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184-152
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. 2D-02 KUPARUK RIV UNIT 2D-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 2D-02 50-029-21177-00-00 184-152-0 W SPT 5875 1841520 3000 2680 2680 2680 2680 380 560 560 560 REQVAR P Bob Noble 8/8/2025 MIT-IA to max injection pressure as per AIO 2B.052 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 2D-02 Inspection Date: Tubing OA Packer Depth 1550 3300 3200 3190IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250810105009 BBL Pumped:1.8 BBL Returned:1.2 Monday, September 22, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2D-02 KUPARUK RIV UNIT 2D-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 2D-02 50-029-21177-00-00 184-152-0 W SPT 5875 1841520 3000 2450 2450 2450 2450 616 835 823 819 OTHER P Bob Noble 6/14/2024 MIT-IA to max anticipated injection pressure as per Sundry #324-179. MITIA to maximum anticipated injection pressure per AIO 2B.052 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 2D-02 Inspection Date: Tubing OA Packer Depth 1250 3310 3190 3180IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240616135735 BBL Pumped:1.8 BBL Returned:1.6 Thursday, July 25, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 Sundry #324-179 AIO 2B.052MIT-IA James B. Regg Digitally signed by James B. Regg Date: 2024.07.25 12:35:10 -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: Seal-Tite Repair 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 7780'feet None feet true vertical 6309' feet None feet Effective Depth measured 7290'feet 7273'feet true vertical 5889' feet 5875' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 7320' MD 5900' TVD Packers and SSSV (type, measured and true vertical depth) 7273' MD 1884' MD 5875' TVD 1884' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 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: Contact Name: Contact Email: Contact Phone: 3281' 3076' Burst Collapse Production Liner 7741' Casing 6302'7771' 3246' 117'Conductor Surface Intermediate 16" 9-5/8" 82' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-152 50-029-21177-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025653, ADL0025658 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2D-02 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 117' ~ ~~ INJECTOR ~~ ~ 324-179 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl N/A Packer: Baker FHL HYD Set Packer SSSV: Baker FVL Sfty Vlv (Locked Out) Jaime Bronga jaime.bronga@conocophillips.com (907) 265-1053 7388-7390', 7411-7412', 7415-7417', 7425-7426', 7430-7432', 7435-7439', 7443-7445' 5971-5973', 5991-5991', 5994-5996', 6002-6003', 6007-6008', 6011-6014', 6018-6019' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name and Digital Signature with Date: Authorized Title: Well Interventions Engineer By Grace Christianson at 1:08 pm, Jun 26, 2024 DTTMSTART JOBTYP SUMMARYOPS 5/12/2024 ACQUIRE DATA (AC EVAL) T-POT (PASS) T-PPPOT (PASS) IC-POT(PASS) IC-PPPOT (PASS) ESTABLISH IA LLR (IN PROGRESS) 5/13/2024 ACQUIRE DATA (AC EVAL) MIT-T TO 3500 PSI (PASS) ESTABLISH IA LLR OF 5.5 GPM @ 1455 PSI, ESTABLISH IA LLR OF 8.4 GPM @ 1825 PSI, ESTABLISH IA LLR OF 10.5 GPM @ 2330 PSI 5/14/2024 ACQUIRE DATA SET 3.5" AVA CATCHER ON TOP OF 2.75 CA-2 PLUG @ 7290' RKB. PULLED DV @ 7216' RKB. READY FOR DHD. 5/17/2024 ACQUIRE DATA (AC EVAL) SEAL-TITE TREATMENT, CIRC 275 BBL NAC1 & 30 BBL DIESEL, INJECT SEAL-TITE PILL INTO IA FOLLOWED BY 108 BBL DIESEL (IN-PROGRESS) (AC EVAL) SEAL-TITE TREATMENT, CIRC 275 BBL NAC1 & 30 BBL DIESEL, INJECT SEAL-TITE PILL INTO IA FOLLOWED BY 108 BBL DIESEL (IN-PROGRESS) Initial T/I/O = SI 540/538/154 LRS rig up and pump 275 bbl of 9.6 ppg NaC1, taking returns off IA LRS pump 30 bbl diesel. Mix 1st part of Seal-Tite pill & inject into IA (bleed tubing while injecting) Mix 2nd part of Seal-Tite pill & inject into IA (bleed tubing while injecting) Mix 3rd part of Seal-Tite pill & inject into IA (bleed tubing while injecting) Mix 4th part of Seal-Tite pill & inject into IA (bleed tubing while injecting) *Bled total of 10 bbl back while injecting* LRS pump 108 bbl diesel down IA while taking returns off tubing. Ready for S/L Final T/I/O = SI 500/850/262 5/18/2024 ACQUIRE DATA SET DV IN ST #6 @ 7216' RKB. ACHIEVED PASSING MITT TO 2500 PSI. PULLED AVA CATCHER & CA-2 PLUG @ 7290' RKB. FREEZE PROTECT TBG DIESEL W/ 20 BBLS OF DIESEL. BRUSH n' FLUSH 2.75" D-NIPPLE @ 7290' RKB & SET BACK CA- 2 PLUG. ACHIEVED PASSING MITT TO 2500 PSI. READY FOR PLAN FORWARD. 5/19/2024 ACQUIRE DATA (AC EVAL) PRESSURE SEAL-TITE TO 3300 PSI (COMPLETE), SEAL-TITE CURE CYCLE (IN PROGRESS) 5/21/2024 ACQUIRE DATA (AC EVAL) PERFORM SEAL-TITE PRESSURE CYCLES TO 3300 PSI (COMPLETE) (AC EVAL) PERFORM SEAL-TITE PRESSURE CYCLES TO 3300 PSI (COMPLETE) T/I/O = SI 2218/3022/170 (-66 psi, since 16:30 pm 5-20-24) (6:50 am) T/I/O = SI 2224/2993/171 (-29 psi), (14:30 pm) LRS on location Bled IA for 2 min (fluid) to 2234 psi, (16 gal to bleed trailer) Bled IA for 2 min (fluid) to 1509 psi, (26 gal to bleed trailer) Bled IA for 4 min (fluid) to 750 psi, (26 gal to bleed trailer) LRS pressured IA with 1.7 bbl of diesel to T/I/O = 2247/3318/175 Bled IA for 10 min (fluid) to T/I/O = 1902/794/157 (88 gal to bleed trailer) LRS pressured IA with 2 bbl of diesel to T/I/O = 2246/3330/175 5 min IA = 3262 psi LRS bled IA for 5 min (fluid) to T/I/O = 1924/815/158 (LRS bled 2 bbl) 2D-02 Seal-Tite Repair Summary of Operations 10 min IA = 870 psi LRS pressured IA with 2 bbl of diesel to T/I/O = 2252/3300/175 50 min T/I/O = 2287/3208/175 LRS bled IA for 3 min (fluid) to T/I/O = 1932/793/158 (LRS bled 2 bbl) Final T/I/O = SI 1932/793/158 5/25/2024 ACQUIRE DATA BAILED FILL ON TOP OF CA-2 PLUG @ 7290' RKB. SHEARED PULLING TOOL ATTEMPTING TO PULL EQUALIZING PRONG ON CA-2 PLUG. JOB IN PROGRESS. 5/27/2024 ACQUIRE DATA BAILED FILL ON TOP OF CA-2 PLUG @ 7290' RKB. SHEARED PULLING TOOL ATTEMPTING TO PULL EQUALIZING PRONG. JOB IN PROGRESS. 5/28/2024 ACQUIRE DATA RUN HYDROSTATIC BAILER 2 TIMES TO TOP OF CA-2 PLUG @ 7090' RKB, RECOVERED 1/4 CUP SCALE, MAKE SEVERAL ATTEMPTS TO PULL CA-2 PRONG @ 7090' RKB, KEEP SHEARING, RUN 2.65" BAILER TO TOP OF CA-2, RECOVERED 2 CUPS SCALE, CHANGE PULLING TOOL TO RB, W/ SAME RESULTS, JOB IN PROGRESS. 5/29/2024 ACQUIRE DATA SET 2.72" BAIT SUB W/ GUTTED JD ON CA-2 PRONG @ 7290' RKB, MAKE SEVERAL ATTEMPTS TO PULL W/ GR, THEN GS, PULLED 2.72" BAIT SUB W/ JD (NO PRONG), ATTEMPT TO RE-SET, UNABLE TO LATCH, RUN 2.65" PUMP BAILER TO TOP OF PRONG @ 7290' RKB, SET SAME BAIT SUB W/ JD ON CA-2 PRONG, SHEARED GR LEAVING BAITED JD ON PRONG, JOB IN PROGRESS 5/30/2024 ACQUIRE DATA PULL 2.72" BAIT SUB W/ GUTTED JD, & CA-2 PRONG @ 7290' RKB, RUN PUMP BAILER W/ 2.65" BOTTOM TO PLUG BODY W/ NO RETURNS, PULL CA-2 PLUG BODY @ 7290' RKB, JOB COMPLETE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,410.0 2D-02 5/30/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled 2.75" CA-2 Plug 2D-02 5/30/2024 spilch Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - T x IA COMMUNICATION 9/8/2010 lmosbor 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 35.0 117.0 117.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 34.9 3,280.7 3,076.0 36.00 J-55 BTC PRODUCTION 7 6.28 30.0 7,771.2 6,302.3 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.0 Set Depth 7,302.2 Set Depth 5,899.6 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD 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) 30.0 30.0 0.05 HANGER 8.000 FMC TUBING HANGER 3.500 1,884.1 1,883.8 5.77 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE (LOCKED OUT 8/21/88) BAKER FVL 2.810 1,937.3 1,936.5 7.45 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 3,720.3 3,347.4 53.01 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 5,247.0 4,374.0 45.05 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 6,242.7 5,084.7 43.24 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 6,782.5 5,485.2 39.85 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 7,215.7 5,828.3 35.22 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 7,259.2 5,864.0 34.52 PBR 4.000 BAKER PBR BAKER 3.000 7,272.8 5,875.3 34.29 PACKER 5.968 BAKER FHL HYD SET PACKER BAKER FHL hyd 2.937 7,289.9 5,889.4 34.01 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 7,301.4 5,898.9 33.83 SOS 4.570 BAKER SHEAR OUT SUB, ELMD TTL @ 7288' during Otis TEMP LOG on 03/16/85 BAKER 3.015 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) 4,497.0 3,849.3 46.17 LEAK - CASING CASING LEAK IDENTIFIED BY ACOUSTIC LDL AT 4497' RKB 2/6/2024 6.280 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) 1,937.3 1,936.5 7.45 1 GAS LIFT DMY BK2 1 0.0 11/10/1984 0.000 3,720.3 3,347.4 53.01 2 GAS LIFT DMY BK2 1 0.0 11/10/1984 0.000 5,247.0 4,374.0 45.05 3 GAS LIFT DMY BK2 1 0.0 11/10/1984 0.000 6,242.7 5,084.7 43.24 4 GAS LIFT DMY BK2 1 0.0 11/10/1984 0.000 6,782.5 5,485.2 39.85 5 GAS LIFT DMY BK2 1 0.0 11/10/1984 0.000 7,215.7 5,828.3 35.22 6 GAS LIFT DMY BK 1 0.0 5/18/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,388.0 7,390.0 5,971.3 5,972.9 A-5, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,411.0 7,412.0 5,990.6 5,991.4 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,415.0 7,417.0 5,994.0 5,995.6 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,425.0 7,426.0 6,002.4 6,003.2 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,430.0 7,432.0 6,006.6 6,008.3 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,435.0 7,439.0 6,010.8 6,014.2 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,443.0 7,445.0 6,017.6 6,019.3 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 2D-02, 6/25/2024 12:59:07 PM Vertical schematic (actual) PRODUCTION; 30.0-7,771.2 IPERF; 7,443.0-7,445.0 IPERF; 7,435.0-7,439.0 IPERF; 7,430.0-7,432.0 IPERF; 7,425.0-7,426.0 IPERF; 7,415.0-7,417.0 IPERF; 7,411.0-7,412.0 IPERF; 7,388.0-7,390.0 PACKER; 7,272.8 GAS LIFT; 7,215.7 GAS LIFT; 6,782.5 GAS LIFT; 6,242.7 GAS LIFT; 5,247.0 LEAK - CASING; 4,497.0 GAS LIFT; 3,720.3 SURFACE; 34.9-3,280.7 GAS LIFT; 1,937.3 SAFETY VLV; 1,884.1 CONDUCTOR; 35.0-117.0 KUP INJ KB-Grd (ft) 40.71 RR Date 10/17/198 4 Other Elev 2D-02 ... TD Act Btm (ftKB) 7,780.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292117700 Wellbore Status INJ Max Angle & MD Incl (°) 53.07 MD (ftKB) 3,700.00 WELLNAME WELLBORE2D-02 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT 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: SealTite Repair 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7780'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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4/3/2024 3-1/2" Packer: Baker FHL HYD SET Packer SSSV: Baker FVL SFTY VLV Perforation Depth MD (ft): J-55 7741' 7388-7390', 7411-7412', 7415-7417', 7425-7426', 7430-7432', 7435-7439', 7443-7445' 5971-5973', 5991-5991', 5994-5996', 6002-6003', 6007-6008', 6011-6014', 6018-6019' Perforation Depth TVD (ft): 3281' 7771' 82' 16" 9-5/8" 7" 3246' 7302' MD 3076' 6302' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: 117' 117' PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025653 184-152 P.O. Box 100360, Anchorage, AK 99510 50-029-21177-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7273' MD and 5875' TVD 1884' MD and 1884' TVD Dusty Freeborn Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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: Tubing Size: Dusty.Freeborn@conocophillips.com (907) 659-7224 Staff Well Integrity Specialist KRU 2D-02 6309' 7290' 5889' 7290' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dusty Freeborn DN: OU=Well Integrity, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2024.03.25 13:57:15-08'00' Foxit PDF Editor Version: 13.0.0 Dusty Freeborn By Grace Christianson at 11:53 am, Mar 27, 2024 10-404 SFD 3/27/2024 X X ADL2225658, VTL 4/11/2024 SFD DSR-4/12/24JLC 4/12/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.12 14:28:24 -08'00'04/12/24 RBDMS JSB 041624 Proposed Procedure for ConocoPhillips Diagnostics and Repair of Casing Leak Prepared by Seal-Tite International Field: Kuparuk Well: 2D-02 Date: March 13th, 2024 Objectives 1. Determine leak rate. 2. Cure the leak using Seal-Tite sealants and procedures. Mechanical Considerations The subject water injection is completed with 3-1/2” tubing anchored to a production packer at 7272’.The well failed an MIT-IA in 2023 and the well was secured in November with a tubing plug below the production packer followed by a successful MIT- T which suggested a casing leak. An acoustic leak detection log located a leak at 4497’ MD in Feb 2024. Leak rate was measured at 4.4 GPM @ 1500 psi and decreased to 3.9 GPM @ 2360 psi. The change of leak rate could be a function of changing leak geometry due to pressure differential or maybe that the leaking fluid is pressurizing a pocket behind the production casing. MIT IA required test pressure is 3300 psi (max anticipated injection pressure). The well directional design is a build and drop with leak site angle of 46 degrees and 3850’ TVD. Maximum angle –53 degrees @ 3700’ MD Tubulars Tubing: 3-1/2” 9.3# J-55 EUE 8RD –2.992” ID Production Casing: 7” 26# J-55 Buttress – 6.276” ID Capacities Tubing - 0.0097 bbls/ft x 7259’WLM = 70 bbls Annulus – 0.0264 bbls/ft x 7242’WLM = 191 bbls Intended Diagnostic Procedure 1. Meet with field personnel; review field history and verify condition of well as matching information provided. 2. Perform Job Safety Analysis with all concerned personnel. 3. Record all tubing and casing pressures. Page 1 of 3 Page 2 of 3 4. Locate the test port for subject casing hanger. The test port may access the void between primary and secondary seals for a conventional casing hanger, or between pack-off seals for a pack-off style casing hanger. Rig up pressure relief tool with gauge and bleeder valve to the test port fitting. Sting in to move check valve off seat, record pressure in the void, and compare with adjacent casing pressures. Bleed void pressure to zero. If possible, measure stable fluid flow rate from the test port. Shut in and monitor for pressure build up. 5. Bleed all well pressures to zero. Document return type and volume. 6. Rig up and pressure circulation manifold to tubing and annulus. 7. Pressure test tubing to 3200 psi and document results. 8. Pressure test annulus at three intervals (1000 psi, 2000 psi, and 3300 psi) and measure leak rate at each interval. Record the volume to pressure up and volume to maintain pressure. 9. Report leak rate data to office for evaluation and consent to proceed with the leak repair. Intended Repair Procedure 10. RIH and pull dummy GLV from SPM at 7216’ MD. If necessary, install circulation orifice (no check) to reduce SPM washout. 11. Circulate 9.6 ppg NaCl down tubing taking annulus returns until all diesel has been removed. 12. Load tubing with 30 bbls of diesel to create an underbalance that will be used to suck sealant into IA. 13. Rig up IA suction lines to Seal-Tite sealant drums/tank. 14. Slowly bleed and regulate diesel from the tubing until 10 bbls of sealant has been introduced to the IA. Sealant will be designed to float on the annulus fluid which equates to 380’annulus column. 15. Pump 108 bbls of diesel into the IA taking water returns from the tubing to spot the leading edge of sealant @ 4467’ WLM. 16. Reinstall dummy GLV in SPM at 7216’MD and pressure test tubing to confirm dummy holding. Page 3 of 3 17. Slickline RIH and pull CA-2 plug from nipple @ 7290’ MD. POOH. This will allow COP to bullhead diesel into the tubing for freeze protection. 18. Continue pressurizing annulus with diesel in 500 psi increments and hold for 30 minutes at each step until reaching 3300 psi to squeeze sealant through the leak site and seal the leak. 19. Shut in this test pressure for a minimum of 48 hours to allow the sealant to cure. 20. Record casing pressures regularly during the cure period. 21. Perform 3 pressure cycles from 0 psi to 3300 psi to verify the seal durability. Document fluid volume in and out. Note: Recommendation is to leave the sealant in the annulus across the leak site with 300 psi applied pressure for monitoring purposes. 22. RIH and pull CA-2 plug from nipple at 7290’MD. 23. Put well back on injection and monitor until at normal injection rate. 24. Rig down equipment and turn well over to COP. State witnessed MIT-IA after stabilized injection.VTL 4/11/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,410.0 2D-02 5/30/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Annotate Casing Leak 2D-02 2/6/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL - T x IA COMMUNICATION 9/8/2010 lmosbor 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 35.0 117.0 117.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 34.9 3,280.7 3,076.0 36.00 J-55 BTC PRODUCTION 7 6.28 30.0 7,771.2 6,302.3 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.0 Set Depth … 7,302.2 Set Depth … 5,899.6 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD 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) 30.0 30.0 0.05 HANGER 8.000 FMC TUBING HANGER 3.500 1,884.1 1,883.8 5.77 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE (LOCKED OUT 8/21/88) BAKER FVL 2.810 1,937.3 1,936.5 7.45 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 3,720.3 3,347.4 53.01 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 5,247.0 4,374.0 45.05 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 6,242.7 5,084.7 43.24 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 6,782.5 5,485.2 39.85 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 7,215.7 5,828.3 35.22 GAS LIFT 5.312 MMH/3 1/2" X 1" MMH FMHO 2.867 7,259.2 5,864.0 34.52 PBR 4.000 BAKER PBR BAKER 3.000 7,272.8 5,875.3 34.29 PACKER 5.968 BAKER FHL HYD SET PACKER BAKER FHL hyd 2.937 7,289.9 5,889.4 34.01 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 7,301.4 5,898.9 33.83 SOS 4.570 BAKER SHEAR OUT SUB, ELMD TTL @ 7288' during Otis TEMP LOG on 03/16/85 BAKER 3.015 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) 4,497.0 3,849.3 46.17 LEAK - CASING CASING LEAK IDENTIFIED BY ACOUSTIC LDL AT 4497' RKB 2/6/2024 6.280 7,290.0 5,889.5 34.01 TUBING PLUG Set 2.75" CA-2 Plug in D Nipple 11/24/2023 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) 1,937.3 1,936.5 7.45 1 GAS LIFT DMY BK2 1 0.0 11/10/1984 0.000 3,720.3 3,347.4 53.01 2 GAS LIFT DMY BK2 1 0.0 11/10/1984 0.000 5,247.0 4,374.0 45.05 3 GAS LIFT DMY BK2 1 0.0 11/10/1984 0.000 6,242.7 5,084.7 43.24 4 GAS LIFT DMY BK2 1 0.0 11/10/1984 0.000 6,782.5 5,485.2 39.85 5 GAS LIFT DMY BK2 1 0.0 11/10/1984 0.000 7,215.7 5,828.3 35.22 6 GAS LIFT DMY BK2 1 0.0 10/28/1999 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,388.0 7,390.0 5,971.3 5,972.9 A-5, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,411.0 7,412.0 5,990.6 5,991.4 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,415.0 7,417.0 5,994.0 5,995.6 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,425.0 7,426.0 6,002.4 6,003.2 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,430.0 7,432.0 6,006.6 6,008.3 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,435.0 7,439.0 6,010.8 6,014.2 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,443.0 7,445.0 6,017.6 6,019.3 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 2D-02, 3/20/2024 10:25:45 AM Vertical schematic (actual) PRODUCTION; 30.0-7,771.2 IPERF; 7,443.0-7,445.0 IPERF; 7,435.0-7,439.0 IPERF; 7,430.0-7,432.0 IPERF; 7,425.0-7,426.0 IPERF; 7,415.0-7,417.0 IPERF; 7,411.0-7,412.0 IPERF; 7,388.0-7,390.0 TUBING PLUG; 7,290.0 PACKER; 7,272.8 GAS LIFT; 7,215.7 GAS LIFT; 6,782.5 GAS LIFT; 6,242.7 GAS LIFT; 5,247.0 LEAK - CASING; 4,497.0 GAS LIFT; 3,720.3 SURFACE; 34.9-3,280.7 GAS LIFT; 1,937.3 SAFETY VLV; 1,884.1 CONDUCTOR; 35.0-117.0 KUP INJ KB-Grd (ft) 40.71 RR Date 10/17/198 4 Other Elev… 2D-02 ... TD Act Btm (ftKB) 7,780.