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Home My WebLink About186-103KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϳͲĞĐͲϮϱ,ĂůůŝďƵƌƚŽŶ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵ͘tŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ ƚƚŶ͗͘EĂƚƵƌĂůZĞƐŽƵƌĐĞdĞĐŚŶŝĐŝĂŶƚƚŶ͗&ĂŶŶǇ,ĂƌŽƵŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬϲϵϬϬƌĐƚŝĐůǀĚ͘ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϭϴKĨĨŝĐĞ͗ϵϬϳͲϮϳϱͲϮϲϬϱ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵdŚĞƚĞĐŚŶŝĐĂůĚĂƚĂůŝƐƚĞĚďĞůŽǁŝƐďĞŝŶŐƐƵďŵŝƚƚĞĚŚĞƌĞǁŝƚŚ͘WůĞĂƐĞĂĚĚƌĞƐƐĂŶǇƉƌŽďůĞŵƐŽƌĐŽŶĐĞƌŶƐƚŽƚŚĞĂƚƚĞŶƚŝŽŶŽĨƚŚĞƐĞŶĚĞƌĂďŽǀĞt>>ED W/η ^Zs/KZZη &/>ED :KdzW ddzW >K''/E'd WZ/Ed^η /'/d>η ^dηϭ ϭͲϭϰ ϱϬͲϬϮϵͲϮϮϵϱϬͲϬϬ ϵϭϬϱϬϴϬϭϭ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϭͲĞĐͲϮϱ Ϭ ϭϮ ϭͲϭϯϬ ϱϬͲϬϮϵͲϮϮϴϭϱͲϬϬ ϵϭϬϰϳϰϬϵϵ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϳͲEŽǀͲϮϱ Ϭ ϭϯ ϭͲϬϯ ϱϬͲϬϮϵͲϮϬϰϳϳͲϬϬ ϵϭϬϰϯϮϬϱϱ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϮϭͲEŽǀͲϮϱ Ϭ ϭϰ ϭͲϬϯ ϱϬͲϬϮϵͲϮϬϰϳϳͲϬϬ ϵϭϬϰϯϮϬϱϱ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϯͲEŽǀͲϮϱ Ϭ ϭϱ ϭͲϬϰ ϱϬͲϬϮϵͲϮϬϰϳϴͲϬϬ ϵϭϬϰϯϮϭϱϰ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϵͲEŽǀͲϮϱ Ϭ ϭϲ ϭͲϭϴ ϱϬͲϬϮϵͲϮϬϵϬϰͲϬϬ ϵϭϬϰϳϰϮϯϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϵͲĞĐͲϮϱ Ϭ ϭϳ ϭ'ͲϭϮ ϱϬͲϬϮϵͲϮϭϬϬϵͲϬϬ ϵϭϬϱϬϴϬϮϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϱͲĞĐͲϮϱ Ϭ ϭϴ ϯͲϭϴ ϱϬͲϬϮϵͲϮϮϲϵϮͲϬϬ ϵϭϬϰϳϯϯϲϴ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϵͲEŽǀͲϮϱ Ϭ ϭϵ ϯ<ͲϬϯ ϱϬͲϬϮϵͲϮϭϲϬϮͲϬϬ ϵϭϬϰϯϮϬϰϬ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϲͲEŽǀͲϮϱ Ϭ ϭϭϬ ϯ<ͲϯϮ ϱϬͲϬϮϵͲϮϮϳϲϯͲϬϬ ϵϭϬϰϳϰϯϬϭ <ƵƉĂƌƵŬZŝǀĞƌ >ĞĂŬĞƚĞĐƚ>ŽŐ &ŝĞůĚͲ&ŝŶĂů ϮͲĞĐͲϮϱ Ϭ ϭW>^<EKt>'Z/Wdz^/'E/E'EZdhZE/E'KWzK&d,dZE^D/dd>>ddZdKd,ddEd/KEK&͗&ĂŶŶǇ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗199-089197-183180-056180-057183-016183-132196-133186-103197-076T41200T41201T41202T41202T41203T41204T41205T41206T41207T41208Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.12.17 13:38:53 -09'00'186-103ϵϯ<ͲϬϯϱϬͲϬϮϵͲϮϭϲϬϮͲϬϬ ϵϭϬϰϯϮϬϰϬ<ƵƉĂƌƵŬZŝǀĞƌWůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϭϲͲEŽǀͲϮϱϬϭ 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: Secure/Diagnostics 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): 8900' 8397' 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 11/12/2025 2-7/8" Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: CamcoHRP-1-SP Packer SSSV: Camco TRDP-1A SSA Sfty Vlv Perforation Depth MD (ft): J-55 4791' 8523-8552', 8562-8629' 8849' 6645-6667', 6674-6725' 7" Perforation Depth TVD (ft): 110' 4828' 6930'8884' 16" 9-5/8" 72' 8338' MD 110' 3896' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: 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 ADL0025519 186-103 P.O. Box 100360, Anchorage, AK 99510 50-029-21602-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Jack Lau 11/12/2025 Tubing Grade: Tubing MD (ft): 5799' MD and 4623' TVD 5820' MD and 4639' TVD 8311' MD and 6488' TVD 1822' MD and 1720' TVD Shelby Sumrall 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: Shelby.Sumrall@conocophillips.com (907) 265-6678 Staff Well Integrity Engineer KRU 3K-03 6941' 8900' 6941' None 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 Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E= Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2025.11.13 11:41:04-09'00' Foxit PDF Editor Version: 13.1.6 Shelby Sumrall 325-696 By Grace Christianson at 12:20 pm, Nov 13, 2025 10-404 J.Lau 11/13/25 A.Dewhurst 13NOV25 DSR-11/19/25JLC 11/19/2025 11/20/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 13 November 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3K-03 (PTD 186-103) to remediate the sustained casing pressure of 2400 psi on the inner annulus (exceeding 45% of the burst rating of the production casing) through the following secure plan. If you need additional information, please contact us at 265-6678. Sincerely, Shelby Sumrall Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2025.11.13 11:42:39-09'00' Foxit PDF Editor Version: 13.1.6 Shelby Sumrall Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,397.0 3K-03 6/3/2020 famaj Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added leak identified by EL 3K-03 4/5/2021 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL: IA x OA COMMUNICATION 12/31/2003 WV5.3 Conversio n 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 38.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.0 4,828.0 3,895.9 36.00 J-55 BTC PRODUCTION 7 6.28 35.4 8,884.4 6,929.8 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.0 Set Depth 8,337.9 Set Depth 6,507.8 String Max No 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABM OD ID (in) 2.44 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) 35.0 35.0 0.09 HANGER 6.000 CAMERON TUBING HANGER 2.875 1,822.1 1,720.3 37.97 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 2,765.4 2,393.8 47.61 GAS LIFT 4.750 MERLA TMPD 2.375 4,739.7 3,830.9 42.93 GAS LIFT 4.750 MERLA TMPD 2.375 5,806.0 4,628.6 40.32 GAS LIFT 4.750 MERLA TMPD 2.375 6,279.5 4,986.7 41.01 GAS LIFT 4.750 MERLA TMPD 2.375 6,692.4 5,294.8 42.04 GAS LIFT 4.750 MERLA TMPD 2.375 7,105.3 5,600.2 42.59 GAS LIFT 4.750 MERLA TMPD 2.375 7,514.5 5,900.6 42.86 GAS LIFT 4.750 MERLA TMPD 2.375 7,925.7 6,201.8 42.32 GAS LIFT 4.750 MERLA TMPD 2.375 8,244.6 6,438.2 41.75 GAS LIFT 5.460 MERLA TGPD 2.375 8,293.5 6,474.7 41.78 SBR 5.625 CAMCO OEJ SBR 2.297 8,311.1 6,487.8 41.82 PACKER 6.151 CAMCO HRP-1-SP PACKER 2.347 8,327.3 6,499.9 41.88 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 8,337.2 6,507.3 41.92 SOS 3.500 CAMCO SHEAR OUT SUB 2.441 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) 5,799.0 4,623.2 40.30 PACKER - PATCH - UPR UPPER PACKER (CPP2807023) 2.285" X 3.23', HANG OFF XO 2.2" X .4', SPACER PIPE 2.070 X 15.99', ANCHOR LATCH SEAL 2.25" X .40' OAL=20.02 5/5/2021 5,810.0 4,631.6 40.34 LEAK - TUBING EL IDENTIFIED POSSIBLE TUBING LEAK AT GLM STATION #3 AT 5810' RKB 4/5/2021 0.000 5,820.0 4,639.2 40.37 PACKER - PATCH - LWR 2.28" P2P Packer (CPP287079) OAL=3.23' 5/5/2021 0.000 8,397.0 6,551.7 42.14 FISH 2.225" P2P (CPP287056SC) w/ Equalizing Valve (CPEQ287SC025). OAL 7.55'. Fell into 7" Casing during pulling attempt. 