treatment. A future IPROF may be performed to verify post- treatment injection splits. 1.%3-091 2 009 WELL LOG TRANSMITTAL Erb) To: Alaska Oil and Gas Conservation Comm. September 15, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 2C -04 Run Date: 9/7/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2C -04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20973 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 20973 -00 ? d ' R;;;,, 7 1U1? PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com i Date: 11,11014 Signed: #121444: 6404 t13' cot %9 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 22, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2C -04 Run Date: 8/1/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2C -04 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 20973 -00 Injection Profile Log 1 Color Log 50- 029 - 20973 -00 /1) ° ' ^ ` PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: -� Sin Signed: /1/14-: JtI ~ ~ ~ ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Deax Mr. Maunder: ~ `~~~~~~~~ ~`~UV ~ ~ ~Ui~`~ ~las~c~ ~~il ~ ~as i;arr~r ~ammission ~nchorag~ ~,~~~~~~ 1~~ ~' ~ ~ ~p0~ ~ ~ 3~0~~ ~ G.~' O ~"f' Enclosed please fmd a spreadsheef with a list of wells from the Kuparuk field (KR~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pum.ped September 20~' and October 13~' 2009. The corrosion inhibitor/sealant was pumped October 15th and 31 ~+ November 1 St and 2"a 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. mcerely, ~ Perry Kle~ ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 2C. 2D. 2Z & 3K Pad Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbis ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10/15/2009 2C-02 50029209720000 1830930 12" NA 12" NA 2.97 10/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10/15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10/31J2009 2C-06 50029209790000 1831000 28" NA 28" NA 7.65 10/15/2009 2C-08 50029209740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 10J15/2009 2C-10 50029212300000 1842140 54' 5.5 22" 10/13/2009 4.67 10/31/2009 2C-11 50029212310000 1842150 38' 5.3 26" 10/13/2009 5.52 10/31/2009 2C-12 50029212220000 1842060 25' 4.5 26" 10/13/2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 1841710 38" NA 38" NA 6.8 10/31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10/31/2009 2D-10 50029211350000 1841010 21" NA 28" NA 2.97 11/1%2009 2D-11 50029217340000 1840990 19" NA 19" NA 2.55 11/1/2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1/2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530100 2071110 14" NA 14" NA 1.7 11/1/2009 2Z-02 50029209600000 1830800 18" NA 18" NA 5.1 11/2/2009 2Z-03 50029209640000 1830850 24" NA 24" NA 5.5 11/2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9/20/2009 2.12 11/1/2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11/1/2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11/1/2009 2Z-18 50029218840000 1881330 37'6" 6.5 39" 9/20/2009 8.9 11 /2/2009 2Z-22 50029225240000 1941470 16" NA 16" ~ NA 5.95 11/1/2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11/1/2009 3K 103 50029233920000 2081150 29" NA 29" NA 11.9 11/2/2009 3K-108 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 ~ MEMORANDUM To: Jim Regg ~ g~'ZS~~ L i P.L Supervisor ~ > ~ ~ FROM: John Crisp Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 24, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2C-04 KUPARUK RIV UMT 2G04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.1. Suprv ~~~--- Comm Well Name: KUPARUK RIV LTNIT 2C-04 API Well Number: 50-029-20973-00-00 Inspector Name: John Crisp Insp Num: mitJCr090823165810 Permit Number: 183-094-0 Inspection Date: g~21/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2c-oa ' Type Inj. ~ N TVD s6~s ' IA taoo zs2o - z~zo ~ 2~00 - P.T.D 1830940 TypeTest SPT Test psi 2800 =/ QA 160 180 180 180 Interval a~TST p~F r ~ Tubing 2oso 2oso 2oso zoso NOtes• 2.1 bbls pumped far test. No problems witnessed. ;M~,~, r~'d ~s1~ ~~s~.-~ c5vv~; 4~.~~4~,'.~~4~w. ~~,~t' ~~''~_ Monday, August 24, 2009 Page 1 of 1 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth °~ ~~~~~~ .\~,~~,' ~. ~L~u~ Well Job # Log Description NO.4914 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 1 L-23 12097405 SBHP SURVEY 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - fC. (y p C 09/10/08 1 1 3G-25X 12080437 LDL J - '3 L./(o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE G C (~ 09/14/08 1 1 3M-13 12096541 LDL - (yL( ( (~C.( 09/10/08 1 1 2Z-13A 12100446 LDL Q(o- ('~ p ~U ~l3 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - ~ 5 'mil 09/22/08 1 1 iC-111 12100451 INJEGTION PROFILE ~ p 09/20/08 1 1 30-15 12100452 LDL - ~ Q 09/21/08 1 1 iC-117 12100453 INJECTION PROFILE o 09/23/08 1 1 iR-11 11966277 SBHP SURVEY '- ~ (~ 09/25/08 1 1 1R-35 11966279 SBHP SURVEY ~ - 09/25/08 1 1 i R-14 11966286 LDL _ ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30/08 1 1 1R-34 12080444 _ GLS gL _ 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .= C ~/ 10/02/08 1 1 1 D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ter: -~ ( 10/06/08 1 1 1 H-19 12096548 INJECTION PROFILE ~-/ 10/03/08 1 1 16-16 12097426 GLS CI _ =' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE 09/12/08 1 1 3K-103 12096550 USIT _ 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - (~ 10/07/08 1 1 1 B-04 12096552 INJECTION PROFILE ^- 10!08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 i B-16 12096554 PRODUCTION PROFILE G) C_ G 10!10/08 1 1 2D-15 12096555 PRODUCTION PROFILE J'OC . 10/11/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. a ~~ _`~ ,. ;.- 10/31/05 Schlumbepgep NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 1 R-16 2X-10 1 D-128 3J-06 3J-07 A 2Z-29 1A-02 1 Q-26 1G-16 2A-08 2G-15 2N-329 2Z-07 3G-02 2B-03A 3N-09 (REDO) V2C-04 ~M-07 (REDO) 2A-01A 1 R-1 0 2Z-08 1 E-170 1J-154 2F-03 SIGNED: ~ANNED NOV 2 :1 2005 Company: Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk .~ Job# Log Description CD Date Color BL PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PROFILE SBHP SURVEY SBHP SURVEY PRODUCTION PROFILE INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE USIT US IT Ü ~::¡ROFILE 10/24/05 1 10/26/05 1 10/27/05 1 10/30/05 1 10/30/05 1 10/28/05 1 10/18/05 1 10/17/05 1 10/21/05 1 10/23/05 1 10/23/05 1 10/15/05 1 10/16/05 1 09/20/05 1 10/05/05 1 08/29/05 1 10/14/05 1 09/26/05 1 10/26/05 1 10/25/05 1 10/24/05 1 10/19/05 10/12/05 10/31/05 1 1 1 11015756 11015758 11015759 11072927 11072926 11072924 11022938 11022937 11015753 11015755 11072919 11022935 11022936 11056697 11015749 11015722 11022934 11015737 11072922 11015757 11072920 11015750 11022931 ~/ DATE: / r tv a " .t t}C r Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r )?" (- {~ 0J..../ Schlumbel'gep NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Com pany: §CANNEl; NOV 0 2 2D05 Field: Well Job# Log Description Date BL 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1 E-18 11015745 GLS SURVEY 10/02/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 2D-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 1 D-122 11015730 INJECTION PROFILE 09106/05 1 1 C-111 11015732 INJECTION PROFILE 09/22/05 1 1 D-114 11015728 INJECTION PROFILE 09104/05 1 2V -08A 11072913 INJECTION PROFILE 10/03/05 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09125/05 1 31-04 10092325 PRODUCTION PROFILE 10/02105 1 1E-105 11015726 TEMPERATURE SURVEY 09/02/05 1 SIGNED: Z.l {JjjJ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 10/07/05 ?(oQ4' \It C--/óY ~ Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk '_C Color CD - / 7 {\)~Âtt- r- f~¡>c..-tit~~~oc~u.u ¡;;;. ~ ) MEMORANDUM State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ''''--;1</ a( ;;:oj . err' {( 7¡Ö':; DATE: Monday, August 15,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2C-04 KUPARUK RlV UNIT 2C-04 \{ ~/oq \~') FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ..T!5iZ- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2C-04 Insp Num: mitJJ0508IOl22110 Rei Insp Num: API Well Number: 50-029-20973-00-00 Permit Number: 183-094-0 Inspector Name: Jeff Jones Inspection Date: 8/8/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~šfFó:~~;:f~~ e~d-~I::~5 L~;t;~o~- ~- ~::--!--~~:-l-~~{~*~j -~--- __.__..... -_...._,,__.._....__ ..._____ ___.""_._._'--_____._,,._____.._,,_____.._~___.______..,,'_,,_._L...___......_ Notes: 1.6 BBLS diesel pumped. 1 well house inspected, no exceptions noted. f. (' r)nn'l; ,'¡ ¡"If (\' {""[¡) (.. \J ·c' i' L U !.J "'~ \··~~--Þ\\Ì\WV.\xrf;) .·')f ¡i" ..~ .,'~":":) .......fl;· ,...\, ,·,1 .' .......... " .'.~'''' Monday, August 15, 2005 Page 1 of I .. ........ . ..... :;~ ç()nQ~OPl1l1lip$ AI:C~a.tnc. API: 500292097300 SSSV Type: LOCKED OUT Annular Fluid: Reference Log: I Last Tag' 8'305 lust T3g D:;!e lJ.l22'2Ij(l5 ICasing String - ALL STRINGS Description Size Top Bottom TVD Wt CONDUCTOR 16.000 0 102 102 65.00 SUR. CASING 9.625 0 3610 2844 45.00 PROD. CASING I 7.000 0 9162 6299 26.00 TubihgStril1g- TUBING (WellheädTest. PortVaJve Installedon3J2.6/96) Size IT op I Bottom I TVD I Wt I Grade I 3.500 0 8529 5879 9.30 J-55 Perfor.ationsSumrnary Interval TVD 8342 - 8363 5751 - 5765 8363 - 8363 5765 - 5765 8363 - 8365 5765 - 5767 8365 - 8365 5767 - 5767 8365 - 8371 5767 - 5771 8371 - 8371 5771 - 5771 8371 - 8379 5771 - 5776 8379 - 8383 5776 - 5779 8383 - 8387 5779 - 5782 8387 - 8389 5782 - 5783 8389 - 8395 5783 - 5787 8395 - 8399 5787 - 5790 8399 - 8402 5790 - 5792 8433 - 8435 5813 - 5815 8435 - 8439 5815 - 5818 8439 - 8440 5818 - 5818 8448 - 8450 5824 - 5825 8450 - 8450 5825 - 5825 8450 - 8452 5825 - 5826 8452 - 8452 5826 - 5826 8452 - 8454 5826 - 5828 8454 - 8454 5828 - 5828 8454 - 8456 5828 - 5829 8578-8613 5913-5936 Gas LiftMàndrels/Vàhies St MD TVD Man Mfr Man Type V Mfr SSSV (1831-1832, 00:3.500) Gas Lift mdrel/Dum m y Valve 1 (8084-8085, 00:5.940 ) PBR (8128-8129, 00:3.500) PKR (8150-8151, 00:6.151) Injection MandrelNalve 2 (8195-8196. Injection MandrelNalve 3 (8277-8278, Pert (8363-8363) Pert (8371-8371 ) Pert (8342-8402) Pert (8387-8389) Pert (8433-8440) Pert (8435-8439) Pert (8450-8450) Injection - MandrelNalve 4 (8478-8479. PKR (8498-8499. 006151) NIP (8516-8517. 00:3500) ruBING - (0-8529, 00:3 500 102.992) 50S -.l (8528-8529. 00:3500) Perf (8578-8613) L___ Ie ¡ lli "t....!."." ...:.......::.....::...:.:....:.::.::::.:.::.::'.r,....!.1I J!IIi:::::· ~ . ¡ J.' .. I I \ I ¡ LwJ ~ ~ ; :. ::::; ~ .. '!:I I ~""It::::::::::::<. <:::1·:::::::,J ~~Ifn:/\;:;::':::: I-tlfl =±---+ :: +- . ~ -~ ~L j --r -r- ~ -. o-- ~ =f= t 1 -l.- ]~ ~ ~~ ::¡ -~ ~ I i ~ f, i --or ---r- ~. +-- -l [ :!= ! ........ ~ L. . II" j 1>1 ! .., ·······j<I··....· j 1:1 ~ rjcijl I !::::~:.j ~ I··········· .......: ¡ .:~ -r- ') ') Well Type: INJ Orig Completion: 7/12/1983 Last W/O: 10/24/1987 Ref Log Date: TD' 9190 ftKB r'¡3'~ Hüle ':'ngle :5';' -:16g @ J.200 Zone C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4,C-3 C-3 C-3 C-3,C-1 C-1 ,UNIT B UNIT B UNIT B UNIT B UNIT B UNIT B UNIT B UNIT B UNIT B UNIT B UNITB UNIT B A-3 1 8084 5573 0 tis Injection Mal'1drelsNalves St MD TVD Man Mfr Man Type LBX 2 8195 5649 Otis LBX CV 1.5 3 82771 5706 Otis LBX CV 1.5 4 8478 5844 Otis I LBX CV 1.5 ~~hp~~ ~P~%SI . eq¥~.~ etc.) -J EWELRY Description 1831 11739 SSSV Cameo TRDP-1A; Flapper Locked Out on 5/24/96: CL Sleeve Locked Out 3/26/96 8128 5603 PBR Cameo OEJ-10 8150 I 5618 PKR I Cameo HRP-1-SP 8498 5858 PKR \Baker'FB-1,perm. 8516 I 5870 NIP Cameo '0' Nipple NO GO 8528 5879 SOS 'I Cameo 8529 5879 TTL I i i I I V Mfr Status Ft 21 o 2 o 6 o 8 4 4 2 6 4 3 2 4 1 2 o 2 o 2 o 2 I 35 V Type DMY V Type SPF 4 5 4 5 4 5 4 5 4 5 4 5 4 4 5 4 4 5 4 5 4 5 4 12 Date 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 2/23/1985 8/4/1983 VOD 1.5 VOD KRU Type RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF RPERF APERF Latch RM Latch RM RM RM 2C-04 Angle @ TS: 46 deg @ 8338 Angle @ TO: 49 deg @ 9190 Rev Reason: Post FCO Tag Last Update: 4/28/2005 Grade H-40 K-55 K-55 Thread Thread EUE 8RD AB-MOD Comment o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 21/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 118" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" Ener Jet o deg. Phase; 2 1/8" Ener Jet o deg. Phase; 2 1/8" EnerJet o deg, Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 21/8" EnerJet o deg. Phase; 2 1/8" EnerJet o deg. Phase; 2 1/8" EnerJet 5" Geo Vann Port TRO Vlv Cmnt 0.000 o Date Run 2/24/2000 Port TRO 0.000 0.000 0.000 o o o Date Run 4/7/2004 4/7/2004 4/7/2004 Vlv Cmnt -..