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292117700 Wellbore Status INJ Max Angle & MD Incl (°) 53.07 MD (ftKB) 3,700.00 WELLNAME WELLBORE2D-02 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT 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: SealTite Repair 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7780'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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4/3/2024 3-1/2" Packer: Baker FHL HYD SET Packer SSSV: Baker FVL SFTY VLV Perforation Depth MD (ft): J-55 7741' 7388-7390', 7411-7412', 7415-7417', 7425-7426', 7430-7432', 7435-7439', 7443-7445' 5971-5973', 5991-5991', 5994-5996', 6002-6003', 6007-6008', 6011-6014', 6018-6019' Perforation Depth TVD (ft): 3281' 7771' 82' 16" 9-5/8" 7" 3246' 7302' MD 3076' 6302' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: 117' 117' PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025653 184-152 P.O. Box 100360, Anchorage, AK 99510 50-029-21177-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7273' MD and 5875' TVD 1884' MD and 1884' TVD Dusty Freeborn Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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: Tubing Size: Dusty.Freeborn@conocophillips.com (907) 659-7224 Staff Well Integrity Specialist KRU 2D-02 6309' 7290' 5889' 7290' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 7:53 am, Mar 26, 2024 324-179 Digitally signed by Dusty Freeborn DN: OU=Well Integrity, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2024.03.25 13:57:15-08'00' Foxit PDF Editor Version: 13.0.0 Dusty Freeborn SFDADL0025658, Superseded Proposed Procedure for ConocoPhillips Diagnostics and Repair of Casing Leak Prepared by Seal-Tite International Field: Kuparuk Well: 2D-02 Date: March 13th, 2024 Objectives 1. Determine leak rate. 2. Cure the leak using Seal-Tite sealants and procedures. Mechanical Considerations The subject water injection is completed with 3-1/2” tubing anchored to a production packer at 7272’.The well failed an MIT-IA in 2023 and the well was secured in November with a tubing plug below the production packer followed by a successful MIT- T which suggested a casing leak. An acoustic leak detection log located a leak at 4497’ MD in Feb 2024. Leak rate was measured at 4.4 GPM @ 1500 psi and decreased to 3.9 GPM @ 2360 psi. The change of leak rate could be a function of changing leak geometry due to pressure differential or maybe that the leaking fluid is pressurizing a pocket behind the production casing. MIT IA required test pressure is 3300 psi (max anticipated injection pressure). The well directional design is a build and drop with leak site angle of 46 degrees and 3850’ TVD. Maximum angle –53 degrees @ 3700’ MD Tubulars Tubing: 3-1/2” 9.3# J-55 EUE 8RD –2.992” ID Production Casing: 7” 26# J-55 Buttress – 6.276” ID Capacities Tubing - 0.0097 bbls/ft x 7259’WLM = 70 bbls Annulus – 0.0264 bbls/ft x 7242’WLM = 191 bbls Intended Diagnostic Procedure 1. Meet with field personnel; review field history and verify condition of well as matching information provided. 2. Perform Job Safety Analysis with all concerned personnel. 3. Record all tubing and casing pressures. Page 1 of 3 Superseded Page 2 of 3 4. Locate the test port for subject casing hanger. The test port may access the void between primary and secondary seals for a conventional casing hanger, or between pack-off seals for a pack-off style casing hanger. Rig up pressure relief tool with gauge and bleeder valve to the test port fitting. Sting in to move check valve off seat, record pressure in the void, and compare with adjacent casing pressures. Bleed void pressure to zero. If possible, measure stable fluid flow rate from the test port. Shut in and monitor for pressure build up. 5. Bleed all well pressures to zero. Document return type and volume. 6. Rig up and pressure circulation manifold to tubing and annulus. 7. Pressure test tubing to 3200 psi and document results. 8. Pressure test annulus at three intervals (1000 psi, 2000 psi, and 3300 psi) and measure leak rate at each interval. Record the volume to pressure up and volume to maintain pressure. 9. Report leak rate data to office for evaluation and consent to proceed with the leak repair. Intended Repair Procedure 10. RIH and pull dummy GLV from SPM at 7216’ MD. If necessary, install circulation orifice (no check) to reduce SPM washout. 11. Circulate 9.6 ppg NaCl down tubing taking annulus returns until all diesel has been removed. 12. Load tubing with 30 bbls of diesel to create an underbalance that will be used to suck sealant into IA. 13. Rig up IA suction lines to Seal-Tite sealant drums/tank. 14. Slowly bleed and regulate diesel from the tubing until 10 bbls of sealant has been introduced to the IA. Sealant will be designed to float on the annulus fluid which equates to 380’annulus column. 15. Pump 108 bbls of diesel into the IA taking water returns from the tubing to spot the leading edge of sealant @ 4467’ WLM. 16. Reinstall dummy GLV in SPM at 7216’MD and pressure test tubing to confirm dummy holding. Superseded Page 3 of 3 17. Slickline RIH and pull CA-2 plug from nipple @ 7290’ MD. POOH. This will allow COP to bullhead diesel into the tubing for freeze protection. 18. Continue pressurizing annulus with diesel in 500 psi increments and hold for 30 minutes at each step until reaching 3300 psi to squeeze sealant through the leak site and seal the leak. 19. Shut in this test pressure for a minimum of 48 hours to allow the sealant to cure. 20. Record casing pressures regularly during the cure period. 21. Perform 3 pressure cycles from 0 psi to 3300 psi to verify the seal durability. Document fluid volume in and out. Note: Recommendation is to leave the sealant in the annulus across the leak site with 300 psi applied pressure for monitoring purposes. 22. RIH and pull CA-2 plug from nipple at 7290’MD. 23. Put well back on injection and monitor until at normal injection rate. 24. Rig down equipment and turn well over to COP. Superseded C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2024-02-06_22144_KRU_2D-02_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22144 KRU 2D-02 50-029-21177-00 LeakPoint Survey 06-Feb-24 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 PTD: 184-152 T38511 2/16/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.16 13:01:31 -09'00' 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 2D-02 (PTD #184-152) Report of IA pressure fall off Date:Wednesday, November 22, 2023 9:59:45 AM Attachments:image001.png AnnComm Surveillance TIO for 2D-02.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, November 21, 2023 1:57 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: Kuparuk injector 2D-02 (PTD #184-152) Report of IA pressure fall off Chris- Kuparuk injector 2D-02 (PTD #184-152) failed the diagnostics MIT-IA. CPAI intends to shut in and secure the well and conduct additional diagnostics to identify the failure mechanism of the MIT-IA. The proper notifications for continued injection or repair will be submitted at that time. Attached is the current 90 day TIO plot and well bore schematic. Please feel free to contact me with any questions or if you disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, November 9, 2023 1:07 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: Kuparuk injector 2D-02 (PTD #184-152) Report of IA pressure fall off Chris- Kuparuk injector 2D-02 (PTD #184-152) was identified to have an IA pressure fall off during the review of the Monthly Waivered Wells report. CPAI intends to conduct an initial set of diagnostics and depending on the results, leave the IA with an elevated pressure and monitor for 30 days for continued IA pressure decrease. At the end of the 30 day monitor period the proper notifications for continued injection or repair will be submitted as required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 35.0 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.921 Top (ftKB) 34.9 Set Depth (ftKB) 3,280.7 Set Depth (TVD) … 3,076.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 30.0 Set Depth (ftKB) 7,771.2 Set Depth (TVD) … 6,302.3 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 30.0 Set Depth (ft… 7,302.2 Set Depth (TVD) (… 5,899.6 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 30.0 30.0 0.05 HANGER FMC TUBING HANGER 3.500 1,884.1 1,883.8 5.77 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 8/21/88)2.810 7,259.2 5,864.0 34.52 PBR BAKER PBR 3.000 7,272.8 5,875.3 34.29 PACKER BAKER FHL HYD SET PACKER 2.937 7,289.9 5,889.4 34.01 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,301.4 5,898.9 33.83 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 7288' during Otis TEMP LOG on 03/16/85 3.015 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 7,388.0 7,390.0 5,971.3 5,972.9 A-5, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,411.0 7,412.0 5,990.6 5,991.4 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,415.0 7,417.0 5,994.0 5,995.6 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,425.0 7,426.0 6,002.4 6,003.2 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,430.0 7,432.0 6,006.6 6,008.3 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,435.0 7,439.0 6,010.8 6,014.2 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,443.0 7,445.0 6,017.6 6,019.3 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 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 1,937.3 1,936.5 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 11/10/1984 2 3,720.3 3,347.4 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 11/10/1984 3 5,247.0 4,374.0 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 11/10/1984 4 6,242.7 5,084.7 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 11/10/1984 5 6,782.5 5,485.2 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 11/10/1984 6 7,215.7 5,828.3 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 10/28/1999 Notes: General & Safety End Date Annotation 9/8/2010 NOTE: WAIVERED WELL - T x IA COMMUNICATION 9/29/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Comment SSSV: LOCKED OUT2D-02, 5/31/2016 2:39:40 PM Vertical schematic (actual) PRODUCTION; 30.0-7,771.2 IPERF; 7,443.0-7,445.0 IPERF; 7,435.0-7,439.0 IPERF; 7,430.0-7,432.0 IPERF; 7,425.0-7,426.0 IPERF; 7,415.0-7,417.0 IPERF; 7,411.0-7,412.0 IPERF; 7,388.0-7,390.0 SOS; 7,301.4 NIPPLE; 7,289.9 PACKER; 7,272.8 PBR; 7,259.2 GAS LIFT; 7,215.7 GAS LIFT; 6,782.5 GAS LIFT; 6,242.7 GAS LIFT; 5,247.0 GAS LIFT; 3,720.3 SURFACE; 34.9-3,280.7 GAS LIFT; 1,937.3 SAFETY VLV; 1,884.1 CONDUCTOR; 35.0-117.0 HANGER; 30.0 Annotation Last Tag: SLM Depth (ftKB) 7,410.0 End Date 5/30/2016 Annotation Rev Reason: TAG Last Mod By pproven End Date 5/31/2016 KUP INJ KB-Grd (ft) 40.71 Rig Release Date 10/17/1984 Annotation Last WO: End Date 2D-02 H2S (ppm) Date ... TD Act Btm (ftKB) 7,780.0 Well Attributes Wellbore API/UWI 500292117700 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 53.07 MD (ftKB) 3,700.00 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 2D-02 (PTD #184-152) Report of IA pressure fall off Date:Thursday, November 9, 2023 2:49:53 PM Attachments:image001.png TIO and Table.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, November 9, 2023 1:07 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: Kuparuk injector 2D-02 (PTD #184-152) Report of IA pressure fall off Chris- Kuparuk injector 2D-02 (PTD #184-152) was identified to have an IA pressure fall off during the review of the Monthly Waivered Wells report. CPAI intends to conduct an initial set of diagnostics and depending on the results, leave the IA with an elevated pressure and monitor for 30 days for continued IA pressure decrease. At the end of the 30 day monitor period the proper notifications for continued injection or repair will be submitted as required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 2500 rocs, :i 1500 N N L a 1D00 ro BDO 0 V 600 Ul i 0 ❑ 400 a m v 200 Pressure Summary for 2D-02 H a N O N L6 CO H M-b A N U) CO H It N O M 4 M N Le) CO ri It N O N Le) W ri ri ri N N N N M O O O ri ri ri N N N T O O O H ri ri N N N T C] C7 O W W W co W W W W m m m m m m 0 m m m r7 0 r7 r7 0 r7 0 r7 r7 r7 ri ri ri qo I I I I I I I I I I I I I I I I ra rI ra ra rI I I Ia ra ra ra rI ra m m M rO m rO m rO m rn m m m m rO m m M m M m m M m m m rO m m m m N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N Date 132.0 131.5 v 130.5 v 130.0 E F 129.5 129.0 - IA PRESSURE - CA PRESSURE - TUBING PRESSURE (PSI) - TEMPERATURE(DEGF) - DRY GAS(MSCFD) - MI GAS (MSCFD) - PRODUCED WATER(BPD) - SEAWATER(BPD) 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. 2D-02 KUPARUK RIV UNIT 2D-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/29/2023 2D-02 50-029-21177-00-00 184-152-0 W SPT 5875 1841520 3000 2675 2675 2675 2675 223 500 489 485 REQVAR P Guy Cook 8/9/2023 MIT-IA to maximum anticipated injection pressure per AIO 2B.052. 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 2D-02 Inspection Date: Tubing OA Packer Depth 340 3500 3320 3300IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230808102217 BBL Pumped:3.4 BBL Returned:3.3 Friday, September 29, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg <] I st 2 P.I. Supervisor Ke 1 FROM: Matt Herrera Petroleum Inspector Well Name KUPARUK RIV UNIT 2D-02 Insp Num: mitMFH210818070143 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. 2D-02 KUPARUK RIV UNIT 2D-02 Src: Inspector Reviewed By: P.I. Suprv�— Comm API Well Number 50-029-21177-00-00 Inspector Name: Matt Herrera Permit Number: 184-152-0 Inspection Date: 8/14/2021 Packer Depth Well 2D-02 Type In' w ' TVD 5875 Tubing T e Test SPT est si 3000 IA PTD Isalszo BBL Pumped: 2.8 - ,BBL Returned 2.9 �— OA Interval 1, REQVAR P/F P —� Notes: MIT -IA Performed to MAIP Per AIO 213.052 Pretest Initial 15 Min 30 Min 45 Min 60 Min 2630 2650 - 1 2650 ' 2640 - 880 3430 I ,- 3300 3265 ' 255 362 355 — 347 -- -� ---- -- Friday, August 20, 2021 Page I of I MEMORANDUM State of Alaska Well 2D-02 '!Type lnj r 'TVD Alaska Oil and Gas Conservation Commission PTD 1841520 ' ;Type Testi SPT Test psi DATE: Monday, August 26, 2019 TO: Jim Regg q P.I. Supervisor �P,g1 7 p /'i'II� SUBJECT: Mechanical Integrity Tests Interval REQVAR P/F Conocol billips Alaska, Inc. Notes: Tested as per AIO 26.052 to max ant. inj. Pressure 2D-02 FROM: Adam Earl KUPARIJK RIV UNIT 2D-02 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm I Well Name KUPARUK RIV UNIT 2D-02 IInsp Num: mitAGE190826083219 Rel Insp Num: API Well Number 50-029-21177-00-00 Inspector Name: Adam Earl Permit Number: 184-152-0 Inspection Date: 8/24/2019 _ Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2D-02 '!Type lnj r 'TVD 5875 ' Tubing 0 - X30 0 - o PTD 1841520 ' ;Type Testi SPT Test psi 3000 IA 1200 >90 ;3100 - 3290 BBL Pumped: F 23 BBL Returned: 2.2 ' OA 31831 ;ao spa - 8310 - Interval REQVAR P/F P Notes: Tested as per AIO 26.052 to max ant. inj. Pressure Monday, August 26, 2019 Page I of 1 S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim jtegg / DATE: Thursday,August 10,2017 P.I.Supervisor keen Z((( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2D-02 FROM: Chuck Scheve KUPARUK RIV UNIT 2D-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,\SP-- NON-CONFIDENTIAL Y✓NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2D-02 API Well Number 50-029-21177-00-00 Inspector Name: Chuck Scheve Permit Number: 184-152-0 Inspection Date: 8/7/2017 Insp Num: mitCS170808074811 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2D-02 Type Inj W {TVD 5875 Tubing 2600 - 2600 - 2600 - 2600 PTD 1841520 Type Test SPT Test psi 3000 IA 1270 3300 3200 3200 BBL Pumped: 2.3 BBL Returned: 2.2 OA 380 " 480 - 480 480 Interval REQVAR P/F P ✓� Notes: MITIA per AIO 2B.052 SCANNED w'= 2 3 Thursday,August 10,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday,July 10, 2017 4:23 PM To: Wallace, Chris D (DOA) Subject: RE: [EXTERNAL] RE:2D-02 (AIO 2B.052, PTD 184-152) and 2E-10 (PTD 184-230) update 07-02-17 Chris, That sounds like a fantastic idea! We will operate 2E-10 under an internal waiver only which will limit the well to only produced water injection. To make it official, CPAI would like to rescind the Administrative Approval application that Brent submitted on July 2. With this in mind, I plan to also send in AA cancellation requests for the two 2D wells (2D-02 and 2D-04)which are already waivered for TxIA communication, but which appear to demonstrate the same temperature-dependent leak type as 2E-10. They were initially AA'ed without understanding fully the underlying failure mechanism. Going forward, these wells will also be operated under an internal waiver to limit them to produced water only injection. Let me know if you see a problem with this. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 SCANNED AUG 1 0 £USI Mobile Phone(907)943-0170 From:Wallace, Chris D(DOA) [mailto:chris.wallace@alaska.gov] Sent: Monday,July 10,2017 3:34 PM To: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com> Subject: RE: [EXTERNAL] RE: 2D-02 (AIO 2B.052, PTD 184-152)and 2E-10 (PTD 184-230) update 07-02-17 Brent, Kelly, Looking this over I am struck with the thought that AOGCC shouldn't get that restrictive for a water well with temperature sensitivity. I mean,we do not have a way of recording a pressure test with seawater vs. differentiate from a produced water test. What about CPAI doing an internal requirement to restrict to produced water and then you could continue (without additional AOGCC restriction and without the 2 yr MIT)? If the packer leaks on produced water you would see the pressures and CPAI would need to act at that point. Maybe that is the better approach here. Regards, Chris From: - - -_ ' ' ' . - uailto:n1617 - conoco.hilli.s.com] Sent:Thursday,July 6,2017 7:30 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: 2D-02 (AIO 2B.052, PTD 184-152) and 2E-10(P i , : -230) update 07-02-17 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday,July 2, 2017 6:28 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: RE: 2D-02 (AIO 2B.052, PTD 184-152) and 2E-10 (PTD 184-230) update 07-02-17 Attachments: 2E-10 AA Application 07-02-17.pdf;2D-02 1 month TIO plot.JPG Chris, The 30 day injection test on produced water for 2D-02 and 2E-10 has ended. 2D-02 did not display any signs of TxIA communication while on produced water. There were a couple of IA pressure rises but one can be attributed to a thermal response and the other was due to an increase in rate and wellhead pressure. This well will remain online and continue to follow the provisions under AIO 26.052 at this time. Attached for reference is a 1 month TIO plot to cover the test period. 2E-10 did not display signs of TxIA communication while on produced water injection as well. The plan is to apply for an AA for produced water injection only allowed. I have attached a copy of the AA application for reference and the paper copy is in the mail. The well will remain on injection while the AA is being processed. Please let me know if you disagree with these plans. Brent Rogers I Kelly Lyons NSK Well Integrity Supervisor CPF 1 &2 ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Cell Phone(907)394-0402 ilpt:WELLS TEAM 2,017 conourPhimps SC.P0k n nil tt Fro • NSK Well Integrity Supv CPF1 and 2 Sent:Sa .rday, March 18, 2017 9:26 PM To: 'chris.wa a@alaska.gov'<chris.wallace@alaska.gov> Cc:Senden, R.Tyle °.Tyler.Senden@conocophillips.com> Subject:2D-02 (AIO 2B.0 •TD 184-152),2D-04(AIO 2B.037, PTD 184-151)and 2E-10(PTD 184-230) update 3-18-17 Chris, � 2D-02 (AIO 26.052, PTD 184-152), 2D-04(AI1� 13.037, PTD 184-151)and 2E-10(PTD 184-230)were all identified with TxIA communication earlier this winter after their s were swapped to colder seawater injection for the first time in years. (Please see the attached latest email communicate regarding each well.) We believe that the wells only display communication when on cold fluid injection due to shrinkage oe>„metal, causing the tubing to pull out of the PBR. Two of the wells (2D-04 and 2E-10) had this theory corroborated w1ext LDL's were run while on seawater and discovered that the PBR's were in fact the leak sources. 