5/29/2020 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) 2,765.4 2,393.8 47.61 1 GAS LIFT GLV BK 1 1,282.0 5/6/2021 0.156 4,739.7 3,830.9 42.93 2 GAS LIFT OV BK 1 5/6/2021 0.156 5,806.0 4,628.6 40.32 3 GAS LIFT DMY BK 1 0.0 3/26/2021 0.000 6,279.5 4,986.7 41.01 4 GAS LIFT DMY BK 1 0.0 12/6/2010 0.000 6,692.4 5,294.8 42.04 5 GAS LIFT DMY BK 1 0.0 2/7/2021 0.000 7,105.3 5,600.2 42.59 6 GAS LIFT DMY BK 1 0.0 3/19/2006 0.000 7,514.5 5,900.6 42.86 7 GAS LIFT DMY BK 1 0.0 8/23/2002 0.000 7,925.7 6,201.8 42.32 8 GAS LIFT DMY BK 1 0.0 8/28/1986 0.000 8,244.6 6,438.2 41.75 9 GAS LIFT DMY RK 1 1/2 0.0 8/23/2002 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,523.0 8,552.0 6,645.1 6,666.7 A-3, 3K-03 6/10/1990 6.0 RPERF 2 1/8" Dyna Strip 8,533.0 8,534.0 6,652.5 6,653.3 A-3, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,541.0 8,542.0 6,658.5 6,659.2 A-3, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,545.0 8,546.0 6,661.5 6,662.2 A-3, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,562.0 8,629.0 6,674.2 6,724.9 A-2, 3K-03 6/10/1990 6.0 RPERF 2 1/8" Dyna Strip 8,581.0 8,582.0 6,688.5 6,689.2 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,591.0 8,592.0 6,696.0 6,696.8 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,593.0 8,594.0 6,697.5 6,698.3 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 3K-03, 11/12/2025 2:06:05 PM Vertical schematic (actual) PRODUCTION; 35.4-8,884.4 IPERF; 8,614.0-8,626.0 IPERF; 8,602.0-8,603.0 IPERF; 8,598.0-8,599.0 RPERF; 8,562.0-8,629.0 IPERF; 8,593.0-8,594.0 IPERF; 8,591.0-8,592.0 IPERF; 8,581.0-8,582.0 IPERF; 8,545.0-8,546.0 IPERF; 8,541.0-8,542.0 RPERF; 8,523.0-8,552.0 IPERF; 8,533.0-8,534.0 FISH; 8,397.0 Primary Full Bore; 7,820.0 ftKB PACKER; 8,311.1 GAS LIFT; 8,244.6 GAS LIFT; 7,925.7 GAS LIFT; 7,514.5 GAS LIFT; 7,105.3 GAS LIFT; 6,692.4 GAS LIFT; 6,279.5 PACKER - PATCH - LWR; 5,820.0 LEAK - TUBING; 5,810.0 PACKER - PATCH - UPR; 5,799.0 GAS LIFT; 5,806.0 SURFACE; 37.0-4,828.0 GAS LIFT; 4,739.7 GAS LIFT; 2,765.4 Squeeze Behind Casing Squeeze; 2,020.0 ftKB Primary Full Bore; 40.5 ftKB SAFETY VLV; 1,822.1 CONDUCTOR; 38.0-110.0 KUP PROD KB-Grd (ft) 40.49 RR Date 6/29/1986 Other Elev 3K-03 ... TD Act Btm (ftKB) 8,902.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292160200 Wellbore Status PROD Max Angle & MD Incl (°) 47.95 MD (ftKB) 2,700.00 WELLNAME WELLBORE3K-03 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,598.0 8,599.0 6,701.3 6,702.1 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,602.0 8,603.0 6,704.3 6,705.1 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,614.0 8,626.0 6,713.5 6,722.6 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 40.5 4,828.0 40.5 3,895.9 Primary Full Bore Lead 516 bbl 11.9 ppg Arctic Set III + Tail 72 bbl 15.8 ppg Class G... Finish cementing w 1400 sx AS III mixed 11.9 516 bbl slurry Tailed w/ 350 sx Cl G W/ 2.0% S-1 + .2% D-4 mixed 15.8 ppg 72 bbl slurry displaced w/ water- Bumped plug to 2000 psi- Full returns- 193 bbls cement return to surface CIP @ 0845 Floats OK. DRLG float equipment cement & 10' formation to 4858' Displace w/ mud- test formation to 12.5 EMW- w/ 8.5 mud @ 3931 TUD 820 psi NO leak off. DRLG w/ turbine 4858 t 5896 ADT 6.3 hrs. Turbine NOT drilling as should - average 166 7t/hr in soft formation- will not slide properly. ^^Csg OD=9.625 7,820.0 8,879.0 6,123.9 6,925.4 Primary Full Bore Lead 100 sx 12 ppg Class G + Tail 300 sx 15.8 ppg Class G... Pump 10 bbls H2O. Test lines to 4000 psi. Mix and pump 100 sxs Class "G" + 4% D-20 + .2% D46 @ 12.0 ppg. Tail with 300 sxs Clss "G" + 3% KCL + .9% D127 + .3% D13 + .2% D46 15.8 ppg. Displace cement with 100 brine. Bumped plug to 3500 psi. Floats held. R/D D/S Full returns entire job. Pipe stuck on bottom. Could not reciprocate. - Chang rams to 5". PU stack, set slips, mae cuton 7" casing. Insal packoff in Bradenhead. Attempt to test Flange. No test. N/D lower seal assembly cut. P/U new tbing head and seal assembly. Attempt to test. No Test. N/D an change out seal assembly. Test Flange to 3000 psi. OK. Move rig to 3K-04 ^^Csg OD=7 2,020.0 3,015.0 1,870.1 2,565.3 Squeeze Behind Casing Squeeze Top Job 29 bbl 15.7 ppg Arctic Set I + Tail 60 bbl 7.7 ppg Arctic Pack... Water wash volume injeced: 300 bbls- rate 6 bpm; 800 psi. Depth of ArcticPack/ cement interface: +-2000 tvd ft. Pump rate: 7.0 bpm; Pump pressure initial: 850 psi; Final; 900 psi. Pressure results: P/U to 1000 psi. Cos 90# in1 hr. Good test. 7/15/86 **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 3K-03, 11/12/2025 2:06:05 PM Vertical schematic (actual) PRODUCTION; 35.4-8,884.4 IPERF; 8,614.0-8,626.0 IPERF; 8,602.0-8,603.0 IPERF; 8,598.0-8,599.0 RPERF; 8,562.0-8,629.0 IPERF; 8,593.0-8,594.0 IPERF; 8,591.0-8,592.0 IPERF; 8,581.0-8,582.0 IPERF; 8,545.0-8,546.0 IPERF; 8,541.0-8,542.0 RPERF; 8,523.0-8,552.0 IPERF; 8,533.0-8,534.0 FISH; 8,397.0 Primary Full Bore; 7,820.0 ftKB PACKER; 8,311.1 GAS LIFT; 8,244.6 GAS LIFT; 7,925.7 GAS LIFT; 7,514.5 GAS LIFT; 7,105.3 GAS LIFT; 6,692.4 GAS LIFT; 6,279.5 PACKER - PATCH - LWR; 5,820.0 LEAK - TUBING; 5,810.0 PACKER - PATCH - UPR; 5,799.0 GAS LIFT; 5,806.0 SURFACE; 37.0-4,828.0 GAS LIFT; 4,739.7 GAS LIFT; 2,765.4 Squeeze Behind Casing Squeeze; 2,020.0 ftKB Primary Full Bore; 40.5 ftKB SAFETY VLV; 1,822.1 CONDUCTOR; 38.0-110.0 KUP PROD 3K-03 ... WELLNAME WELLBORE3K-03 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:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3K-03 (PTD 186-103) Report of IA SCP over 45% burst. Corrected to 3K-03 Date:Wednesday, November 12, 2025 3:35:48 PM From: Lau, Jack J (OGC) Sent: Wednesday, November 12, 2025 3:35 PM To: 'NSK Wells Integrity Eng CPF1 & CPF3' <n1617@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 3K-03 (PTD 186-103) Report of IA SCP over 45% burst. Corrected to 3K-03 Thanks for the notification Shelby. You have approval to progress diagnostics and securing operations. Jack