- 10 2.812 2.875 3.000 4.000 2.750 2.992 2.992 ------.- ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ?/ O~Lf Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us \Lt' OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: Kuparuk/ KRU/2C DATE: 08/08/05 OPERATOR REP: Arend/Greewood - AES AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. we1l12C-01 I Type Inj. I S TVD I 5,757' Tubing I 2,9501 2,9501 2,9501 2,95Ollnterval 4 P.T.D. 1830830 Type test P T est psi 1500 Casing 1,650 2,200 2,200 2,200 P/F P Notes: well 2C-02 I Type Inj. I S TVD I 5,658, TUbing 2,2501 2,2501 2,2501 2,250 lnterval 4 P.T.D. 1830930 Type test P T est psi 1500 Casing 1,780 3,080 3,050 3,050 P/F P Notes: well 2C-03 Type Inj. N TVD I 5,608, TUbingl 2,3001 2,3001 2,3001 2,300 lnterval 4 P.T.D. 1830890 Type test P T est psi 1500 Casing 740 1,620 1,600 1,590 P/F P Notes: well 2C-04 Type Inj. S TVD I 5,618, TUbingl 1,8751 1,8751 1,8751 1,8751Interva, 4 P.T.D. 1830940 Type test P T est psi 1500 Casing 1,300 2,470 2,370 2,320 P/F P Notes: well 2C-05 Type Inj. S TVD I 5,618, TUbingl 1,6001 1,6001 1,6001 1,600 Intervall 4 P.T.D. 1830990 Type test P T est psi 1500 Casing 1,030 2,200 2,150 2,150 P/F P Notes: well 2C-06 Type Inj. S TVD 1 5,667'1 TUbingl 2,5001 2,5001 2,5001 2,5OOllnterval 4 P.T.D. 1831000 Type test P T est psi 1500 Casing 1,300 1,800 1,700 1,690 P/F P Notes: well 2C-08 I Type Inj. P.T.D. 1830950 Type test Notes: s P I TVD I T est psi 5,794'1 TUbing 1500 Casing 2,8751 2,8751 2,8751 2,875 lnterval 810 1,700 1,530 1,500 P/F 4 F Test Details: SC/.,.NNED II\UG 1 1. 2005 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 2C 08-08-05.xls WELL LOG TRANSMITTAL II. ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE' Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / deni Thompson ProActive Diagnostic Services, Inc, P. O. Box 13S9 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S} OR CD-ROM FILM BLUE LINE Open Hole I 1 1 2Q04 8-1 1-03 Res. Eval. CH I I 1 Mech. CH Caliper Survey 1 Rpt or 2 Color Print Name: ProActive Diaqnosti~'~S~rvices,... Inc., pO Box 1369 Stafford lx 77477 Phone: (281) 565-9085 Fax: (281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMMIoolON REPORT OF SUNDRY WELL OPERATIONS Stimulate Repair well 5. Type of Well' 1. Operations Performed:. Operation Shutdown Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 511' FNL, 608' FEL, SEC 21, TllN, R9E, UM At top of productive interval Plugging Development Exploratory Stratigraphic Service Perforate _ Other (;:;(;)NVERSION Datum elevation (DF or KB) 118 RKB. 7. Unit or Property name Kuparuk River Unit 8. Well number 2C-04 fe~ 9. Permit number 1341' FNL, 1429' FWL, SEC 16, T11N, R9E, UM At effective depth 911' FNL, 1197' FWL, SEC 16, T11N, R9E, UM At total depth 782' FNL, 1131' FWL, SEC 16, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 91 9 0' feet 6 31 6' feet Plugs (measured) 88-94 10. APl number 50-029-20973 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 102' 3610' 9162' measured 8342'-7402' 8433'-8440' true vertical 5749'-5791', Tubing (size, grade, and measured depth) 3 1/2" J-55 set @ 8529' 9078' feet 6 2 4 3' feet Size Junk (measured) Cemented 1 6" 265' SX AS II 9 5/8" 1650 sx AS III & 250 sx AS I 7" 500 sx CLASS G & 250 sx AS I 4 SPF 8448'-8456' 4 SPF 4 SPF 8578'-8613' 4 SPF 5810'-5818', 5823'-5829', Packers and SSSV (type and measured depth) CAMCO HR @ 8150', BAKER FB @ 8485', CAMCO TRDP-1A @ 1831' Measured depth True vertical depth 102' 102' 3610' 2844' 9162' 6298' R£¢EIVED 5911'-5936' JUL 2 ' gB3 Alaska Oil & Gas Cons. C0mrnJsl Anchoraa~ 13. Stimulation or cement squeeze summary Intervals treated (measured) CONVERTED FOR WAG INJECTION. ~- G~,, ~ /~///sT/q/ Treatment description including volumes used and final pressure 14. Pre ssure Representative Daily Average Production or Injection Dalta OiI-Bbl Gas- Mcr Water-Bbl Casing Pressure Tubing Prior to well operation 47OO 940 21 92 Subsequent to operation 6.8 200 3900 15. 17. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector __ Daily Report of Well Operations__ Oil _ Gas Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge. Service WAG INJECTOR Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE or) To: ql-..-I o Well Name I.og Type Run I)atc Kuoaruk Kuparuk Kupamk Kuparuk iKuparuk Kupamk Kupamk Kuparuk Kuparuk Kupamk Kuparuk Kuparuk Kuparuk Ku pa~ uk Kuparuk .Kuparuk Kupamk Kupamk Kuparuk Kuparuk Kuparuk River iinit iF.-iA River Unit IA-II River Unit 1 t.-10 River unit IL-14 River Unit IL-17 River U.it 11.-22 ~vcr Unit 1It 04 River Unit 1Y'-I0 River Unit 1Y-t2 River Unit IV-15 River Unit 2B-08 ni~ u.it 2o02 Ri,~ u,,it 2c-o4 hirer Unit 2C 05 lfiver Unit 2C4)6 ~vcr Unit 2V-13 rover Unit 3G-12 River Unit 3tt--02 River Unit 3G-20 Water iqow I.og ('il)'I'-P) Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile injection Profile Injection Profile Injection Profile Injection .Profile Injection Profile Injeclion Profile Survey Injection Profile Survey Injection Profile Production l.og Production Log Injection Profile Injection Profile Survey Injection Profile 07.lA N 1991 10-1-91 03 NOVEMBER1991 4 NOVEMHER 1991 4 NOVEMBER 1991 11-06.1991 6/30/91 12-13--1991 1 I-i9-91 I l- 17-1991 12.2-91 12-27-1991 26 DE(.' 1991 10-27--1991 11/25/91 11--16-1991 8-.IIJNE-1991 31-JULY--1991 11 NOV 1991 10/ItU/Ut 11-29-1991 R::ccivcd by:: ~~~'- ~ D~ted: Copy sent to sender: Yes ,// No ~ RECEIVED MAR 2 6 1992 Alas~ 011 & Gas Cons. Commission Anchorage STATE OF ALASKA AI_AoKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program X Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 511' FNL, 608' FEL, Sec. 21, T11N, R9E, UM At top of productive interval 1341' FNL, 1429' FWL, Sec. 16, T11N, R9E, UM At effective depth 911' FNL, 1197' FWL, Sec. 16, T11N, R9E, UM At total depth 782' FNL, 1131' FWL, Sec. 16, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 91 9 0' feet true vertical 631 6' feet Effective depth: measured 9 0 7 8' feet true vertical 6 2 4 3' feet Casing Length Size Structural Conductor I 02' 1 6" Surface 3610' 9 5/8" Intermediate Production 91 6 2' 7" Liner Perforation depth: measured 8342'-84O2' 8433'-844O' true vertical 5749'-5791 ', Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 118' 7. Unit or Property name Kuparuk River Unit 8. Well number 2C-04 9. Permit number 83-94 Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 8529' feet 10. APl number 50-029-20973 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 265 Sx AS II 1 02' 1 02' 1650 Sx AS III & 3610' 2844' 250 Sx AS I 500 Sx Class G & 91 6 2' 6 2 9 8' 250 Sx AS I 4 SPF 8448'-8456' 4 SPF 8578'-8613' 5810'-5818', 5823'-5829, Packers and SSSV (type and measured depth) Camco HR @ 8150', Baker FB @ 8485', Camco TRDP-1A @ 1831' 4 SPF 4 SPF APR 1 2 t991 Alaska Oil & Gas Cons, Commisslon 13. Attachments Description summary of proposal _ Convert well from water injector to WAG (water alternating immisicible gas) injector. 14. Estimated date for commencing operation I 15. Status of well classification as: May, 1991 - J Oil 16. If proposal was verbally approVed Name of approver Date approved Service .WAG I n!ector 17. I here~lv ce~if~ tt'~t the foregoing is true and correct to the best of my knowledge. Signed'~--~ ~.~ Title FOR COMMISSION USE ONLY Detailed operation program rum~,,v,~l~p sketch Suspended _ Conditions of approval: Plug integrity_ Mechanical Integrity Test Notify Commission so representative may witness Approved by order of the Commission BOP Test Location clearance __ Subsequent form ORIGINAL SIGNED BY I flNNII~ C. SMITH require 10- ~.~,L( Approved Copy Returned -. Commissioner Dato IApproval No, ARCO Alaska, Inc, Date: April 20, 1988 Transmittal#: 7146 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles 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. ~ 1 G- 1 6 Kuparuk Well Pressure Report 2 - 8 - 8 8 Static 'C' Sand "--~1 G-09 Kuparuk Well Pressure Report 2 - 3 - 8 8 'A' Sand '--"-~1G-09 Kuparuk Well Pressure Report 2-3-88 Static 'C' Sand .~~. Kuparuk Well Pressure Report 2 - 3 - 8 8 Static Both Sands ~' Kuparuk Well Pressure Report 1 2- 1 3 - 8 7 'A' Sand -~3H-05 Post-Frac Report 4- 6 8 8 AIIo Frac 10 3H-02 Post-Frac Report 4- 6- 8 8 AIIo Frac 10 '~~H-03 Post-Frac Report 4-6-88 AIIo Frac 10 H- 0 7 Treatment Report 4 - 1 3 - 8 8 ~ 1 Y- 1 4 Pulse Test 3 - 1 1 - 8 8 'A' & 'C' Sands E ......... Anchorage Receipt Acknowledged' DISTRIBUTION; D & M ~'.-~lask Date' Chevron Mobil SAPC Unocal '~--"-" STATE OF ALASKA - · .... " ALASKA OIL AND GAS CONSERVATION L, OMMISSION ELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICERS] WATER INJECTOR 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-94 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20973 4. Location of well at surface 9. Unit or Lease Name 511' FNL, 608' FEL, Sec.21, TllN, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1341' FNL, 1429' FWL, Sec.16, TllN, R9E, UM 2C-4 At Total Depth 11. Field and Pool 782' FNL, 1131' FWL, Sec.16, T11N, 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 RKB 118'J ADL 25654 ALK 2580 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 07/03/83 07/11/83 08/04/83*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9190'MD, 6316'TVD 9078'MD, 6243'TVD YES~ NO []I 1831 ' feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/SP/Cal, CBL, Gyro, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED lb" 62.~# H-40 Surf 102' 24" 265 sx AS II 9-5/8" 40.0# J-55 Surf 3610' 12-1/4" 1650 sx AS Ill & 250 s~ AS I 7" 26.0# J-55 Surf 9162' 8-1/2" 500 sx Class G & 250 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf, 0° phasing 3-1/2" 8529' 8498' 8342'-8402'MD 5749'-5791 'TVD 8433'-8440'MD 5810'-5818'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8448'-8456'MD 5823'-5829'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8520'-8522' 415 sx Class G Perforated w/12 spf 8258'-8260' 150 sx Class G 8578'-8613'MD 5912'-5936'TVD See attached Well Service repot1; dated 5/22/84. for fracture data. 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 $ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None D£C 2 9 Alaska 0il & Gas Cons. C0mrnissi0~ Anchorage *Note: Drilled RR 7/12/83. Completed well & perforated 8/4/83. Fractured well 5/22/84. Perforated well 10/16/84. Reperforated well 2/23/85. Converted to water injector 11/6/85. Workover performed 10/24/87 Form 10-407 Rev. 7-1-80 WC~,/13: DAN I CONTINUED ON REVERSE SIDE Submit in duplic at e~i~)~' 'GEOLOGIC MARKERS · :~; ..... ';: ~: : ':7'..'fo... 'i,,' ";i"F6RMATIONTESTS :::-. ?:: :.: ,~J -_ . ..~ . . . . ::..:: ~;- :. . ,.: .: .. '~.~.'. . ~;.: ...... ... , ...... NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8340' 5749' N/A Base Upper Sand 8398' 5789' Top Lower Sand _ 8552' 5894, . Base Lower Sand 8705' 5997' - , · ~ ';~ . : ''. : .., 31. LIST OF ATTACHMENTS Weii Service Report (dated 5/22/84) 32. I hereby certify that the foregoing is true and correct tO the best of my knowledge · . Signed ~-/~(/~/~'J~" J~JL/~FJ[ / Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water Supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is Used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attach'ments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken:, indicate "none". Form 10-407 .......... SulJd;~ of. Atlantic Ri~hfletd Company~ ~ r I 7~/~' DAYS "WELL ' CONTRACTOR H ~ u r~u RTON REMARKS IFIELD - DISTRICT- STATE I HJp~u~< I OPERATION AT REPORT TIME oq$o i Oo~, l ooq I0-1 ~ ioIq 1 0 Z.:3 P-,0 ;C bPI PL_F-FI:C CH Ec K / C_-n L.. PRES~ "'/" C.