2D-04's acoustic LDL wasrun on 02/07/17 and 2E-10's acoustic LDL was run on 02/15/17. 2D and 2E pads will be swapped back to the warmer produced water injection (PWI) later this spring,currently anticipated to occur mid-April. To confirm that the leaks are indeed only present when on cold water,when the pads resume PWI,CPAI intends to return the 3 wells to produced water injection and be put on a 30 day diagnostic 1 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, January 22, 2017 9:03 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of high IA pressure 2D-02 (AIO 26.052, PTD 184-152) 1-22-17 Attachments: 2D-02 schematic.pdf; 2D-02 90 day TIO 1-22-17.PNG Chris, KRU injector 2D-02 (AIO 2B-052, PTD 184-152) is currently waivered for TxIA communication. Per AIO 26.052, which was initially issued in 2010, the IA is allowed to equalize with the injection pressure up to 3000psi. It has been ConocoPhillips' internal policy for several years now to not allow wells to operate with TxIA communication when on water injection. This well was allowed to remain online because it had not experienced communication in years. However yesterday the IA spiked up to 3000psi and multiple attempts to bleed off the pressure were unsuccessful. The well was shut in and freeze protected. We will commence with initial DHD diagnostics today (MITIA/packoff testing/drawdown testing) and then move into securing the well with a tbg plug with follow-up diagnostics as needed. Based on the results, a path forward will be established. Prior to returning the well to injection, appropriate paperwork will be filed. Please let me know if you disagree. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 SCANNED `.. 1 U •cc s W zao v$ W W U = U U) 0) u1 r- O Ls w w re It. a o `� uj ai al w m . CO w CC 0. Ca Q ry (a I- 0 t- t W C? CJ _ (V rV F (,l ','-1 ra —I ,V 1,1 J C) C) J I, (r, `War r4 CA 0) C.1 C.1 jBap ) dBap a (1 C1 lJ (J (J (J r. e- e- e- CO (G 1 1 CJ t I $ 1111 _- L ID o tL , (' W W 7 h- r' (_ W R 03 r c 00C RI SD (D la gil U O 7 CO 41 C.O. C ' n; o r ❑ ❑ y R c CD CD E r, ❑ E ' o ✓ o • o `- z z lbR LO Q z z so m LC) 1l O i i O O N f z N a ....2 C i i i Jr., ko111i11 8 E V lJ LJ lJ (J [J (J (1 rld n h M11 V `- i (J n (J O . (1 0. .r. + n a Cles fts ui (7 Ifl [qQ� Vl (J ll, .Z ❑ O V rl ,r (J (V e- . ^ UTE'a1 DA t N mtuTID isd 5. c%) pw ,124-N5 2 • • 1 WELL LOG TRANSMITTAL#903018290 To: Alaska Oil and Gas Conservation Comm. January 29, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED / 1/201 Anchorage, Alaska 99501 ZK`BENDER RECEWED FEB 02 2013 RE: Multi Finger Caliper: 2D-02 AOGCC Run Date: 12/29/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2D-02 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21177-00 Multi Finger Caliper(Field Log) NNfD I z_ 2 Sd , is 1 color log 50-029-21177-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: v Aeb'' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg }Neil� DATE: Wednesday,April 01,2015 P.I.Supervisor 4 �i31i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-02 FROM: John Crisp KUPARUK RIV UNIT 2D-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvj'4— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2D-02 API Well Number 50-029-21177-00-00 Inspector Name: John Crisp Permit Number: 184-152-0 Inspection Date: 3/22/2015 Insp Num: mitJCr150325124752 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wel 2D-02 • !Type Inj W TVD 5875 1 Tubing 2500 2500 2500 - 2500 PTD 1841520 • 1'rype Test SPT i''est psi{ 1500 IA 550 3300 3140 - 3100 - Interval REQvAR f P i OA 255 i 502 • 476 ' 470 — Notes: Per AIO 2B.052 3 bbls pumped for test Wednesday,April 01,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,April 12,2013 TO: Jim Regg P.I.Supervisor � �( Z�`13 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-02 FROM: Jeff Turkington KUPARUK RIV UNIT 2D-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry g------ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2D-02 API Well Number 50-029-21177-00-00 Inspector Name: Jeff Turkington Permit Number: 184-152-0 Inspection Date: 3/23/2013 Insp Num: mitJAT130324073836 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2D-02 Type Inj W TVD 5876 IA 3315 3260 - 3240 1841520 i SPT 3000 260 ■ YP P i Interval P / zbso � 2700 I- 2600 2600 T e Test, Test s. OA 260 �REQvAR lP/F Tubing - 3.2 BBIs fluid to fill.MITIA-waived witness of MITOA although CPAI tested per Amended Ad min g p min Approval Area Injection Order 2B.052. SCANNED MAR 1 3 ZD14 Friday,April 12,2013 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I DATE: Wednesday, March 23, 2011 TO: Jim Regg P.I. Supervisor I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D -02 FROM: Chuck Scheve KUPARUK RIV UNIT 2D -02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 4 NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2D - 02 , API Well Number: 50 029 - 21177 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110322163619 Permit Number: 184 - 152 - Inspection Date: 3/22/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well , 2 D -02 Type Inj. W TVD 5875 IA 1300 3000 - 2935 2920 P.T.D 1841520 _ TypeTest SPT Test psi 1500 ' OA 380 380 380 380 Interval REQVAR per, P - Tubing 2450 2450 2450 2450 Notes: qs-o MAR 'fit "�'k Wednesday, March 23, 2011 Page 1 of 1 • • SEAN PARNELL, GOVERNOR ALASKA ®IL AID (icA-S 333 W. 7th AVENUE, SUITE 100 COI~TSEIiQA`I`IO1~T COMIIIISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 2B.052 Mr. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 ~~ `' ''~~~' `~~`-`'' '~' ;'~i'~(; RE: KRU 2D-02 (PTD 1841520) Request for Administrative Approval Kuparuk River Oil Pool Dear Mr. Rogers: In accordance with Rule 9 of Area Injection Order (AIO) 028.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) APPROVES ConocoPhillips Alaska h1c. (CPAI)'s request for an administrative approval to continue water injection in the subject well. CPAI notified the Commission of two occasions that Kuparuk River Unit (KRU) 2D-02 exhibited intermittent tubing x inner annulus (TxIA) communication. Diagnostic testing on several occasions has not been able to confirm the location of the leak. CPAI requests that the tubing and IA pressures be allowed to equalize at up to 3000 psi. Since 3000 psi is approximately 60% of the published internal yield of the 7" casing, CPAI proposes to install automatic shut-in equipment tied to the well's outer annulus pressure that will activate at 1000 psi. A similar installation has been approved previously in KRU. The reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 2D-02 exhibits at least two competent barriers to the release of well pressure. Installation of automatic shut in equipment on the well's outer annulus set to activate at 1000 psi will provide an additional Level of protection due to the anticipated high annulus pressure. The Commission finds that the well's condition does not compromise overall well integrity so as to threaten human safety or the enviromnent. AOGCC's administrative approval to continue water injection only in KRU 2D-02 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; AIO 2B.052 August 16, 2010 Page 2 of 2 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall limit the iruler annulus pressure to 3,000 psi and outer annulus pressure to 1,000 psi; 4. CPAI shall install, maintain and operate automatic well shut-in equipment linked to the well's outer annulus pressure. The actuation pressure shall not exceed 1,000 psi. Testing of the shut-in equipment shall be performed in conjunction. with production well pilots and. safety valves; 5. CPAI shall perform a mechanical integrity test .(MIT) of the inner annulus every 2 years. to the maximum anticipated injection pressure. The initial M1T should be performed after thermal stabilization when the well is returned to operation; 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 7. After well shut in due to a change in the well's mechaiucal condition, AOGCC shall be required to restart injection. ~,-~ ~ DONE at Anchorage, Alaska and dated August 16, 2010. ~ ;~ , . ~~'i Cathy . Foerster Jo . N rman 'ro;~,..~_« Commissioner m inner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within IO days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision aid the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[tJhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • ConocoPhillips ~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August S, 2010 • Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: ~U G ~ ' 2010 ~I~s~~ ~ C~ Cep Gt~ission ~,~ch~r~ge ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing we112D-02 (PTD 184-152) to be online in water only injection service with known T x IA communication. If you need additional information, please contact myself or Martin Walters at 659-7224, or MJ Loveland / Perry Klein at 659-7043. Sincerely, i Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Attachments ~ ~ ~~.~ ConocoPhillips Alaska, Inc. ~~ U h i~ q 2 010 Kuparuk Well 2D-02 (PTD 184-152) t~~as~~ ~' ~ ~~° C'° Ce€~nission ~~.harag~ Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue injection with known annular communication for Kuparuk injection we112D-02. Well History and Status Kuparuk River Unit well 2D-02 (PTD 184-152) was drilled and completed in 1984 as a development well and converted to a service well in November 1985. 2D-02 was originally reported to the Commission on May 16, 2006 as showing signs of T x IA communication. The well was shut in on 06/01/06 due to a lack of water injection capability at 2D Pad. After water injection pipeline repair, permission was obtained from AOGCC on 04/30/08 to return the well to injection to conduct diagnostic tests. Injection was initiated on OS/17/08 and the well has shown intermittent minor TxIA communication since this time. The following diagnostics were subsequently completed: Date Test Result Comment , 06/06 2D pad water injection line SI for repairs S/27/08 MITIA/MITOA Passed Following returned to injection on OS/17/08 S/27/08 IA DD test Failed Reported to AOGCC on OS/30/08 and well SI on 06/03/08. 06/16/08 Ultrasonic LDL Unable to locate leak. IA bleeds to 0 psi. 07/OS/08 State witnessed MITIA Passed 08/21/08 AOGCC granted permission to BOI. 02/08/09 Reported to AOGCC with suspected communication 02/19/09 Diagnostic MITIA Passed 08/21/09 State witnessed MITIA Passed 10/08/09 MITOA Passed Due to the intermittent nature of the communication, the location of the leak has not been identified. ConocoPhillips requests Administrative Approval which will allow the IA to equalize with the tubing in water only injection at a pressure not to exceed 3000 psi. If the condition of Well Integrity Supervisor 8/5/2010 • • the well deteriorates and the leak point can be identified, repair options will be evaluated at that time. Barrier and Hazard Evaluation Tubing: The 3 1/2" 9.3# J-55 tubing has integrity to the packer @ 7273' MD, based on the most recent passing MITIA to 2020 psi. Production casing: The production casing has integrity to the packer @ 7273' MD (5875' TVD) based on the passing MITIA. The 7", 26 ppf, J-55 production casing has an internal yield pressure rating of 4980 psi. 3ooc~ p5~~ =~ CPO~o o~b~~ac- Surface casing: The surface casing has integrity based upon a passing MITOA to 1800 psi. The well is completed with 9-5/8", 36 ppf, J-55 surface casing with an internal yield pressure rating of 3520 psi set at 3281' MD (3076' TVD) Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing or packer fail. Tertiary barrier: The surface casing in the tertiary barrier should the production casing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing above the surface casing shoe it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including ashut-in of the well. T/IO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. SYS: ConocoPhillips has proactively installed automatic well shut-in equipment on the well's outer annulus. The actuation pressure shall not exceed 1,000 psi. Testing of the shut-in equipment shall be performed in conjunction with production well pilots and safety valves. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed), IA pressure may equalize with injection pressure not to exceed 3000 psi; 2. Perform a passing MITIA every 2-years as per AOGCC criteria (0.25 x TVD @ packer, 1500 psi minimum); 3. Perform a passing MITOA to 1800 psi every 2 years; 4. IA pressure not to exceed 3000 psi & OA pressure not to exceed 1000 psi. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes; 6. Shut-in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. Well Integrity Supervisor 8/5/2010 2 ~ ~ KUP ~ 2D-02 l~ F S ax Angle 8 MD _ elt Attributos TD i p Wr e~n.Vr t r ' W _ aIICOra APIIUWI flald Nama Wsll Slatua Incl (°I MD (flNB) Aci Blm (ttKB) R1d5k:d~inC j 50 029 211 7 7 00 KUPARUK RIVER UNIT INJECTING 53.07 j _ 3,70U.D0 7,780.0 - C ommenl M2S Ippm) D ala Annob[lon End Data KB-Grtl Ifl) Rlg Rsleasa Data "' S SSV. LOCKED OUT U 111/2009 Last WO. 40.71 10/1711984 Well Con -2D-0Y 9!1]/l ScMmetic -Ac UU9 1'.l Uatl tual AM A .__ - nnotation Devih (flNB) End Dab A nnobllon Laal Mod By End Dale L ast Tag: SLM 7,437.0 3/722009 R ev Reason: adtl TTL comments ehelton 517912009 -~ __- C asing Strin s siting oD s61ng to sei D.pin s.l o.pm tTVO) siring wi siring Caaing Deacrlptlon Iln) Itn) Top IttNB) IRNB) IRKS) Il6am) Grada String Top TM4 C ONDUCTOR 16 15.062 40.7 117.0 117.0 62.50 H-40 R S URFACE 9518 8.765 D.0 3,281.0 3,076.3 36.00 J-55 . CONDUCTO n P RODUCTION 7 6.151 0.0 7.771.0 6.302.1 26.00 J-55 T ubin Strtn s String OD Slring ID Set Daplh Sat Dapth ITVD) String Wi Slring SAFETY VLV, Tuhing DescrlpilOn IIN Iln) Top (RKB) IRKS) /RKB) (IGnltt) Grade Siring Top Thrd t,a8< T UBING 3 112 2.992 0.0 7.302.0 5,899.4 9.30 J-55 EUE BRD Other In Hote (Ail Jalw elry: Tubi Run 8 Retrievable, Fish, etc.)__ _ - GAS LIFT. T op D.pih ITVD) Top Incl ~ ~ I 1 93] T op (RKB) (RKB) (') Dascrlpllon Comment Data ID Iln) 7,884 1,883.6 5.76 SAFETY VLV Baker'FVL (Lock Out 8121/88) 1111 0/1984 2810 suRTACE. - 1,937 1,936.1 7.05 GAS UF7 MMH/31/2 X 1/1/DMYIBK2/ll CommenC 11110/1984 2.867 3,L61 3,720 3.347.2 53 Ot GAS LIFT MMHl3 112 X 1IIIDMY/8K21/I Comment: 11/10/7984 2.867 GAS LIFT 5,247 4,374.0 44.98 GAS LIFT MMHI3 12 X 1I11DMYIBK2l/I Comment. 11110/1984 2.867 , __ ano 6,243 5,084.8 43.05 GAS LIFT MMHl3 112 X 117/DMY/BK2ll/ Commenl. 11/1011984 2.867 6,783 5 485.5 39.84 GAS LIFT MMHl3 1/2 X 1/11DMY/8K2//I Comment. 11110/1984 2.867 7,216 5,828) 34.75 GAS LIFT MMHl3 112 X 111/OMY/BK2/// Commenl: WATER INJ PKG 10/28/1999 2.867 _AS LIFT i --- 7,259 5863.9 3429 PBR Baker 1111011984 3.000 s za 7,273 5.875.4 34.14 PACKER 8aker'F HL'hyd sal 11/1011984 2.8917 7,290 5,889.5 33.96 NIPPLE Camco'D' Nipple NO GO ___ 11110/1984 2.750 GAS LIFT 7,301 5,898.6 33.84 SOS Baker 11/10/1984 2.882 s,za~ 7,302 5.899.4 33 83 TTL ELMD TTL @ 7288'during Otls TEMP LOG on D3/18/85 11/1011984 2.992 Perforations & Siots - - snot GAS LIFT, Top ITVD) BIm ITVD) Dam _ Fi.]63 Top IRN B) Btm (flNB) IRKS) IRKS) Iona Data (°h Type Comment 7.388 7,390 5.971.3 5,972.9 A -5, 2D-02 12115/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7,411 7,412 5,991 6 5,992 4 A -0, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing Irom vertical, 2 SIB' cns uFT e Slimkone lzi 7,415 7 417 5.994.9 5,996.5 A -4, 2D-02 12/15/1984 1.D IPERF 45 tleg. Phasing from vertical. 2 5/8" Slimkone 7,425 7 426 6,003.1 6,004.0 A -4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/B" Slimkone PBR. 1159 -~- - 7,43U 7,432 6,007.3 6,008.9 A-0. 2D-D2 12/15/7984 1.0 IPERF 45 deg. Phasing Irom vertical, 2 5!8' Slimkone 7,435 7,439 6,011 4 6,014 7 A-4, 2D-02 12/1511984 1.0 IPERF 45 deg. Phasing from vertical, 2 5/8" PACKER 11]3 Slimkone 7,443 7 445 6,018.0 6,019.7 A-4, 2D-02 12/15/1984 1.0 IPERF 45 deg. Phasing from vertical, 2 518" Slimkone NIPPLE ]z9o sos, ].301 TTL ],302 • IPERF. 1.38a~1 39U IPERF, 1 a11~).~lz IPERF, 7 X15/ a17 IPERF 1 az5.] IIti IPERF _ ].oaoa a3z IPERF 1,435-],139 IPERF Ia3-] Ie5 PRODUCTION. 1 ]]t TD. / ]BU # ~ TRti A1AtL ~anyme~ intt SOD_ 3000. ?00. 3000. 3D00. 3000. k~f ~~~$ 3000. sc 3000 z7oo 2400 2100 leoo lsoo lzoo 900 0. 0. 600 (i Q, 300 0_ 0. 0 n. ~' PLOT START TIME 07-MAY-10 10:46 ,ANNULUS PRESSURE TRENDS MINOR TIME MAJOR TIME WEER SC TAG NAME WL2D-02-CHOKE SCRATCH 97 SCRATCH_97 SCRATCH_97 SCRATCH_97 DESCRIPTION FLOW TUBING CHOKE FLOW TUHINO PRESSURE FLOW TUOINO TEMP INNER ANNULUS PRES OUTER ANNULUS PRES PICK TIME:~$-~-.~0 ~Z :'~~:~~ P VAiUE LATES7 77"J 777"1 7777777 7777777 ?7??7?7 ????7?? 7????7? 7777777 7777777 PLOT DURATION PLOT _END TIME +82160:00:80 NRSO~-AS14-10 18:46 DRILLSITE WELL PREV WELL 2p 02 NEXr WELL ENTRY TYPE OPERATOR ~ OPERATOR VERIFIED ~' srsrEM Auro ENTRY ~ BOTIj WELL NAM F WLERU2D-02 ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 1St, 2010 Mr. Guy Schwartz Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Guy Schwartz: t~-~sa- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 pumped November 10th, 20th and 24th, 2009. The corrosion inhibitor/sealant was pumped December 29th and 30th, 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 Peny Klein at 907-659-7043, if you have any questions. .J ~„ e~ ~ ~~~ ~~ ~Ai~ ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 01/01/10 - a„~ ~e ~r_ ~n tt zit 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 bbls ft al 2A-26 50103205750000 2080940 12" n/a 12" n/a 4.25 12/30/2009 2A-27 50103206040000 2091070 36" n/a 36" n/a 12.75 12/30/2009 2C-14 50029212260000 1842100 18' 2.5 50" 11/20/2009 12.32 12/30/2009 2C-15 50029212190000 1842030 SF n/a 26" n/a 4.67 12/30/2009 2C-16 50029212180000 1842020 SF n/a 33" n/a 7.22 12/30/2009 2D-02 50029211770000 1841520 SF n/a 24" n/a 4.45 12/30/2009 2D-03 50029211780000 1841530 SF n/a 24" nia 4.67 12/30/2009 2D-04 50029211760000 1841510 SF n/a 24" n/a 4.45 12/30/2009 2A-05 50029211570000 1841260 SF n/a 24" n/a 4.45 12/30/2009 2D-08 50029211580000 1841270 SF n/a 28" n/a 4.67 12/30/2009 2D-13 50029210700000 1840120 21' 3.0 27" 11/10/2009' 5.1 12/30/2009 2D-14 50029211830000 1841590 SF n/a 24" n/a 6.37 12/30/2009 2D-16 50029211850000 1841610 28' 4.0 26" 11/10/2009 5.1 12/30/2009 3K-27 50029227510000 1970460 7' 1.0 12" 11/24/2009 2.97 12/29/2009 ~ MEMORANDUM To: Jim Regg 8C2S ~'j P.I. Supervisor ~~ ' FROM: lohn Crisp Petroleum Inspector i State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 24, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-02 KUPARiJK RIV iJNIT 2D-02 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~-- Comm Well Name: KUPARUK RIV L7NIT 2D-02 API We~l Number: 50-029-27 ] 77-00-00 Insp Num: mitJCro9o823160725 Permit Number: 184-152-0 - Rel Insp Num: Inspector Name: John Crisp Inspection Date: g/21/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zD-o2 Type Inj. N TVD ss~s ' IA s2o 202o i9ao 1940 P.T.D lsa~szo TypeTest SPT Test psi zooo ~ pA sao 600 60o boo Interval a~TST p~ r ~ Tubing iozs ~ozs io2s ~ozs NOtes: 2•4 bbls pumped for test. No problems witnessed. ~6~. r~'d ~~~ ~+~s~,,,.e , ~ ~~s a:= k. '~~ ~~_ ~' ~":. ~- . ` ~ ~ ~ ^ ` Monday, August 24, 2009 Page 1 of 1 2D-02 (PTD# 184-152) Report Of TxIA Communication • Regg, James B (DOA) From: Sent: To: Cc: NSK Problem Well Supv [n1617@conocophillips.com] Sunday, February 08, 2009 3:05 PM Regg, James B (DOA); Maunder, Thomas E (DOA) f~J Page 1 of 1 NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Santana, Luis Alfredo Subject: 2D-02 (PTD# 184-152) Report Of TxIA Communication Attachments: 2D-02 TIO Plot.ppt; 2D-02 Weltbore Schematic.pdf Jim/Tom, Kuparuk WAG injector 2D-02 (PTD# 184-152) is suspected of having TxIA communication based upon recent frequent bleeds and pressure performance. The well has been shut in with a current T/IA/OA of 2765/2500/350 and will be added to the Monthly Failed MIT report. ConocoPhillips received AOGCC permission to return the well to water only injection on 8/21/08 with the condition that "administrative approval will be required if reinstated injection in KRU 2D-02 indicates pressure communication or leakage". Therefore, CPAI intends to inject in the well only if necessary to conduct diagnostics and will submit a 10-403 to repair or seek administrative approval to continue water only injection. Attached is a 90 day TIO plot and a wellbore schematic. «2D-02 TIO Plot.ppt» «2D-02 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~` j~~t r ~`9 ',~'~ i y. L.i~ii.w..