From: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, November 12, 2025 2:53 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 3K-03 (PTD 186-103) Report of IA SCP over 45% burst. Corrected to 3K-03 From: NSK Wells Integrity Eng CPF1 & CPF3 Sent: Wednesday, November 12, 2025 2:46 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Automation, AK Wells <akwellsautomation@conocophillips.com> Subject: KRU 3K-03 (PTD 186-103) Report of IA SCP over 45% burst Well Name: 3K-03 Facility: CPF3 PTD: 186-103 Well Type: Prod AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): Yes Type of Issue: IA Exceeded 45% Burst Maximum Pressure (if applicable): 2400 Date of Occurrence (if applicable): 11/12/25 Victoria, KRU 3K-03 (PTD 186-103) was reported by Operations today 11/12/25 to have an IA pressure of 2400 psi over OPL. The 7” 26 lb/ft, J-55 has a burst rating of 4980 psi (45% burst rating = 2241 psi). Because the pressure exceeded 45% of the burst pressure of the 7” casing, a 10-403 form will be submitted with a proposal for corrective action. The current T/I/O is at 2400/2400/840 with an IA fluid level at 858’. The well has been shut in for water handling since November 2022 and recently passed a wavier compliance MITOA and shut in TIFL on 9/15/25. CPAI intends to progress troubleshooting the source of the high IA pressure and securing the well as soon as possible. Could you please let me know if you verbally approve for us to progress diagnostics/secure? I plan to submit 10-403 paperwork tomorrow. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you have any questions. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2E-10 50-029-21246-00 907100157 Kuparuk River Packer Setting Record Field- Final 19-Apr-21 0 1 2 2H-11 50-029-20052-00 n/a Kuparuk River Packer Setting Record Field- Final 18-May-21 0 1 3 2M-07 50-103-20178-00 907126248 Kuparuk River Plug Setting Record Field- Final 30-Apr-21 0 1 4 3K-03 50-029-21602-00 907097693 Kuparuk River Leak Detect Log Field- Final 16-Apr-21 0 1 5 3K-03 50-029-21602-00 907132626 Kuparuk River Packer Setting Record Field- Final 5-May-21 0 1 6 3K-30 50-029-22777-00 907098723 Kuparuk River Multi Finger Caliper Field & Processed 16-Apr-21 0 1 7 3K-30 50-029-22777-00 907098126 Kuparuk River Packer Setting Record Field- Final 6-May-21 0 1 8 3Q-06 50-029-21674-00 907089173 Kuparuk River Multi Finger Caliper Field & Processed 13-Apr-21 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 06/01/2021 PTD: 1861030 E-Set: 35191 Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2E-10 50-029-21246-00 907100157 Kuparuk River Packer Setting Record Field- Final 19-Apr-21 0 1 2 2H-11 50-029-20052-00 n/a Kuparuk River Packer Setting Record Field- Final 18-May-21 0 1 3 2M-07 50-103-20178-00 907126248 Kuparuk River Plug Setting Record Field- Final 30-Apr-21 0 1 4 3K-03 50-029-21602-00 907097693 Kuparuk River Leak Detect Log Field- Final 16-Apr-21 0 1 5 3K-03 50-029-21602-00 907132626 Kuparuk River Packer Setting Record Field- Final 5-May-21 0 1 6 3K-30 50-029-22777-00 907098723 Kuparuk River Multi Finger Caliper Field & Processed 16-Apr-21 0 1 7 3K-30 50-029-22777-00 907098126 Kuparuk River Packer Setting Record Field- Final 6-May-21 0 1 8 3Q-06 50-029-21674-00 907089173 Kuparuk River Multi Finger Caliper Field & Processed 13-Apr-21 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 06/01/2021 PTD: 1861030 E-Set: 35190 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8902 feet none feet true vertical 6499'feet 8397 feet Effective Depth measured 8902 feet 5799, 5820, 8311'feet true vertical 6499'feet 4623, 4639, 6488'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)2-7/8" J-55 8338' MD 6508' TVD Packers and SSSV (type, measured and true vertical depth)5799' MD 5820' MD 8311' MD 1822' MD 4632' TVD 4639' TVD 6488' TVD 1720' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 13. Prior to well operation: Subsequent to operation: 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: Authorized Title: Contact Email: Contact Phone: 8523-8552', 8562-8629' feet 6645-6667', 6674-6725' feet Senior Well Integrity Specialist Jan Byrne jan.byrne@conocophillips.com Water-Bbl (907) 659-7224 Authorized Name: Jan Byrne P.O. Box 100360 Anchorage, AK 99510 89 2393 Oil-Bbl WINJ WAG 93 4828' 1326 80 Representative Daily Average Production or Injection Data 129705 Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Camco HRP-1-SP Packer SSSV: Camco TRDP-1A-SSA SV ConocoPhillips Alaska, Inc. ADL 0025519 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-103 50-029-21602-00-00 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15 Gas-Mcf measuredPlugs Junk measured SizeCasing KRU 3K-03 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 197 Production Packer 8849' 3. Address: Casing Pressure Tubing Pressure measured true vertical Kuparuk River Field/ Kuparuk River Oil Pool Conductor Surface Intermediate Authorized Signature with date: N/A Treatment descriptions including volumes used and final pressure: 1237 7"8884' Structural 16" 9-5/8" Length 80' 4791' TVD 110' 3896' 6930' 110' MD Burst Senior Engineer:Senior Res. Engineer: Collapse t Frac O y 6. API N y GJ L GIG 25.070, 2 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:03 pm, May 20, 2021 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孴孱孳學孱孵孳季孳孼孽孶學孽孳孹孰孳孻孪孳孳孪安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孶 Jan Byrne SFD 8/21/2021 SFD 5/21/2021 8,900 RBDMS HEW 6/10/2021 6,941 DSR-5/24/21 6,941 8,900 VTL 8/9/21 ! "#$% &'" (#)* &+" ,##$ - #. $&+ " / #$ # $ " .0 .&,+ '1&//- &" ,- &/& " # $0# .#. " &/" ,- ,&+1&/+&/ +- &" ,- //& " //" # $ ,- *## ##$ ' %/+" %,+'- %/' " $%, +&- # $ ,- $..# /&" +"+23456789: 2;;7<=>?@A<784>5B Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,397.0 6/3/2020 3K-03 famaj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Added leak identified by EL 4/5/2021 3K-03 bworthi1 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 4,828.0 Set Depth (TVD) … 3,895.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.4 Set Depth (ftKB) 8,884.4 Set Depth (TVD) … 6,929.