$G "FO IgCC> ~ l~EGIht PP..EPAD ',,V/ FLUID LOSS BEGIN II S OT" I C;> ~lt, J ZlS'O PSZ: tOZS 10~ IO- ,, 3 " ,, :~l ,, q " " I~pt~ Iq, 7.. BPA~ /vi I I~ ,S~:TP ZOiO ,, ~, iq<A:) ,, lo~- RDMO H,qal...l~u ~:'F0 N To - z--~ B~-~ ~ q5lo Pst' qStO Co g'T' q02~9o 5'0, oo Es'T'/~ mT'F_- Anchorage I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK w~m~r J'r~mp. Chill Factor J Vllibility Report J~ "F lC) 'F ~ miles IWlnd Vel. Signed STATE OF ALASKA - ALA~, . OIL AND GAS CONSERVATION CO, .,5SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate © Plugging [] Perforate ,~ Pull tubing Alter Casing ~ Other ~ WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 118' 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 511' FNL,_ 680' FEL, Sec.21, T11N, RgE, UH At top of productive interval 1341' FNL, 1429' FWL, Sec.16, T11N, RgE, UM At effective depth 911' FNL, 1197' FWL, Sec.16, T11N, RgE, UM At total depth 782' FNL~ 1131' FWL~ Sec.16~ TllN, R9E, UM 11. Present well condition summary Total depth: measured 9190 'MD true vertical 6316'TVD 7. Well number 2C-4 8. Approval number 7-253 9. APl number 50-- 029-20973 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet Effective depth: measured 9078 'MD feet Junk (measured) true vertical 6243 'TVD feet Vann Gun, 367' long Casing Length Size Cemented Measured depth Conductor 102' 16" 265 sx AS II 102'MD Surface 3610' 9-5/8" 1650 sx AS III & 3610'MD 250 sx AS I Production 9162' 7" 500 sx Class G & 9162'MD 250 sx AS I True Vertical depth 102'TVD 2844'TVD 6298'TVD Perforation depth: measured 8342'-8402'MD, 8433'-8440'MD, 8448'-8456'MD, 8578'-8613'MD true vertical 0 t987 57~9~-5791~TVD, 5810~-5818~TVD~ 5823~-5829~TVD~ 5912~-5936~TV Tubing (size, grade and measured depth) .... ,~;" 0~ & GaS Co~S. 3-1/2", J-55, tbg w/tail ~ 8529' ;':';~'~ ~6~ Packers and SSSV (type and measured depth) FB-1 pkrs @ 8495' & 8498' & TRDP-1A SSSV (~ 182,1' 12. Stimulation or cement squeeze summary N/A Intervals treated (measuredi Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel I Histor, j(_) Daily R, eport of Well Operations ~ Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,4(.;~4~~~ Title Associate Engineer Date /1'1~'~ Form 10-404 Rev. 12-1-85 '~/ (Dani) SW03/9 Submit in Duplicate Feet and Gas COmpany Well History- Initial Report- Dally In~: Prepare and submit the "lnillll Rel~rl" 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 :; County. parish or borough North Slope Borough IT State Alaska' ' Field - - - ' Lea~e or Unit ' - /uparuk River . ADL 25654 · .. Auth. or-W.O, no~ ' itle ~ AF~. AK2335' . ' Workover · "'-,.',?~;.-'.Nbrd:t.c'~ 1- :'" ~ 'i-<'--'?~---:-.· - ~ ~l 50-029-20973 O~r~r' ~-'-~:-_ ~-? - ,: , ~-?_ :. _ ~_,~ . . . [ARCO W.I. ' ;' ' ~ (~ :__~CO~;~as~,--._ T~-~"~:-~ - ~ ' [IPrlor status .- %~.~_. -. -..- ./- _:. _ . ._;;~.~.~~ve~-~:~";':~_~:?~-'--~,~_:--/-.: .'- [ . ~u/07/87 [ 1045 hrs. I .:-L ' :'?'~:"::-'~; - '?-:-'":']--'-' 9190-~ PB~, Tst .BOPg - - . . _ 10/13/87 Alaska IWell no. 2C-4 56.24% .-' - 7" @ 9162' - - 9190' PBTD, Ch$ couplings R NaC1 Putt tbg. Set dummy vlv & std'g vlv. Pull on tbg. RU Gearhart & cut tUg @ 8185', POE w/tbg & chg couplings to -. AB-Hod. _ , , 7" @ 9.162' ,:,'.25!% 9190' PB~D, POH w/OS 9,6.ppg NaCl/NaBr Chg tbg colts to AB Mod. RU to rn DP & OS; rn same. Snag feb &:~ar, back o£f fsh & POOH. POOH w/OS assy. RIH w/wsh over assy, wsh f/8183'-8190' & circ. P00E w/web over assy. MU OS assy, RIH & jar on fsh. RIH w/string shot, manually break free, wrk ptpe~ POO~ w/string shot. PO & wrk pipe, P00E w/3½" DP. _ 7" @ 9162L 9190' PBTD, RIE w/OS 9.6 ppg NaC1/NaBr POOH w/3~'! DP. RXHw/3%" tbg & X0, tag fsh & wrk over same. RIH w/std'g vlv, P00E w/3½" tbg & X0. RIH w/OS assy & 3½" DP. 10/_14/87 _.. - . . _ 10/15/87 _ - 7" @ 9162' 9190' PBTD, Circ& jar on fsh 9.6 ppg NaCl/NaBr RIE w/OS & jar. RIE w/guns, shoot; no press loss. RU Gearhart, shoot @ 8220' WLM. Broke circ& jar pipe. RIE, set off string shot to jar pipe. Circ& jar pipe. 7" @ 9162' 9078' PBTD, TIH w/OS 9.6 ppg NaCl/NaBr Jar on OgJ, TOE; rec'd 12.29' of 3½" tbg & 13.57' OEJ. TIH w/OS & grapple to latch slick stick; would not go over fsh, TOE. PU 4-1/8" grapple & TIH. _ Title Drilling. Superintendent AtlanticRichfieldCompany Daily Well History-Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25654 Complete record for each day while drilling or workover in progress 10/16/87 10/17/87 thru 10/19/87 10/20/87 10/21/87 10/22/87 JStste Alaska Well no. 2C-4 7" @ 9162' 9078' PBTD, TIH 9.6 ppg NaCl/NaBr TIH, tag fsh @ 8202'; unable to latch fsh, TOH. TIH w/imp block, tag fsh @ 8202', TOH. TIH w/OS & 4" grapple. 7" @ 9162' 9078' PBTD, Repair mud pmp 9.6 ppg NaCl/NaBr TIH, jar on pkr; no movement. Spot 15 bbls hot wtr above pkr, jar. Spot 15 bbls hot wtr & jar; no movement, TOH, LD OS. TIH w/wsh pipe & shoe, mill over OEJ f/8202'-8206.5', circ, TOH. PU new shoe, TIH, mill over OEJ f/8206.5'-8210.5', CBU w/sweep, TOH & chg shoe. TIH, RD & repair electrical problem to mud pmp. 7" @ 9162' 9078' PBTD, TOH w/fsh 9.6 ppg NaCl/NaBr Repair electrical sys. Mill over OEJ f/8210.5'-8212', CBU, TOH, LD wshpipe. PU 4" grapple fsh'g assy, TIH, latch pkr, jar, CBU, TOH w/fsh. 7" @ 9162' 9078' PBTD, Wsh fill 9.6 ppg NaCl/NaBr TOH w/fsh; hole swabbing. Bullhead gain into formation &cont TOH. Att to bullhead; pkr holding pressure. TIH, circ, TOH, LD pkr & tailpipe assy. TIH w/BHA, wsh fill @ 8652'. 7" @ 9162' 9078' PBTD, NU BOPE 9.6 ppg NaC1/NaBr Tag fill &circ @ 8652'. Drl & circ to 8701'. Pmp sweep, POOH w/3½" DP; tight @ 8610'-8590'. RIH w/BP, set @ 8231', POOH. PU storm pkr & set. ND BOPE, chg out tbg head & tst. NU BOPE. The ab/e~ts correct For forn~preparation,x~lljll' dist ri bution see Procedures Mal~u~Section 10, Drilling. Pages 86 ~t/f'd 87 Drilling Superintendent ARCO Oil and Gas Company .~, Daily Well History-Final Report "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 Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alas~], County or Parish Field Lease or Unit Kuparuk River ADL 25654 Auth. or W.O. no. T tie AFE AK2335 Workover North Slope Borough Accounting cost center code State Alaska IWe,, ~Oc_4 Nordic #1 AP1 50-029-20973 Operator ~ A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~Date Workover [ 10/07/87 Date and depth Complete record for each day reported as of 8:00 a.m. 10/23/87 10/24/87 thru 10/25/87 Iotal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well I our [Prior 8tatua If a W.O. 1045 hrs. 7" @ 9162' 9078' PBTD, NU BOPE 9.6 ppg NaCl/NaBr Tag fill & circ @ 8652'. Drl &circ to 8701'. Pmp sweep, POOH w/3½" DP; tight @ 8610'-8590'. RIH w/BP, set @ 8231', POOH. PU storm pkr & set. ND BOPE, chg out tbg head & tst. NU BOPE. 7" @ 9162' 9078' PBTD, RR Diesel in tbs & ann. POOH w/10 stds DP. RIH, CBU. RU Gearhart, make GR rn. RIH w/perm pkr, set @ 8485'. RU & rn 262 its, 3½", 9.2#, J-55 EUE 8RD AB Mod tbs w/SSSV @ 1831', FB-1 Perm Pkr @ 8498', TT @ 8529'. Set pkr. Tst tbs. ND BOPE. NU & tst tree. Displ ann & tbg to diesel. Tst tbs. RR @ 2100 hfs, 10/24/87. Old TD New TD 9078' PBTD Released rig Date IPB Depth Kind of rig 2100 hrs. 10/24/87 Rotary Classifications (oil, gas, etc.) J Type completion (single, dual, etc.) Oil I Single Producing method I Official reservoir name(s) Flowing I 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 ~'~rrect SD re~ll, tnr~.c ~da~ reesS 1~6 aannU~l, ? .S~J~ o n 10. -- t~Oc"lDate,'/1~ [ri,,e Drilling Superintendent 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' 0069 Attachments Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ATTACHHENT 1 PAGE 1 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES FIRST QUARTER 1987 SUBMITTAL WELL NUMBER '><,.32C_03 ;:~:'2c-oq ,~2D-05 :'~'~2W-05 ~ 2w-08 ->Z.j 2X-02 *>~.2X-03 '>~--"-' 2X-06 ~ 3F-O~ ~ 3F-07 APl DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING 50-029 INJECTION SURVEY SURVEY ~URVEY WATER 20968 12/12/85 02/03/87 SPINNER FOLLOWUP A&C S 20973 11/09/85 02/01/87 SPINNER FOLLOWUP A&C S 21157 11/09/85 02/0~/87 SPINNER FOLLOWUP A&C SS 21208 11/22/85 03/05/87 SPINNER FOLLOWUP A&C SS 21228 11/15/85 03/06/87 SPINNER FOLLOWUP A&C SS 20982 11/19/85 02/07/887 SPINNER FOLLOWUP A&C SS 20987 11/0q/85 03/02/87 SPINNER FOLLOWUP A&C SS 20988 11/0q/85 03/0h/87 SPINNER FOLLOWUP A&C SS 21hh9 05/0q/86 02/08/87 SPINNER INITIAL A&C SS 21h63 05/06/86 02/09/87 SPINNER INITIAL A&C SS A&C t A&C A&C A~C A&C A&C A&C A&C A&C A&C INJECTION BWPD · Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALAS,. _ OIL AND GAS CONSERVATION COMN .SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well D Alter casing D extension ~ Change approved program ~ Plugging [] Stimulate [] Pull tubing ,~,~.Amend order [] Perforate ~ Other Time 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc, RKB 118' 6~ Unit or, Pr,.operty 3'Act~cl.re~)s. Box 100360 Anchorage, AK 99510-0360 uparuK r~,ver nl~nrr~et 4. Location of well at surface 511' FNL, 680' FEL, Sec.21, TllN, RgE, UM At top of productive interval 1341' FNL, 1429' FWL, Sec.16, T11N, R9E, UM At effective depth 911' FNL, 1197' FWL, Sec.16, T11N, R9E, UM At total depth 782' FNL, 1131' FWL, Sec.16, T11N~ RgE~ UM 11. Present well condition summary Total depth: measured 91 90 ' MD feet Plugs (measured) true vertical 631 6 ' TVD feet 7. Well number 2C-4 8. Permit number 83 -94 9. APl number 50_029-20973 10. Pool Ku'paruk River Oil Pool None Effective depth: measured 9078 ' HD true vertical 6243 ' TVD Casing Length Size Conductor 102 ' 1 6" Surface 361 0 ' 9-5/8" P roducti on 91 62 ' 7" feet Junk (measured) feet Cemented 265 sx AS II 1650 sx AS Ill & 250 sx AS I 500 sx Class G & 250 sx AS I Vann Gun, 367' long Measured depth 102'MD 3610'MD Perforation depth: measured 8578'-8613' (12 spf) 8456'-8448', 8440'-8433' true vertical 5805 ' -5829 ' ( 1 2 spf ) 5829'-5823', 5818'-5810' Tubing (size, grade and measured depth) 3-1/2", 9.3#)Srd3tbg (~ 8249' Packers and SSSV (type and measured depth) Camco HRP-1SP pkr ~ 8219', 3-1/2" Camco TRDP-1A SSSV (~ 1925' Rue Verticaldepth 102'TVD 2844'TVD , 91 62 ' MD 6298 ' TVD , 8402'-8372' , 5791 '-5770' , 8372'-8342' (4 spf) , 5770'-5749' (4 spf) 12.Attachments Description summary of proposal [] Detailed operations program 'J~ BOP sketch/W~-~_ 13. Estimated date for commencing operation August 15, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed & ~r~j~_/' ~..~j~_~ Title Associ ate En;ii n~,r Commission Use Only (DS) $A2/42 Conditions of approval Approved by Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Date NO. by order of the commission Date ,,'-~ feet Form 10-403 Rev 124-85 "' Submit in triplicate KUPARUK WELL 2C-4 CONVERSION TO SELECTIVE SINGLE PRELIMINARY PROCEDURE 1. RU WL. Obtain BHP. 2. MIRU workover rig. Kill well. 3. ND tree. NU and test BOPE. 4. Shear off of SBR. POH with tubing. Change out collars to AB MOD while POOH. 5. GIH with packer retrieving tool on 3-1/2" drillpipe. Retrieve packer. 6. Run CET. Squeeze as required. Reperforate if necessary. 7. GIH with bit and casing scraper. Circulate well clean. POH. 8. Set RBP and test casing. Change out tubing spool to 5000 psi equipment. 9. Pull RBP. 10. Run 3-1/2" selective single completion. 11. ND BOPE. NU tree and test. 12. Displace well to diesel. 13. Secure well, release rig. Completion Fluid: NaC1/NaBr Brine Anticipated Bottom Hole Pressure: 2900 psi SA2/42a ii ANNULAR PREVENTER § PIPE RAHS 4 BLIND RAMS 5 TUBINe HEAD 1. 16" CONDUCTOP SWA~ED TO 2. 11"-3000 PSi STAP, TIN~ HEAD 3. 11"-3000 PSi x 7-1/~8"-5000 TUBING HEAD 4. 7-1 / 16" - 5000 PS1 PIPE ~AMS 5. 7-~/~6" - 5000 PSI BLIND RAMS ~ 7-i/~6" - 5000 ~51 ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK ANO FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRE$$UI~ I$ ~000 PSI WITH I SO0 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME ANO PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING DUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 4S SECONDS CLOSING TIME ANO 1200 PSI REi"IAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN 5.::-"_WS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TES- ::)LUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DQ¥,?