- 2/12/2009 • • dau~l~~~l~U~ ~ N ~ o r r ~ a ....~ .<_._ I .~_- __ _. __ r_ ~ _ I ,. . ~ ~ 1 t ~ _.: _..___ ., S2 ~ ~ L ' J' T /~ ~4i- ~ ~ y V • i' k ~(~ ~: .. E --~_ _ - ~ ~ 1 ,~~ 'A•~• r ~ ~~ f :~~ fi ~ ~ ,{ ~ Y..i 1' `~. °`~. r` II I L I ~ ~ I 1 I I I I I 1 T i .jl ~ w I L Q 'lam T ~~~ ARCO Alaska, Inc.A LJ GKA 2D-02 Zo-oz SSSV API: 500292117700 Well T pe: INJ Angle @ TS: 34 deg @ 7303 (1884-1885 SSSV Type: Orig Completion: 10/17/84 Angle TD: 29 deg @ 7780 O 3 00 Annular Fluid: Last W/O: Rev Reason: TAG/GLM BY VG D: .5 ) Reference Log: Ref Log Date: Last Update: 10/31/99 Last Tag: 7604 TD: 7780 ftK6 Last Ta Date: 10/27/99 Max Hole Angle: 53 deg @ 3700 Casin Strin -CONDUCTOR Size To Bottom TVD Wt Grade Thread 16.000 0 117 117 62.50 H-40 Casin Strin -SURFACE Size To Bottom TVD Wt Grade Thread 9.625 0 3281 3076 36.00 J-55 Casin Strin -PRODUCTION Size To Bottom TVD Wt Grade Thread 7.000 0 7771 6302 26.00 J-55 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 7302 5899 9.30 J-55 EUE SRD Perforations Summar Interval TVD Zone tatus Feet SP Date T e Comment 7388 - 7390 5971 - 5973 A-5 2 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7411 - 7412 5991 - 5991 A-4 1 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" ` ' Slimkone ~: 7415 - 7417 5994 - 5996 A-4 2 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" ~ " Slimkone 7425 - 7426 6003 - 6003 A-4 1 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7430 - 7432 6007 - 6008 A-4 2 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5!8" Slimkone 7435 - 7439 6011 - 6014 A-4 4 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7443 - 7445 6018 - 6019 A-4 2 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone Gas Lift MandrelsNalves -_ Stn MD TVD Man Man V Mfr V Type V OD atch Port TRO Date Vlv ~ Mfr T e Run ommen 1 1937 1936 Mc Murry 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 Hughes 2 3720 3347 Mc Murry 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 Hughes PBR 3 5247 4374 Mc Murry 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 (7259-7260, Hughes OD:3.500) 4 6243 5085 Mc Murry 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 Hughes 5 6783 5486 Mc Murry 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 Hughes PKR 6 7216 5829 Mc Murry 3 1/2 X 1 DMY 1.0 BK2 0.000 0 10/28/99 (1) (7273-7274, ` ~ Hughes OD:6.151) 7. Water In" Pk Other lu s, a ui ., etc. -JEiN~RY De th TVD T e Descri lion ID NO GO 1884 1884 SSSV Baker'FVL (Lock Out 8/21/88) 2.810 7259 5864 PBR Baker 3.000 Q290-7291, 7273 5876 PKR Baker'FHL' hyd set 2.890 OD:3.500) 7290 5890 NO GO Camco'D'Nipple 2.750 7301 5899 SOS Baker 2.992 TUBING 7302 5899 TTL 2.992 (a73o2, - OD:3.500, ID:2.992) Perf (738&7390) Perf Q411-7412) Ped (7425-7426) Page 1 of 1 • • Regg, James B (DOA) ~ ~ ~Q~ -~ ~ ~~~- From: Regg, James B (DOA) Sent: Thursday, August 21, 2008 4:48 PM ~C!~C ~ ~r~~~ To: 'NSK Problem Well Supv' ~' Cc: Maunder, Thomas E (DOA) Subject: KRU 2D-02 Your request dated 7/14/2008 indicated CPAI would like to put the well back on injection. KRU 2D-02 has suspect TxIA but no leak was detected from diagnostic work, including a leak detect log and various pressure tests. It is acceptable to put on water injection while continuing to monitor and report pressures. Administrative approval will be required if reinstated injection in KRU 2D-02 indicates pressure communication or leakage. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~AN~1€~ S ~ ~ ~ ~ 200$ 8/21 /2008 nn 3000. ~' t) t7 . 3000. 3000. 3000. 3000. 3000. Q. 0. 0. n. o. o. o. o. ANNULUS PRESSURE SC 3000 2700 2400 2100 1800 1500 1200 900 600 (~~~ ~~a-~s~- WELL NAME 300 0 PLOT START TIME MINOR TIME PLOT DURATION 1'1.0'1' ETdD ~t it~f•_ 25-MAR-08 06:55 MAJOR TIME WEEK +02160:00:00 utr;23-JUN-O 8 01 PICK TINE 15-J 1JN-08 03:15:16 ~;~; TAG NAME DESCRIPTION t'-VALUE LATEST ~ WL2D-02-CHOKE FLOW TUBING CHOKE ??????? SCRATCH 57 FLOW TUBING PRESSURE ??77777 57 SCRATCH FLOW TUBING TEMP ??????? ~ _ ??77?77 ~ ??????? 7777??7 SCRATCH_57 INNER ANNULUS PRES 777777? SCRATCH_57 OUTER ANNULUS PRES ??????? DRILLSITE WELL PREV WELL 2D O ~ NEXT WELL ENTRY TYPE OPERATOR OPERATOR VERIFIED IY:;1'i•:M Ail"Cil t?N'1'RY BOTH ~+ ~® ~~~ • Toy Jim Regg ~ P.I. Supervisor~C? qi_~~ ~ J~ FROM: Bob Noble Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 08, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-02 KUPARUK RIV UNIT 2D-02 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name• KUPARUK RIV UNIT 2D-02 Insp Num: mitRCN080707074859 Rel Insp Num: API Well Number: 50-029-21 t 77-00-00 Permit Number: I84-I52-o Inspector Name• Bob Noble Inspection Date: 7/si20os Packer- Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! zD-oz TYPe Inj. N TVD I ss76 IA ! as ~ 22so ~~ 2200 ! ztao I P.T. ; tsalszo jTypeTest SPT Test psi '' 22so ~ OA 6ao ~ 7ao I Tao ~ 73o Interval aYRTST p~F P .~ Tubing j aso sso 850 ~ sso Notes: ~i l~ ~ ~-es~- ps~ssz<ti~~ l ~~~~ ~~dN~~ BUG Q ~ ~aDB Tuesday, July 08, 2008 Page I of I 2D-02 WAG injector, PTD # 184-152 notice of injection results Page 1 of 1 • • Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Monday, June 23, 2008 7:25 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) L Cc: NSK Problem Well Supv; CPF2 Prod Engrs Subject: 2D-02 WAG injector, PTD # 184-152 notice of injection results Attachments: 2D-02 90 day TIO.jpg; 2D-02.pdf Tom & Jim, On 4/30/08 AOGCC approved 30 days of injection into 2D-02 for testing and monitoring purposes, the well was placed on injection 5/20/08. 2D-02 was identified and reported in 2006 as having suspect T X IA while in MI service. Due to issues with the water injection header on 2D pad it has taken until May 2008 to restore water injection to the pad. 2D-02 recent pressure trend charts indicate rapid tubing by inner annulus communication. The well has passed all MITIA testing but fails an IA draw down test. We suspect the packer or PBR. A sonic leak detect log was performed on 6/16/08, logging from the injection packer to surface. No leak was identified. The log was performed with the IA bled to zero. The well now passes an IA draw down test. The well was shut in 6/3/08. 6/17/08 Monitor WHP's T/I/0=900/0/400 ~~1f~~G~' A~~ ~ ~~ ~~~~ 6/19/08 Monitor WHP's T/I/0= 890/0/450 The well will remain shut in and we will propose a plan forward at a later time. I have enclosed a 90 Day TIO plot and well bore schematic for your convenience. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 «2D-02 90 day TIO.jpg» «2D-02.pdf» 7/30/2008 • • N .-~ O ~ i ~ Q ~ .-~ Q ~ a 0 ~o ~o .^ o F c i ~M `.. N x ~ N Z o ~ ,~ o o i N ,'~ •d O C' G o0 w ^ N J O C t Z a a w 3 7 ~ , AG A.I 3 2 F F ~ as ° ~ z° ~' ~• W ~ ~~ E" o am ,¢ a F ~ ~ o O O O o O O O O O O O (y N O O O O O O O O O O O n r N m L!f N O~ .d f~i P7 N N N N N N 0 m a a W 3 °wa N i.y H O W Z W F ~" w x H ti a a wo a~ c A orx.¢ ~F7e s: w~ a a W a a W wwc,~ caa~o ,., O i m e W ~ rr a ~ F w F a u~ c n. n. n. n. ~.. ti ~. N. .a ,.., n~ n• n~ n• n• n• e~ n• •c n n• n n n n• n ~• ~., > n n• n n• n• n• n n• o !n n'nn n•n•e!a• --n n•n n•n•n'n n~ m n, n n n n n• n n• 0 i i N .:? iq F V w w Uf N xaw as ~ u a F N N °C7 C7 C7 a~ W H M H Fzxz ~~ J~~~ as °o~o ~~ aaa www .+o w 0 W V lfl Lf1 1!7 N ]E I I I ~ ~ N r~i S" !~~ xi ~ O ~ ~ W ~ a U V v u 3 N Vi to VI ~~~~~ ARCO Alaska, Inc.A • GKA 2D-02 .20.02 SSSV API: 500292117700 Well T pe: INJ Angle @ TS: 34 deg @ 7303 (18841885 SSSV Type: Orig Completion: 10/17/84 Angle TD: 29 deg @ 7780 , OD Annular Fluid: Last W/O: Rev Reason: TAG/GLM BY VG :3.500) Reference Log: Ref Log Date: Last Update: 10/31/99 Last Tag: 7604 TD: 7780 ftKB Last Tag Date: 10/27/99 Max Hole Angle: 53 d @ 3700 Casin Str'ih -CONDUCTOR Size To Bottom TVD Wt Grade Thread 16.000 0 117 117 62.50 H-40 Casin Strin -SURFACE Size To Bottom TVD Wt Grade Thread 9.625 0 3287 3076 36.00 J-55 ~- Casin Stein -PRODUCTION Size To Bottom TVD Wt Grade Thread 7.000 0 7771 6302 26.00 J-55 Tubirr Strin -TUBING Size To Bottom TVD Wt Grade Thread ~ 3.500 0 7302 5899 9.30 J-55 EUE 8RD ' ' Perforation s Summar Interval TVD Zone tatus Feet SP Date T e Comment 7388 - 7390 5971 - 5973 A-5 2 1 2115/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7411 - 7412 5991 - 5991 A-4 1 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5!8" Slimkone 7415 - 7417 5994 - 5996 A-4 2 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7425 - 7426 6003 - 6003 A-4 1 1 2/1518 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone ;,, 7430 - 7432 6007 -6008 A-4 2 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone ' 7435 - 7439 6011 - 6014 A-4 4 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7443 - 7445 6018 - 6019 A-4 2 1 ZJ15l8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone Gas Lift MandrelsNalves Stn MD TVD Man Mfr Man T e V Mfr V Type V OD atch Port TRO Date Run Vlv ommen "`' ~ 1 1937 1936 McMurry Hughes 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 2 3720 3347 McMurry Hughes 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 PBR Q259-7260, 3 5247 4374 McMurry Hughes 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 OD:3.500) 4 6243 5085 McMurry Hughes 3 1/2 X 1 DN1Y 1.0 BK2 0.000 0 11/9/84 5 6783 5486 McMurry Hughes 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 PKR (7273-7274, 6 7216 5829 McMurry Hughes 3 1/2 X 1 DMY 1.0 BK2 0.000 0 10/28/99 (1) OD:6.151) 7. Water In" Pk Other lu s, a ui ., etc.. - JEUVH.RY De th TVD T e Descri tion ID 1884 1884 SSSV Baker'FVL (Lock Out 8/21/88) 2.810 NO GO 7259 5864 PBR Baker 3.000 Q290-7291, 7273 5876 PKR Baker'FHL' hyd set 2.890 OD:3.500) 7290 5890 NO GO Camco'D' Nipple 2.750 7301 5899 SOS Baker 2.992 TUBING 7302 5899 TTL 2.992 (a73oz, OD:3.500, ID:2.992) Perf Q388-7390) Perf (7411-7412) Perf (742'x7426) - '~S L ~/'f~! V/1/T/ ~~ ProActive Diagnostic Services, Inc. To: ABC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-51 Q2 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (907j 245-8952 1) Caliper Report 2j LeakDetection - WLD 19-Jun-08 2D-04 15,Jun-08 2D-02 U"`-- C t ~ ~-(- t S ~ 1(0 ~l9 ,` vz~ ~~s~l- ~5 ~ !(o~!`j5~ i ,V Signed : ~ 1,, Prtint Name: (' /~<i 5i! 7 tti ~V cp,(~I ~i.~~ 50-029-21176-00 50-029-21177-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL ~ r?s'~ ~ , ~e ~ Wa = sue, ="~."3 1'~~ "'=c-~ WEBSITE : `r~ f r - n- - - _ z. ~~~~ JUi~ 2008 1 Report / EDE 1 BL / E~ C:\Documanls and Settmgs\Owne,\Desktop\Transmi[_Conoco.doc ZD-02 (PTD# 184-152) Report of Failed IA Drawdown Page 1 of 1 • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, May 30, 2008 9:12 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; NSK Problem Well Supv ~ ~~~~~ Subject: 2D-02 (PTD# 184-152) Report of Failed IA Drawdown ~~~ Attachments: 2D-02 TIO Plot.ppt; 2D-02 Wellbore Schematic.pdf Jim/Tom, Kuparuk injector 2D-02 (PTD# 184-152) failed a diagnostic IA drawdown test on 05/27/08. The T/I/O prior to the test was 1750/650/650 and the T/I/O after the test was 1750/1150/650. CPAI previously received AOGCC approval for temporary water injection into this well which expires on 06/16/08. It is our intent during this time period to inject as necessary to diagnose the nature of the communication. Depending on the outcome of the diagnostics, CPAI will follow up with a 10-403 for repair or an AA request for continued injection. A 3 month TIO plot and Wellbore schematic are attached. «2D-02 TIO Plot.ppt» «2D-02 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~~~iVNE®JUN . i 200 6/5/2008 ~~ I ~,u- 15 Z IAP OAP 2500 2000 1500 a 1000 500 T/IIC) Plot - 2D-D2 ............................ ri,~...1~'. ~.J ..... 0 -}-++~+-+- 29-Feb-08 13-Mar-08 25-Mar-08 08-Apr-08 21-Apr-08 04-~1ay-08 17-May-08 Date 200 150 a E 100 ~ Y O t V 50 0 • • ARCO Alaska, Inc.A GKA 2D-02 2D-o2 SSSV API: 500292117700 Well Type: INJ Angle TS: 34 deg @ 7303 18841885 SSSV T pe: Orig Completion: 10/17/84 Angle TD: 29 deg @ 7780 ( , Annular Fluid: Last W/O: Rev Reason: TAG/GLM BY VG OD:3.500) Reference Log: Ref log Date: Last Update: 10/31/99 Last Tag: 7604 TD: 7780 ftKB last Tag Date: 10/27/99 Max Hole Angle: 53 deg @ 3700 'Casin Strin -CONDUCTOR _ Size To Bottom TVD Wt Grade Thread '- 16.000 0 117 117 62.50 H-40 Casin Strin -SURFACE Size To Bottom TVD Wt Grade Thread 9.625 0 3281 3076 36.00 J-55 g _' ~ Casin Strin -PRODUCTION ~ ` y Size To Bottom TVD Wt Grade Thread 7.000 0 7771 6302 26.00 J-55 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 7302 5899 9.30 J-55 EUE SRD ~ ~ Perforations Summar Interval TVD Zone tatus Feet SP Date T e Comment 7388 - 7390 5971 - 5973 A-5 2 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7411 - 7412 5991 - 5991 A-4 1 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone _ ` ~t 7415 - 7417 5994 - 5996 A-4 2 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7425 - 7426 6003 - 6003 A-4 1 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone ~;_ 7430 - 7432 6007 - 6008 A-4 2 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone ~~ ~- 7435 - 7439 6011 - 6014 A-4 4 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone 7443 - 7445 6018 - 6019 A-4 2 1 2/15/8 IPERF 45 deg. Phasing from vertical, 2 5/8" Slimkone Gas Liff MandrelsNalves =.~ Stn MD TVD Man Mfr Man T e V Mfr V Type V OD atch Port TRO Date Run Vlv ommen 1 1937 1936 Mc Murry Hughes 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 2 3720 3347 Mc Murry Hughes 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 PBR (7259-7260, 3 5247 4374 N1cMurry Hughes 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 OD:3.500) 4 6243 5085 Mc Murry Hughes 3 1/2 X 1 DMY 1.0 BK2 0.000 0 11/9/84 5 6783 5486 Mc Murry Hughes 3 112 X 1 DMY 1.0 BK2 0.000 0 11!9/84 PKR (7273-7274, 6 7216 5829 Mc Murry Hu hes 3 1/2 X 1 DMY 1.0 BK2 0.000 0 10/28/99 (1) OD:6.151) 1. Water In" Pk Other lu s, a ui .,etc. -JEWELRY De th TVD T e Descri tion ID 1884 1884 SSSV Baker'FVL (Lock Out 8/21!88) 2.810 NO GO 7259 5864 PBR Baker 3.000 (7290-7291, 7273 5876 PKR Baker'FHL' hyd set 2.890 OD:3.500) 7290 5890 NO GO Camco'D' Ni ple 2.750 7301 5899 SOS Baker 2.992 TUBING 7302 5899 TTL 2.992 (0-7302, OD:3.500, ID:2.992) Pert (/388-7390) Perf (7411-7412) Perf (7425-7426) i~ur ua uas ~~..i r r uwa aaa~ vva.avaa aua~. Regg, James B (DOA) 1 CI~IJ 1 V J/L < Jam' From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, May 20, 2008 3:13 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: Kuparuk 2D Water injection line Jim, The approved wells mentioned have been returned to water injection as follows: 2D-02 - BOI on 05117!08 at 08:30. ~~ ~ ~ - ! 7~- 2D-04 - BOI on 05/17108 at 08:30. ~T~~ 1 ~A- l5 I 2D-05 - BOI on 05/19108 at 07:28. P~ t~,q _ i Z~ Diagnostic testing and monitoring will be conducted during the 30 day test period. The results will be reported to the AOGCC followed by any appropriate paperwork. Please let me know if you have any questions or need any more informs#ion. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone {907) 659-7224 Pager {907) 659-7000 pgr. 909 From: Regg, James B (DOA} [mailto:jim.regg@alaska.gov] Sent: Wednesday, April 30, 2008 1:55 PM To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: Kuparuk 2D Water injection line You are authorized to inject as outlined below to complete dia ostic testing and prepare your action plan. Please provide copies of'the diagnostic MITs mentioned in ur email. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [ ailto:N1878@conocophillips.com] Sent: Tuesday, April 15, 200 :30 PM To: Regg, James B (DOA); sunder, Thomas E (DOA) Cc: NSK Problem Well S v; NSK Well Integrity Proj Subject: Kuparuk 2D ater injection line 6/5!2008 Kuparuk 2D Water injection line Page 1 b ~ l~- Regg, James e (DOA) ~~ From: Regg, James 6 (DOA)....... _ ~~ Sent: Wednesday, April 30, 2008 1:55 PM ~~ ~ ~f ~~~ To: 'NSK Well Integrity Proj'; NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: Kuparuk 2D Water injection line You are authorized to inject as outlined below to complete diagnostic testing and prepare your action plan. Please provide copies of the diagnostic MITs mentioned in your email. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, April 15, 2008 2:30 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: Kuparuk 2D Water injection line Jim, The produced water injection line to 2D pad has been shut down for repairs since June 2006. Repairs are currently in progress with an expected completion date of 27APR08. At that time produced water injection capabilities will be restored to the pad. Just before and during the time of the water line shut down, three wells were reported with suspect TxIA communication. D-02 184-152 2D-04 (184-151) 2D-05 (184-126) Due to the lack of injection water, build up rate (BUR) and trending diagnostics were not completed and the suspected leaks were not confirmed. Each well has however passed a diagnostic MITIA. At the completion of the water line repairs, ConocoPhillips requests approval to bring the above listed wells on produced water injection for 30 days for additional diagnostics and BUR TIO trending. Due to the lengthy shut in, a 30 day injection period is requested to adequately allow each well to come up to operating temperature throughout the well bore and become thermally stable before BUR TIO trending. If any of the wells indicate TxIA communication before the 30 days has passed it would be shut in and the AOGCC notified. At the end of the 30 days ConocoPhillips would present the AOGCC with the status and an action plan for each well. The action plans could included applying for an AA, 10-403 for repair, or returning the well to normal status depending on the test results. Please let me know if any additional information is required to gain approval for the 30 day injection period. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 4/30/2008 . WELL LOG TRANSMITTAL . RECEIVED /\UG ~" u 20m) PROACTIVE DiAGNOSTIC SERVicES, INC. ~ 011 & Gas Coos. COlTlmission Anchornge To: AOGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 1 00 Anchorage. Alaska 99501-3539 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 1 ) 2) 3) 4) 5) 6) 7) 20-02 Caliper report 19-Jun-06 2V-01 Caliper report 24-Jun-06 5(;ANNED AUG 3 0 2005 Print Name: ¿lj~ -- (!.ll r ì~ /J1 e 111 {}..JL{A t'.oAA Date: ~iy:J/ö ç., v , Signed: PRoAcTivE DiAGNOSTic SERviCES, INC., I}O W. INTERNATioNAl AiRpORT Rd SuÎTE C, ANChoRAGE, AK 99518 PhONE: (907)245-8951 FAX; (907)245-8952 E-MAil; pdSANChoRAGE@MEMonyloG.COM WEbsiTE: MEMORyloq.COM C:\My Documents\ Work\ DistributionLablesNew\ Transmit_ Original.doc JJC,. I~'-/- 16-d I I I I I I I I I I I I I I I I I I I Company: Log Date: Log No.: Run No.: Pipe1 Desc.: Pipe1 Use: .I~I~4-1~;) . Memory Multi-Finger Caliper Log Results Summary ConocoPhillips Alaska, Inc. June 23, 2006 6581 1 3.5" 9.3 lb. J-55 EUE 8RD Tubing Well: 2D-02 Field: Kuparuk State: Alaska API No.: 50-029-21177-00 Top Log InM1.: Surface Bot. Log InM1.: 7,271 Ft. (MD) Inspection Type: COMMENTS: Corrosive & Mechanical Damage Inspection This log is tied into the PBR @ 7,259' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing logged is in good to fair condition, with a maximum recorded wall penetration of 27% in joint 59 (1,845'). The damage recorded appears in the form of scattered, shallow isolated pitting and shallow areas of corrosion. No significant areas of cross-sectional wall loss or J.