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 35.0 Set Depth (ft… 8,337.9 Set Depth (TVD) (… 6,507.8 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 35.0 35.0 0.09 HANGER CAMERON TUBING HANGER 2.875 1,822.1 1,720.3 37.97 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 8,293.5 6,474.7 41.78 SBR CAMCO OEJ SBR 2.297 8,311.1 6,487.8 41.82 PACKER CAMCO HRP-1-SP PACKER 2.347 8,327.3 6,499.9 41.88 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,337.2 6,507.3 41.92 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,799.0 4,623.2 40.30 PACKER - PATCH - UPR UPPER PACKER (CPP2807023) 2.285" X 3.23', HANG OFF XO 2.2" X .4', SPACER PIPE 2.070 X 15.99', ANCHOR LATCH SEAL 2.25" X .40' OAL=20.02 5/5/2021 5,810.0 4,631.6 40.34 LEAK - TUBING EL IDENTIFIED POSSIBLE TUBING LEAK AT GLM STATION #3 AT 5810' RKB 4/5/2021 0.000 5,820.0 4,639.2 40.37 PACKER - PATCH - LWR 2.28" P2P Packer (CPP287079) OAL=3.23' 5/5/2021 0.000 8,397.0 6,551.7 42.14 FISH 2.225" P2P (CPP287056SC) w/ Equalizing Valve (CPEQ287SC025). OAL 7.55'. Fell into 7" Casing during pulling attempt. 5/29/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,523.0 8,552.0 6,645.1 6,666.7 A-3, 3K-03 6/10/1990 6.0 RPERF 2 1/8" Dyna Strip 8,533.0 8,534.0 6,652.5 6,653.3 A-3, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,541.0 8,542.0 6,658.5 6,659.2 A-3, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,545.0 8,546.0 6,661.5 6,662.2 A-3, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,562.0 8,629.0 6,674.2 6,724.9 A-2, 3K-03 6/10/1990 6.0 RPERF 2 1/8" Dyna Strip 8,581.0 8,582.0 6,688.5 6,689.2 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,591.0 8,592.0 6,696.0 6,696.8 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,593.0 8,594.0 6,697.5 6,698.3 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,598.0 8,599.0 6,701.3 6,702.1 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,602.0 8,603.0 6,704.3 6,705.1 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet 8,614.0 8,626.0 6,713.5 6,722.6 A-2, 3K-03 8/27/1986 1.0 IPERF 120° phasing; 4" Densi Jet Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,765.4 2,393.8 47.61 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,282.0 5/6/2021 2 4,739.7 3,830.9 42.93 MERLA TMPD 1 GAS LIFT OV BK 0.156 5/6/2021 3 5,806.0 4,628.6 40.32 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2021 4 6,279.5 4,986.7 41.01 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/6/2010 5 6,692.4 5,294.8 42.04 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/7/2021 6 7,105.3 5,600.2 42.59 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/19/2006 7 7,514.5 5,900.6 42.86 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/23/2002 8 7,925.7 6,201.8 42.32 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/28/1986 9 8,244.6 6,438.2 41.75 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/23/2002 Notes: General & Safety End Date Annotation 12/31/2003 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 3K-03, 5/19/2021 1:34:52 PM Vertical schematic (actual) PRODUCTION; 35.4-8,884.4 IPERF; 8,614.0-8,626.0 IPERF; 8,602.0-8,603.0 IPERF; 8,598.0-8,599.0 RPERF; 8,562.0-8,629.0 IPERF; 8,593.0-8,594.0 IPERF; 8,591.0-8,592.0 IPERF; 8,581.0-8,582.0 IPERF; 8,545.0-8,546.0 IPERF; 8,541.0-8,542.0 RPERF; 8,523.0-8,552.0 IPERF; 8,533.0-8,534.0 FISH; 8,397.0 PACKER; 8,311.1 GAS LIFT; 8,244.6 GAS LIFT; 7,925.7 GAS LIFT; 7,514.5 GAS LIFT; 7,105.3 GAS LIFT; 6,692.4 GAS LIFT; 6,279.5 PACKER - PATCH - LWR; 5,820.0 LEAK - TUBING; 5,810.0 PACKER - PATCH - UPR; 5,799.0 GAS LIFT; 5,806.0 SURFACE; 37.0-4,828.0 GAS LIFT; 4,739.7 GAS LIFT; 2,765.4 SAFETY VLV; 1,822.1 CONDUCTOR; 38.0-110.0 KUP PROD KB-Grd (ft) 40.49 Rig Release Date 6/29/1986 3K-03 ... TD Act Btm (ftKB) 8,902.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292160200 Wellbore Status PROD Max Angle & MD Incl (°) 47.95 MD (ftKB) 2,700.00 WELLNAME WELLBORE3K-03 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP C:\Users\aebell\Desktop\April 2021 Data Drop\Read Cased Hole Data Drop04192021\2021-04-05_20146_KUP_3K-03_LeakPointSurvey_AOGCCTransmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20146 KUP 3K-03 50-029-21602-00 LeakPoint Survey 05-Apr-21 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 FTP ______________________________ ______________________________________ Print Name 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: 1861030 E-Set: 35017 Received by the AOGCC 04/19/2021 Abby Bell Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-06 50-029-21336-00 906905927 Kuparuk River Multi Finger Caliper Field & Processed 6-Jan-21 0 1 2 3B-06 50-029-21336-00 906953734 Kuparuk River Packer Setting Record Field- Final 1-Feb-21 0 1 3 3K-03 50-029-21602-00 906961911 Kuparuk River Multi Finger Caliper Field & Processed 9-Feb-21 0 1 4 3K-27 50-029-22751-00 906880550 Kuparuk River Packer Setting Record Field- Final 22-Dec-20 0 1 5 3M-17 50-029-21729-00 906892184 Kuparuk River Packer Setting Record Field- Final 29-Dec-20 0 1 6 3M-17 50-029-21729-00 906892184 Kuparuk River Temperature Record Field- Final 30-Dec-20 0 1 7 3N-02A 50-029-21527-01 906798653 Kuparuk River Packer Setting Record Field- Final 31-Dec-20 0 1 8 3O-20 50-029-22750-00 906941859 Kuparuk River Multi Finger Caliper Field & Processed 24-Jan-21 0 1 9 3N-07A 50-029-21539-01 906604302 Kuparuk River String Shot Record Revised 16-Jul-20 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 1861030 E-Set: 34738 Originated:Delivered to:19-Aug-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Sari 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 Leak Detect Log 2 Plug Setting Record 3 2L-310 50-103-20616-00 906449149 Tarn Packer Setting Record Field-Final 13-Apr-20 0 1 4 2T-37 50-103-20227-00 906480199 Kuparuk Plug Setting Record Field-Final 30-Apr-20 0 1 5 3A-08 50-029-21445-00 906499970 Kuparuk Plug Setting Record Field-Final 17-May-20 0 1 6 Multi Finger Caliper Field-Processed 26-May-20 7 Packer Setting Record Field-Final 27-May-20 8 3H-14B 50-103-20092-02 906486722 Kuparuk