~ SCREWS IN HEAD. `3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PS1 AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSi AND HOLD FOP. 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. 1NCI~EASE PP, E$SURE TO ,3000 PSi AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY IjPSTP. EAM OF CHOKES. BLEED DOWNSTPEAr'I PRESSURE TO ZERO PSi TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY. 'WITH 3000 PSi UPSTREAM OF VALVE AND WITH ZERO PSi DOWNST!~EAM. BLEED SYSTEM TO ZERO g. OPEN PIPE RAMS. BACKOFF .~UNNING JOINT AND PULL OUT OF HOLE CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZE~O PSI. 10. OPEN BLIND RAM'$ AND~ECOVE~ TESTDLUG. MAKE SURE MANIFOLD LINES APE FULL OF AP, CTIC DIESEL AND ALL 'v'ALVF.$ AP, E SET !N THE DP, tLLING POSITION. ! I TEST STANDPIPE VALVE~ TO 3000 ~Sl. !2. TE-~T KELLY COCKS AND iNSIDE ~0P TO 3000 DS1 WITH KOOMEY :'UMP !3. ~EC0PD TEST !NF0~MATION 0N BLOWOUT P~EVENTE~ TE'~T FOP. M AND SEND T0 DRILL:,NG SUPER. VISOR !4 PEP. FOI~M COMPLETE ~,]PE TEST ::NCE A WEEK AND FUNCTIONALLY OPERATE BORE DAILY. Attachment Page 3 Drill Site Well No. Log Date 1Y 1Y-1 6/6~83 10/21/83 1Y-2 6/10/83 3/4/84 ~~ 6/18/83 1Y-4 - 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1.Y-9 6/20/83 l~1~L~l~ 5/10/83 ~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2~28~85 2C-7 10/15/84 $2C=10~12/-11/85 Drill Site Well No. Log Date 2Z' ~_.Z~._ 7/10/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF:pg'O052 R C ED _ AJaska Oil & Gas Anchora~ : ~--- - Drill Site _-- Wel 1 No. ~lY-2 ~1Y-12 '~ 1Y-13 '~lY-14 '~lY-15 ~lY-16 Log Date ~%'- 6/6/83~..'~ ~10/21/83/ '~6/10/83"~ ~3/4/847 ~ 6/18/83 7/2/83 ~6/29/83 ~6/27/83 ~6/22/83 ~/20/83 ~5/zo/83~ ~11/21/8~ ~5/25/83 ~5/27/83 ~/13/83~ ~5/18/83/ ' ~/29/83 ~'5/30/83~ ~10/23/83~ Drill Site Well No. Log Date "2Z-1 -~2Z-2 .,~ "~z-3 '~2Z-4 ~2Z-6 ',-27-7 "~2Z-8 2Z 7/10/83 6/24/83x,, ~/' 7/19/83/ 8/5/83 7/12/83 7/27/83 7/28/83 8/3/83 Drill Site 2C Well No. Log Date --- 2C-4 '"'2/19/85 .~' 2/28/85.~ '~ 2C-7 X-~lO/15/84 .I VLF:pg:O029 RECEIVED FEB 2 1 1986 AI~' Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc.' Post Office t.~. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' Well Action Date Performed on the 1F-4 1F-5 1F-8 1G-3 1G-4 1L-3 1L-5 1Q-8 1Q-12 1Q-14 1R-3 1R-10 1Y-7 1Y-10 1Y-15 1Y-13 2B-6 2B-8 2B-11 2B-12 2C-2 2C-4 2C-5 2C-7 2D-4 2D-5 2F-3 2F-4 2F-15 2F-16 2D-10 2D-16 Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers Convers on 10/ on 10/ on 10/ 'on 10/ 'on 10/ 'on 10/ 'on 10/ '°n 10/ on 10/ on 10/ On 10/ on 10/ on 10/ on 10/ on 10/ 'on 10/ on 11/ on 11/ on 11/ 'on 11/ 'on 11/ 'on 11/ 11/ 11/ 'on 11/ 'on 11/ 'on 11/ 'on 11/ 'on 11/ 'on 11/ 'on 11/ 'on 11/ Convers'on Convers'on Convers Convers Convers Convers Convers Convers Convers Convers 24/85 24/85 24/85 25/85 25/85 24/85 24/85 25/85 25185 25/85 26/85 26/85 26/85 26/85 26/85 26/85 5/85 5/85 5/85 5/85 6/85 6/85 6/85 6/85 6/85 6/85 2/85 2/85 2/85 2/85 6~85 6/85 · .. ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany .: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [],z., OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 608' FEL, 511' FNL, SEC. 21, T11N, RDE, UM 6. Lease Designation and Serial No. ADL 2565q 5. Elevation in feet (indicate KB, DF, etc.) 11 7' (RKB) 12. 7. Permit No. 83-9~. 8. APl Number 50- 029-20973 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number 2C-4 11. Field and Pool KUPARUK RIVER FIELD KIJPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 6, 1985 Kuparuk well 2C-4 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into both the "A" and "C" sands. RECEIVED I./.. '-.-.~ . Alaska Oil & Gas Cons. '" Anch0ra,Os 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Date 11 / 1 5 / 85 Signed ~.~, /~.~' -_~,.,¢.,,.,~,,---- Title OPERATIONS COOI~DI NATOR The space below for Commission use ~ <~_ /~,,_ ~/~ Conditions of Approval, if any: -- By Order of Approved by COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.: ~' Post Office -b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 PorcUpine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to-water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincere ly, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .-~. STATE OF ALASKA ~--. ALASKi~ 'LAND GAS CONSERVATION" "IMISSION SUNDRY NOTICES AND REPORT ON WELLS 1. DRILLING WELL I-1 COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, ]:nc. 3. Address P 0. Box 1'00360, Anchorage, Alaska 4. Location of Well N/A. 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. Perforate Stimulate Repair Well 99510 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached I6. Lease Designation and Serial No. see attached Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEOUENT REPORT OF' Pull Tubing 11, Field and Pool Kuparuk River Field Kuparuk River 0il Pool (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [~ Altering Casing '1--] Abandon [] Stimulation [] Abandonment [] Change Plans ~ Repairs Made [] Other [--I Other X~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state alt pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list o~^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to.a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. SE? 2 o 19B5 Gas Cons. commission Anchorage 14, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,.~, /~-'~ ~,~-~"'~'~'-~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 COMMISSIONER ~tl~loroved Cotoy Returned By Order of the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1E- 6 -26 IF- 2 - 4 - 5 - 8 1G- 2 - 3 ' 4 - 5 iL- 1 - 3 - 5 - 7 -16 iQ- 1 - 2 - 7 - 8 -11 -12 -13 -14 1R- 3 - 8 -10 -13 1Y- 1 - 7 -10 -13 2B- 5 - 6 - 7 - 8 - 9 -10 -11 -12 2C- 1 - 2 - 3 - 4 - 5 MARK: 009 Permit 80- 78 82-166 81-211 172 132 162 82-138 149 161 83- 20 84-173 158 123 145 181 84-231 232 218 209 199 193 85- 44 45 85-177 73 96 150 83- 50 68 51 15 84- 4 22 24 28 27 29 35 38 83- 83 93 89 94 99 API# 029-20493 029-20840 029-20881 20846 20807 20836 029' 20813 20824 20835 20908 029-21196 21182 21155 21171 21202 029-21247 21248 21234 21225 21216 21210 21306 21307 029-21406 21333 21351 21385 029-20933 20950 20934 20903 029-21067 21078 21080 21079 21082 21084 21089 21092 029-20962 20972 20968 20973 20978 Lease & Serial # Convert Date 25651 469 10/15/85 " " 10/15/85 25652 2578 10/15/85 " " 10/15/85 " " 10 / 15 / 85 " " 10 /15 / 85 25640 2571 10/15/85 " " 10/15/85 " " 10/15/85 " " 10/15/85 25659 2585 12/15/85 " " 10/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 25634 2567 10/15/85 " " 12/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 25635 2568 10/15/85 " " 10/15/85 " " 10/15/85 " " 10/15/85 25641 2572 12/15/85 25646 2577 12/15/85 " " 12/15/85 25548 2662 12/15/85 25656 2582 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 25655 2581 12/15/85 " " 12/15/85 " " 10/15/85 " " 10/15/85 25654 2580 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 $ E P 2 o ~.lask'a [iii & (:,a~ Bt, ns. C;omm!ssk}r~ RETURN TO: ARCO Alaska, in~--~-.. Post Off~' ox 100360 Anchorage, Alaska 99510-0363 Telephone 907 276 1215 ARCO ALASKA, INC. KU PARU K OPERA%'ION~3 RECORDS CLERK ATO-1115B P.O. BOX 1U0360 ANCHORAGE, AK 99510 DATE: 08-16-85 TRANSMITTAL NO: 5254 ENGINEERING ., TRANSMITTED RECEIPT AND RETURN ONE PRESSURE FINALS CAMCO lB-3 1D-8 1E-5 1H-6 1L-2 1L-5 lQ-6 lQ-9 2A-5 2A-5 2C-4 2F-7 2F-8 2F-9 2G-1 2G-1 2U-5 2U-6 2U-7 2U-8 2X-'l 0 OTIS 2A-2 2U-14 ' 2V-2 2V-5 2V-13 2V- 14 _w-7 3B-3 3B-8 RECEIPT B. CURRIER CtiEVRON* D & M* HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE THIS TRANSMITTAL. PBU STATIC PBU STATIC PBU PBU PRESSURE FALL OFF PBU PRESSURE FALL OFF STATIC PBU PBU PBU PBU STATIC PBU STATIC STATIC- S TAT IC STATIC PBU STATIC PBU ' PBU PBU STATIC STATIC PBU STATIC. STATIC SIGNED COPY OF 04-21/22-85 04-29-85 04-26-28-85 04-29-85 04-24/25-85 04-28/29/85 05-07-85 05-12/13-85 04-21/22-85 .· 05-05-85 04-24/25-85 04-14-85 04-19/20-85 04-13/14-85 04-17-85 04-29-85 05-02-85 ':-05-03-85 05-04-85 05-04-85 04-25/26-85 07-04-85 06-30-85 07-27-85 06-25-85 06-22-85 06-22-85 07-26-85 06-28-85 06-28-85 ACKN O;~LEDGED: DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* STATE OF ~ASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska, Inc Post Office ~,oX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I) A T E ' 05 ...., ~.': - ;, (:'> _, ":' 'FF;:Ai'~SMITTAL. N.O:U~86 "ETURN 7'0: A R C 0 A I.. A.'.<; I", A, I N C. AT'¥N: F.'ECOI;:I)S CL. 17F;:I< A ]" [) -- t ~ i '.5 B I::'.0,, BOX i 0036(') ANC. HOF;:AE-E, A.I( 795'i (') :' R A N,7 [-I I ]' T r-: D H li!] R E H ]: ]' H A I:;: IZ -FI-I I:i] F 0 I... I... (] W I N [, ': E C E I F:' T A N D I:;: l":"I' U R N · 0 N E .? :[ (;- l",lli: D 71: ...... "'" .... "' I k. ~'1,.: , F.' L ~:. ,--, :'¢ I"'~ A C K P. 0 W I... E l) 6 I'.i~ COF:'Y JIF THIL,' TF;:ANSriITTAL. J,,l.,,, ,~E. qUEr,!CE OF:' 'I I= '- 7 I::: U N L. Y N I:"' S R E C 0 R 1) E R,!'.,' ('," 4 '" '2 t .... Ii! .5 "~ F - 7 R E ]' R I E V E L_ Y N E ,'":I:;: Ii" C. 0 F;: D Ii; F;: .S' 04-' '"~:,_ '~ "" , "r" ," S ' I [; '- 4 I_ ~ N,:: a I::: R E S U I:;: E B 0 H B.7 "" P ['.'ti (:) 4-' 2 t - 8'5 'i C;-'5 SBHF' 'C.' SAND '.'34-'~6-,c:15,... i1_--2 'C' SANDS -ONLY F:'BU 04-2t i L_- 2 'C '?AND PBU 04-''')~'',:...)-85 ; (;!....6 'r,.'-,c; I:.- I LL/SI3HF' 04-.27,--85 'i 0,-7 TA(; F"II_.L../SBHF' ' A' )2,'-'.,NDS 04"-1 ./:)-'8'"i ")A-- t "" " .... .; B H F 04 - '') '')- 8 5 ") A- 4 li'B H F' (3' .a ,-~.'~_. o,.= .... ~ '"' g.. K~ ")A<. .... 5 I'-' ALL OFF" TEST (')4-'"~ 4.-.. o"'":'-, 2A-5 FALl_ OF"F TEST 04'-22-85 '..:.! A - 7 SBI"iF' 04 -273-85 "'B-~'> E/t. INI: SI:"IN/T[;L EUi:;:VI:.Y LEAK DE'I'ECTZON C SAND 04-'t :::.!C-'4 PBU 04-24--8'"5 2C-4 I':'BU 04-''~":',.. _~ -' '"' "-',::, ::>f.',-5 ....... RUN TOR~UF' 'I-LIRN/Ai'iI:F~flDfiS 04-'2 ~ _o<,.,., .:;'.C,-5 PBU-PULL TORQUE 'TURN/ ANI"i:RAI)A BOHBS 0 '1-' ") :.'~-;:~"''"'~ ,.,., 2C,-14 RUN 'FOR0`UE TURN/AHEF~ADAS 04-'2t-85 :..!C-.~ 4 F' I!". [J '- I::' [.I 1.. [. T OF;:QUI:' AHITF;:ADA BOMBS ~4 ..,'. ~ ,'~ r,,,,' F,r-ll:.l'~r~][)~-~,T 04-2~ -d..~ :.:.!D-2 Ir(UN 'roF4QUE TU'""~ ........'" ' ~ ""- ?.I)-'t'3 I;:UH TOI:;:f;~UI: ]'LIF;:N/AHI;~Fi:ADAS 04-21-85 2IL)-~ 0 I:'I'.';LI'-I:'LII..L TOI:i:I..:]UE 'I'URN/ A-MEI"(ADA I"~OHI:,'$ 0,1-23-' "~ 1.7 '- 6 P B U ~.-, 'x _. ,-) ,.~ _. ,_': ,.~ 2F--S PBLJ O.q-" t c~. _ 2F-8 F'I.~I.I ';.'}.4-20'" S 5 21""- t t F'ii;LI 04-t 8-8'5 ?. F'-- i t F' B t.i 0 4 - '1 ";' '"'"-' _ '~ -. ")<.. I;. - t P B U 0 4 - 'i 7- ,.,° _,':< 2 I.; - t F:' B U C' 4, .... t 8 - 2(:;-'8 F'BU 03-2t -85 · -) iT) .-...17.,--,_, F:'B L! O "3 -' 22- 85 5:ECliE I PT ACKNOWLI:i]I)G EI): .,?, F:' A I::: 90 I) R I L_ I._ :1: N :),. C U R .1:.;: I I .... l(.} I-.I f-I S ]" 0 i'.( '] I.-I I:: V F,' 0 N :,~ -)(- l'f (:) B :1: L .~ .... . ! ,' ': & N~:' N..::.'K C L_ r::. t.. ,,, OTIS (]'FI 2 CAMCO C A hi C [) · CAMCO CANCO CAMCO CAHCO [}'F I £ [; A H C 0 CAHCO CJTI 2. CAHCO CAMCO BAKER BAI( ..'---- R/TORQUI-': TURN OTI~ BAI<ER/TORQUE TLIRN 0 T I ~ BAKER BAK ER/'I'OI:;:r2UE 'I'LJF;:N (]'r 12_, CAMCO CAMCO ~_~z. / ,~' CAMCO ~~Z~ CAMCO 2 :: C)]'I Z Alaska. Oil & Gas 0 '1' I S DATE: ....... · x'STATE OF AI. ASI(A x. S [} H ]] 0 ~- tJ N I 0 N t% ,. K , 'FL/L. I N/V~UI_ ] ARCO Alaska, In(; Post Office E~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Corr~nission 3001 Porcupine Drive Anchorage, AK 99501 Oear Mr. Chatterton- Attached in following wells duplicate are subsequent notices at the Kuparuk River Field' Well Action Date Performed 1E-6 Fracture 1/26/85 1E-7 Reperf 1E-7 Fracture 3/1/85 1E-8 Reperf 1/28/85 1E-11 Reperf 2/1/85 1E-11 Fracture 2/7/85 1E-18 Fracture 3/13/85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3/23/85 1E-22 Fracture 3/22/85 1E-24 Fracture 3/22/85 1L-6 Fracture 2/2/85 1L-7 Fracture 1/30/85 1Q-9 Fracture 3 / 1 8 / 85 1Q-1 0 Fracture 3/5/85 1Q-1 2 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Conversion 3/12/85 2A-5 Conversion 3/12/85 2A-6 Conversion 3/12/85 2A-7 Conversion 3/12/85 2C-4 Reperf 2/23/85 2D-4 Reperf 2/2/85 2V-8A Conversion 2X-8 Perforation 1/27/85 on If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) the ARCO Alaska, Inc. is a Subsidiary o! AllanlicRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, :]:NC 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 608' FEL, 511' FNL, SEC. 21, T11N, RgE, UH BOTTOMHOLE LOCATION' 1130' FWL, 1068' FNL, SEC. 16, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. I 12. 