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Isolated Pitting Isolated Pitting Corrosion ( 27%) ( 25%) ( 22%) ( 22%) 1 ,845 Ft. (MD) 5,318 Ft. (MD) 545 Ft. (MD) 1 ,224 Ft. (MD) Jt. Jt. Jt. Jt. 59 171 17 40 @ @ @ @ No other significant wall penetrations (> 20%) are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 10%) are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant J.D. restrictions are recorded throughout the 3.5" tubing logged. RECEIVED AUG 2 9 2006 AlaSka 011 & Gas Cons. Commission Anch0fa98 I Field Engineer: N. Kesseru Witness: T. Senden Analyst: M. Lawrence ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, Tl 7749ì Phone: or (888) 565-9085 Fa>;: (281) 565-1369 E-mail: PD5@memorylog.com Prudhoe Bay Field Office Phone: 659-230ì Fa>e 659-2314 I I S Repo dy R egi I We!!: Field: Company: Country: 2D-02 Kuparuk ConocoPhillips Alaska, Ille USA Survey Date: rool Type: rool Size: No. of Fingers: Overview n nalysis lune 23,2006 MFC 24 No. 99628 1.69 24 I Penetration and Metal toss (0/0 wall) I metal loss penetration penetration 250 I 200 150 I 100 .50 ~.. oL o to % GlM 1 10 to 20% 20 to 40% I to 10% 40 to over 85% 85%, I 4 o 85 o loss 3 233 I I Damage C ollfiguration ( body) GlM 2 40 GUv\ 4 I 30 20 GlM 3 I 10 o I Isolatï:,d gener;:tI line nng hole I pOSS pmmg corrosion COITOSlon (OITOSlon ¡b!e hole ClM 5 I 36 Cll\¡\ 6 Bottom of Survey = 232.3 21 o o I I Analysis Overview page 2 I I Damage Profile (% wall) metal loss 50 100 I I I I ¡ ¡I· .LLJ~ I I Pipe 1 I I I I I I I I I I I I I I 3118 W ...0 ..., GLM ') LL i- S c: z 3879 ..r:: +J Q. Q) 0 4654 eLM ,) .> 5434 Correlation of Record Borehole Profile 3.5 in (23.2' - 7271 .2') Well: Field: Company: Country: Survey Date: 20-02 Kuparuk ConocoPhillips Alaska, Inc. USA June 23,2006 Appro\,. rool Deviation Appro\,. Borehole Profile eli'"j 1 eLM C;LM 4 ~ ~ CL\1 5 o 50 Profile (% wall) I rool Deviation (degrees) I Bottom of Survey = 232.3 I I 27 766 1535 2342 6210 7001 7271 100 I I I I I I I I I I I I I I I I I I I REPORT INTTABULATION S Pipe: Body Wall: Upset Wall: Nominal i.o.: 3.5 in 9.3 ppf EUE 8RD 0.254 in 0.254 in 2.992 in 2D-02 Kuparuk ConocoPhiliips Alaska, Inc. USA June 23, 2006 Well: Field: Company: Country: Survey Date: loint It Depth I\'IL Pen. Pen. i \1 f'tlI Min Damage Profile No. t ID. Comments (%wall) ) (Ins.) (Ins.) 0 50 100 ¡ 23 n om p \ ).89 PUP LL Deoosìts. III II I 27 n 002 9 ) 2.9) 2 ')9 n 0.01 4 ) 2.91 I I I 3 91 0 0.03 10 \ . 2.91 4 121 C 0.05 19 In 2.91 Shallow corrosion. 5 151 0 OJn I; 4 2.90 Shallow nittilllI. (, 183 0 002 9 ) 2.90 LL Deoosìts. ----- 7 213 0 0.02 9 ) 2.92 ß 243 C 0.04 14 \ 2.87 Shallow corrosion. Lt DeDosits. ~ ---_.~- 9 275 (I 0.02 9 ) 2.91 I 10 307 n CJ.O 3 n 3 2.92 I I 11 3.37 0 0.03 12 ( 2. 12 366 0 0.02 9 2. I 1 398 0 0.1)4 16 2. 311"HVVV 1 4;~8 0 0.02 0 2. 1 !.,O 0 0.01 4 4 2. 1 )0 Ii CJ.O 3 10 3 2. Ii 0.06 22 2 2,92 ISOlaIe( oittilì\:!. 0 0.02 9 ) 2.92 I I 0 0.03 13 3 2.90 I 0J5 0 .0,04 16 7 2.91 I 645 >. 0 O,QL 10 3 2. 8 8.» ~..~~.~-------_._------- >- ~I 22 675 0 (}04 16 I, 2.89 Shallow corrosion. )I{ in: ( >0.01' 4 2 . 2.92 24 "{ I 0.03 10 ) I 2.90 )') '6¡ I 0.ü2 8 1 2.92 I )6 '\)¡ 0 0.02... C) ) 2.93 I ) 8213 I . .~Hll 12 ) 2.91 I I I I ... I 860 n 0,02 7 2 2.92 892 I 0.04 14 9 2.90 Shallow 92; ( 0.02 9 2 2.91 9,)¡") I 0.0.3 ti 3 2.91 I I .......~; 1~~> ).. ...U...... QJlL ) 2,91 I I I 1 n 0,03 3 2,90 Shallow Dittim;¡. I 34 11M1 ( 0.02 I I ! "35 10; '0 001 ~I 3(, 1100 0.02 37 1131 0,01 'J?' 1163 0.04 6 Shallow corrosion. I "39 1194 I 0.ü2 ) 2.91 I »_.4Il..... 1224 0 0.06 L) 2.89 )n. Lt. Deposits. II1i 41 1~,)6 0 o O{ I \ 2.92 I Shallow Dittimr. 4) 121'17 Ii OJn I 3 2.89 j' Lt DeDosits. 43 1 '3 If) () om 9 ) 2,()jJ...ht Deposits. 44 134<1». 0 (un 11 ) 2. 9(L>L.LQ~~ ts. 45 1379 0 0.0.3 12 2.91 I 46 1.41.L. )) 0.04 17 2.1'11'1 Shallow corrosion. Lt DeDosits. II .. 47 1442 II 0.03 Ii 2,93 Shallow Ditting. Lt Deposits. 48 1474» II CUB 10 2.94 49 1506 0 0,03 10 2.91 Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION EET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Su¡vey Date: 2D-02 Kuparuk ConocoPhiUips Alaska, Inc. USA June 23, 2006 Joint Jt. Depth PPI Pen. Pen ¡\;let11 Min. Damage Profile 'I I.D. Comments (%wall) ( (Ins.) 0 50 100 ~ 1535 I 0.03 13 2 2.91 Shallow oi ttil1\l. I 51 .. ~-=-- I (l05 18 ) 2.92 Shallow oitti!ìQ. It Deoosits. ~I ---.- 1 0.04 15 j 2.88 !:'" ') 1598 Shallow corrosion. It Deoosits. j.... .. .~. 5.1~ 1628 u , 0.03 I 13 1 2.88 Shallow Ditlinll. .. 1660 . "'1 10 2 2.92 0.03 , 1690 I 0.04 14 2.91 Shallow oíUÌlw. iì22 ( 0.04 1.5 I 2.91 Shallow nittnll. 1753 I 0.03 11 '1 2.90 1 II I' '1 2.91 Shallow m I I 2. 4 I 2.90 Isolated Pittinll. I I ( I . 2.89 1 0 I ) 2.88 P(JP Ii 0 0 Ii N/A SSSV Ii 0.}5 19 ') 2.86 PUP Shallow oittin\:!. Lt ¡pnosHs I!II I I 0 O. 13 11 3 2.91 Lt I (' 1 0 0 0 N/A ClM 1 (No ,I) 0 O. 12 9 ) 2.90 ,''1 Ii O. )4 17 6 2.93 Shallow Ditlin\:!. Lt. II ',4 Ii O. )3 Ii 3 2.92 ,'1 Ii 0.03 II 4 2.90 I 66 20(1! Ii CUB I ) 2.90 Shallow oittimL It. Deposits. I I 67 2096 Ii 004 ¡ ) 2.90 Shallow 68 2127 n 0.05 I U 2.90 SJJ.i~lQ:\:Y cor rosio n. I 69 2158 Ii 004 1 (, 2.92 ShaJloW..i2!Iosion. _l.L[2eposits. I 70 2189 , II Q.03 11 3 2.91 .. 71 2220 II CUB P ) 2.93 Sha!l;)w pittin\:!. Lt ï2 2249 II or)') c. ) 2.92 I n 21m! II (0) t. 4 2.93 , I 74 :nn II 0.04 F ) 2.89 Shallow Ditlin\:! I I I 7S 2142 II 0.02 e 2 2.94 , 7() 2m) Ii 0.05 1 3 2.89 Shallow I 77 2401 II 004 I ) 2.90 Sha!low I I ,]8 2414 I (UB 1 ) )1 79 246'1 I 0.03 2 ~7 Lt I I \0 2497 I (1 I) (1 2'128 I O. 2'160 II 0 Shallow níttimL 2'192 Ii 0 3 Shal10vv nitting. 2622 U 0 26'14 0.0'1 OJ)2 Shallow nitting at upset 2684 0 0.04 17 ,," '''"UW Lt. I!Ii 2716 U "002 q ) I ...... 2746 II 12 ; I 88 0.03 ;:;~90 89 277(, 0 0.02 '} ) L92 ------ 90 21)01) 0 0.0'1 10 ) 2.91 91 21)'19 0 , 0.03 11 ) 2.91 Sha!low nitti!1..~~ I ~--_.... -_.."~,-"~.,~~"..,~-,~,~.__._.,------.- __________m___ (J) 2869 0 ..Q.03 Ii 2.9"1 S.h,}IIQw pi tling. I c--"- 93 2902 0 0.01 '1 ) 2.91 I 94 2933 Ii (Un II ;; 2.93 It. <)'; 2964 II (J.O 2 9 i 2.92 ! I I I I I I , i Body Meta! loss Body Page 2 I I I I I I I I I I I I I I I I I I I JOINT Pipe: Body Wail: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf EUE 8RD 0.254 in 0.254 in 2.992 in 20-02 Kuparuk ConocoPhillíps Alaska, Ine. USA June 23, 2006 Well: Field: Company: Country: Survey Date: loint It Depth I Pe Pen. I Pen !v1elal Min. e> Profile I No. Ilpset Body I 1.0. Comments (%wall) ,I I (Ins.) I (Ins.) 0 l¡¡jT 96 _~(l2i)n.. ... n 0.02 9 4 2.90 II .--.--..:..'-~ 0 12 ) ." - ~-_._-----~.~_..~ III 97 :;027 om 2.94 .-- ---- 3057 - . ':>iw¡¡u,,~ nitting. It -. III (8 ...n 0.0414 2 2.91 ':9 3088 jÏ31~Ej~) 3 2.94 I 'I Ii 10 3118 __ - 0 J)Jl2. ~¡ ) 2.91 III! II )I 3147 3 2.92 102 :;180 ) 2.94 I I I -- ---~---~,~.,- __~___M~ 103 3207 o 0.01. 6 ) 2.90 ~--~-~- 0 om 3 2,91 0 0.01 2 2,92 ! I I I) 0.02 ..1. '} 9) I .-- - --------------_._-_._--_.~-.... -- -,-,~ I) 0.02 :I_~_Et9Õ .~. ------~---- _...,-,~ 3356 I) 0.02 .91 I 3385 0 O.cn 3 2.87 ,JlldIlUW IInUIIX. I 10 3415 I I) om 2 "'d"UVV III nu IX ·b I 0 0.03 )IIUl IX. [\ 0 0.01 2 ß i! 0.ü2 2.92 0 0.02 2.91 115 0 0.02 '4 ...... 2.91 116 3 l) i! 0.01 ¡ ) 2.90 117 3631~. i! 0.02 118 3(162__ i! 0,02 ¡ ) I 119 3Y¡2 i! 0.02 ( ) 119.1 3721 0 () ) N. ClM 2 II ateh (iii¡ :10\ I 120 3728-' 0 0.02 121 3758 i! 0,02 122 3788 i! 0,01 I I 123 3817 i! 0,02 124 3846 i! 0.01 I I I I 125 3879 i! 0.01 (; I 126 39HJ i! 0.02 9 I 127 3941 ... D 0.03 II 128 3971 i! 0,02 7 2,88 129 4001 0 0,03 1 ) Shallow !)itting. 13D 4D30 i! D.02 9 I 131 4060 U OJI2 8 D2 4091 0 0.02 9 (; 133 4123 0 0.02 7 D4 4154 0 0.03 10 ) US 4186 0 0.02 (; ) 2,91 .....IJ(1 :1 n 10 I 2.91 42JZ.. D7 4249 i! 0.02 ') I 2,92 I D8 4279 i! 0.02 7 ) 2,91 I 139 4309 0 O.cn U 4 2,87 Shallow 140 434Ó' . . I) 5 2 2.94 I n. 0.01 I 141 4372 0 Q..Q}. II ) 2.91 142 4403 0 0.01 5 ) 2,92 143 4435 0 0,02 9 ) 2,91 jIII I I 144 4467 0 0.01 4 ) 2.91 I J Body Metal loss Body Page 3 I I I I I I I I I I I I I I I I I I I p Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2D-02 Kuparuk ConocoPhiUips Alaska, Inc. USA June 23, 2006 jt. Depth 1'1'1 I Pen. I Pen ;\11"t11 ~ ^~ - --"-,~ ,,~ Damage Profile Joint Min. I No. (Ft.) I I.D. Con1mel1ts (% wall) ¡ I (Ins.) I (ll1s) I 0 50 100 I 145 4497 !) 0.02 R ) 2.92__ -'- _ __~_~__~M_..'_.~~__ ,-", I i I I ~,14& 4528 {I 0,01 5 I If)! i1~ 4560 {I 0.02 ') 3 2.90 4590 {I 0.02 ') 2 2.93 -~...~~.~_.."._----- -~,~- 149 4622 7 --.- {I 0.02 2.93 _~..m 150 4654 {I 0.02 "7 2.90 -.-.- 151 4685 II 0.02 ! 6 2,93 ! 152 II 3 --~---- --..--- 4717 (UB 2.91 m.m._. I 1 t" '"~ 4749" II 0.03 I 2.93 .:).:) 154 4781 {I 0.02 q -...-- i 2.92 155 4812 {I f1QL 6 ) 2.89 I -- -- - ---,.~-_......,- .... ~.,- 156 4844 {I (1.03 2.91 157 4875 I) 0.04 2.92 Shallow I 158 4908 I I) 0.02 2.93 159 4939 U 0.03 2 93 160 4971 U 0.02 2, 92 I 161 S002 U (HB 12 ) 2 92 Shallow nittinl:!. 162 on I) 0.03 I 3 2 93 I 163 'O( )2 0 (W2 9 ) 2.90 I 164 '0' 0 0.02 7 3 2.93 1 1. 0 0,01 4 2 2.93 I 1 b t 1 0 0.02 R 3 2.91 1 t I) 0.02 9 4 2.92 1 g r () 0.02 9 2 2.91 161 ,1 r i( U 0 0 0 N/A ClM 3 i latch !.it) 10:30\ 169 i( 0 0,02 0 3 2.90 ..1 70 g( 0 0,03 2 ) 2.93 71 n 0 0.06 25 ) 2,92 ! Isolated Pittil1l¿ 72 5145 () 0.03 13 2 2.93 Shallow nittinl:!. I 73 U 0.02 3 2.93 74 [)f U 0,02 2 2.92 3' II 0.02 ) 2,94 , b. U 0.05 19 I 2.92 Shallow Dittim;¡. 1 I) 0.03 12 2,91 1 0 0.0'1 11 2.90 1 U 12 2.90 1 0 f) 2.90 I 1 0 a 2.93 I I I I 1 0 11 2.91 I 18 0 . 0.03 10 2.91 184 5716 U OJ)) 12 2.93 Shallow Ditul~ 185 574R U 0.02 q 2,92 186 5777 I) 0.02 i) 2,92 I 187 5Bm 0 0.D3 1 , 2.94 188 SR'IS I) ().D3 1 ') 90 Shallow DitUIJiL I 189 5869 0 , 0.01 '2:C¡{=+ III I 190 5898 U 0.02 2.90 l. 191 5929 I) 0.02 .93 192 5958 0 0.02 .88 193 5991 (I 0,02 .94 Body Metal loss Body Page 4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION S Pipe: Body Wall: UpselWa!l: Nominal I.D.: 3.5 in 9.3 ppf EVE 8RD 0.254 in 0.254 in 2.992 in 2 D-02 Kuparuk ConocoPhillips Alaska, Inc. USA June 23, 2006 Well: Field: Company: Country: Survey Date: Joint I Jt. ~epth Pen ! Pen. Pel :Vlet11 Min. I Damage Profile No. (Ft) ! I (Ins.) !.D. Comments (% I (Ins. ) 10 50 100 194 n 10 ! )2 . 6022 0.0;2 I 19S 6()S-;¡' 0 0.02 7 I' )2 !II 1% 60W; n 0.04 In )J Shallow Ditling II 197 6115 n 0.02 I H ¡¡ fii!J 19H ... n !II 6148 0.03 2.90 I 199 6178 n CW3 I 2.90 Shallow DitlinR.. [!II ^~_. 200 6210 n CUB 2.88 [!II ~ 6242 n 0 ! N/A ClM 4 (latch @ 1 :')0) I 6249 n 0.02 2.94 I I ( ~80 n (} ') ( 110 n o ') ( 142 n ') ( 173 n ') 2( ,404 n U12 I I 2( ,437 n 1.02 I 2( ,7 n 0.02 l2( )9 n OD2 I ( :n II 0.02 B I () 0.02 B I () 0.02 () > I ( () 0.0;;: 7 2.92 n 0.02 (j ¡ 2.91 :>15 n 0.04 17 4 2.87 Shallow 216 () 0.02 ß ') 2.92 ')17 n 0.02 9 ') 2.92 I I 21 1 () 0 () n N/A C;I M S (I arch @ 9:30) ') 0 0.03 I ) 2.91 I :> \1 0 0·02. 8 > .2.89 ¡ t. npnncìtc :> Vi] 0 0.03 13 ') 2.92 Shallow nit1iml. 221 \79 n 0.02 I 8 ) 2.94 222 6911 n 0.02 8 ') 2.93 . ') ,) '") 6941 0 0.01 I ) 2.95 I .4.4....) t'¡ 224 (i' (0) I o.tiT- S ) 2.95 Shallow nitlÌnQ at !Inset. 225 71 0 0.02 ) 2.90 226 71 0 3 2.93 227 71 n I (, 2.91 Shallow nitlÌnQ. 22ß 709 n 2.93 229 712- n h 2.93 I no 7155 n ll04 16 ==tt~~ Shallow 2') 1 71ß4 n 0.03 _...~ II nu 7214 n 0 ( ( J/A ClM 6 (latch @ 8:30\ I 212 7222 n CUB 10 3 I 2.88 It. II I 212.1 7254 n 0.02 ( II 2.90 PUP III I 212.2 72S9 () 0 ( I ( 2.94 PBR 2123 72n () n ( ( 2.84 PACKER ¡SliQht Mash) Body Metal loss Body Page 5 .. .. .. .. .. .. .. .. .. Well: Field: Company: Country: 2D·{)2 Kuparuk ConocoPhillips Alaska, Inc. USA at depth 1 Tool speed 57 NominallD 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 1 0 .. .. .. .. .. .. .. P S R ep rt S ns Survey Date: Tool Type: Tool Size: No. of Fingers: June 23, 2006 MFC 24 No. 99628 1.69 24 13 ft Finger 12 Penetration = 0.068 ins Isolated Pitting 0.07 ins 27% Wall Penetration HIGH SIDE = UP Cross Sections page 1 .. .. .. - .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. PDS Cross S ons Well: Field: Company: Country: 20-02 Kuparuk ConocoPhil!ips Alaska, Inc USA Survey Date: Tool Type: Tool Size: No. of Fingers: June 23, 2006 MFC 24 No. 99628 1.69 24 Cross Section 13 ft Tool speed = 57 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 52 0 Finger 8 Penetration = 0.064 ins Isolated Pitting 0.06 ins'" 25% Wall Penetration HIGH SIDE '" UP Cross Sections page 2 .. .. .. I ARC a Alaska, I I I SSSV (1884-1885 00:3500) I I I I I I I I I I I I I I I I I API: 500292117700 I SSSV Ty pe Annular Fluid: : 7604 Interval 7388 - 7390 TV 5971 - 5973 7411 - 7412 5991 5991 7415 - 7417 5994 - 5996 7425 - 7426 6003 - 6003 7430 7432 6007 - 6008 7435 7439 6011 6014 I 7443 7445 6018 - 6019 GKA Well Type: INJ Orig Completion: 10/17/84 Last W/O: Rei Log Date: TD: 7780 ftKB 99 o Zone A-5 L 2D-02 ~ Last Update: 110/31/99 I 700 Thread I Thread EUE 8RD ERF Comment 45 OOg. Phasing I rom vertical, 2 5/8" Slimkone 45 deg. Phasing I rom vertical. 2 5/8" Slimkone 45 OOg. Phasing I rom vertical. 2 5/8' Slimkone deg. Phasing I rom vertical, 2 5/8" kone Phasing I rom vertical. 2 5/8" Slimkone 45 deg. Phasing I rom vertical, 2 5/8" Slimkone 45 deg. Phasing I rom vertical. 2 5/8" e A-4 1 2/15/ïIPERF 1 2I15181IPERF 1 2/15/ IPERF istn MD TVD Man Mfr 1937 1936 ~~~~:~ 2 3720 3347 ~ 31/2X1 Hughes 3 5247 4374 McMurry 3 1/2 X 1 Hughes 4 6243 5085 McMurry 3 1/2 X 1 Hughes 5 6783 5486 M~X 1 6 7216 5829 ~Murry 3 1/2 X 1 Hughes In1i884W;~ SSC¥ VL("'''O",~''''8)~;~ 7259 5864 PBR 7273 5876 PKR 'FHL' hyd set 7290 5890~ NO GO ¡Camco'D' Nipple 7301 SOS lBaker 7302 m I 1 A-4 2 PBR (7259-7280, 00:3500) PKR (7273-7274, 00:8151) NO GO (7290-7291, 00:3.500) TælNG (0-7302, 003.500, 10:2.992) Pert =t f.--- (7388-7390) f.--- f.--- Pert - f.--- (7411-7412) - É - - Perf (7425-7426) m A-4 1 A-4 2 1 Ä-4 4 1 2/1 A-4 2 1 ~v 31/2 X 1 DMY 1.0 DMY DMY DMY DMY DMY Date Vlv Run r.ommen BK2 0000 0 11/9/84 BK2 0.000 0 11/9/84 BK2 0.000 0 11/9/84 BK2 0.000 0 11/9/84 BK2 0000 0 11/9/84 BK2 0.000 0 10/28/99 (1) ~ I 2.992 ¡ 2.992 1.0 1.0 1.0 1.0 1.0 12/30/05 Schlumberger RECEIVED NO. 3638 Schlumberger -DCS JAN 0 9 2006 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman A TTN: Beth Alaska Oil & Gas Cons. Commission 333 West 7th Ave, Suite 100 Anchorage Anchorage, AK 99501 Field: Kuparuk ~ Well Job# Log Description Date BL Color CD 2D-02 i64 - /5~ N/A SHUT IN BOTTOM PRESSURE 12103/05 1 1A-07 N/A INJECTION PROFILE 12/06/05 1 1 H-21 11166748 PROD PROFILE W/DEFT 12/26/05 1 2X-12A 11166749 PROD PROFILE W/DEFT 12/27/05 1 2U-08 11166750 PROD PROFILE WIDEFT 12/28/05 1 2X-13 11144057 GLS 12/25/05 1 2V-11 11166736 PROD PROFILE W/DEFT 12/16/05 1 30-09 11166737 LDL 12/17/05 1 35-21 11166738 INJECTION PROFILE 12/18/05 1 3F-17 11144054 PROD PROFILE W/DEFT 12/22/05 1 2X-15 11144058 PROD PROFILE W/DEFT 12/26/05 1 30-09 11144055 LDL 12/23/05 1 2V-01 11144056 INJECTION PROFILE 12/24/05 1 '-- SIGNED&w1DO001-¡ StìANNEP JAN 3 1 2J}í)fi DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Consen'ation Commission TO: Jim Regg ':? 4f~ t,IZ~ /cA Pol. Supervisor I "\ -~ ( DA TE: Wednesday. June 23. 2004 SllBJECT: !\lechanicallmegrity Tests CONOCOPHILLIPS ALASK..o\ rNC 20-02 FROM: Chuck Scheve Petroleum Inspector KUPARUK. RIV UNIT ~o-ü~ Src: Inspector NON-CONFIDENTIAL Reviewed By: r-:- Pol. Suprv-_- \W---- Comm Permit Number: 184-152-0 Inspector Name: Chuck Scheve Inspection Date: 6119/2004 Well Name: KUPARUK RJV UNIT 2D-02 Insp Num: mitCS040619191:!28 Rei Insp Num: API Well Number: 50-029-21177-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 20-02 Type Inj. p TVD 6309 IA 600 2310 2270 2270 P.T. 1841520 TypeTest SPT Test psi 1469 OA .J80 500 500 500 Inten'a) .JYRTST PIF P Tubing 2250 2250 2250 2250 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday. June 23. 2004 Page I of I AL OIL AND GAS CONSERVATION COMM, N REPORT OF SUNDRY WELL OPERATIONS ORIGIN - 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other X 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 109' FNL, 677' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1174' FSL, 1331' FWL, Sec. 23, T11N, R9E, UM At effective depth 1198' FSL, 1280' FWL, Sec.23, T11N, R9E, UM At total depth 1277' FSL, 1109' FWL, Sec. 23, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7780' feet Plugs (measured) 6 3 0 9' feet 6. Datum elevation (DF or KB) 6200' SS 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-02 (Water In!ector) 9. Permit number . 84-1,52 / ~'" ©Oq 10. APl number 5o-029-211 77 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured true vertical 7689' feet Junk (measured) 62 2 9' feet Casing Length Structural 1 6" Conductor Surface 9 5/8" Intermediate Production 7" Liner Perforation depth: measured 7388' Size Cemented 62.5# 204 Sx CS II 3 6.0# 750 Sx AS III 450 Sx G 26,0# 400 Sx G 250 Sx AS I - 7439' Measured depth True vertical depth 117' 117' 3281' 3075' 7771' 6317' 13. true vertical 5968' - 6012' Tubing (size, grade, and measured depth 3 1/2" J-55, 9.3#, 7302' Packers and SSSV (type and measured depth) Baker FVL 1884' Baker FHL 7273' Stimulation or cement squeeze summary Intervals treated (measured) Install Non-surface control SSSV Treatment description including volumes used and final pressure .' J;_.-~;i-~a Oil & ~as Cons. Commission, Anchorage 14. Re_oresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1650 1700 2020 2350 700 2165 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 2ate ~SUBtvIIT IN D~IIC~TE Form -10-404 ~ev 06/15/88 Subsidiary of Atlantic Richfield Compa..~ ,,~0-2_ .. i 76F?. I . * ONTRACTOR ~OPERATION AT REPORT TIME ~; T/~ ,'~/L L E ~ I 0 ~ ~,,~/,--,"~c REMARKS /.R oo -- I/..13o -. · /Oo~ I---] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK AL, OIL AND GAS CONSERVATION COMM~. N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ 2. Name of Operator ARCO Alaska,, Inc. 3. Address P. ©. Box 100360, Anchorage, AK 99510 5. Type of Well: Development .X__ Exploratory _ Stratigraphic _ Service _ Location of well at surface 109' FNL, 677' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1174' FSL, 1331' FWL, Sec. 23, T11N, R9E, UM At effective depth 1198' FSL, 1280' FWL, $ec.23, T11N, R9E, UM At total depth 1277' FSL, 1109' FWL, Sec. 23, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7780' feet Plugs (measured) 6309' feet Effective depth: measured true vertical 7689' feet Junk (measured) 6 2 2 9' feet Casing Length Structural I 6" Conductor Surface 9 5/8" Intermediate Production 7" Liner Perforation depth: measured 7388' Size Cemented 62.5# 204 Sx CS II 36.0# 750 Sx AS III 450 Sx G 26.0# 400 Sx G 250 Sx AS I - 7439' true vertical 5968' - 6012' Tubing (size, grade, and measured depth 3 1/2" J-55, 9.3#, 7302' Packers and SSSV (type and measured depth) Baker FVL 1884' Baker FHL 7273' 13. Attachments Description summary of proposal X 14. Estimated date for commencing operation August 21, 1988 16. If proposal was verbally approved Name of approver Date approved Other 6. Datum elevation (DF or KB) 6200' $$ 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-02 (Water Injector) 9. Permit number ~14-152 10. APl number 50-02 ~)-211 77 11. Field/Pool Kuparuk River Oil Pool Measured depth True vertical depth 117' 117' 3281 ' 3075' 7771' 6317' .k C iYED JAN u 19 9 Detailed operation program _ 15. Status of well classification as: Oil Gas Service .Wa,ter Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require oRiGiNAL SIGNED BY LoNN!F ~,, ~NI!TH BOP sketch Suspended Approved by the order of the Commission Form 10-403 Rev 06/15/88 .