Packer Setting Record Field-Final 7-May-20 0 1 9 3K-03 50-029-21602-00 906531280 Kuparuk Plug Setting Record Field-Final 29-May-20 0 1 10 3A-08 50-029-21445-00 906499689 Kuparuk Multi Finger Caliper Field-Processed 16-May-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: 1 3H-03 50-103-20085-00 n/a Kuparuk 0 1 Transmittal Date: 2H-09 50-103-20050-00 906426492 Kuparuk Field-Final 5-Apr-20 0 Received by the AOGCC 08/26/2020 08/26/2020 Abby Bell PTD: 1861030 E-Set: 33695 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ 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 feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15. Well Class after work: Exploratory Development Service Stratigraphic 16. Well Status after work: Oil Gas W DSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) J G Plug Perforations Fracture Stimulate Pull TubingOperations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory StratigraphicService 6. API Number: mber): 8. Well Name and Number: onic data per 20AAC25.071): 10. Field/Pool(s): ry: ured feet feet ticalfeet feet ured feet feet ticalfeet feet epth feet epth feet true vertical depth) d and true vertical depth) summary: lumes used and final pressure: tion: ion: CollapseBurstTVD 5. Permit to Drill Number: Size Gas-Mcf g Ju easu ed 4. W ell Class Before W ork: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl ue e ca W ater-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 186-103 50-029-21602-00-00 ADL 0025519 KRU 3K-03 N/A Kuparuk River Field/Kuparuk River Oil Pool 8900 6941 8323 N/A 8798 6858 8311 6488 Conductor 80 16" 110 110 Surface 4791 9-5/8" 4828 3895 Production 8849 7" 8884 6929 8523-8626 6645-6722 2-7/8" J-55 8338 6508 Camco HRP-1-SP 8311 6488 N/A N/A N/A verbal approval received 5/22/20Stephanie Pilch Well Integrity & Compliance Specialist Stephanie Pilch/Sara Carlisle n2549@conocophillips.com (907) 659-7126 Secure Well ✔ ✔ ✔✔ ✔ Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-06-04 16:50:38 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch By Samantha Carlisle at 8:12 pm, Jun 04, 2020 320-212 RBDMS HEW 6/10/2020 DSR-6/9/2020VTL 7/27/20 SFD 6/10/2020 !"##$ % & '( )'*) +( , -"./"*0+1% 23*45! ') ! ' !( )( 06 '!$7 )5 ! )( ' !4- + 3$#*3)8 89 - 8 (+ ,!8 ( ( +( , - Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-06-04 16:50:55 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch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ast Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag: RKB 8,397.0 6/3/2020 famaj 3K-03 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Added RBP fish in 7" Casing, RBP in tubing. 6/3/2020 famaj 3K-03 Notes: General & Safety End Date 12/31/2003 Annotation NOTE: WAIVERED WELL: IA x OA COMMUNICATION Wellbore 3K-03 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.06 38.0 110.0 110.0 62.50 H-40 WELDED 3K-03 SURFACE 9 5/8 8.92 37.0 4,828.0 3,895.9 36.00 J-55 BTC 3K-03 PRODUCTION 7 6.28 35.4 8,884.4 6,929.8 26.00 J-55 BTC 3K-03 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 2 7/8 2.44 35.0 8,337.9 6,507.8 6.50 J-55 EUE8rdABMO D 3K-03 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 35.0 35.0 0.09 HANGER CAMERON TUBING HANGER 2.875 3K-03 1,822.1 1,720.3 37.97 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 3K-03 8,293.5 6,474.7 41.78 SBR CAMCO OEJ SBR 2.297 3K-03 8,311.1 6,487.8 41.82 PACKER CAMCO HRP-1-SP PACKER 2.347 3K-03 8,327.3 6,499.9 41.88 NIPPLE CAMCO D NIPPLE NO GO 2.250 3K-03 8,337.2 6,507.3 41.92 SOS CAMCO SHEAR OUT SUB 2.441 3K-03 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 6,434.0 5,102.8 41.71 LEAK - 6434-65' RKB Slickline identified poss. Tbg Leak w/ Holefinder Between 6434'-6465' RKB 9/24/2019 0.000 3K-03 8,322.5 6,496.3 41.86 PLUG 2.225" P2P (CPP287057SC) w/ Equalizing Valve (CPEQ287SC06). OAL 5'. Max OD 2.25" 6/3/2020 0.000 3K-03 8,397.0 6,551.7 42.14 FISH 2.225" P2P (CPP287056SC) w/ Equalizing Valve (CPEQ287SC025). OAL 7.55'. Fell into 7" Casing during pulling attempt. 5/29/2020 0.000 3K-03 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 37.0 37.0 0.09 HANGER 8.921 3K-03 38.0 38.0 0.09 CONDUCTOR 15.062 3K-03 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 8,523.0 8,552.0 6,645.1 6,666.7 A-3, 3K-03 6/10/1990 6.0 RPERF 2 1/8" Dyna Strip 3K-03 8,533.0 8,534.0 6,652.5 6,653.3 A-3, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 3K-03 8,541.0 8,542.0 6,658.5 6,659.2 A-3, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 3K-03 8,545.0 8,546.0 6,661.5 6,662.2 A-3, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 3K-03 8,562.0 8,629.0 6,674.2 6,724.9 A-2, 3K-03 6/10/1990 6.0 RPERF 2 1/8" Dyna Strip 3K-03 8,581.0 8,582.0 6,688.5 6,689.2 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 3K-03 8,591.0 8,592.0 6,696.0 6,696.8 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 3K-03 8,593.0 8,594.0 6,697.5 6,698.3 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 3K-03 8,598.0 8,599.0 6,701.3 6,702.1 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 3K-03 8,602.0 8,603.0 6,704.3 6,705.1 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 3K-03 8,614.0 8,626.0 6,713.5 6,722.6 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 3K-03 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 2,765.4 2,393.8 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,278.0 4/1/2011 3K-03 2 4,739.7 3,830.9 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,281.0 3/31/2011 3K-03 3 5,806.0 4,628.6 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,313.0 3/31/2011 3K-03 4 6,279.5 4,986.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/6/2010 3K-03 5 6,692.4 5,294.8 MERLA TMPD 1 GAS LIFT OPEN Open 5/20/2020 3K-03 6 7,105.3 5,600.2 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/19/2006 3K-03 7 7,514.5 5,900.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/23/2002 3K-03 8 7,925.7 6,201.