7. Permit No. 83-94 8. APl Number 5o- 029-20973 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2C-4 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL 117' (RKB) ADL 25654 POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) ~] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On February 23, 1985, the "C" sands of Kuparuk well 2C-4 were re-perforated. After testing the lubricator to 3000 psi, the well was shot with a wireline conveyed gun. Interval (MD)' 8342-8402' (4 SPF) 8433-8440' 8448-8456' 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ , j Title OPERATIONS The space below for Commission use COORDINATOR Conditions of Approval, if any: 3/28/85 Date. Approved by By Order of COMMISSIONER the Commission Date ..... Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alask~i, Inc. ' Post Office Bo,~ 360 Anc.horage, Alaska 99510 Telephone 907 277 5637 !-'I Iii; r;: r::' !.,j .]i -l"l-.I A I.~ E; T I..I I!!; I::' TM t ....... I...(')[.,.I I iqE; I T""H,? I(i".!r'll,.tl...lii]I.'."ql!i; ..... I;;. .,, ... ANI) I:;;I]!;'l'L)l"',~i'~,l ONE ,':.CI,.C. Nli!;)) COPY C!I'"" TI'-I];,iS 'i'jF;.:K:',,i',!,'.'-i'HI'I"'I"AI...,,, . ... 0 I::' E V I~!i N 1" ,S' F' L_ IJ,S' I... 0 (;i- (.,.'.,:~,~ (., (.) ~, "r (.),:.'.) :r~ ,.: ,'.:.: C;' ,..' . ""t.; :.., .., ....... 5-' C I..I I... U H )..'.', l!:'. IR C E I':~'.' ( i'.! ii ,!;,' I N 6 I... Ii!; I i'.! 'l' E1:1 ;,,,' L. ,, ) C: A H C (.1 ',, .... C) ...... ::, 0 ()"" lil ,S 5: () C.. A H C (] 7 ?; (.) ~,~ .... ? Ii!5 © · .,~.' . ". , )} IR li!i,!-...~,!-;'lii; R rr',.T !... A .../ .,./ i..i - ¥ ~.,: ~,... ., · 0 T I ,? '7 .:I 5: ('.') .... '?";, v.- n ' ' i ...., -./ 7 4 5 ¢? .... '7'ix Ill; fi C A i"'i C 0 '? 4.'5 0 .... '7 7 0 9 ;() ;ii ;? 'i' 1:;,' I .E': U -f' ;I; 0 N ' ~.~ ........ I'' ,", i::. "" '; ~.)' '"' ;t; L I._ I H 6 ~, I I-"" ~..:" :".:- ,',' I::. ..... I',,' -- i'\ ~.. ~ /. ?,., C.I..~ F.' J:;'. ;I:',... .... I';.: I .... ~ ;..I r).. H i-..~ ':' "1' ,""~ i'--~ Iii: >.-1 )i((:) ~-.,.' .'"..'1. ;' r'l'!li~:~"l':'f'~H~~,.. ,...- 'i ,,,U:~l:-.' '[I .:,~ '~ p!.~ 'r I ~ T F' '"? ~'"~ i1: L.-X. , , - , ]985 Alaska Oil & Qi,h.fi (;ONS, Commiss!on /~tic?iO;';,mg ... )~:; ,':'i 'i" li~ ' ...: ....... ,. ...... : ........ ..:_:..::., ..... ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 8, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton' Attached is our notice of intention to perforate Kuparuk Field well 2C-4. If you have any questions, please call me at 263-4253. Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanticRJchfieldCompany STATE OF ALASKA ALASKA L~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-94 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20973 OTHER [] 4. Location of Well SURFACE L0CATION' 608' FEL, 511' FNL, T11N, R9E, UN SEC. 21, BOTTOMHOLE LOCATION' 1130' FWL, 1068' FNL, SEC. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2C-4 11. Field and Pool 16, T11N, R9E, UM KUPARUK RIVER 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KU PARU K R I V ER 117' (RKB) I ADL 25654 POOl 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] FIELD OIL (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "C" sand in Kuparuk well 2C-4 be perforated for production. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. The well is currently open in the "A", "B", and "C" sands. This job will add perforations in the "C" sand. Proposed Intervals (MD)' 8342-8402' (4 SPF) 8433-8440' 8448-8456' ANTICIPATED START DATE' February 12, 1985 Surest Work R~port~l RECEIVED F E B 0 8 198-5 AlasKa 011 & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use COORDINATOR Date 2/8/85 Conditions of Approval, if any: Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Il._ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field- Well Action Date Performed 1F-4 Fracture 9/18/84 1F-7 Fracture 9/21/84 1L-1 Fracture 10/23/84 1L-8 Fracture 10/16/84 1Y-2 Fracture 10/9/84 1Y-2 Acidize 10/22/84 1Y-3 Fracture 10/7/84 1Y-5 Fracture 10/4/84 1Y-14 Fracture 10/6/84 .~ii~~ Perforate 10/16/84 If you have any questions, please call me at 263-4253. M.ike L. Laue ._ Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED OCT 2 9 Alaska 0il & Gas Cons. c0mmissl0n Anchorage ARCO Alaska, inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION L, OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-94 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20973 9. Unit or Lease Name KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION' 608' FEL, 511' FNL, SEC. 21, T11N, R9E, UM BOTTOMHOLE LOCATION' 1130' FWL, 1068' FNL, SEC. 16, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 11 7 ' (RKB) 6. Lease Designation and Serial No. ADL 25654 10. Well Number 2C-4 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105o170). On October 16 1984, the "C" sands of Kuparuk well 2C-4 were perforated for production. After testing the lubricator to 3000 the well was shot with a wireline conveyed gun. Intervals (MD). (1 SPF) 8363' , 8365' 8371' 8379' -8383' , 8387'-8389' · d 8395'-8399', 8435'- 439' , 8450' , 8452' , 8454' psi, 14. I hereby certify that the foregoing is true and correct to the best of my~jo~,~:~i Signed /~~ C~ ~U-(~ Title OPERAT IONS COORD I NATOR The space below for Commission use 10/29/84 Date ,, , , Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, I, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1984 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Oear Mr. Chatterton: Attached is our notice of intention to perforate Kuparuk Field well 2C-4. If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator ML L / kmc Attachment (In Triplicate) RECEIVF!3 ,'-i:":' 1 ~" '1984 ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany -~"~ STATE OF ALASKA "~'-~-- ALASKA~OIL AND GAS CONSERVATION uOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-94 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20973 9. Unit or Lease Name KUPARUK RIVER UN IT 4. Location of Well SURFACE LOCATION. 608' FEL, 511' FNL, SEC. 21, T11N, R9E, UM BOTTOMHOLE LOCATION. 1130' FWL, 1068' FNL, SEC. 16, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 11 7 ' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25654 10. Well Number 2C-4 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Per te 1984, perfor perfor lephone conversation with Lonnie Smith (AOGCC) October 15, it is proposed that the "A" sand in Kuparuk well 2C-4 be ated for production. Procedures call for the well to be ated with a wireline conveyed gun under a lubricator. Proposed Intervals (MD): (1 SPF) 8363', 8365', 8371' 8379'-8383', 8387'-8389' 8395'-8399', 8435'-~439', 8450', 8452', 8454' ANTICIPATED START DATE- October 15, 1984 .. Subsequent ~'Vork l~eported iVFu · . ' "'!0¢9, ' ~ ! ;" '. - ~ i c.. [" 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Tit~e O~ERAT ! O~S COORD I NATOR The space belo~ for Commission use Date 10/15/84 Conditions of Approval, if any: Approved b _ Form 10~03 Rev. 7-1-80 ~Fprovect Copy Returned By Order of COMMISSIONER the Commission Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. · .. - ,~ j..-. . -.-;-';c-,~.~ .°.;~7 2:77 $~37 Return To: . . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/08/84 Transmittal No: 4759 PAGE 1 of 2 ,~aTransmitted herewith are the following items. Please acknowledge receipt nd return one signed copy of this transmittal. , ~u - '.S~RV~S / PaESSORE ANALYSTS <lA-2 5/11,12/84 Torque Turn (Pressure & Temp Surveys) -~_lA~6__~ 7/06/84 Camco ~' ~ "zlB-11./ 7/10,12/84 ~ ~ ............. ~IA-i0 5/10/84 /lC-1 12/17/83 ~1C-6 8/04/84 ~!G,~O-' ~Z/2!/83 8/11/84 5/21/84 ~ ~_~G~--37 5/13,14/84 /1G~}~ 6/26/8~ /~G-2> 6/30/.84 ~ .~'~'~5~) 5/26/83 2!G-6'. 8/11/84 . M~2~6 ~/28/~ ~-~ 12/27/83-. ~ZY-5 12/1~/83 ~lY-7 12/15/83 ~~)1 ~/10/g~ C~o Otis Otis Otis Camco Camco Otis Camco Static Torque Turn (Pressure & T~mp Surveys) Camco Static Camco Camco HP Camco Camco · Otis Otis Static Otis Otis Otis "' C~ B. Adams F.G. Baker P. B~xter BPAE Chevron Date: D%STRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R & D C. R. Smith ~,~tat~o~AI~ Sohio Union Well Miles ~ . , -. ;.':c-r.c ?: .77 5~c37 Date: 10/08/84 Transmittal No: 4759 PAGE 2 of 2 Return To: · . . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~79-~-~:- 5/28/84 2C-1 11/09/83 " 2C-2 11/09/83 2C-6 11/08/83 2C-7 11/08/83 (2C~~ 4/18/83 ~2~%[~> 4/24/83 ~C~-~ 4/22/83 f~ 4/30/83 2~--~3 4/28/84 "6ZE-~> 4/29/84 ~ 4~_-~> 5/04/84 - 5/06/84 -' 2X-5 8/12/84 3C-6 5719/84 3C-6 5/17/84 -Otis Lynes -Lynes Lynes Lynes Camco Camco Camco Otis C~o Camco Dresser PBU Flow Survey (Gradient) Otis Static Gradient Otis Camco Dresser Dresser Mini Drawdown &Buildup Survey /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter Chevron Date: DISTRIBUTION D&M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips'Oil J.J. Ra thmell R&D C. R. Smith Sohio Union Well Files ARCO Alaska. Inc. : :-:~' :-:.;..-_-.. A .... ~.a . -~ -. :-.:'7- hc n~. 9,-' 7 277 5~.37 Date: 0/23/04 Transmittal No: 4699 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/PRESSURE ANALYSIS 2C-4 7/21/84 Camco SEQUENCE OF EVENTS Post Frac PBU 7/21/84 /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Ch err on DISTRIBUTION Drilling Geology Mobil " NSK Operations G. Phillips Phillips Oil J.J. Rathmell R&D State of '~Rlaska Sohio Union Well Files STATE OF ALASKA ALASKA L~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] a~,~8 ~ 7. Permit No. 2. N P SKA, INC. 83-94 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20973 4. Location of Well SURFACE LOCATION. 511' FNL, 608' FEL, SEC. 21, T11N, RgE, UM BOTTOMHOLE LOCATION: 1130' FWL, 1068' FNL, SEC. 16 T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 11 7' (RKB) 6. Lease Designation and Serial No. ADL 25654 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2C-4 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On May 22, 1984, the "A" sands of Kuparuk well 2C-4 were hydraulically fractured and propped to improve production. The treatment consisted of 412 BBLS of gelled diesel as pad and carrying fluid and 21,300 LBS of 20/40 sand as proppant. Prior to pumping, equipment and lines were tested to 4500 psi. sand was tagged with R.A. tracer to aid determination of job performance. The RECEIVED J u L 0 ]984 Alaska 0il & Gas Cons. Commission Anchorage 14.1 hereby certify that the foregoing is true and correct to the best of /~ ~~::~~ O PERATIONsr~U~Kur~ COORDINATOR Signed __ _ Title The space below for Commission use 6/28/84 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date. Form 10-403 Rev. 7-1 ~80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field: Well Action Date Performed 1F-1 Fracture 6/1 0/84 1F-3 Fracture 6/11 / 84 1F-5 Fracture 6/1 2/84 1 F-9 Per forate 6 / 16 / 84 1F-9 Fracture 6/19/84 1F-1 0 Perforate 6 / 1 4/84 1F-1 0 Fracture 6/1 8/84 1F-11 Perforate 6/19/84 1F-1 3 Perforate 6/19/84 1F-1 4 Perforate 6/22/84 1F-1 4 Fracture 6/23 / 84 1F-15 Perforate 6/1 7/84 1F-1 5 Fracture 6/21/84 1F-16 Perforate 6 ! 1 9/84 1G-7 Choke 5 / 4/84 1G-1 0 Perforate 5 / 29/84 1G-1 0 Fracture 5 / 30 / 84 1G-12 Perforate 5 / 29/84 1G-1 2 Fracture 5/31/84 RECEIVED JUL 0 3 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsid!a_ry:of AllanlicRichfieldCompany June 29, 1984 1G-15 Perforate 5/27/84 1G-15 Fracture 6/9/84 1G-16 Perforate 6/11/84 1G-16 Fracture 6/13/84 2C-1 Fracture 5/19/84 2C-2 Fracture 5/20/84 2C-3 Fracture 5/21/84 2C-4 Fracture 5/22/84 2C-5 Fracture 5/23/84 2C-6 Fracture 5/25/84 CPF-2 Perforate 6/23/84 3C-6 Fracture 5/19/84 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEiV' ,D J (J L 0 _:-~ !g84 Oil & Gas Cons. Cornmissior] Anc1]orage Well Name: Transmittal KUPARUK ENGINEERING · DISTRIBUTION NSK Operations Blueline Dr ill ing Bluel ine .Geolbgy/Keri __ ~ Film ~:'::'~-:::::-: :'_:.l;~. f:-:.-i~-t~,t- '; ~ ':' ~: -~ ~:-~-:~.-_--r-~:.~ ~-~:~.