~,pr~'ovad Copy Returned 9-~? Commissioner Date IIAppr°val No~_ {:~ ~ Date SUBMIT IN TRIPLICATE SUNDRY NOTICE - WELL 2D-2 INSTALL NON-SURFACE CONTROLLED SSSV WIRELINE BOP'S ARE USED DURING THE INSTALLATION. A SAND PRESSURE (6200' SS) = 2914 PSI 8/30/86 SIBHP NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. Alasl'~ Oil.& Gas Cons. Commiss~o~ , :.~ ~chorage 3 f '1' J 1 , J 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PS1 4 1/6" FLOW TUBE PACK-OFF H I REL I NE BOP EOU I PHENT ARCO Alaska, Inc. Post Office Bux '100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 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 1L-1 Convers 1L-7 Convers 1Q-2 Convers 1Q-7 Convers 1Q-11 Convers 1Q-1 3 Convers 2B-5 Convers 2B-9 ~Convers 2C-1 Convers 2C-3 Convers 2C-6 Convers 2C-8 Convers 2D-2 Convers 2D-7 Convers 2D-11 Convers 2D-14 Convers 2F-1 Convers 2F-2 Convers 2F-1 3 Convers 2F-1 4 Convers 2G-3 Convers 2G-3 Convers 2G-5 Convers 2G-7 Convers 2G-10 Convers 2~-12 Convers 2G-16 Convers 2U-3 Convers 2U-4 Convers 2U-7 Convers 2U-16 Convers 2W-2 Convers 2W-4 Convers on on on on on on on on on · on on · on on on · on on · on · on on · on on on on · on · on on · on on on on · on on on 11118185 11/18/85 11/17/85 11/17/85 11/17/85 11117185 11/23/85 11/23/85 11/19/85 11/19/85 11/19/85 11/19/85 11/20/85 11/20/85 11/20/85 11/20/85 11/21185 11/21/85 11/2i/85 11/21185 11114185 11114185 11/14185 11/1/4185 11114185 11114185 11114185 11/16/85 RECEIVED 11/16/85 ~,.. l l /16/85 J AN2 11/16/85 11 / 15 / 8~kl Oil & Gas Oo~s. GOF,~)~:~':, 11 / 22 / 85 f.~cher22~ ARCO Alaska. Inc. is a Subsidiary of Atlant!cRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I-IX OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360 4. Location of Well SURFACE LOCATION: T11N, R9E, UM ANCHORAGE, ALASKA 9 9 51 0 109' FNL, 677' FEL, SEC. 26, BOTTOMHOLE LOCATION' 1420' FSL, 1091' FWL, SEC. 23, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 127' (RKB) 6. Lease Designation and Serial No. ADL 25653 7. Permit No. 84-152 8. APl Number 50- 029-21177 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2D-2 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 November to a water conversion "C" sands. 20, 1985 Kuparuk well 2D-2 was converted from a producer injector well as part of the full field waterflood effort. Water is being injected into both the "A" and RECEIVED 2 0 Alaska 0ii & 6a$ C0rls, 60rnmis~J;9,~ Anch0ra~,je 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ /¢/¢¢-&~-/~ ~;~-~..,¢-~ Title KUPARI_IK The space below for Commission use OPERAT IONS COORD I NATOR Date ! ?/! 8/85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. :' Post Office [ t00360 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 Kupar~k 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. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED s st:' o 0~ ~ 6~s Cor~s. Commission .¢ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCornpany - 6 - 7 - 8 2D- 2 - 4 - 5 -- '7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3' - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK: 0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 8O 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 21169 21135 21134 21183 21185 029-21246 21227 21213 21214 029-21058 21063 21062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 029-21037 21041- 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25653 25658 25658 25657 25656 25644 !! 25643 25655 25644 !! 25655 25642 2580 12/15/85 " 10/15/85 " 12/15/85 2579 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 2584 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 2584 12/15/85 " 12/15/85 " 12/15/85 " 12/15/85 2583 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2582 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 2575 10/15/85 " 12/15/85 " 10/15/85 2574 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 2575 10/15/85 " 10/15/85- " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 !! r ,ECEIV SE? 2 0 !BBS STATE OF ALASKA ALASK/~' L AND GAS CONSERVATION C ~MISSION SUNDRY NOTICES AND REPORT ON WELLS DRILLING WELL [] COMPLETED WELL ~-I OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 6. Lease Designation and Serial No. see attached 7. Permit No. see attached 8. APl Number so- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 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 [] 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). Io Pursuant to form 10-403, it is proposed that the attached list of]^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/:[5/85. The: second conversion to a line drive pattern will occur approximately :[2/:[5/85. Injection will be into the A and C sands. RECEIVED SE? 2 o 19 5 AlasV, a Oil & 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 Approved Copy .R. eturn~l / By Order of COMMISSIONER the Commission Date Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska. Ir~~-''~''' Post Offk . 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-05-85 TRANSMITTAL NO: 5331 Rf~TURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH A~L tx'HE FOLLOWING I'i'~l~. P~,EASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSHITTAL. PRESSURE FINALS/ASSORTED VENDEES CAMCO 1C-4 / STAT.lC GRADIENT 04-25-85 ' 2G-! ~ PRESS UF~E BUILD-UP 04-17-85 OTIb 2X-"5 '~ FLO~ING PRESSURE ~7-09-85 TOk,2UE TURN 2D-2~'''~ 24 HOUR PBU 04-21/22-~ 5 GUAGE #63137 LYNES/ 2X-4 "' PRESSURE RJEPOi{T 08-12-85 DRESSER ATLAS lA-5/ PRESSURE SURVEY 08-13-85 lB-2 '/ PRESSURE SURVEY 08-05/06-85 1Y_2~'' PRESSURE SURVEY .08-07-85 2C-8~/ PRESSURE SURVEY 08-16-85 2G-9~' PRESSURE SURVEY 08-22-85 2H-1 ~ PRESSURE SURVEY 08-24-85 2W-7~' PRESSURE SURVEY 08-22-85 2X-ll-/ PRE$SUR]~ bURVEY 08-25-85 RECEIPT ACKNL)WLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DRILLING L. JOHNSTON MOBIL* NSK CLERK DISTRIBUTION: %~. PASHER EXXON PHILLIPS OIL* J. RATHMELL* DATE: STATE OF ALASKA* SOHIO* UNION* K.TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompany ARCO Alaska, Inc. ~ Post Office l~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 07-02-85 TRANSMITTAL N0:5237 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-11i5B P.O. BOX 10'0360 - '/~A~ ~ ANCi!ORAGE, AK 99510 TRANSt.iITTED i!ER-C.'.~ITH ARE TIlE FOLLOWING IT~4S CKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TPJ[NSMITTAL. PRESSURE TEST FINALS CAMCO _c~ 9~: PBU 03-30-85/'' !Y-12 FALL-OFF 05-05-85/'/ OTIS 2E-9 2E-13 2E-!4 2E-!5 2U-14 2U-i6 2U-~-, 6 -~W-lO_ i 3B-!3 'TORQUE 1 STATIC GRADIENT STAT'lC GRADIENT c~-.- ~Tr' GRADIENT STATIC Cf'cAD !E NT PRESSURE BUiLD-UP PRESS UXE BUILD-UP STATIC GRADIENT PRESSURE BUiLD-UP STATIC GRADiEw"'~,_, STATIC G Fe%D '- E.','~T TURN STATIC ~,.ST'~.~' 24 !IR PBU PRESSURE BUILD-UP AC KN OV; LEDGED 06-11-85/'; 06-10-85/' 06-10-85/ o -o9-ss/ 06-17-85/ 06-06-85'f 06-13-85/ 0-6-16-85 / 06-08-85' 05-29-85/ 03-30/3!-85 GAUGE ~63132 ' 04-21/22-85 GAUGE' ~63137 ' 03-03/04-85 GAUGE ~2059 / DATE: ~S~_ATE 0,~ ALASI',A*~- SOIilO* UNION* X .TULZi~/VAULT ARCO Alaska, Post Ofh,..~ Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-18-85 TRANSMITTAL NO: 5219 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B °' ANCHOR GE, AK 99510 TTED HER~,~I~H ARE THE FOLLOWING ITI~¢~S. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF TItIS TRANSMITTAL. FINAL PRINTS/SCtIL CBL'S (ONE * OF EACH) 1E-15 - 11-01-84 RUN ~2 6994-7910 1L-16-'~ 11-05-84 RUN ~1 5693-7620 2D-2-/ 11-03-84 RUN 91 6760-7663 2D-4 j 11-04-84 RUN #1 6987-8492 2U-1/ 03-01-85 RUN #1 4550-7316 2U-2-~ 03-01-85 RUN #1 5850-8446 2U-13~' 02-05-85 RUN #1 4600-7786 2U-14~' 02-09-85 RUN #1 4900-6991 2U-16 '" 02-10-85 RUN #1 4600-6070 2W-5-- 11-25-84 RUN #1 5750-8059 2~-~-7 -'" 11-27-84 RUN~:~rl 4530-6241 2%~-8 /' 11-27-84 RUN ~rl 5140-7702 2X-16 " 11-07-84 RUN ~1 7900-9568 RECEIPT ACKNOWLEDGED: DISTiIIBUT ION: BPAE DRILLING*BL W. PASHER B. CURRIER L. JOHNSTON EXXON CHEVRON MOBIL PHILLIPS OIL D & M NSK CLERK*BL J. RATHMELL ' JuN 2 DA~: STATE OF ALASKA*BL/ SOHIO SE UNION K. ~UL IN/VAULT '* FILMS '.: li:'l' U l'::i'-,~ TI;]' i i---7 iF-7 i6-4 'i i1_-2 iL-2 ~ Q--..6 I Q-7 2A-- t 2A-4 2 A-5 ?.A-7 2B-t2 2C-.4 2C-4 2C-5 2C-5 2 D - 2 2I)-- t G 2. D-I 0 ... ARCO Alaska, Inc.`/' Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE'05 .... 15-.-85 '¥ I:;: A N.? M I T T,-., L. i"40 · .5 to '~' ,6 A I:;: C 0 A AT'FN: 'Al"O- t t I::'. O. B A N C I"i 0 I:;; T E D I--I IE R [..". H I ]' AND I::~iE'¥UF;:N · I._AYI(A, I I::'E C 0 R I) S C I... lie I:;; I< OX i 00360 ,::'~[;IE, Al< 995:i 0 H AI:;:E "l'l-Ilii; FOI...I...OW]:N[, I]"IEM,S'. I::'I...EAS;I; ACI<NOWI..IZI)C;E; [) N E Y I C- i'4 E D C 0 F:' Y 0 F" '!' H I L,' T F;: A N £' M I T'f' A L. E N C E 0 F:' Ii:: V E N T 5' I:;: U N L Y N E"' S R r-: C 0 I:;; l) E I:;:,'..~' R I..-'E l' R I I.'-: v,r:" L'1' N I!: S I:;: Ii: C. 0 I:;: D I!: I:;: S I_'FNI!-"5' I:::RESSLJF;:I:~ I(','OMB:'~'-F:'BtJ XISI"II:' 'C' SAND 'C' SANDS ONLY F:'BU 'C'5'AND F'BU TAG 1:'" ]]LL/~BHP T,-.,b F"II.../../,TBHi:' 'A' YAND.7 ~ l:'. I'-1 I:' ~;,' B H I:' I'-'ALL OI'"'F" TEST F"AL_L. OF"F 'I"E.i';'T SI~':I-'iP E/L. INli" YF'IN/TCL ~IJI::,'VIT. Y I_EAi( DE'I'EC'FION 'C' e,,.;. F'BU F'BU i:~ l..!i,l 'T'ORQUE F:'BU-I::'ULL. T AMERAI)A BO RIJN TOI:(qUE PBIJ-PUI_L TO AMFRADA BOM RUN 'FORQUE R U N T 0 R Q U IT. I:'BLI-I:'UI_.L T ,.qHERADA BO PBU F' B L1 I""BU RBU F'BU PBLI I'-" B U PBU F:'BU ACI<NOWLEDGED: '1' L/I"(N/{', i'i I: 1::: A D~-, ^ ~" 0 R (i~ U E 'f't.I R N / TURN/AMEF;:;%DAS F:~ C,! U F' ]"LI Fi:N / T U R N / A M I:.:". 1:;,' A I) A ;.~ l' l.I I:;: N / A H 17_ I:i: A D A S 0 R i;~ U E T U R N ? MBS I) F;,' I L I... I N C. l 0 H i'l.?;' ]" 0 i',l *- id 0 B I I._ N,':; I( C L. E F;: I( 04 -2 t ....8 5 0 4 -' '* '~ '"' o (') 4 -' 2 t - 85 04-26-85 04-'2t -85 04-25-85 ~4..- t 6-'85 04 -' 22_~,° .;,: 0,1-.2 t -85 04--22-8~ 01' I S O'F I $ CAMCO C A hi C [) CAMCO CAMCO CAMCO C A M C 0 0 T I S [;ANCO CAMCO OT I5' 04-t 6-85 O4-24-8'5 f,.~A . '], r::..: _. C:, m~ -Y - m;...,/ t.! .1 04-2t -85 OTIS CAMCO CAMCO · , ! BAkEI:< O4-23-85 04-2 t -8'"- 0 A. ") "Z _. 0 04--2t '"':" -' o .D 04-21 -85 BAI< ER/TOI'(Qur--' ]'URN OTIS BAI< ER/I'OI:iQLIE 0 T I Y B A I< E !:;: "1" lll:i: N BAI< ER/I'Oiq:F4UE ]'LJI:;:N O'F' <'' CAMCO CAMCO / CAMCO ii.(~V ~ ~ ~,,~- ,,, .. CAMCO ~'"':-'''- OTIS Ataske 0ii & Gas 0'1' 13~ An,.,%,.a,.,~ Oo;;Imiss;ar; - DATE: ..... ~' "' · X'STRTIF' 01-- AI_A$1(A · .',':' ,S' 0 H I 0 · U N I 0 N I<, TLI/. I N/VAUi_I" ARCO Alaska, Inc. Post Office b~,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 3, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton- Enclosed are Well Completion Reports for the following wells' 2D-2 2D-7 2G-14 If you have any questions, please call me at 263-4944. Sincerely, ~]. Gruber Associate Engineer JG/tw GRU6/LI03 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany tq[CEIVED u N 0 .~ 1~5 Gas Cons. ¢ommissior, Anchorage r=-'- STATE OF ALASKA ~--, ALASKA ._ AND GAS CONSERVATION C(, ~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 84-152 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21177 4. Location of well at surface 9. Unit or Lease Name 109' FNL, 677' FEL, Sec.26, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1174' FSL, 1331' FWL, Sec.2'3, TllN, RgE, UM 2D-2 At Total Depth 11. Field and Pool 1277' FSL, 1109' FWL, Sec.23, 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 127' RKBJ ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/09/84 10/15/84 11/10/84 N/A feet MSL 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7780'MD,6309'TVD 7689'MD,6229'TVD YES [~ NO [] 1884 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run FDC/CNL/DI L/GR, FDC/CNL/DIL, DI L/GR, BHCS/GR, Gyro, CBL/VDL/GR/CCL~ Temp./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" 62.5# H-40 Surf 117' 24" ;~04 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3281' 12-1/4" 750 sx AS Ill & 450 sx Class G 7" 26.0# J-55 Surf 7771' 8-1/2" 400 sx Class G & 250 s: 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) 7388' - 7390' 7435' - 7437' 3-1/2" 7302' 7273' 7411' ' 7412' 7439 w/1 spf 7415' - 7417' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7425' - 7426' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7430' - 7432' See attached Addendum. dated 4/12/85. 27. N/A PRODUCTION TEST .. Date First Production Method of Operation (Flowing, gas lift, etc.) bate of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.k. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE a~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED J U N 0 985. Alaska 0ii & Gas Cons. Commission Anchorage Form 10-407 C;RU6/WC30 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. G EO I::~G lC MARK[ERS NAME Top Upper Sand Base Upper Sand Top LoWer Sand Base Lower Sand MEAS. DEPTH 7301' 7312' 7371' 7504' TRUE VERT. DEPTH 5897' 5906' 5956' 6068' 30. FORMATION TESTS' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (d=~ted ~./!2/85) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: .If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ADDENDUM WELL: 10/22/84 11/04/84 2/o8/85 2/11/85 3/18/85 2D-2 RU Dowell to Arctic Pak 9-5/8" x 7" annulus. Press tst ins to 2200 psi. Pmp 300 bbls wtr wsh. Initial rate was 6 BPM @ 700 psi. Inc'd rate to 8 BPM w/800 psi. M&P 250 sx AS I cmt. Mx'd @ 15.7 to 16 ppg. Inj'd @ 6-3/4 BPM & 1000 psi. Pmp 55 bbls of Magcobar's csg pack fluid. Pmp @ 8 BPM @ 750 psi. Shut dn. ISIP = 300 psi. CIP @ 1835 hrs, 10/19/84. Shut ann vlv & secure well. RU & rn CBL/VDL/GR/CCL/gage ring; stuck gage ring @ 7240'. Pulled loose, POOH, LD gage ring. RBIH w/CBL/VDL/GR/CCL, log 7663'-6760', POOH. RU GCT & calibrate; tl failed, POOH.' Wait on parts. Rn GCT f/7665'-surf. Pmp total 36 bbls 7% HC1 acid w/.5% J120 friction reducer, .1% A250 inhibitor & 5% U66 mutual solvent. Displ w/82 bbls diesel flush. Acid in Place @ 1855 hrs, 2/7/85. Flow well f/cln up. Frac'd well in 7 stages w/284 bbls gelled diesel, 1008# of 100 mesh & 13,994# of 20/40 mesh. Log well w/temp & CCL log to 7600'-7150'. ~-rilli~ Superintendent RECEIVED J U N o Alaska 0il & Gas Cons, Commission Anchorage · DAte ARCO Alaska, Inc.~ Post~ Office ~_ _x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 i ..2'----' :Z"? "Ei~-4 ,? :E: !"I F:' 'i '"" i. 'i .... :.'ii' -.:'" ,S':. . ,r" '," ,' .I::' i '~.'-" - 0 2 ---:!i?-:'! ':" ).-'.-: i-'i F" i :'? ..... :}} 5? -. {!? !- :."" ii!i -.-- F:', U i'-..' 'i (} .... :Z':' .:"."---8'.'.'.:-. ,?.r:.'e I.-I I'-"" ! (.;: ..... 3 ;':/5 .... !!! ..4 ,ti: B' I.-i F:' "-'" ':::' - '7:' "-'? .... ::'-: -"- S' Ei H F' . '--:,'-;'--' ;7" --2. 'i · :5!} .-"i. " '=5' L.,"-.'-:...,, '--!'::' (.'? "7' .... Z,:? ..... :iii: 4 . ,':? B !..I F:' ~ I I ", '-'.'i', '7 ..... 2 'i -- ?,-:-"' /.5: B ,--, 1-' O i .... ;'".'.., ::5.-.--?3 2; :? .r:,"" H I::' :?.'-'-' 'i ..... :3~..:55, "Ei:'.5:E; l{. !"!'/:' :".- -~ .... ,".", ,:. .... !::.': '::5 /:.', f.~, ,r', · ... , -.- .... -...- ....... l"lr' ':7) "; : ;'" "': .... ,.':- :...':,,"1," : '"' 'i '? .... :.::- Z:- "" '~'' ~ r" "1-7:, i ..... i, '"-? ---- ,:::"'; ":'...? ;5...' E.': H F' (-.'? i .... 57.! {!i~'--{? 5: .... 3' B' I'-! F:' 2 X .... '"-, 2:: / (-.": -i. ..... i "':'.--' ..::::"'". ''?.. ,.'.,':" :.'.'..~'"I--~ '"' .. · ARCO- Alaska, I/" Post Office ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 O'f'I 5: [) 'T ]1; ;ii.' (3 "f' :[ ,:'--' (]'F .[ S [;, i"-;I; ,.":." C)'f' ]: .? (;) T ]. ,? O ...r :[ ,~....-, (;) T .[ £ H ,q I... I... ;[ T'.-: U I:;: 'T () b.! ..--'" !.( C.' T_'-', ;iL ,.q I< .. ARCO Alaska. Ir~c. ,s a subsidiary' of Allant cR,crq,:eidComparty Alaska, Inc~ Post Office 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 26, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 sUBJECT- Well Completion Reports Dear Mr. Chatterton- Enclosed are Well Completion Reports for the following wells' 2D-3 2D-4 If you have any questions, please call me at 263-4944. Sincerely, ~ Gruber Associate Engineer JG/tw GRUS/L56 Enclosures RECEIVED MAR 2 ? 1985 011 & Gas Cons. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~-'~'- STATE OF ALASKA ALASKA .AND GAS CONSERVATION CC _ilSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-152 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21177 4. Location of well at surface 9. Unit or Lease Name 109' FNL, 677' FEL, 5ec.26, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1174' FSL, 1331' FWL, Sec.23, T11N, RgE, UN 2D-2 At Total Depth 11. Field and Pool 1277' FSL, 1109' FWL, Sec.23, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.} I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 127' RKBJ ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/09/84 10/15/84 11/10/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD} 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7780'MD,6309'TVD 7689'MD,6229'TVD YES [] NO []} 1884 feet MD] 1500' (Approx) 22. Type Electric or Other Logs Run FDC/CNL/DIL/GR, FDC/CNL/DIL, D IL/GR, BHCS/GR, Gyro, CBL/VDL/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" 62.5# H-40 Surf 117i 24" 204 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3281' 12-1/4" 750 sx AS III & 450 sx Class G 7" 26.0# J-55 Surf 7771' 8-1/2" 400 sx Class G & 250 s. AS I 24. Perforations open to Production (MD+TV D of Top and Bottom and 25. TUBING R ECOR D interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7388' - 7390' 7435' - 7437' 3-1/2" 7302' 7273' 7411' - 7412' 7439 w/1 spf 7415' - 7417' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7425' - 7426' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7430' - 7432' See attached Addendum, 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 TEST PERIOD II~ , Flow Tubing Casing Pressure CALCULATED,4~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~F 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED 2 7 1985 Alaska Oil & Gas Cons. Commission ~Anchorage Form 10-407 GRUS/WC27 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ---:~ ~ ~ -.t-;~ -"': '~:'-':~ ......... ~-..~ :-.~...~._: ~ 30~ ~:,~, ~;:. " NAME laclude interval tested, pressure data, all fluids r~overed and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and:time Of each phase. .. . _ Top Upper Sand 7301' 5897' N/A Base Upper Sand 7~12' 5906, Top Lower Sand 7371 ' 5956' Base Lower sand 7504' 6068' '.. 31. LIST OF ATTACHMENTS Add~nd,,m 3~. I herebv cer~JfV zh~ the foregoing Js ~rue ~n~ correc~ ~o t~e best of mv ~nowle~ge Signed &~&~ ~~ 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 attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so 'state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). : Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas InjectiOn, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 10/22/84 11/04/84 2/o8/85 2/11/85 2D-2 RU Dowell to Arctic Pak 9-5/8" x 7" annulus. Press tst ins to 2200 psi. Pmp 300 bbls wtr wsh. Initial rate was 6 BPM @ 700 psi. Inc'd rate to 8 BPM w/800 psi. M&P 250 sx AS I cmt. Mx'd @ 15.7 to 16 ppg. Inj'd @ 6-3/4 BPM & 1000 psi. Pmp 55 bbls of Magcobar's csg pack fluid. Pmp @ 8 BPM @ 750 psi. Shut dn. ISIP = 300 psi. CIP @ 1835 hrs, 10/19/84. Shut ann vlv & secure well. RU & rn CBL/VDL/GR/CCL/gage ring; stuck gage ring @ 7240'. Pulled loose, POOH, LD gage ring. RBIH w/CBL/VDL/GR/CCL, log 7663'-6760', POOH. RU GCT & calibrate; tl failed, POOH. Wait on parts. Rn GCT f/7665'-surf. Pmp total 36 bbls 7% HC1 acid w/.5% J120 friction reducer, .1% A250 inhibitor & 5% U66 mutual solvent. Displ w/82 bbls diesel flush. Acid in Place @ 1855 hrs, 2/7/85. Flow well f/cln up. RECEIVED ~iAR 2 7 1985 Alaska 011 & Gas Cons. Commission Anchorage Drilling ~uperintendent ARCO Alaska, Inc. ~r~ Post Office B,.... 