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/28/1986 3K-03 9 8,244.6 6,438.2 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/23/2002 3K-03 Comment SSSV: TRDP 3K-03, 6/4/2020 4:05:24 PM Vertical schematic (actual) PRODUCTION; 35.4- 8,884.4 IPERF; 8,614.0-8,626.0 IPERF; 8,602.0-8,603.0 IPERF; 8,598.0-8,599.0 RPERF; 8,562.0-8,629.0 IPERF; 8,593.0-8,594.0 IPERF; 8,591.0-8,592.0 IPERF; 8,581.0-8,582.0 IPERF; 8,545.0-8,546.0 IPERF; 8,541.0-8,542.0 RPERF; 8,523.0-8,552.0 IPERF; 8,533.0-8,534.0 FISH; 8,397.0 SOS; 8,337.2 NIPPLE; 8,327.3 PLUG; 8,322.5 PACKER; 8,311.1 SBR; 8,293.5 GAS LIFT; 8,244.6 GAS LIFT; 7,925.7 GAS LIFT; 7,514.5 GAS LIFT; 7,105.3 GAS LIFT; 6,692.4 LEAK - 6434-65' RKB; 6,434.0 GAS LIFT; 6,279.5 GAS LIFT; 5,806.0 SURFACE; 37.0-4,828.0 GAS LIFT; 4,739.7 GAS LIFT; 2,765.4 SAFETY VLV; 1,822.1 CONDUCTOR; 38.0- 110.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 40.49 Rig Release Date 6/29/1986 Annotation Last WO: End DateH2S (ppm) Date... TD Act Btm (ftKB) 8,902.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292160200 Wellbore Status PROD Max Angle & MD Incl (°) 47.95 MD (ftKB) 2,700.00 Legal Wellname 3K-03 Common Wellname3K-03 AK All Wellbores Schem 1 Carlisle, Samantha J (CED) From:Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent:Thursday, June 4, 2020 4:55 PM To:AOGCC Permitting (CED sponsored) Cc:Haggerty-Sherrod, Ann (Northland Staffing Services) Subject:KRU 3K-03 Secure for SCP 10-404 Electronic Submission Attachments:3K-03 SCP Secure 10-404 Packet 6-4-20.pdf Goodafternoon! Attachedisthe10Ͳ404forsecuringKRU3KͲ03(PTD186Ͳ103)afteritexperiencedsustainedcasingpressureon5/22/20. VerbalapprovalwasreceivedfromVictoriaon5/22/20toproceedwithsecureoperations.The10Ͳ403wassubmitted 5/26/20butwehavenotyetreceivedtheofficialapproved10Ͳ403.Thesecureworkwascompleted6/3/20andthewell passedacombodrawdowntestandacomboMIT. Regards, StephaniePilch/alt:SaraCarlisle CPF3&AlpineWellIntegrity&ComplianceSpecialist ConocoPhillipsAlaska Office:(907)659Ͳ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y Samantha Carlisle at 8:37 am, May 26, 2020 Digitally signed by Sara Carlisle DN: OU=Drilling & Wells, O=ConocoPhillips Alaska, CN=Sara Carlisle, E=sara.e.carlisle@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-05-23 21:12:02 Foxit PhantomPDF Version: 9.7.0 Sara Carlisle 320-212 SCP IA DSR-5/26/2020 X VTL 6/5/20 X X NA DLB 05/26/2020 DLB (entire well) 10-404 X dts 6/5/2020 6/5/2020 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.06.05 12:29:38 -08'00' RBDMS HEW 6/9/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 23 May 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Sincerely, Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Please contact Stephanie Pilch or myself at 659-7126 if you have any questions. production casing) through either repair or secure. pressure of 2700 psi on the inner annulus (exceeding 45% of the burst rating of the Alaska, Inc. well KRU 3K-03 (PTD 186-103) to diagnose and remediate sustained casing Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 CPAI Well Integrity & Compliance Specialist Submit 10-404 to AOGCCC.6. repaired, continue normal daily surveillance of the annular pressure. When annulus pressures indicate that the well has been mechanically secured or5. pressure below DNE. interventions to secure the well. Heavy fluids may be used to reduce the CA-2 plug, continue diagnostics based on these findings or progress If it is determined that the sustained casing pressure has a cause other than thea. Perform CMIT TxIA to 2500 psi and CDDT TxIA to 500 psi against RBP to verify integrity.4. Pull CA-2 plug and set RBP in tubing beneath the production packer.3. pressurization. If the CMIT-TxIA passes, further diagnostics to identify the source of IAa. integrity. Circulate seawater into the well and perform a CMIT TxIA to verify the CA-2 plug2. Mobilize Slickline to 3K-03.1. Proposed Overview of Work: pressurization and mechanically secure the well. path is present. The scope of the troubleshoot procedure will be to identify the source of the IA The high IA pressure exhibited suggests the plug is not holding or an additional communication which was successfully recovered in May 2020. The well was secured 5/20/2020 with a plug. stuck downhole. Multiple fishing and coiled tubing attempts were made to recover the fish, known tubing leak. While performing diagnostics to repair the leak, a standing valve became pressure while the well was shut in. This well has been shut in since September 2019 due to a Kuparuk River Unit gas-lifted producer 3K-03 was reported for sustained inner annulus (IA) 3K-03 (PTD 186-103) Proposal Summary for Troubleshooting High Inner Annulus Pressure CMIT TxIA t Specify test pressure CMIT TxIA to 2500 psi a Test should be at least 2700psi (54% of 7" csg internal yield). AOGCC witness CMIT and CDDT Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,521.0 9/21/2019 3K-03 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Plug / Catcher & Pulled OV 5/20/2020 3K-03 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 4,828.0 Set Depth (TVD) … 3,895.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.4 Set Depth (ftKB) 8,884.4 Set Depth (TVD) … 6,929.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 35.0 Set Depth (ft… 8,337.9 Set Depth (TVD) (… 6,507.8 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 35.0 35.0 0.09 HANGER CAMERON TUBING HANGER 2.875 1,822.1 1,720.3 37.97 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 8,293.5 6,474.7 41.78 SBR CAMCO OEJ SBR 2.297 8,311.1 6,487.8 41.82 PACKER CAMCO HRP-1-SP PACKER 2.347 8,327.3 6,499.9 41.88 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,337.2 6,507.3 41.92 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,434.0 5,102.8 41.71 LEAK - 6434-65' RKB Slickline identified poss. Tbg Leak w/ Holefinder Between 6434'-6465' RKB 9/24/2019 0.000 8,324.0 6,497.5 41.87 2.25" AVA Catcher 2.25" AVA Catcher (33" OAL) 5/20/2020 1.810 8,327.0 6,499.7 41.88 2.25" CA-2 Plug 2.25" CA-2 Plug (25" OAL) 5/20/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,523.0 8,552.0 6,645.1 6,666.7 A-3, 3K-03 6/10/1990 6.0 RPERF 2 1/8" Dyna Strip 8,533.0 8,534.0 6,652.5 6,653.3 