~ ..... . .... : ':::-.':~:d:~;--~J~: ~ .:::~ ' .? ~a:~.: ~- Sign & return the attached ~, copy as receipt of~.~ata~z, Return to: ARCO ALASKA, ATO-1115B P.O. Box 100360 Anchorage, AK 99510 KUPARUK ENGINEERING Transmittal Log Date Run DISTRIBUTION R&D D&M Union (Lambe~) Sohio (Burwasser) Mobil Chevron Phillips Alaska Oil& ~-C~s--Comm~n Return to: ARCO~~~.',--~'R~; ATTN: D.--'~ay ALLISON ATO-1115B P.O. Bom 100360 Anchorage, AK 99510 PBU ARCO Alaska, h~f Post Offic~ Jox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Apri I 16, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached are notices of intention to stimulate the following Kuparuk wells' 1F-13 1F-16 2C-1 2C-2 2C-3 2C-4 2C-5 2C-6 2C-7 If you have anv questions, please call me at 263-4253. Mi ~ue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) ARCO Alaska, Inc. is a Subsidiary of AllanticRJchfieldCornpany .... STATE OF ALASKA --' ALASK~ ,LAND GAS CONSERVATION f~ .,IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO ALASKA, I NC, 3. Address P. O. BOX 100360, ANCHORAGE, COMPLETED WE LL)~] 4. Location of Well SURFACE LOCATION' T11N, RgE, UM 511 ~ FNL, BOTTOMHOLE LOCAT ION' 1 1 3 0 ' R~/L, T11N, R9E, UM OTHER [] 5. Elevation in feet (indicate KB, DF, etc.) 12. 7. Permit No. 83-94 8. APl Number ALASKA 99510 50- 029-20973 9. Unit or Lease Name 608' FEL, SEC. 21 , KtJPARIJK RIVER tJNIT' 10. Well Number 2C-4 1068' FNL, SEC.16 11. Field and Pool KtJPARUK RIVER FIELD I 6. Lease Designation and Serial No. KUPARIJK RIVER O I L 117' (RKB) ADL 25654 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate )t~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand fractured and propped to improve diesel as the carrying fluid with proppant. A 12% HCL spear will Pumping rate will average 20 BPM. in Kuparuk well 2C-4 be hydraulically production. The treatment has gelled 12/20 sand and 16/20 ceramic as the be used to clean the perforations. proppant and pre/post frac production program. 800 GAl_ 1 7,900 GAL logs are Radioactive tagging of the included in the treatment FLUIO: 12% HCL Oiesel PROPPANT: 12/20 Sand 16/20 Ceramic 13,000 LBS 8,300 LBS Subsequent Work Be_ported ANTICIPATED START DATE. Mav 16, 1984 Signed Title Ktj PARUK OPERAT I '""""' COORD I "^~-'~ Approved Copy l~®tur~ed By Order of coMMISSIONER the Commission Date 4/13/84 The space below for Commission use Conditions of Approval, if any: ill /ltl~I~l[ C. SLIT/ Approved by Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KuPARUK EHGINEERING TRANSH t TTAL .-'-.' ~Z~ Z~ TO: FROM: D. Fay Allison Transmitted herewith are the following' WELL NAME' PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE,i~- PHOTOCOPY T ACKNOWLEDGED- EASE RETURN RECEIPT TO' ARCO ALAS. KA, IHC. · ATTN' D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 DATE' ' ~-~"" '-' .... Commi~ior~ ~?.', :S'<.~' , ,~i ,.~ ~...,,~.., ....... Anshorage KUPARUK ENGINEERING TRANSMITTAL TO' ~ ,,L'~ FROM: D. Fay Allison DATE' ~ 0~. /~/ TranSmitted herewith a~e the fo]low~n9' WELL NAME' ~¢ ---~-- PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE,I~)- PHOTOCOPY yPT ACKNOWLEDGED: LEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN' D FAY ALL I SON ATO/1115NBsk~ O'd & Gas Cons. Commission. · - Ar,.~horage P. O. BOX 100360 ANCHORAGE, AK. 99510 IgJP~4 ~ i NEERI I',,IG TO: William VanAlen DATE: ~: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following' F- FI LM, T- TAPE, PC- R-OTO(~PY ARCO ALASKA, IN~S. ~;~s A~: ~E~Y J. ~~D~ A~/1115-~as~a~ P, O. ~X 100360 ~~~E, ~. 99510 KUPARL/K EkE; I NEERI KC; TRA~LSM I q-FAL #~ TO: _/z~. _k/_~--~¢/_ ~//d __ FRCM: D.W. Bose/Shelby J. Matthews ' DATE: Transmitted herewith are the fol I(~incj- PLEASE NOTE: BL- BLUEL1NE, S- SEPIA, F- FILM, T- TAPE~-~ PLEASE P. EfUF~'4 RECEIPT TO: ~ ALASKA, I AT'iN: SHELI3Y J. MATI'HB',?J - ATOI 1115-B P. O, BOX 100360 ~d',EItOP~E, ~(. 99510 AR'CO Alaska, In Post Office ,.,ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 20, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2C-4 Dear Mr. Chatterton- Enclosed are the well completion report and gyroscopic survey for 2C-4. If you have any questions, please call me at 263-4944. Sincerely, ~. Gruber Associate Engineer JG' tw GRU4/L62 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -' ' --~'" ?-' STATE OF ALASKA ~-'-"--" 0 ~ I (~ I N ~/~~. ALASi. .,L AND GAS CONSERVATION . .~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG" 1. Status of Well Classification of Service Well OILX[~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-94 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20973 4. Location of well at surface 9. Unit or Lease Name 511' FNL, 608' FEL, Sec. 21, TllN, RgE, UM 'LOCATIONS Kuparuk River Unit VEP, IFIED ~ 10. Well Number At Top Producing Interval 1341' FNL, 1429' FWL, Sec. 16, TllN, RgE, UM [Surf.J--- 2C-4 E H.---~----L 11. Field and Pool At Total Depth ,5. 782' FNL, 1131' FWL, Sec. 16, TllN, RgE, UM ~-- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 118' RKBIADL 25654 ALK 2580 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 07/03/83 07/11/83 08/04/83I N/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9190'MD,6316'TVD 9078' MD,6243'TVD YES~] NO [] 1925 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/FDC/CNL/SP/Cal, CBL, Gyro, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.8# H-40 Surf 102' 24" 265 sx AS II 9-5/8" 40.0# J-55 Surf 3610' 12-1/4" 1650 sx AS Ill & 250 sx ,5 I 7" 26.0# J-55 Surf 9162' 8-1/2" 500 sx Class G & 250 sx i.S I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) 1SACKER SET (MD) 8578'- 8613' w/12 spf 3-1/2" 8249' 8219' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8520'- 8522' 415 sx Class G 8258'- 8260' 150 sx Class G 27. N/A PRODUCTION TEST Date-First Production Method 'of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TES'r PER~OD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Alaska Oil & Gas Co,is. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :- ' "': FORMATION TESTS "' ':" : !': GE6LoGICMARKERS :-;~- '"- ' .... ' ' ' -" NAME InClude interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 83z~0' 57z~9' Base Upper Sand 8398' 5789' N/A Top Lower Sand 8552' 589~" Base Lower Sand 8705' 5997' 31. LIST OF ATTACHMENTS Drilling History, Completion Summary, Gyroscopic Survey (2 cop~es) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~ Title Area Drilling Engr. 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". ! W~LL: ~C -4 ~---~PRDDUCTIDN (]NDECIIDN) TEST DAIA TEST SIJHHARY ARCD REP: TEST TYPE: WELL TYPE: -- PERFORATIONS: 'TEST DATE: · . Producer PERF TYPE: INTERVALS: TEST SUt.~ARY o AVERA[;E PRODUCTIDN CIN3ECTIDN) RATE DURING TEST: J AVERAC;E [;DR: /~ ~ 7...- AVERAg'E WDR: CUt,fI, JLATIVE PRODUCTIDN (IN3ECTIDN) DUR]'I'~; TEST: BPD BBL PSI i~-IT ~.~'F CHDKEi7 L/6~" /[PI GRAVITY FFI~IP ]~1~,. PSI SIBHP Z?Z~ .PS1 i-~ AT ~",,5~0 ' lid = ~ ~.O..' SS JI~~ IDT~ SHUI 1N ~I~: TOT~ PRD~CING (I~ECTION) LO~m TOOLS HRS H/ODR I~-LL EVENT HISTORY DATE START L'VENT . · L '~-. L I 'AP~ ~ / c. u Aiaska 'Oil & Gas Cons. Commission I~LS Anchorage 'PoO CUt~JLAT]VE PRODUCTION (1N3ECTIDN): TOIAL PRDDUClIDN (INJECTION) TIHE: DAYS ~ELL: ~'Z~ C ARCO REP: // ~ /1~o ~ /~1~ /~2 I~i I~~ KUPARUK RIVER UNIT SEI]UENCE ~3F EVENT ,/ EVENT OPERATZON: PT- AR60 REP: lIHE EVENT KUPARUK RIVER UNIT SEQUENCE OF EVEh~S .po ¥/ 2C-4 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0930 hrs, 07/02/83. Drld 12-1/4" hole to 3647'. Circ & cond hole. Ran 93 jts 9-5/8", 40#, J-55 HF-ERW BTC csg w/shoe @ 3610'. Cmtd 9-5/8" csg w/1650 sx AS III & 250 sx AS I. Bumped plug to 2000 psi - floats held - ok. ND 20" Hydril & diverter. Instld FMC wellhead. NU BOPE & tstd to 3000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.2 ppg EMW - ok. Drld 8-1/2" hole to 9044'. Ran logs; DIL/SFL/FDC/CNL/SP/Cal f/9038' to 3610', Cont drlg to 9190' TD as of 07/11/83. Ran 233 jts 7" 26# J-55 HF-ERW BTC csg w/shoe @ 9162'. Cmtd 7" csg w/500 sx Class "G" cmt. Bumped plug w/3000 psi - floats held - ok. Tstd csg to 3000 psi - ok. ND BOPE. Instld 7" packoff, set tbg head spool & tstd packoff to 3000 psi. Displ 50 bbls diesel down 7" x 9-5/8" ann. Secured well & released rig @ 1100 hrs, 07/12/83. HILL/DH31 08/10/83 2C-4 COMPLETION SUMMARY RU Gearhart. Ran CBL & Gyro. RD Gearhart. Secured well. Accepted rig @ 0200 hrs, 07/21/83. ND tree. NU BOPE & tstd to 3000 psi - ok. RIH & perf'd 8520' - 8522' w/4 spf. Set retainer @ 8462' Tagged & sting into retainer; pumped 150 sx Class G cmt. RIH & perf'd 82~8' - 8260' w/4 spf. Set retainer @ 8190' Tagged & sting into retainer. Attemped to squeeze; but, retainer was plugged. RIH & drld retainer @ 8190' RIH & tstd perfs 8258' - 8260' to 1500 psi - lost 200 psi in 5 minutes. ~IH & set retainer @ 8179'. Sting into retainer; pumped 150 sx Class G cmt. Drld retainer @ 8179'. Drld hard cmt to 8265'. Tested perfs (8258' - 8260') to 1500 psi - ok. Drld retainer @ 8462'. Drld cmt to 8560'. Tested perfs to 1500 psi; dropped to 1000 psi in 15 seconds. Ran CBL f/9066' - 7700'. Set retainer @ 8490'. Pumped 150 sx Class G cmt. Drld retainer set @ 8490'. Drld cmt to 8560'. Tstd csg to 1500 psi - bled to 700 psi in 15 min. Set retainer @ 8420'; tagged & sting into retainer; attempted to squeeze; retainer plugged. RIH & drld retainer @ 8420'; tstd csg to 1500 psi; bled to 700 psi in 15 min. RIH & set retainer @ 8420'. Squeezed 115 sx Class G into perfs. Drld cmt & retainer @ 8420'. Tstd csg to 1500 psi - ok. Ran CBL f/9060' - 7700' - good bond. Ran 3-1/2" completion assembly w/tail @ 8249', pkr @ 8219', & SSSV @ 1925' Ran GR/CCL. ND BOPE. NU tree & tstd to 3000 psi - ok. Set pkr. ~ropped bar & perforated the following interval: 8578' - 8613' w/t2 spf Closed SSSV. Set BPV. Secured well & released rig @ 2400 hrs, 08/04/83. GRU4/CS03 AF~C:O ALASKA, INC:, ............ ~!:.A.~!,._;~:!.-_.i.,_ ...... ..W,.~k~_.....~!!:!.,.,". ....... 4_; ..... :__:_:~ Gu..n..:GY;F:C, ,.. I-::;I_IF'~RI_IK F T ELD, NORTH ..':.L JF E ~L~i~:i-:::A STG-GYRL:I:, O--c'./A/-.A ..... MD, '-'I.:..JRVEYOR.=.' ' "-". ._I~HN/L-.:F~R~M, SIGMA GYRO Nh-- 774., F'RABE hil-~: ,/_-.7 I::: O'RE S ]'L',-' H 'r," N 14 4 :;;;".,::: ."'"'"'.., W . , ***NOTE: RKB C:HANAED_ OI-.ALIG-83 FROM 1'-"-'..-._-, . , ,' :,'~i;:,; -., 'i;~' .. ,:~, VERTIC:AL '.;;EC:TION C:AI_C:LILATE[~.:{IN pLANE OF PROF,',0~.AL · DIRECTION: N'36":DEG, · . ,, .. REC:ORD .. '~ i:: ·:"" ~:'" ':"' '?';:~!~: i~'?'~tl~'~' ' ~"-., ,,, ,:.~ ,~',:i' , ............... ~ .... -"LT, ',,,', , ,\ . .. .. ~'~ .. ,~.. ,, .,: ~ ,.... . , ,~"~ '; ~ :~ ' .:', .'~ ~:.'. ~: ..t...~,~,:;.'...;': ., . , . · . ;. .., . '.. · ....~.. · .. t . -. ......... RAD II I::; OF. F:I iRVATilRE~-~ETF:iT':il-i' .... :~ ...........................' .... ~RCO ALASKA, INC:. .' 'AD 2C, WELL NO: 4 SIGMA-GYF(O . ' :UF'ARUK FIELD, Nf.!RTH SLOF'E7 ALASi!:.'.A .~ ."?' C:c,M'~'I'iTAT I ON" 71 F'A'3E Nl~i~: .... ' ,_lob Nh: .A(.)78:3.Z 1621' T:IME DATE -. 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NO: 4 '.::.;If".iMg-F:iYRF~":' ,_lOB NO: "')'-"~' ·., . _ _ ' .AC. 7 ,:, ...,Z l ,6 2. '~IME DATE ,, '.. , ::]I_IF'AI.~I..II.::; F I ELD-,, NORTH SLOF'E., AL..ASI.::;A ' . ,,, L),_,: 57: :'~/-, ..... ......................................................................... , ...................... .¥ ............................ ._..:. .......................................................................................... ,, · .: · ,. .. TRUE " ..:- .'. '.'. ',IEAF;I..IRE£1 f'~RIFT DRIFT f":OURF:;E 'VERTICAL VERTICAL '.=;UBF-;EA R.i E c:'T. A ',N 6 U L.i'A R C L F'i.S U R E rloGI.. ......................................... : .................................... ..................... DEPTH gNF~[_.E DIREF:TION LENG"rH . r'~EF'I'H SECTION TVD C:. 0 0 R ri ....I N A T'.'E SF'-i~i~i'".5~'TAi~L~.:'~ ..... Ei'IREE:]'~iEilq-~=':E~EF FEET B M D M FEET FEET FEET . FEET ... F[ET ....' FEET D M DG/1 ( '.-.-~b'Oi)", "'4'.~/' '2':f,-kl"-~'? ....... ;'~'-~ ............ ~'i:i'O','"'-' ........ 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' ~' "'" ' ':':; ' · . - , .... · ',~,.. ..., . .... · - ,, A.','h (i]'}~..