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 27, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-2 Dear Mr. Chatterton' Enclosed are copies of the 2D-2 Well History Addendums to include with the Well Completion Report, dated 01/10/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L201 'RECEIVED Enclosures MAR 0 8 1985 Alaska 0il & Gas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Commission Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field' Well Action Date Performed 1E- 15 Fracture 12/17/84 1F-6 Stressfrac 1/11/85 1L-4 Fracture 1/9/85 1L-5 Fracture 1/10/85 2C-5 Perforate 12/22/84 2C-6 Perforate 12/25/84 2D-1 Perforate 1/13/85 .... '2D--~2 Perforate 12/15/84 2D-3 Perforate 12/16/84 2D-8 Stressfrac 1/9/85 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED F 0 6 19B5 Alaska Oil & Gas Cons. commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I-)( OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-152 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21177 9. Unit or Lease Name KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION' 109' FNL, 677' FEL, SEC, 26, T11N, RgE, UH BOTTOMHOLE LOCATION' 1420' FSL, 1091' FWL, SEC. 23 5. Elevation in feet 127' 12. 10. Well Number 2D-2 11. Field and Pool , T11N, R9E, UM KUPARUK RIVER (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KU PARU K R I V ER (RKB) ADL 25653 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 i-IX 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). On December 15, 1984, the "A" sands of Kuparuk well 2D-2 were perforated for prod'uction. After testing the lubricator to 3000 psi, the well was shot with a wireline conveyed gun. Interval (MD)' 7388-7390' (ISPF) 7411', 7412', 7415-7417' 7425', 7426', 7430-7432' 7435-7437', 7439' RECEIVED FEB 0 6 1985 Alaska 0il & 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 2/4/85 Conditions of Approval, if any: 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 Alaska, Inc. --' - . Post Office - ~0 Anchor3ge, Amska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RETURN TO: PAGE 1 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-11t5B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH FINALS Schlumberger -Density Neutron "Poro" ~ 11 Il . Il I I ~.awl ! 10/16/84 Run 1 10/16/84 " 7100 - 7733 2"/5" 7100 - 7733 2"/5" ,, DiL_'sFL/GR 10/16/84 " 3276- 7758 2"/5" 10/16/84 " 7100- 7759 2"/5" " CPL Cyberlook 10/16/84 " 7100 - 7700 ~)~/~ 2B-i~-~'CPL Cyberlook · " Density Neutron "Poro" 10/03/84 Run 1 10/03/84 " 6400 - 7050 6400 - 7048 2"/5" " "Raw" 10/03/84 " 6400- 7048 2"/5" " DIL-SFL/GR 10/03/84 " 2805 - 7074 2"/5" ', 2D-3 II CPL Cyberlook Density Neutron "poro'' 10/07/84 Run 1 10/07/84 " 7200- 7710 7200 - 7878 2"/5" " "Raw" 10/07/84 " 7200 - 7878 2"/5" " DIL-SFL/GR /cat Receipt Acknowledged: B. Currier BPAE Chevron 10/08/84 " DISTRIBUTION Drilling W. Pasher Geology ' G. Phillips Mobil Phillips Oil 3624 - 7910 2"/5" AlasKa Oil & G~s Cons. comm~ssion State of ~~~ Sohio Union D&M NSK Ops. J. Rathme!l Well Files ARCO Alaska, Inc. ,.-~ Post Office [ ~0 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RETURN TO: PAGE 2 of 3 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. 1L-1 CPL Cyberlook ,,' 2,/5-DIL-$FL/OR 10/08/84 Run 1 '1o/o8/84 ,, 2359- 7470 2"/5" Density Neutron"Poro" 10/08/84 " 2359- 7447' " 2"/5" " " "Raw" 10/08/84 " 2359- 7447 " 2"/5" BHCS/GR 10/08/84 " 6750 - 7473 2W-6 CPL Cyberlook 11/06/84 Run 1 3198 - 7286 2"/5" DIL-SFL/OR 2"/5" Density Neutron '"Poro" 11/06/_84 " 3198- 7286 11/06/84 " 6600- 7261 " 2"/5" " " "Raw" 11/06/84 " '5600 - 7261 RFT "DIL-SFL/GR, FDC-CNL/GR" 11/07/84 ,, f /--~" 2"/5" Density Neutron "Poro" · · ! " 2"/5" " " "Raw" " 2"/5,, DIL-SFL/OR / .. /cat ---- Receipt Acknowledged: 10/31/84 10/31/84 10/31/84 10/31/84 DISTRIBUTION B. Currier BPAE Chevron Drilling ~Geology Mobil W. Pasher G. Phillips Phillips Oil Run 1 7350 -'.8050 3757 - 8080 " 3557 - 8050 " 3757 - 8080 · ' B 0 5 1985 Alaska 0it & Gas Cons. Commission State of Sohio Union D&M NSK Ops. J. Rathmell Well Files A~f% ~,l~,~km Ir~, ;& ~, ,~,~hKidiarv I~! AlJanticRich'lieldCemnanv ARCO Alaska, Inc. ~-"- Post Office F" Anchorage, A..,ska 99510 Telephone 907 277 5637 "RETURN TO: Date: 1/31/85 Transmittal No: 5014 PAGE 3 of 3 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. , CPI~ cyberl°gk 10/01/84 . Run 2 6050 ' 6520 " 2"/5" DIL-SFL/GR 10/01/84 " '3200- 6626 " 2"/5" Densi'ty Neutron "Raw" 10/01/84 " 6050 - 6600 " 2"/5" "' " "Poro" 10701/84 " 6050-- 6600 20-15 CPL CYberlook . 2"/5" FDC-CNL/GR "Poro" 2"/5" " "Raw" 10/15/84 10/15/84 lO/15/ s4 - Run 1 6350 - 6894 " 6350 - 6894 " 6350 - 6894 "2"/5" DIL2SFL/GR Str~atigraphic Dipmeter. SI-IDT" -. 10/15/84 10/'15/8_4 " 2728 - 6934 " 6350 - 6940 /cat Receipt Acknowledged: Bo Currier BPAE Chevron D&M DISTRIBUTION .. Drilling Geology'7~~ Mobil W. Pasher G. Phillips Phillips Oil NSK Ops. J. Rathmell Alaska 0il & Gas Cons. Commission Anchorage State of AK ~,~ Sohio Union Well Files ARCO Alaska, Ir~c. is a subsidiary, o! AllanhcRichfieldCompany post Ot ^,o~a 99510 Anchorage'_~'~76 1215 1. etephone ~u~ C. ~' chattertOn ommi ssi oner C~*e o¢ ~l~sk_~_ ation b~ ~"1 & ~as conserV Commissi°q 99501 SUBJ~C%: 2D-2 -~c surveY~f°r Den ' le~° . t~e P I ~o, - -~ the Well.C°?not rece~!e~t~ils, when the sub3~[., coverin9 ~" {orW~r .... s please c~ll me If you h~ve ~nY queStiOn ' s~ncerelY, ~. ~ssoc~te Engineer OG/tW GRu3/L47 EnclOsures RECEIVED JAN 1 5 1985 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc, is a SubSidiarY oi AttanticRich~ietdC°mpan¥ "'~-'"' STATE OF ALASKA .... ALASKA C _AND GAS CONSERVATION CO ,IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL (~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-152 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21177 ,, 4. Location of well at surface 9. Unit or Lease Name 109' FNL, 677' FEL, Sec.26, T11N, R9E, UN Kuparuk River Unit i LOCATIONS 1 10. Well Number At Top Producing Interval I VEPd}:IED I 1174' FSL, 1331' FWL, Sec.23, T11N, RgE, UM ISurf ~v, I 2D-2 At Total Depth~--~' '----'~'~- ~_ H' ~;! 11. Field and Po01 1277' FSL, 1109' FWL, Sec.23, T11N, 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 127' RKBJ ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/09/84 10/15/84 11/10/84 N/A feet MSL 1 17. Total Depth (MD+TVD} 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set [ 21.Thickness of Permafrost 7780'MD,6309'TVD 7689'MD,6229'TVD YES [] NO []I 1884 feet MDJ 1500' (Approx) 22. Type Electric or Other Logs Run FDC/CNL/DIL/GR, FDC/CNL/DI L, DIL/GR, BHCS/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24" 204 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3281' 12-1/4" 750 sx AS Ill & 450 sx Class G 7" 26.0# J-55 Surf 7771' 8-1/2" 400 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2" 7302' 7273' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED None ,, 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 CHOKESlZE IGAS-OILRATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATEDi~ 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 ECEI VED JAN. 1 5 1985 Alaska Oil &,Gas Cons. CommiSSion ~nchorago Form 10-407 CRU3/WC05 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. \ ! ' 30. : - · GEoLoGIcMA[RKERS ' ' ' - :" FORMATION TESTS ., 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 7301' 5897' N/A Base Upper Sand 7312' 5906' Top Lower Sand 7371' 5956' · Base Lower Sand 7504' 6068' · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~,"...~J-'~" ' 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: G'as 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 wh-ether from ground level (G L) 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 jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 10/22/84 2D-2 RU Dowell to Arctic Pak 9-5/8" x 7" annulus. Press tst ins to 2200 psi. Pmp 300 bbls wtr wsh. Initial rate was 6 BPM @ 700 psi. Inc'd rate to 8 BPM w/800 psi. M&P 250 sx AS I cmt. Mx'd @ 15.7 to 16 ppg. Inj'd @ 6-3/4 BPM'& 1000 psi. Pmp 55 bbls of Magcobar's csg pack fluid. Pmp @ 8 BPM @ 750 psi. Shut dn. ISIP = 300 psi. CIP @ 1835 hrs, 10/19/84. Shut ann vlv & secure well. RECEIVED MAR 0 8 1985 'Alaska Oil & Gas Cons. Commission Anchorage Drilling~Superint endent ~ 'I~ate AtlanticRichfieldCompany '~' Daily Well History-Initial Report Instructions: Prepare and submit the :"ll~tlal~ Rel~rt" 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 I County or Parish Alaska Field Lease or Unit Kuparuk River ADL 25653 Auth. or W.O. no. ITitle AFE 802930 I . Drilling Parker 191 API 50-029-21177 I State North Slope Borough Alaska IWell no. 2D-2 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate ]Hour Spudded 10/09/84 1630 hrs Date and depth as of 8:00 a.m. lO/lO/84 10/11/84 10112/84 10/13/84 thru 10/15/84 Complete record for each day reported 16" @ 117' 1700', (1603'), DD Wt. 9.5, PV 19, YP 20, PH 9, WL 10, Sol 6 Accept ri~ @ 1130 hrs, 10/9/84. NU diverter sys. 1630 hrs, 10/9/84. DD 12¼" hole to 1700'. 1710', Assumed vertical IA.R.Co's W.I. Prior status if a W.O. The above is correct Spud well @ 16" @ 117' 3301', (1601'), POOH to rn 9-5/8" csg Wt. 9.9, PV 21, YP 25, PH 9.0, WL 9.8, Sol 10 DD, drl & surv 12¼" hole to 3301', 10 std short trip, C&C f/9-5/8" csg, POH. 3.8°, N78.5W, 1813.92 TVD, 3.37 VS, .69, 3.38 15.6°, N69.5W, 2146.84 TVD, 57.81VS, 17.27, 55.54 29.0°, N66.5W, 2546.70 TVD, 223.76 VS, 75.64, 211.12 39.2°, N63.5W, 2802.36 TVD, 396.52 VS, 148.13, 367.98 51.5°, N61.5W, 3063.04 TVD, 658.71VS, 271.35, 600.30 Signature For form preparafi~-n andj~istribution, see Procedures Manual, ~ction 10, Drilling, Pages 86 and 87. 1814', 2152', 2586', 2895', 3266', 9-5/8" @ 3281' 3301', (0'), DO FC Wt. 9.4, PV 11, YP 7, PH 9.0, WL 12, Sol 5 POH to rn csg. RU & rn 82 its, 9-5/8", 36#, J-55 BTC csg w/FC @ 3199', FS @ 3281'. Cmt w/750 sx AS III @ 12.2 ppg, followed by 450 sx C1 "G" + 2% S1 + 0.2% D-46 @15.8 ppg. Displ using rig pmp, bump plug. CIP @ 1700 hrs, 10/11/84. ND diverter sys. Perform 100 sx top job. NU & tst BOPE to 250/3000 psi. TIH w/8½" BHA to 3199', tst csg to 1500 psi. DO FC. 9-5/8" @ 3281' 7485', (969'), Drlg ahead Wt. 9.8, PV 12, YP 6, PH 9.5, WL 7.4, Sol 7 DO FC, cmt, FS + 10' new hole. Conduct leak-off tst to 12.5 ppg EMW. DD, drl & surv 8½" hole to 7485'. 3645', 52.7°, N64.5W, 3295.85 TVD, 957.18 VS, 407.10N, 866.73W 3933', 50.8°, N68.5W, 3472.50 TVD, 1184.53 VS, 498.33N, 1074.97W 4212', 46.4°, NT1.5W, 3652.48 tVD, 1397.37 VS, 574.70N, 1273.85W 4618', 46.0°, N72.5W, 3933.49 TVD, 1689.04 VS, 665.25N, 1552.54W 5555', 44.7°, N69.5W, 4593.54 TVD, 2351.63 VS, 878.09N, 2182.53W 6181', 43.5°, N70.5W, 5041.28 TVD, 2788.01VS, 1024.46N, 2594.75W 7118', 36.3°, N68.5W, 5751.77 TVD, 3397.10 VS, 1241.23N, 3164.68W RECEIVED JAN 1 5 1 85 56.24% lDate ~l~,~ka 0ii I~T~ ~- 10/25/84-1, '~. vo~S. Cq~[r~ Superintendent ~.cri0rag8 AR3B-459-1-B INumber all daily well history forms consecutively as they are prepared for each well. Pag; no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "~ Re~e~t" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also whell operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completl'~;aild- representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District )Courtly or Parish 8State Alaska North Slope Borough Alaska Field iL ...... Unil IWell eD. Kuparuk River ADL 25653 2D-2 Auth. or W.O. no. ~Title AYE 802930 I Drilling Parker 191 API 50-029-21177 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 10/09/84 Date and depth Complete record for each day reported as of 8:00 a.m. 10/16/84 10/17/84 10/18/84 Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our I Prior status if a W.O. 1630 hrs 9-5/8" @ 3281' 7780', (295'), Logging Wt. 9.8, PV 16, YP 10, PH 9.0, WL 6.8, Sol 10 Drl & surv to 7780', circ, 50 std short trip, C&C f/logs, POOH. RU Schl, rn FDC/CNL/DIL/GR f/7764'-7100', FDC/CNL/DIL f/7767'-6300', DIL/GR f/7767'-3281', BHCS/GR f/7767'-7100'. 7" @ 7771' 7689' PBTD, (0'), Cmt'g 7" Wt. 9.8, PV 15, YP 6, PH 9.5, WL 6.8, Sol 10 Rn Sonic/BHC/GR, RD Schl. RIH, C&C f/7", POOH. RU & rn 195 its + mkr jt, 7", 26#, J-55 HF-ERW BTC csg w/FS @ 7771', FC @ 7690'. RU to cmt. 7" @ 7771' 7689' PBTD, RR Cmt w/400 sx Cl "G" + 3% KCL + .8% D-60 + .2% D-46 @ 15.8 ppg, displ w/284 bbls brine, bump plug w/3000 psi. CIP @ 0800 hfs, 10/16/84. ND BOPE, NU & tst tree to 3000 psi. RR @ 1345 hrs, 10/17/84. Old TD New TO iP.Depth 7689' I Released rig Date ~ Kind of rig 1345 hrs 10/17/84 I Rotary Classifications (oil, gas, etc.) 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 gasTest 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, ....... t R~2~/~ Signature I Date /itv Z~.~'f' ~ Drilling Superintendent For fo;m~reparation-a~d d~tribution, J~. J A N I 5 1985 see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Alaska 0il & Gas Cons. C0mmissi0a Anchora~o Number all daily well history forms consecutively I Page no. as they are prepared for each well. I 2 AR38-459-3-C Dlvliton of AllantlcRIchfleldCompan¥ $ UB-S URFA CE DIRECTIONAL SURVEY r~ UIDANCE F~ONTINUOUS [-~-] CO L Company Well Name Field/Location ATLANT[~ R~HF, I~LD COMPANY (109' F~:L. 677' FEL. S26. T11N. RgE. UM) , .K.U_PARUK, N,O,,RTH SLOPE, ALASKA _ . Job' Reference No. 69803 Lo~:ed ,By: MCBRIDE RECEIVED JAN 1 5 ]985 Alaska 0il & Gas Cons. Commission Anchorage iii Date DEC-04-1984 Computed By; STEVENS (;C'r DiR~;C[I'IdI'..'AI, SUR~F.¥ Ai,~C(.J A[,ASKA~ .INC., 2L~- 2 Ki. JPARLiK N t) R '.1.' H S [..('1 P I-.7, l';i*;f'~,JltlC"l"t',f" (.';i; l',.J t~ l'Ak(;t.'JT ,~Z i mu t.l) AZ!MU"t"tf r~b C I1 i., P u T ,R "1' i, ('] r, T~('. i)~t~F: ,3,-L)F:C-~,j4 , ' ' r' , '% I.t~,i'FkPL)I AfL ' VAI 1,~[. .... 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DI.S 1', F t.; F: 1 0.00 0.()0 O,OO N 0,00 0,00 0,00 O,O0 N 0.00 -0,08 0,09 0,10 N 0.12 -0.27 0.14 0.32 0,44 '0.28 0.15 0,58 ~ 0.55 -0.20 0,12 0,69 N 0,52 '0,25 0,23 0,Ol N 0,53 '0,51 0.16 0.52 N 0,79 -0.55 0.11 O.Ofl N 0,90 -0.3~ O, 30 t;, ~ 4 ['AGk 4 -0. ],4 0.17 U.05 N 0.~3 0.09 0,44 0,35 N 0,06 0.89 0.27 O,ZO k, 0,~9 2.02 0.13 0,05 S 2.23 3,07 0,16 0,41 S 3.52 4.22 0.07 0,()2 S 4,87 5,51 0,13 0,'12 S b,32 6.61 0,52 0,96 S 7.63 7,40 1,98 1.26 $ 8,61 11,40 3,2R 0,71 $ 12,74 12 '/. 0 () 1,' '1' 21,08 36,32 58.34 ~7.54 123.9~ lo7'9.5 218.15 275,20 3~1 ,fl4 418.85 2 86 371 3 59 3 o3 2 92 2 55 3 82 3 26 3 t~5 1,94 N 22,14 b.'19 N 36,65 14 62 N 5'1,2'6 25::L3 N 84,54 3'1.42 N 118.93 52,80 N 160,lq 72,53 N 20~,]5 95,58 N 258,54 123,03 N 319.05 155~85 N 38~.96 DLPAR"['URE A Z l M t,l T H I~EG ~ 1N 508.1 '4 61'].58 '137 , 5 '1 gO1. ,qt, 991 .45 1123,R5 'l. 2bo.O1 3"1~, (')2 4 ~ 2.23 !5~J6.6~ 3,54 3,44 0,31 1.bO 1,2g 1,01 0.50 'l,U3 O, 25 0,39 Iq.t,94 N 469.34 242,16 N 563,7~ 2qS,b7 N 674.45 355,25 N 785.45 ,1.2,~6 ~ 901,00 q6~,54 N 1071,76 b17.15 N 1138,20 563.16 N 1255,59 597.80 r4 135~,3~ 630991 r,! 1455,79 0,00 ,~ O 0 E 0,00 i~ 90 0 E 0,16 a 52 21 E 0,54 f~ 53 42 E 0,80 N 43 41E 0,~6 m 36 43 E O.81 i~ 41 9 E O,W5 l~ 56 21 E 1.13 k 41 Sa E U."18 ,~ 33 49 g t~, 35 ~ 9 4 R u,91 ~ 77 9 ~ 2,23 $ 88 47 W 3,55 S 83 24 ~ 4,91 S 82 47 W ~ 37 5 8~ ~7 ', 8,'11 5 81 41 w 1.2.76 S 86 4~ . 22,23 37.28 59,10 8B,19 124.57 168,07 218,'13 275,54 341,95 4~9.~3 613,59 991,~3 1124,07 1250,18 137~,10 1,t82,25 158o,62 'i f) [~ '[' ti 15 l, t..) 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'17 2973,14 ~06b, )-2 .3153,52 323't ' 24 3317,21 3393,30 ~460, u7 3531.92 0,,9 1290,o'1 h! 3291i.1.9 3596,63 O,V8 1317.16 N 3349.24 3657,23 2,17 1342,22 N 3404,43 3'112.77 0.00 136o.21 N 3454.5~ 3757,02 0,00 13Bb.b2 N ~94,27 3534,29 350d,93 3659,%6 3'114,90 3't59,05 a 66 34 w N o8 31 ~ a 08 22 ~ .Ii N 1' E: t,.: P 0 I. A ? ~; 1~ V A I, U I~ 5 [~' f') 7 30 ! 737! 7b04.00 7 'l ~ () I,:)ATI-:: 4-D[':C-S4 L"RO!4 09' 5897.28 hq06.42 59.55.59 b228.58 6308.55 577u.28 5"179.e2 5t{28.59 5940.8B 6101.b8 6181.55 DATtr; L)[" ~LJlRV[~:'t: 3-1~uV-R~ K~:l~b¥ ?,L.JSiiI'N('; [<bEvA'II, LJN; 127.0() t,' FNL , SuR~'AC IfF 677 ~FCT NoR i'H/'SO 12~2.61 12~5.08 1298,41 1327.5o 13~5.82 bOCA'ri(la 26 TI1N C~}uRDI tll'H g~Sq'/W t:ST 3272.0{,~ 3277.6 "i 3307.44 3372.47 3465.33 3494.2 't 12'/.0o ~'r 7301, O0 7371.,00 7b04, O0 7989,00 7780,00 b897.2~,~ hq06.42 5955,59 6067,SR 6228,5H b.]08.55 UlilGIN= 109' FNb, ~'/7' ~'l<t., T V O R ECT~N SU B-SEA NOR i H 5'i 70,28 12lt2, 5'179.42 12~5, 5628,59 5940, mB 1327, 6i01. bB 1366. 61~1,b5 13~5, 61 N 32't2, Ot~ 0~ I,,. 32'17,67 41 ~ 3307,44 56 I'~ J372 47 59 i~ 3455:33 82 N 3494.2? u M 7'1 8(), 0(I Wr,T,b t.,,flC A'f T UN Vl;RT,[CAI, A ;'1' T I); S ti F~ - S ~ A v ER '.[' I CA L 618l.b5 i,) E P h R T t,J R E h Z ] M U 'i H PEG MI bi J7b9.Ob ~ b~ 22 w SCHLUMBEROER ARCO ALABKA, INC. 20-2 KUPARUK NORTH SLOPE, ALASKA NOVEMBER 3, ]984 TVW PLOT FROM OCT DATA dOB REFERENCE 69803 SE WELL: 2D-2 SURFACE LOCATION: 109' FNL, 677' FEL, S26, T11N, R9E, UM VERTICAL PROJECTION -4000 -3000 -2000 - !ODO 0 0 ! 000 2000 3000 4000 NW .... ~ ~ . ; : : ~ . ~ - "'?'r"Y"!-'~-',~7--?-.?'- : ~ ~ ~ ~ ~ : ~ ~ ~ [rT ~T! 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PROJECTION ON VERTICAL PLANE OF AZIMUTH 294 St:ALEB IN VERTIC~ILO~PTH~ HORIZ SCALE = 1/IOOD IN/FT WELL: 2D-2 SURFACE LOCATION: 109' FNL, 677' FEL, S36, T11N, RgE, UM HORIZONTAL PROJECTION N~R'rH 2000 REF 69809 ~CRLE = 1/IOO0 IN/FT 1000 ' ' : : ' : : : ...:-..~---i.--~--L--i...~.--,--~-.! ...... .4.....,....;...;...1 ...... , ...... ;'- ::: L:...:; "!--t'i-'~--kf'f-!--i-' ..:...; ........... .L.i .......... ~....--~---~--~---;---t.-.,--*-.+--~--~-~--.;--.,---;--b.~-.;---;--.,--k.F+-~--?i-+--~--:--~-- ~ ...... I -2000 ...... ' ......... ~:' ,:~ '--' "' '+-'"-'+-+'--'+-"-' ........... : .. , ..... ~ ..... ...i_.i_.,_.?.!._i._.~_..r_.:._. ..-,---.~-...~---.:---.t--,---~--~-.----., , .:: , : ..... ---N--; -~---L-~.-;-.i-.-; .... 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',._~_ £ .......... · .~ ....... ;..; ................ ! ...... .: ...... ~...."..--:---:....;-..-,...~..; ............... ,.'--:-.:---:--:--I---:---~---:--~--L:-.-:-.-: ....... ~---- - ~-----; ....... ;--:- .... l--------:---;--.:--+-: ...... i.--~ ........ :--: .~ ........... ~ ........ ~.. ;"~":"--~-- ll.~'ml:.'';'l';l 1~ ...... : 111: ....... il. i--.~---;-.-;---!.-ll---;-~..:-.-j.--:---!---;--:---i---:--i-..L-----j--.'` ..... Z..i...i...;..2 .C..Z..j...;...;...:._-...;...,....'..; ..... [......:.. :.2.. ;...~_..: ._:.. ;-~' ..... :---+---:---i.--~--;---'.-;--~-; ......... ;. !...: .......... ;...ii ..................- i f' ...............:: ~. I. .................. . . : ;,; .................: ; .I....,. ............... . i. ....... .. ........ ;...~...;...,~....L..:...,!., ~ · i ! ! ................ ~"I '" ~- ........: 4,; ............ . Ii ............... ". ................. . ,~, ................. ~.! ..... ~--.~---...~ ............... ;: .......... . , .Ii -6000 -S000 -4000 -3000 -2000 - 1000 0 100OAsTE -4000 SOUTH -6000 -?000 wEST ' Su~gesteu form to be inserted in each "Active" well folder to d:eck for timely ccmpliance with our regulations. · · Op~ratbr, ~el 1 Nan.' and Reports and Materials to be received by: , Date Required Date Received Remarks . . ... Completion Report Yes ij .... ? ,~ .... .?;.~, _ ', · .. Core Chips '' ~/~ .-;.~-'-~_ ~: ~/~/~,.~.~...~.~-/ . .-f c'/v ~. . . Registered Survey Plat Inclination Sur'~ey ~'~ , Drill Stm Test Re~s ~s Yes . ARCO Alaska, Inc. Post Office Box' 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1984 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 300I Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached are our notices of Intention to following Kuparuk Field wells' 2D-l, 2D-2, 2D-3 If you have any questions, please call me at perforate the 263-4253. Mike t. taue Kuparuk Operations Coordinator MLL / kmc Attachment (In Triplicate) RECEIVED Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA,, INC, 3. Address P. O. BOX 100360, 4. Location of Well SURFACE LOCATION° T11N, R9E, UM BOTTOMHOLE LOCATION' 23, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 127 ' (RKB) 12. ANCHORAGE~ ALASKA 99510 109' FNL, 677' FEL, SEC. 26, 1420' FSL, 1091' FWL, SEC. UM 6. Lease Designation and Serial No. ADL 25653 7. Permit No. 84-152 8. APl Number 50- 029-21177 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 2D-2 11. Field and Pool KUPARUK RIVER KUPARUK RIVER POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT FIELD OIL NOTICE OF INTENTION TO: (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.) 