~'PANY ' · , - . .... · .. ;,~ .~. .'.. · .. ........ · ........................... '"" .. .~,- ... · ', .': .. .... . .............. ,. " ....................... ..: ': · · . · · . o. · . . ;'~ .. ... ,~.' · ARCO ALASKA, INC. PAD 2C., WELL. NO: 4 SIGMA-GYRO '::'IG-GYRF~, Ci-7060 MIl, ""Ic._IRVEYCR.=.' ~"'-': ,_IAHN/I_-:FIRAM, 'BATE RUN: 15.--._1UL-8:':: SIGMA GYRO NO: 774, F'ROBE NO: 67 " F"ORE:E: IGHT:N14 ..... 4,-.._.W';' '''''~ ............................... : ........... .-m ......... '.'..- · *.~*NOTE: RKB CHANGED C~l-AIJG-83 FR¢IM 1'-"-','-.:, ,JEIB Nil: AO783Z1 :.,' ... , .. RECORD OF ': *'..I' .... , :" ,*' '!".,;,! I, NTERF'OLATED'cCU~V~Y ...' ~ ..,,. - . .... :... ........... . '[~ '.[ . v .' .22 . :'AD 2E:, WELL NO' 4 '='IGMA-JYRU ,lOB NO: A~.7,:,.:,Z'i/:,~I TIME DATE :UP. ARU[.:.', ..,.FIELD.: .... Ng!R..TH.~...'.~iLE!E'E: AL~..SKA .... ' ¢)':'~ :02: 41 01 -AUO-:B:3 .. Id ARI-:::ER ........ .=,~ B.=,E~ ..... ,."'.'. .'.'": N~NE DEPTH DEPTH D~FF .DEPTH C: IzI '.0 R D'.'.' ! Nil A T E S' DI STANCE D !RECT !ON 'TH ICKNE'S FEET FEET. FEET FEET , FEET · :';' FEET El M TOP I_IF'PER SAND '=:'-' .~ '-' ' ' ' 55()/:,,'43 36 ,_ .-., 4 ,r) , (:)(:)': ..74.,:,. 62 259.'1 4 .5/-,:Rr) /-'-, 445() C)/...,.. N 32:~3 11 W') N 5 W i I - . . · _l~* · .. · . 4 c, 6.. ':;':'"; ""~' BASE I_IF'PERSAND '-'""":"-' ' ' 5 5 4 E: C) ,~7 N I E: ~, . W ,:,.:,:.,:, ¢)0 F, 7°':'.60 2609 4 5/-,70 60 4 e-_, .' ...TLF L..,WER .:,AND ,:,._,._,..".LO ' ._,,:,:.4.14 ~657..': ._77_. 14 Zl. 4 N W. N :35 ._...', , ~"1' ._1 ,_-,._1 :, · .. · ._", ._l W e. I 5997 '~'1 2707 '" M'.:'7 21 ;- R I 5771 55 N :'5 44 W ........ _-., C./ 4 .:". 4 65 '..N ..2:3,'7. 1 1 ,C_: W ~' , '-"- · · .. .... · Suggested fo].~n to lx i~%serted in each "Active" well folder to d:eck for timely compli~U%ce wit~] our regulations. · - Oi~rator, Well ~ ~d ~r ~ Re~s~ ~d ~4aterials tO ~ received by: g -- ~ --~ ~te Required Date Received Remarks Ccmpletion Report' Yes Wel 1 Histo~ Yes~ ~/~~ , . . ~re .miPs-, _ . .~~~_ ~_ , ---, , . . Core ~scription. . ~..~ '~ .~ ' Registered Su~ey' Plat ~~ ~ -- ~..,~.. ~~ ~ ' Incl~on. ,' S~y ., ,~ .~~' ~~ , Drill, . .St~. Test,, Re~s. .~~ ~ .... ' UK. ,. . . ' . , ..... . .... Digitiz~ ~ta , ,, , ,. _ , Ve3 7 ARCO Alaska, ' Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 6, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2C-4 Dear Mr. Chatterton' Enclosed is the Subsequent Sundry Report for the subject well. If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG4L39-sm Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL r~x OTHER [] '~~.,,,, 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-94 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20973 4. Location of Well Surface: 511' FNL, 608' FEL, Sec, 21, T11N, RgE, UH 5. Elevation in feet (indicate KB, DF, etc.) 118' RKB 6. Lease Designation and Serial No. ADL 25654 ALK 2580 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 26-4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). RU Gearhart, Ran CBL & Gyro, RD Gearhart, Secured well, Accepted rig @ 0200 hfs, 07/21/83, ND tree, NU BOPE & tstd to 3000 psi. RIH & perf'd 8520'-8522' w/4 spf. Set retainer ~ 8462'. Tagged & sting into retainer; pumped 150 sx Class G cmt. RIH & perf'd 8258'-8260' w/4 spf. Set retainer ~ 8190'. Tagged & sting into retainer. Attempted to squeeze; but, retainer was plugged. RIH & drld retainer ~ 8190'. RIH & tstd i perfs 8258'-8260' to 1500 psi - lost 200 psi in 5 minutes. RIH & set retainer ~ 8179' (above 8258'-8260' i perfs). Sting into retainer; pumped 150 sx Class G cmt. Drld retainer ~ 8179'. Drld hard cmt to 8265'. Tested! perfs (8258'-8260') to 1500 psi - ok. Drld retainer @ 8462'. Drld cmt to 8560'. Tested perfs to 1500 psi; dropped to 1000 psi in 15 seconds. Ran CBL f/9066'-7700'. Set retainer @ 8490'. Pumped 150 sx Class G cmt. Drld retainer set ~ 8490'. Drld cmt to 8560'. Tstd csg to 1500 psi- bled to 700 psi in 15 min. Set retainer 8420'; Tagged & sting into retainer; attempted to squeeze; retainer plugged. RIH & drld retainer ~ 8420'; tstd csg to 1500 psi; bled to 700 psi in 15 minutes. RIH & set retainer @ 8420'. Squeezed 115 sx into perfs. Drld cmt & retainer ~ 8420'. Tstd csg to 1500 psi - ok. Ran CBL f/9060'-7700'- ok. Ran 3-1/2" completion assy w/tail ~ 8249', pkr ~ 8219', & SSSV ~ 1925'. Ran GR/CCL. ND BOPE. NU tree & tstd to 3000 psi - ok. Set pkr. Dropped bar & perforated the following interval: 8578'-8613' w/12 spf. Closed SSSV. Set BPV. Secured well & released rig ~ 2400 hfs, 08/04/83. 14. I hereby c/~at//~/~the foregoing is true and correct to the best of my knowledge. Signed / /.~,,,/'.~~ ~/~~/-- Title Area Drilling Engineer Conditio~/bf Approva~X any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 GRU4/SN7 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUP~,RtJK DgS I NEERI NG TO: William VanAlen ~A: D.W. Bose/Shelby J. Matthews Transmitted herewith are the fol Iowirg- ~ ALASIGA, INC. - ATTN- SHELBY J. ~4A'Iq'I-IB~,.G - Al'O/111 5-B P, O, BOX 100360 ANE]-DRAGE, AK. 99510 /~RCO Alaska, In¢~--~' Post Offic, _, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Enclosed are the MOnthly State Reports for the following wells' 2X-2 2C-3 2X-3 2C-4 2×-5 2C-5 2X-6 2C-6 2C-7 Thank you. Sincerely, P. A. VanDusen District Drilling Engineer PAV/SH8:sm Attachments Ala.$ka Oil & Gas C~r~s_ Uommissiu~ ARCO Alaska, Inc. is a Subsidiary of Allanl)cRichfieldCompan¥ - -*- ~ r~" STATE OF ALASKA ------. O(~N~ //~f¢/? . - ALASKI __AND GAS CONSERVATION C,_ MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATI · Drilling well J~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-94 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 5o- 029-20973 4. Location of Well atsurface 608' FEL, 511' FNL, Sec. 21, TllN, R9E, UM 9. Unit or Lease Name Kuparuk River 10. Well No. 2C-4 Unit 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool For the Month of. July ,19 83 12. Depth at end of month, footage drilled fishingiobs directional drilling problems, spud date~ remarks Spudded well @ 0930 hr~, 07/02/83. Drlc] 12-1/4" h01e to 3647' Ran, 9-5/8" csg. Drld 8-1/2" h01e to 9044'. Ran 10gs. C0nt drlg 8-1~2" h01e Ran, cmtd & tstd 7" csg. Displ 50 bbls diesel down 7" x 9-5/8" ann. Secured well & released rig @ 1100 hrs, 07/12/83. SEE DRILLING HISTORY 13. Casing or liner r ~ tit~e~f cement, results of pressure tests 9-5/8" 40# Uona_ q~a~_ BTC csg w/shoe @ 3610'. Cmtd w/1650 sx AS III, 250 7" 26# J-55 HF-ERW BTC csg w/shoe @ 9162'. Cmtd w/500 sx Class "G" cmt. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/FDC/CNL/SP/Cal f/9038' to 3610'. 6. DST data, perforating data, shows of H2S, miscellaneous data N/A cmtd, & ts'.td to 9190' TD. sx AS I. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED/~/~~/~------~~''// t',/~ . ¢/ TITLE Area Drilling E naineer_ DATE '~//-~ NOTE--Repo/on {Chis fo/~is required for each calendar month, regardless of the status of operations, and must be fi'ed ih duplicate with the Alaska Oil and Gas/(;onservatio~/~Sommission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 Submit in duplicate 2C-4 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0930 hrs, 07/02/83. Drld 12-1/4" hole to 3647'. Circ & cond hole. Ran 93 jts 9-5/8", 40#, J-55 HF-ERW BTC csg w/shoe @ 3610'. Cmtd 9-5/8" csg w/1650 sx AS III & 250 sx AS I. Bumped plug to 2000 psi - floats held - ok. ND 20" Hydril & diverter. Instld FMC wellhead. NU BOPE & tstd to 3000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.2 ppg EMW - ok. Drld 8-1/2" hole to 9044'. Ran logs; DIL/SFL/FDC/CNL/SP/Cal f/9038' to 3610', Cont drlg to 9190' TD as of 07/11/83. Ran 233 jts 7" 26# J-55 HF-ERW BTC csg w/shoe @ 9162'. Cmtd 7" csg w/500 sx Class "G" cmt. Bumped plug w/3000 psi - floats held - ok. Tstd csg to 3000 psi - ok. ND BOPE. Instld 7" packoff, set tbg head spool & tstd packoff to 3000 psi. Displ 50 bbls diesel down 7" x 9-5/8" ann. Secured well & released rig @ 1100 hrs, 07/12/83. HILL/DH31 08/10/83 KUpAF~K E]~ I NEERING TO: William VanAlen FR[A4: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following: PLEASE lx~, F- FI IA/I, T- TAPE, PC- FHOTCXZ)PY RECE ! PT ASFCE~.',/1 FI'~ED: E R~P-Fb"PJN RECE IFF TO: ARCO ALASKA, INC. ATTN- SHELBY J. IV'A']q'HD,% - ATO/111 5-B P. O. BOX 100360 Alaska 0il ~.; da¢; L'.u,-~,,;. i',-;,-, ...... AC~vaE:;E, ~(. 99510 KUP~ BNGI NEER! NG TRAN~M I TgAL #_~_~ TO:. Wi Il i am. VanAlen ~: - ~ D. W. Bose/Shelby J. Ma.t~hews-., Transmitted herewith are the following' ~/~//~E NOTE: BL - BLUEL I NE, S - SEPI A, F -. F I LM, PC - ~PY PLEASE RETURN RECEIPT TO- AREO ALASKA, INC. ~l'~ka Oil & Gas COilS. Commission ATTN: SHELBY J. MAI-litEr,S - ATO/111 ,mchof' rage P. O. BOX 100360 ~,4GE, AK. 99510 ARCO Alaska, Inc: Post Office _-)x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 8, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conse'rvation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2C-4 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to dispose of reserve pit fluids down the 9-5/8" x 7" annulus. Since we expect to start this work on July 14, 1983, your earliest approval will be appreciated. If you have any questions, Please call me at 263-4970. Sincerely, A~'~n~g E~ng~neer JBK/JG3L65' tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA oIL AND GAS CONSERVATION C,JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-94 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20973 OTHER IZ]X 4. Location of Well Surface: 511' FNL, 608' FEL, Sec. 21, T11N, RgE, UN 6. Lease Designation and Serial No. ADL 25654 5. Elevationinfeet(indicate KB, DF, etc.) 96' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2C-4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] St im u lation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other E~X Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to dispose of reserve pit fluids down the 9-5/8" x 7" annulus of this well. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruption in the disposal process (i.e.; rig move, shutdown of disposal process for an extended period of time, etc.). Estimated start: July 14, 1983 14. I hereby certi]~that the foregoing is true and correct to the best of my knowledge. Signed [ Title yw-- -cy/,-- - The space b fd¢ ssion use Conditions Of Appro~, if any: 0.1111~TNA[ SIGltEg ~Y ~'II~Y W, F._UGLEfl By Order of Approved by COMMISSIONER the Commission Approved Copy Returned .7.-/ // Date ' Date Form 10403 Rev. 7-1-80 GRU3/SN37 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate iii iiii i ~ L_ i ~ i i i ii ii . i i i i i i i i i · .. ~~,~...~, ~,A',,zz .~/7'~ ~'.~ co~cTo~ zo~/o~ - ~ ~u/~T / I ' : I ~~'-~~ I ~ / ~~...~'~...~eT~ ' ~ I .I 1~/~.1~ V ~//~'..-' ~ ",,m '1 I ~ I ~/~'141 b7 I ~"":'"A'~:~:'~'~':'~''' il I. 90o *~ ~. ; 5276- S ...... ,. ,v'l X, a"/,~, z,, zz. z,¢7:. ?Q'/ 7 ',~¢. ..¢'e¢ /,~ " Iillllllll el~ IIlO lV~II~ITIII drawn by' ii i i ARCO Alaska, Inc. Kuperuk Project North Slope Drilllng Jscale' / % ~0 ' dwg. n~ ~.~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 13, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2C-4 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on July 21, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, A~'~~er JBK/JG3L26'tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA uIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-94 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20973 OTHER I~ 4. Location of Welt Surface: 511' FNL, 608' FEL, Sec. 21, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 96' RKB 6. Lease Designation and Serial No. ADL 25654 Unit or Lease Name Kuparuk River Unit 10. Well Number 2C-4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate I~( Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other E~X Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. procedure will be as follows: The 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. (~ 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: July 21, 1983 ..... 14. I hereby ~hat the foregoing is true and correct to the best of my knowledge. ' '/ .... ;~';ij~,(. uulll~i&' '~3- Signed ~ ~-' /~ ~.