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). It is proposed that the "A" for production. Procedures wireline conveyed gun under sand in Kuparuk well 2D-2 be perforated call for the well to be perforated with a lubricator. Proposed Intervals (MD)' 7425' 7426' (1SPF) 7430-7432' 7435-7439' 7443-7445' ANTICIPATED START DATE' December 14, 1984 Work t!e~rt~t RECEIVED DEC t 21984 Alaska Oil & Gas Cons. C:~mmission Anchorage 14. I hereby certifzy~,hat, cthe foregoin is ue and correct to the best of my knowledge. ~ ~/~Z_~_9~ KUPARUK Signed~.~, Title OPERAT IONS The space below for Commission use COORDINATOR Date 12/12/84 Conditions of Approval, if any: Approved by l!llllllllt' {t{illEI1 BY L0,".,~lE 1L ~.pproved Copy Returned 1.2 -/;7 By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, · post Otlice Box 100360 . Anchorage, Alaska 99510 Telephone 907 276 1215 November 21, 1984 Mr. C. V. chatterton commissioner state of Alaska Alaska Oil & Gas Conservation commission · Drive 3001 ?orcup~e 99501 Anchorage, ~ SUBJECT' Monthly Reports · Dear Mr. ChattertOn' Enclosed are the Monthly state ReportS for the following wells 2X-16 WSP #2 1L-1 2D-3 2D-2 2X-15 2X-14 2G-14 2G-15 1L-16 1L-15 2D-1 2G-16 2W-5 2E-16 Sincerely, . /~A~a Drilling Engineer jBK/sH/tw' HILL/05 Enclosures RECEIVED Alas/<a 0il & Gas Cons. Commission Anchora,3e Inc- Is a Subsidiary o! AtlanticRichlletdc°mpan¥ STATE OF ALASKA ALASK, . OIL AND GAS CONSERVATION ~. jIv, MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well I~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-152 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21177 UM 4. Location of Well at surface 109' FNL, 677' FEL, Se¢.26, T11N, RgE, 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 127' RKB, PAD 90' APL 25653 ALK 2579 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2D-2 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. October ,19 84 12. Depth at end of month, footage drilled, fishi/g~j~.bs~,, d/.~er~c!ional drilling problems, spud date, remarks Spudded well ~ 1630 hfs, ~;),41~Nff~r. Drld 12-1/4" hole to 3301'. 9-5/8" csg. Drld 8-1/2" hole to 7780'TD as of 10/15/84. Ran logs. csg. PBTD=7689'. Secured well + RR @ 1345 hfs, 10/1.~7/84. Ran, cmted & tested Ran, cmtd & tstd 7" 13. Casing or liner ru.n and quantities of cement, results of pressure tests · 9-5/8" 36#, J-55, BTC csg w/shoe ~ 3281'. Cmtd w/750 sxs AS II I + 450 sxs Class "G". 7" 26# J-55 HF-ERW BTC csg w/shoe @ 7771' Cmtd w/400 sxs Class "G" 14. Coring resume and brief description N/A 15. Logs run and depth where run FDC/CNL/DIL/GR f/7764' - 7100' FDC/C~L/DIL f/7767' - 6300' DIL/GR f/7767' - 3281'. BHCS/GR f/7767' - 7100' RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data N/A Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. {/~/'~'~.,~¢_/~,~ .... ' .... Area Drilling Engineer_DATE ,~/_,~/4¢~/~' S,GNED \//~/JZ~-~/~//.,,~ ~/ .~_ ~__~?[,,~'~ /I / Et::: ............. NOTE-R~rt o~/t~_.lg/¢m____ is required for each calendar month, regardless of the status of operations, and must bellied i'n duplicate with the Alaska Oil and Gas Conserv/~tjcfn Commission by the 15th.of the succeeding month, unless otherwise directed· ¢~, ~n~n~ v H ! LL/MR22 Submit in duplicate ARCO Alaska, in --' Post Office .360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 11/07/84 Transmittal No: 4~38 RETURN TO: -. ~C0 ALAS~, INC. - _ AT~:. Records Clerk ' ~0. Box 100~60 /~chorage, ~ 99510 - . ~Transmitted here~th are the folding items. Please acknowledge receipt and retu~ one signed copy of this tra~ttal. OH LIS TAPES/Schlumberger ,~69612 1L-1 10/08/84 Run 1 '~#69613 1L-2 10/01/84 Run 2 J #69591 2B-13 10/03/84 Run 1 /#69596 2G-12 9/23/84 " /#69594 2G-14 10/08/84 " ~"#69595 2D-3 10/08/84 " f #69623 2D-2 10/16/84 " 2317 - 7486.5 ,,'!~~ - /cat Receipt Acknowledged: B. Currier Drilling BPAE Geology Chevron Mobil D & M NSK Ops. Date: DISTRIBUTION W. Pasher G. Phillips Phillips 0il J. Rathmell State of AK Sohio Union Well Files .. MEMOR -,: OUM TO: THRU: of Alaska ALASKA OIL AND GAS CONSERVATION COFR.-~ISSION C. V/~~te~ton Chai~~/ Lonnie C. Smith :?' -~.~ Commissioner FROM: Edgar W. S±pple, SUBJECT: DATE: FILE NO: TELEPHONE NO: October 15, 1984 D.51.77 Witness BOPE Test on ARCO' s Kuparuk 2D-2, Sec. 26, TllN,R9E,UM, Permit No. 84-152, Parker Rig 191. ~nursday~ October 11, 1984: I traveled this date from ARCO's ~ru~ ~G~15',"subj-ect o~fanother report, to ARCO's Kuparuk 2D-2, Parker Rig 191, to witness a BOPE test. The drilling contractor was in the process of nippting up. Friday, October !2, 1984: The BOPE test commenced at 12:00 am and was C~ci'ud~d 'at 1:10 am. There were no failures. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk 2D-2, Parker Rig 191. At tacP~nent 02-00IA(Rev. 10/79) 0&G f/4 5/s4 STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Date Well Representative /~ Permit t~ ~pF-~/~ ~ V/Casing Set @ 32 Drillin~ Contractor Location, General ~ Well SignO General Housekeeping /p~ Rig ~ ~ Reserve Pit ~/~,~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack ~-~ Annular Preventer Pipe Rams B~lind Rams ~... Choke Line Valves H.C.R. Valve c i%k ,Valve Ri~ ~//?/ Representative ~, ~/'-Z ACCUMULATOR SYSTEM Full Charge Pressure ~C~c) psig Pressure After Closure / ~ psig / Pump incr. clos. pres. 200 psig ~:' min~'(/.sec. Full Charge Pre~sur~ttained: ~ min~ Remote ~ / ~ Blinds switch cover Kelly and Floor Safety Vaives Test Pressure Upper Kell~~~x Test Pressure / ~ Lower Kelly~ ~i Test Pressure ~~ Ball Type / ~/~ Test Pressure ~ ~ ~ ~ Inside BOP ~/~ Test Pressure ~~ Choke Manifold Test Pressure 3m W o No. flanges ~ Oo Adjustable Chokes ~ ~O~ ~,~ Hydrauically operated choke ~ Test Results: Failures --~ O -~ ..... Test Time /. hrs. /O /Z]/// Repair or Replacement of failed equipment to be made within KL'jt~; days and Inspector/ Co~ission~ice notified. -- i '/ _. Distribution orig. - A0&GCC cc - Operator cc - Supervisor August 24, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re ;- Kuparuk River Unit 2D-2 ARCO Alaska, Inc, Permit No, 84-152 Sur. Loc. 109'F~L, 677'FEL, Sec. 26, TllN, R9E, Btmhole Loc. 1420'FSL, !091'F~, Sec. 23, TllN, R9E, UM. Dear Mr, Kewin: Enclosed i8 the approved application for permit 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 reqf~ired. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys -and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of'any waters of the'State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to comencing installation of the blowout prevention ~>~r. Jeffrey B. Kewin Kuparuk River Unit 2D-2 August 24, !984 equipment so that a representative of the Commission may be ~. · present to witness ~estlng of the equipment before the surface casing shoe is drilled. Mhere 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 abandor~ent, please give this office adequate advance notification so that we may have a wztne~s present Very truly yours, C. V. Chatterton Chairman o f Alaska Oil and Gas Conservation Comission BY ORDER OF TH.E CO~{ISSION Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. ARCO Alaska, Inc. ?% Post Office B 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 21, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2D-2 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2D-2, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on October IO, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Ke~n Area Dril ling Engineer~ JBK/JG/tw GRU8/L113 Attachments RECEIVED AUG 2 21 It AlasKa Oil & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (JiL AND GAS CONSERVATION CO~v, MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL FIEDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE[] STRATIGRAPHIC[] SINGLE ZONE ~, MULTIPLE ZONEi~ 9. Unit or lease name Kuparuk River 10. Well number 2D-2 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 109' FNL, 677' FEL, Sec.26, T11N, RgE, UH At top of proposed producing interval 1277' FSL, 1418' FWL, Sec.23, TllN, RgE, UM At total depth 1420' FSL, 1091' FWL, Sec. 23, TllN, RgE, UM 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) [ 6. Lease designation and serial no. RKB 127', PAD 90' I ADL 25653 ALK 2579 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 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2D-3 well 60' @ surface feet 16. Proposed depth (MD & TVD) 7779' MD, 6243' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1725 feet. 21 14. Distance to nearest property or lease line miles 109 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 46 o (see 20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 10/10/84 2737 psig@ 80°F Surface 3142 psig@ 610~, ft. TD (TVD) i Hole [24" I12-1/4" 8-1/2" SIZE Casing Weight 16" 62.5# 9-5/8" 36. O# 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade I Couplingl Length "-40 / Weldl J-55 HF1ERW BTCI3219' ,J-55 "F1ERW BTCf6207' SETTING DEPTH MD TOP TVD 80' 37' I 37' I 37' 37' I I 36' I I 36' MD BOTTOM TVD 117' 117' 3256' 13097' I 7779' 16243' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 750 sx Arctic Set III & 450 sx Class G 300 sx Class G I ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7779'MD (6243' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 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 2737 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annu]i through the permafrost interval. 2D-2 will be 60' away from 2D-3 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any (see attached sheet) -23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED The space below f~/Commissiy~ Samples required [~YES Permit number APPROVED BY TITLE Area Drilling Engineer DATE CONDITIONS OF APPROVAL IDirectional Survey required [~,Y' ES [-INO Mud log required I APl number I--lYES .[~]NO [ 50-- 0"/.,,~ ."Z. It ~/7 Approval date I SEE COVER LETTER FOR OTHER REQUIREMENTS < ,COMMISSIONER DATE August 24 198/~ %~ by order of the Commission ' ' --[ Submit in triplicate Fgrm 10~01 GRU8/PD47 Permit to Drill 2D-2 interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED AUG 2 2.198~, Alaska 0il & Gas Cons. Commission Anchorage IO, 2: RE~,ISED. PROPOSAL _.N_O__R]'H. S '.I~O_P.E_,_' AL^_I~]II[6._ ..... , . 1000 _ 2000 ~000 BASE PERRAFROST TYD-I$02 ~OP TVD-1725 TND-172S DEP-O 3 TOP UGNU SNDS -TVD-2127 THD-2130 DEP-43 15 21 BUILD 3 DEG PER 100 FT 7...7 TOP ~d SAK SNDS TVD-2Z27 THD-2780 DEP-284 ~ R-12 TVD-~047 TPID-~185 DEP-532 ~ EOC CCSG PT) TVD-3OgT THD-:~:2$6 OEP-S81 4000 AVERAGE ANGLE' 45 DEG 55 MI N 5000 K-5 TVD-4867 T1'1D-5800 DEP-Z40<:J 6000 7000 [. i' 1 000 2OO0 VERTICAL SECT[ON 3000 TOP'UPPR SNDS TVD-5898 TND-7282 OEP-3474 TOP LOgR SNDS TVD-5982 TND-7403 DEP-3561 ', TARGET C~T~ TVD-6001 THD-T430 DEP-3581 BASE KUP SNDS TVD-6104 THO-7579 DEP=~687 TD (LOG PT) TVD-6243 THD-7779 DEP-38~I 4,000 ........ RECEIVED AUG 2 21.98~ Alaska Oil & Gas Cons. Commission Anchorage i, SI~LE 1 11000 Tl1~, ! , Surface DJ verier System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 1G" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/lO" side outlets. 5. 10" ball valves, hydraulically actuated~ ~/10" lines to reserve pit. Velvms to open auto~tical~y upon closure of ~nnular preventer. ~. 20" 2000 psi ennuler preventer. 7. 20" be~ nipple. 4 Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify Ghat Dail 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 fl o~ to surface 'is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in ~ell under any circumstances. 16" Conductor RECEIVED AUG 2 Oil & Gas Cons. Commission Anchorage I 9 ' BLIN~D ? ( ] S DIAGRAM fl !3-5/8" 5000 PSi RSRRA BOP STACK 1. 16" - 2000 psi lankco starting head ll" - 3000 psi casing head 3. ll" - 3000 psi x 13-5/B' - 5000 psi s~acer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi Oriiiing spool 5. 13-5/B' - 5000 psi pipe rams 6. 13-5/8' - 5000 psi drilling spool w/choke ane kill lines 7. 13-5/B" - 5000 psi' pi~e rants 8. !3-5/B' - 5000 psi blind rams 13-~/8~ - 5000 psi annular ACCUMULATOR CAPAC)T9' TEST '1. CHECK AND PILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WiTH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WiTlt 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL'UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REHAINING AFTER ALL UNITS ARE CLOSED WiTH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT !S 45 SECONDS CLOSING TIME AND 1200 PSI RD~b~iNING PR.oSUR~. BOP STACK .-!. '-FILL BOP STACK AND HAJiIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY REiFKACT- DO. PREDETEPJtINE DEPTH THAT TEST PLUG WILL SE. AT AND SE. AT IN WELLHEAD. RUN IN LOCX DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREYEI~gFER AND 'V'.AJ~'v~S )J'~D~i OF DON~T TEST ACAINST CLOSED ~. TEST ALL COMPONENTS TO Z~O PSI AND HOL~'FOR MI NU~ ,._. 5.INCREASE PRESSURE TO 1BOO PSI AND HOLE FOR MINUTES. BLEED TO ZERO PSi. 6.OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PiPE RAHS. 7. iNCREASE PRESSURE TO 3000 PSi AND HOLD FOR ~O ~i~9'?P~SSL~ DOWNST~ OF ChO}CE ]SO~?]O~ VJ-quL¥]~S_ TD ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED .~t~NIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAH OF VALVE AND ZERO PSi DOWNSTREAM. BLEED SYSTEI4 TO ZERO PSI. 9.OPEN TOP SE'F DF PiPE Rt-J~J AND CLOSE SOT'FDM SET, OF PIPE RAHS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR iD MINUTES BLEED TO ZERO PSi. 11. OPEN BOTTOM SET OF PIPE P. AHS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAHS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVE~ TEST PLUG. HAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC D."ESEL AND ALL VALVES ARE SE'F iN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSi. 14. TEST KELLY COCKS AND iNSIDE BOP TO 3000 PSi wiTH KOOHEY PUMP. ).5. RECORD TEST INFORMAT.?ON ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFO.;U4 COMPLETE DOPE TEST ONCE A ~EEK AND FUNC- TIONALLY OPERATE BOPE DAILY. ARCO Alaska, Inc~-'~ Post Office ,.,ax 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 JD- July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2D Pad Wells 1-4, 13-16 Dear Elaine- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L25 Enclosure RECEIVED J U L t ,~. i~4 q!aska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany E Il-- I I ' · ~ · I /~-~.~ I -.., · , DRILL ~T£ 2. D CONDUCTORS · · { AS- BUILT LOCATIONS i WELL 1 Y -- 5,954,045,13 Lat, 70°17'07.882. Z'' _ _ ~ ~ X = 529,129.90 Long, 149¢45'51.288 153' FNL, 656'FEL gl. 89.7 ',~ 86.1' _ ... , ] WELL Z Y = 5,954,089.31 L~t. 70°~7'0B.5i85" i 1[ X = 5Zg,089.~4,one.' ~ 149045'SZ.468''. ;~ 109' FNL~ 677'FEL EL. B9.6'~ O,O, 86.3' '~ WELL ~ Y = 5,954,[53.4Z Lot. 70°17~08.7558'' ' X= 5~g~048.58 Lon~. 149045'53.648'' ........... 65' FNL, 717'FEL IL. 8g.7'~ ~.O. 86.~.'. WELL 4 Y= 5,954,177.4E Lot. 70017'09.1880'' 4' X= 529,008.~ L~.i49°45'D4.SZ2'' g~ 21'FNLz757'FEL ., E~. 89. e',0.0.86.3' ''' ~ ;.,~ ~ ~ 6T ~ 5 ....... WELL 13 Y= 5,953,508.4g Lot. 70°17'O~,5e42'' X= 529,6~4.74 Lo~.{49045'36.95~'' 69~' FNL, i44' FEL EL. 89.6', O.O 86 WELL 14 Y · 5,953,552.6{ Lat. 70017'05.0204'' X= 52g,584.2~ L~. }4g°45'38.{08'' . 647' FNL, I~' FEL EL. 89.8', 0.~. 86 8' ,, , ,, .... WELL 15 Y = 5,953,596.~ L~t. 70~17 ' 03 .4564'' X = 529,543.57_ Lo~. 149°45'~9.287'' 603' FNL, 225' FEL EL. 89.6', O.O 87. ~ wELL-~ Y", 5,955,640. Sl L=t. 70°{7'05.89{0'' [ X = 529,503.~ L~g, 149o46'40.464 { 559'FNL, 265'~EL EL. 89.5', 0.0.86.5' , i , , j .... CONDUCTORS !-4~ 1~-16 AS'BUILT 49ih LOCATED IN PROTRACTED $ECTICN 26 JUL I ~ !~ '-~ ~'~"""~''~"'"' TOWNSHIP ii N RANGE DE., UMIAT MERIDAN. · ' Aaska Oil & Gas Cons. BASIS OF ELEVATION [~ TBM 3D-[~ BASIS OF ~Oc~ION · IS ~NUMENT9 ~D NORTH a ~DSOUTH ~ER LHD ~AS~. ~ ELEV. TAKEN AT TOE OF PAD,S.W. OF WELL. ~ DAVID FILUCCt5276- . ..... .... .............. I HEREBY CERTIFY THAT { AM PRO~RLY R~OISTERE~ ] ~~ B ~AT THIS ~T REPRESENTS. A SURV~ MADE '~~ "~ { ~ ' [/ - ' ' 'DRILL SIY~.2-D ' ~ ~!~D'S' z'9~ ~NDUCTOR D.S. ~-D LOCATION D~t~on: J.n ~ ~.n~:N~ 9.05~'~~ :..- ,. and 11) (4) Cas~; H~7'~/ ~-~3 ¢~ 12' '(12 thru 20) 13,. 14. 15. 16. 17. 18. 1'9. 20. (s) BoPE (21 thru 24) 21. 22. 23. 24. Is s~ Is bp r' the' only., affected pa~ty' ...~ ..... ' . :~ Can'~e~t be'apprbved before t e~LaaY wai'; i i l'.ll~!! il ed: . o .............. , . ' 'om ProPety i~ ]i .'. proper di'stance.'~.fr r .. ' istanc from th Well ' proper d' e o er s .......... e available in this';pool , bore plat, included ..... Does"Oper~tv~!i' ~aPe abond 'in for~e ~' · ieee. Is a ConServationlorder needed' ' .- - eeeeeeeeeee®eee.eeeee®eeeee®eeeeeeeeee Is admini trative approVal needed S e~eeeeeeee.eeeeeeee ..e'eeeeeeeeeee. Is conductor string provided ....................... ' ...... -. Is enough cement.used to circulate'on co~duct°r an~ ~rf~c~ . Will cement, tie in surface and intermediate or production ,strings ... ~'~ Will cement cover all-known.pr0duc~ive horizons ..................... ~ '__ Will surface casing protect fresh water zones ...' . " Will all, casing give adequate safety in collapse, te~i;~ ~nd b~rs~ . 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 .......... ' .................... ~J~ Are.necessary diagrams of diverter and BOP equipment attached ....... ~/~ Does BOPE/have sufficient pressure rating - Test to',~-~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional· Remarks: ~AZ glo -~Q- ~/A4 2~ · / ' ;r' D . TWE R E ,d Geology: Engineering: HWK ~ LjCK~/ BEW %----- WVA HJH /~/~ JAL rev: 12/08/83 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS ~, AREA NO. SHORE Ill Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. R£C£1VF-D NOVt Alask~ Oil & Gas Cons. Commission Anchorage ** TaPE HEADER ** SERVICE NA~E :EDIT DATE; :R4/11/ I ORTG~N :0000 TAPE N~E :~6~3 CONTINI!ATISN ~ :01 PREVIOUS 'iCaP~ : COMMENTS : ** INFOR~ATION . : 102a I~N TT O0 O oO 0 000 000 000 oho (,',ATE 000 000 000 000 000 0~0 0 O0 000 000 016 OO4 u07 OO2 O04, On2 0~2 O0 3 065 (.)65 065 065 065 065 O65 O65 06b TAPE DF, N$ITY = gnO i~PI OA~E LnGGED !.b 0C1' !.,D P: T t.4 A f., (s'f' E; A 0 ENTRY B t.,r3CKS "P Y P t'; S 1 Z t'.7: R i]{; P R C Fl g F:. E tv, T R ¥ · "' 1 66 0 4 I 66 ~ 4 7 3 6 0 9 4.: 65 .11.'.~ , 1 ,:~ 1 66 1. DATUN 8PF'CIFICATTOD.~ RL( CK5 ~N~M SWRViPE ,%~,RVICE '?h,T'i APl AP! .aP:[ ~PT FILE SiZE ID DEPT' SFLU nil ILD nIL :IbM OIL SP P i t, gl, iC 'GR : NPHi', PROCNSS TYPE C[,~,SS MUD NO, 6o ooo~oooooooooo 6~ oooooooooooooo 6~ oooooooooooooo ~ ooo,~oooooooooo ~, ooo~,oooooooooo 1 6B 000 0 00000000 68 00000000000000 ~8 O0000000C)O000fi DEPT 7799,5000 SF'Li.i GR -099.250~..q CAt,i NR~T -q99. 2500 ~CNb -090. ~50,.,~ DE;PT 7400.000() AFl...~u 3,, ~ 54.3 RNRA 757. DEPT 72(.)o. 000o 8 P - 2 G R 1. 01 ~ ~CNL 70~, O(.)O0 OEPT NRAT FCNL DEPr N R A. T rCNL 2.4102 T'Lr] ~05,6875 PT 0.m375 PHOB 3.5352 ~FHI 9~. 0625 PT 10,()234 P.HO~3 4.5 i 56 w p H I 8. c) 625 j [,,, ,n '11 , 6 G 75 r) 'ir o · ~969 .!. 1 ! 1 $ ~"FHI 4,o1.02 5O00 1'1o7 2988 F'pFII 3,2168 TbD 10~.9376 2. R 945 ~,~ P H 1 q.5()39 TLr) 204,5000 UT 1. O, n547 PHOB 3.9863 ,<(PHI 5..12 n 3 t I, ,h , - 99 q. 2500 ~' p H 1 - 995). 2 !500 1 05,3'750 GH -09q,2500 -o~q. 2500 2.12 R 9 T L ~'i 101 ,2500 2,46~!8 PRH[3 40. 2344 2.0293 lb,m, I U9. 0625 2.,4238 F)R!'tO 47. 9004 6,55H6 T!.,~ 91.687b GR 2.]379 DRHO 4,8711 'IbM 95.7500 GR 2.4238 DRHO 35.8398 NCNb 3.0906 Tbm 95.0000 2.4'72'1 32.B613 NCNb 2,~965 Tl.,)i 29,3945 ~!CNL 3.150i Tb~ 1,:13,5625 (JR ~.3164 DRHO ~7.607g NCN'b -999. 250() 105 8125 -999,2500 2.1914 109.0000 0,0§79 2192.0000 2.0605 1.05.0000 0.111,3 195B,0000 6.523,~ '19 4375 -O:0(.)39 3:2.92. 0000 ,4 78¢)1 93 6875 0 0225 2500 O00O 128,0000 0,0190 24,7610000 3,11.13 ,0()15 2033.0000 3. 200.0 247,25 O0 0.00 P 9 20~3. O00t) -99.,2500 999.2500 -g9g.2500 DEPT 6ROn. 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