~ Title Area Drilling E.gineer /- ~/ ~ The space hew f~ Com~ssion use Condition~of Approval, if any: Date Form 10-403 Rev. 7-1-80 GRU3/SN19 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 4/'80 STATN t;/ ALASKA AhASKA OiL g GAS CO.NS':RVATIOi;~ CC:~'.~cciON....,., B.O.P.E. lnspoct~on Re!.-,ort · Da to _~__ Inspector Well ~ ~- ~ General ............. u ........~ -,~ in'- ~ Pr=ssure ' r-ur ,Tlr,s,.:r% psis U'? ~ . i --- --- Reserve Rig BOPE Stack Annular Pipe Rants Blind Choke Line V,:_:Lv-~:s ........ l ......,,..~--~"~-~-'-'~--'~.-- inside BO;" ........ ~. C. R Val ye ..................... June 8, 1983 Mr. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 2C-4 ARCO Alaska, Inc. Perm~_,~ No. 83-94 Sur. Loc. 608'FEL, 511'FNL, Sec. 21, Tll~, R9E, Bt~hola Loc. !130'~L, 1068'~]~L, Sec. 16, TllN, ~gE, U~. Dear ~r. Kewin: EnClosed i~ the approved application for permafit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A contin~ous directional survey ~.s required a8 per 20 AAC 25.050(b)(5). If available, s tape containing tl~e digitized log infor~.ation shall be subr~itted on all logs for co. yzn~ exce-pt experimental logs, velocity surveys and di~eter surveys. ?~any rivers in Alaska and their drainage systems have beep classified as important for the spawning or migration of anadromous fish. Operations in these areas are subj,:ct to AS 16.05.870 and the re~lation~ prom~lgated thereunder (Title 5, Alaska Administrative Code). Prior to cor~m~.encing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Ga~ne. Pollution of any waters of the State is prohibited by Ag 46, C~apter~" _ 3', Article 7 and the re~ulations~. ~romulgated. thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as a~ended. Prior to comm~encing operations you may be ~ontacted by a representative of the Departmept of Environmental Conservation. To aid us in scheduling field ~ork, please notify this office 24 hours prior to c~n]~encing installation of the b!o~zout Jeffrey B. Kewin Kuparuk River Unit 2C-4 -2- June 8, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. in the 'event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly/yo~rs~,~. ,-.~ . / Chai~an of ' Alaska Oil and Gas Conservation Co~ission Enc lo sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. be ARCO Alaska, Inc. -~ Post Office B,, ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 Hay 16, 1983 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2C-4 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2C-4, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A wellbore proximity map. o A diagram and description of the surface hole diverter system. o Diagrams and description of the BOP equipment. We estimate spudding this well on July 10, 1983. If you have any questions, please call me at 263-4970. Sincerely, JBK/JG3/L39 Enclosures RECEIVED JUN-' 1-983 Alask~ Oil & Gas c~n~. bu~,nlllS~lon An~hqraCle ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ,.-'-. ALASKA O,- AND GAS CONSERVATION CO~,,,vllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT G.A,~ % "¢'" 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 608' FEL, 511' FNL, Sec. 21, T11N, RgE, UM At top of proposed producing interval Target ~ 5995'TVD: 1320' FWL, 3960' FSL, Sec. 16, TllN, R9E, UM At total depth 1130' FWL, 1068' FNL, Sec.16, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 96', PAD 67' 6. Lease designation and serial no. ADL 25654 SERVICE [] STRATIGRAPHIC I~ SINGLE ZONE [~X MULTIPLE ZONE [] 9.~i~r lease name Kui)~ruk River Unit 10. Well number 2C-4 11. Field and pool %Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 33 mi. NW of Deadhorse miles 4672' FWL @ Surface feet 2C-~Nell 60' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8926' MD, 6255' TVD feet 2560 07/10/83 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 26/t. 1 KICK OFF P©INT 500 feet. MAXIMUM HOLE ANGLE 51 oI (see 20 AAC 25.035 (c) (2) 3122 psig@ RO°F Surface psig@ R128 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program r SIZE SETTING DEPTH QUANTITY OF CEMENT Hole Casing '24" 16" i2-1/4" 9-5/8" Weight 65# 40.0# 26# 22. Describe proposeo program: CASING AND LINER Grade Coupling H-40 PEB J-55/ BTC HF-ERW J-55/ GTC HF-ERW Length 80' 3539 ' 8898' MD TOP TVD 29' 129' 29' 129' I 28' I 128' MD BOTTOM TVD 109' I 109' 3568' 12853' 8926' 16255' I I (include stage data) ±200 cf 1250 sx AS Ill & 250 sx AS I 238 sx Class"G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8926' MD (6255' TVD). 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. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2641 psig. Pressure calculations are based on latest reservoir pressure data. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-SS buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. 2C-3 will be 60' away from 2C-4 ~ the surface. There are no closer wellbores anywhere downhole. Top of cement for the production string will be placed ~ 7309' MD, approximately 1000' MD above the ~Kuparuk Sands. SIGNED~(//~//¢~~~ TITLE Area Drilling Engineer DATE ~'/~_.~--// The space~for use Samples required []YES eNO Permit number APPROVED BY/ _ Form 10-401 CONDITIONS OF APPROVAL Mud Icg required I DirectionaISurvey required I APl number E]YES ~NO I ~,YES rqNO ) 50- O L~- Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMM ISSI ON E R by order of the Commission DATE June 8, 1983 Submit in triplicate ..... - _ _ ___~ ~ ~ . ., . ...... i --f ..... ~ ~ i-t---~-~~--~' ~ ' ~ i :, . ' :, i : ' i ~, ....... , ~, ;,.. .: ...... ,, ~ :~i~ : : ' . i I [ . : : ' · ~ : ~ . ~ ' ' -- , ', .... I - , . ~ . , , ~ ...... :--~_ ~__ - ' -4 .... ~r---~.: --~~'~-~~~ ' ._~~__,~_~._ ~~~ --~h~: ; _ b~ ...................... ..... ~ ..... ~ .... : : I ...... ~ .... h: ~-~-T ....... ~ ........................................................ ..... ~__ ~ ~ ........ ~-~h~ , . ....... ~ ........ ,__.~:-~ ,_~-~ .... --, . ~- : ~ : ~ ............... :::::::::::::::::::::::::: : . . : ~ ; . , ! ; : . . . , , , ; · ~ ; , _j · , ~ · , ' i ~ J ~ ~ i ' ~ ' i . i , I ~ ~ , , ~ ~ I I ii i~L~ i~i~ ili ~!I~ i ~ i ! ~1i ,.: ,~ '- : :~%~_; ~P'~i'~_:: ~ ~ ; :,~ ;iii , ~*: ..... , ; ~, , ' ' ................. ; ..... ;, · .,': : :: - , r h- , t .... ~_.,.~ .... ~_~~ ....... ~ .......... , .......... t .................... ~-- Surface Oiverte? S~/szem i. !6" - 2000 psi TanKco starting neat. 2. Tankco quick connect assy. 3. 16" x 20" 2000 psi douDle s:u~e~ adapter. 4. 20" 2000 psi drilling spool w/lO" side outlets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve piT. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular'preventer. · 7. 20" bell nipple. Maintenance & Operation 1. Upon initial insi:allation close annular preventer and verify thai: ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. D9, not shul: in well under any circumstances.. 16" Conductor RECEIVED Alask~ Oil & Gas mil ANNULAR PREVENTER 11 BLIND RAMS' · I0 PIPE ARMS 9 ii DRILLING ' SPO80L - . PIPE :~MS 7 ( C' ) HD 3 Oil & Alaska D I AGP~AM .~2 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16" - 3000 psi tubing head 4. 7-1/16" - 3000 psi x 11" - 3000 psi double studded adapter S. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 9. 13-5/8" - 5000 psi pipe rams 10. 13-$/8" - 5000 psi blind rams 11. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH ZSO0 PSI DOWNSTREJLM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NAOC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REI~AINING PRESSURE. 13-5/8' BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTI.C OIESEL. ~. CHECK THAT' ALL HOLD DOWN SCREWS ARE FULLY RETRACT- EO. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAO. RUN IN LOCK DOWN SCREWS IN HEAO. 3. CLOSE ANNULAR PREVENTER AND._CHOKES AND BYPASS VALVES ON MAJ~IFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. S. INCRF. JLSE PRESSURE TO 1800 PSI ANO HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE ~. · 7. INCREASE PRESSURE TO 3000 PSI ANO HOLO FOR I0 MINUTES. 8.. CLOSE VALVES OIRECTLY UPSTREAM OF CHOKES. BLEED OOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLO VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI OOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAHS. 10. INCRE~E PRESSURE TO 3000 PSI AND HOLD FOR MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAJ4S. BACK OFF RUNNING JOINT ANO PULL OUT OF HOLE. CLOSE 8LINO RN4S AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD ANO LINES ARE FULL OF ARCTIC DIESEL ANO ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. [ . - ANNULAR PREVENTER BLIND RAMS L PIPE RAMS ') '~'~ PIPE ARMS ) 5 CSG HD D D',GRAM -.' 1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11' - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 13-5/8" o 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-$/8" - 5000 psi pipe rams 8. 13-5/8' - $000 psi blind rams -g. 13-$/8' - 5000 psi annular RECEIVED ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI Wilt( 1500 PSI OOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNIT5 SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER. ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONOS CLOSING TIME ANO 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. .CHECK I'HAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED.. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT ANO SEAT IN WELLHEAO. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLO. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. " S. INCREASE PRESSURE TO 1800 PSI ANO HOLE FOR lO MINUTES. 'BLEEO TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTEO MANIFOLO VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE ~ ANO CLOSE 801'~OM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI ANO HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN ORILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS Company ,~¢~'~O Lease & Well No. /(i-dL,~ ITEM APPROVE DATE (1) Fee ~.. ....:, ..... (2) Loc .... ¢.' ~" 8) (3) Admin ~ /;.~.~i~ .... ,:'~,~' ~,~.. ',~ 15 (,~ thru 11) (4) Ca sg ~,~)..~ ~':..f- (12 thru 20) (21 thru 24) (6) Add: .~.~/¥ .,.¢~-~:'- .... 1. Is the permit fee attached ......................................... e 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES · NO REMARKS Is well to be located in a defined pool ............................ Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ..' .......... Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day wait Does operator have a bond in force ........................... Is a conservation order needed .... Is administrative approval needed ................................... Is conductor string provided ............ Is enough cement used to circuit;; on 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 collaps;i i;~' ~;~[ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included .on 10-403 . ........... Is adequate well bore separation proposed ........................... Is a diverter system required ............. ~ Are necessary diagrams of diverter ~'~;~';~ul;~;~; ~;t~ch;d 121.2~2~£~ -- Does BoPE have sufficient pressure rating - Test to ~QZJ~ psig'' ff277~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. , Additional Remarks: .2.~-') Geology: Engin~e~r ing: uwr Z Lcs ' EW WVA --' JKT~ HJH --~ , . rev: 12/06/82 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 APPENDIXl No special'effort has been made to chronologically organize this category of information. CUKV£ c','-r ~ _: ~ITICATIONS ECC # 1778 C~r. pany ARCO ALASKA, INC. I,'e!l D.S. JJ 2C-4 ~ Tield KUPARUK Coum:y, State NORTH SLOPE, ALASKA ~ate 7-11-83 Curve Name (Abater.) (THIS TAPE CONTAINS ONE FILE) Standard Curve .Name logs Used Scale GR CAL SP RFOC RIUM RILD CN GA~MMA RAY CALIPER SPONTANEOUS POTENTIAL RESISTIVITY _FOCUSED RESISTIVITY MEDIUM RESISTIVITY DEEP COMPENSATED NEUTRON DIFL-CDL-CD/CN CDL-CD/CN DIFL DIFL DIFL DIFL CD / CN 0-100, 100-200 6-16 0-100 .2--2000 .2-2000 .2-2000 60-0 DENP DEN DENS ITY CDL 2- 3 i CORR t CORRECTION CDL -.5-.5 t , ~. · ! 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