A-3, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 8,541.0 8,542.0 6,658.5 6,659.2 A-3, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 8,545.0 8,546.0 6,661.5 6,662.2 A-3, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 8,562.0 8,629.0 6,674.2 6,724.9 A-2, 3K-03 6/10/1990 6.0 RPERF 2 1/8" Dyna Strip 8,581.0 8,582.0 6,688.5 6,689.2 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 8,591.0 8,592.0 6,696.0 6,696.8 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 8,593.0 8,594.0 6,697.5 6,698.3 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 8,598.0 8,599.0 6,701.3 6,702.1 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 8,602.0 8,603.0 6,704.3 6,705.1 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 8,614.0 8,626.0 6,713.5 6,722.6 A-2, 3K-03 8/27/1986 1.0 IPERF 120 deg. phasing; 4" Densi Jet 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 2,765.4 2,393.8 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,278.0 4/1/2011 2 4,739.7 3,830.9 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,281.0 3/31/2011 3 5,806.0 4,628.6 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,313.0 3/31/2011 4 6,279.5 4,986.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/6/2010 5 6,692.4 5,294.8 MERLA TMPD 1 GAS LIFT OPEN Open 5/20/2020 6 7,105.3 5,600.2 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/19/2006 7 7,514.5 5,900.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/23/2002 8 7,925.7 6,201.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/28/1986 9 8,244.6 6,438.2 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/23/2002 Notes: General & Safety End Date Annotation 12/31/2003 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 3K-03, 5/21/2020 7:30:18 AM Vertical schematic (actual) PRODUCTION; 35.4-8,884.4 IPERF; 8,614.0-8,626.0 IPERF; 8,602.0-8,603.0 IPERF; 8,598.0-8,599.0 RPERF; 8,562.0-8,629.0 IPERF; 8,593.0-8,594.0 IPERF; 8,591.0-8,592.0 IPERF; 8,581.0-8,582.0 IPERF; 8,545.0-8,546.0 IPERF; 8,541.0-8,542.0 RPERF; 8,523.0-8,552.0 IPERF; 8,533.0-8,534.0 SOS; 8,337.2 NIPPLE; 8,327.3 2.25" CA-2 Plug; 8,327.0 2.25" AVA Catcher; 8,324.0 PACKER; 8,311.1 SBR; 8,293.5 GAS LIFT; 8,244.6 GAS LIFT; 7,925.7 GAS LIFT; 7,514.5 GAS LIFT; 7,105.3 GAS LIFT; 6,692.4 LEAK - 6434-65' RKB; 6,434.0 GAS LIFT; 6,279.5 GAS LIFT; 5,806.0 SURFACE; 37.0-4,828.0 GAS LIFT; 4,739.7 GAS LIFT; 2,765.4 SAFETY VLV; 1,822.1 CONDUCTOR; 38.0-110.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 40.49 Rig Release Date 6/29/1986 3K-03 ... TD Act Btm (ftKB) 8,902.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292160200 Wellbore Status PROD Max Angle & MD Incl (°) 47.95 MD (ftKB) 2,700.00 WELLNAME WELLBORE3K-03 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP From:Loepp, Victoria T (CED) To:Well Integrity Compliance Specialist WNS & CPF3 Subject:Re: KRU 3K-03 (PTD 186-103) Report of Sustained Casing Pressure Date:Friday, May 22, 2020 1:47:06 PM Sara, Approval is granted as written. Victoria Sent from my iPhone On May 22, 2020, at 1:36 PM, Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> wrote: Good Afternoon Victoria, KRU producer 3K-03 (PTD 186-103) was reported to have exceed the IA DNE to a maximum pressure of 2700 psi today. The well pressure was bled down this morning to 1750 psi. This well has 7”, 26 lb./ft., J-55 production casing that has an internal yield rating of 4,980 psi (45% here is 2,241 psi). Because the pressure exceeded 45% of the burst pressure of the casing, a 10-403 form will be submitted with a proposal for corrective action. This well has been shut in since September 2019 due to a tubing leak. While performing diagnostics to repair the leak, a standing valve became stuck downhole. Multiple fishing and coiled tubing attempts were made to recover the fish, which was successful recovered in May 2020. The well was secured 5/20/2020 with a plug. The high IA pressure exhibited today suggests the plug is not holding or an additional communication path is present. Additionally, this well is internally waivered for slow IA x OA communication through the packoffs. The outer annulus is presently at 515 psi and did not rise as a result of the IA pressurization. CPAI intends to progress troubleshooting the source of the high IA pressure and securing the well as soon as possible. We will continue to monitor the inner annulus to understand if the pressure continues to build or will remain stable at 1750 psi. Could you please let me know if you approve for us to progress diagnostics/secure? I plan to submit 10-403 paperwork tomorrow. A 90-day TIO plot and wellbore schematic are attached. Sincerely, Sara Carlisle (Heskin) / Stephanie Pilch Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 | n2549@cop.com Cell: 907-331-7514 | sara.e.carlisle@cop.com <3K-03.pdf> <3K-03 90-Day TIO 5.22.20.pdf> Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. /z?~- /-~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. D Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: ~Other:~~ OVERSIZED (Non-Scannable) [] Logs of various kinds i~I r~ Other TOTAL PAGES: NOTES: ORGANIZED BY; BEVERLY BREI~ VINCENT SHERYL MARIA LOWELL DATE; /S/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Scanned (done) PAGES: ~/ SCANNED BY: (at the time of scanning) BEVERLY BRE~ERYL MARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: lei General Notes or Comments about this file: PAGES.'~f Quality Checked (done) . . ~ ConocoPhillips Alaska )0:_ 3 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ¿¡ July 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 \t:¿V \03 5\;ANNED AUG 0 1 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ftom the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ftom 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ) ! --(- 71'L'illo-¡ Perry KI . ConocoPhillips Well Integrity Supervisor . . JUL 3 1 2007 D C! ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/28/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na Qal 3K-1 186-101 19' 2.6 19" 7/7/2007 7 7/27/2007 3K-2 186-102 53' 7.2 9" 7/7/2007 3.7 7/22/2007 3K-3 186-103 43' 5.8 11" 7/7/2007 4.2 7/27/2007 3K-5 186-123 66' 9.0 26" 7/7/2007 9.6 7/22/2007 3K-6 186-124 58' 7.9 13" 7/10/2007 4.8 7/22/2007 3K-7 186-125 70' 10.5 35" 7/7/2007 13.2 7/22/2007 3K-8 186-126 54' 4.0 9" 7/10/2007 3.6 7/22/2007 3K-9 186-174 26' 9.0 16" 7/10/2007 6 7/22/2007 3K~11 186-164 43' 6.5 21" . 7/10/2007 .... 7.8 . .. . 7/1'6/2007 3K-13 186-136 8" none 8" 7/10/2007 3.1 7/16/2007 3K-14 186-137 8" none 8" 7/10/2007 3.1 7/16/2007 3K-15 186-138 50' 6.0 22" 7/10/2007 8.4 7/22/2007 3K-16 186-139 46' 7.0 27" 7/10/2007 9.6 7/22/2007 3K-17 186-152 56' 8.0 30" 7/10/2007 10.7 7/22/2007 3K-18 186-151 38' 5.5 23" 7/10/2007 8.4 7/22/2007 MEMORANDUM- State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, ~ Commissioner Tom Maunder, P. i. Supervisor .¢);~'%'-0''', DATE: May 18, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3K Pad May 1,8,2001' I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. 'SUMMARY: I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested' 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Att~. chments: SVS KRU 3K 5-18-01jc cc.; NON-CONFIDENTIAL SVS KRU 3K 5-18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: Date: Field/Unit~ad: Kupan~ River Unit 3K Pad Separator psi: LPS 65 HPs 5/18/01 '1 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GASorCYCLE 3K-01 1861010 65 70 50 P P OIL , , 3I~03 ~ 1861030 65 70 55 P P OIL 13K-06 1861240 65 70 50 P P OIL 3K-09A 1861740 65 60 54 P P OIL 3K-10 1861630~ 65 70 52 P P OIL 3K-11 1861640 65 70' 50 P P OIL 3K-14 1861370 65 60 58 P P OIL 3K-16 1861390 65 70 70 P P OIL 3K-17 1861520 65 60 35 P P OI~ , , 3K-23 1970970 65 70 58 P P OIL 3K-24 1982490 65 70 50 P P OIL 3K-27 1970460 65 70 521 P 4 OIL 3K-32 1970760 65 70 55: P P OIL , 3K-35 19710901 65 70 50 P P OIL Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.57% [-] 9o Remarks: RJF 1/16/01 Page 1 of l SVS KRU 3K 5-18-01jc MICROFILMED 9/11/00 DO NOT PLACE ANY' NEW MATER/AL UNDER THIS PAGE ARCO Alaska, Inc. v'~JPARUK RIVER UNIT · ' A K1 (3K-03(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-03 FRAC, FRAC SUPPORT 1220970658.6 'DATE DALLY WORK "UNIT NUMBER 03/13/98 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes 0 NoI (~) Yes 0 No DS-YOAKUM CHANE, Y .. FIELD AFC# CC# DAILY COST ACCUM COST Signed/. ~:'-,, ESTIMATE KD1797 230DS36KL $133,901 $138,941 ' ''., ~' ~r ' '~ ...... ~ I nitialTbgPress Final TbgPress 'lnitial lnnerAnn Final lnnerAnn I lnitialOuterA6n IFinalOuterAnn . 450 PSI 2500 PSI 2000 PSI 500 PSI! 10 PSI 500PSI DAILY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 215200 LBS OF PROP IN THE FORM W/10# PPA OF #12/18 @ THE PERF'S. MAXIMUM PRESSURE 8900 PSI & F.G. (.75). FREEZE PROTECTED TBG DOWN TO 3000' W/DIESEL. TIME 06:30 09:00 09:30 10:45 11:50 LOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL TRUCK, & APC VAC TRUCK. HELD SAFETY MEETING (15 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9000 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO 15 BPM. WHTP BROKE DOWN FROM 8900 PSI TO 6900 PSI. SLURRY VOLUME PUMPED 370 BBLS. USED 5801 LBS OF #20/40 PROP FOR SCOURING. MAXIMUM PRESSURE 8900 PSI AND ENDING PRESSURE 4700 PSI. STEPPED RATE DOWN AT END OF STAGE. S/D AND OBTAINED ISIP OF 1854 PSI & F.G. @ (.72). MONITORED WHTP AND PULSED FOR CLOSURE. CLOSURE TIME OF 24 MINS @ 1468 PSI. PUMP DATAFRAC W/50 # DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 167 BBLS. MAXIMUM PRESSURE 6100 PSI AND ENDING PRESSURE 4200 PSI. S/D AND OBTAINED ISIP OF 2069 PSI W/F.G. @ (.75). MONITORED WHTP FOR CLOSURE. CLOSURE TIME OF 17 MINS @ 1684 PSI. PAD VOLUME = 260 BBLS. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. PUMPED 216444 LBS OF PROP (19000 LBS OF #20/40 & 197dd~. LBS OF #12/18). INJECTED 215200 LBS OF PROP IN THE FORMATION W/10# PPA OF #12/18 @ THE PERF'S. LEFT 1244 LBS OF PROP IN THE WELL BORE AND EST FILL TO BE @ 8460' RKB. BHP EST IS 2800 PSI. FREEZE PROTECTED TBG DOWN TO 3000' W/ DIESEL. 13:30 STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL TRUCK. 14:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. 15:30 R/D COMPLETED AND ALL WELL SERVICE PERSONNEL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DALLY COST ACCUM TOTAL $0.00 $280.00 APC $6,200.00 $6,200.00 DIESEL $400.00 $400.00 DOWELL $125,101.42 $125,101.42 HALLIBURTON $0.00 $3,000.30 LI~-FLE RED $2,200.00 $3,960.00 TOTAL FIELD ESTIMATE $133,901.42 $138,941.72 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation Shutdo~ Pull tubing _ I 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 1384' FSL, 318' FWL, Sec 35, T13N, R9E, UM At top of productive interval: 1438' FNL, 811' FEL, Sec 35, T13N, R9E, UM At effective depth: 1257' FNL, 570' FEU Sec 35, T13N, R9E, UM At total depth: 1225' FNL 521' FEL, Sec 35, T13N, R9E, UM 12. Present well condition summary Total Depth: measured 8900 feet true vertical 6941 feet Effective Deptt measured 8798 feet true vertical 6858 feet Casing Length Conductor 80' Surface 4791' Size 16" 9-5/8" 7" Production 8844' Liner Stimulate~X Plugging _ Perforate _ Alter casing _ Repair well _ Other _ Type of Well: Development X. Exploratory ~. Stratagrapic ~. Service 6. Datum of elavation (DF or KB feet): 69' RKE 7. Unit or Property: Kuparuk River Unit 8. Well number: 3K-03 9. Permit number/approval number: 86-103 10. APl number: 50-029-21602-00 11. Field/Pool: Kuparuk River Field/Oil Pool Plugs (measured) None Junk (measured) None Cemented 1540# Poleset 1400 Sx AS III & 350 Sx Class G 400 Sx Class G & 175 Sx AS I Measured depth 110' 4828' 8879' True vertical depth 110' 3895' 6924' Perforation Depth measured 8523'-8552', 8562'-862f true vertical 6644' - 6665', 6672' - 672z Tubing (size, grade, and measured depth) 2.825", 6.5 #/ft., J-55 @ 8338' Packers and SSSV (type and measured depth) Pkr: Camco HRP-1-SP @ 8311'; SSSV: Camco TRDP-1A-SSA @ 1822 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 3/13/98. Intervals treated (measured) 8523' - 8552', 8562' - 8629' Treatment description including volumes used and final pressure Pumped 215200 lbs of 20/40 and 12/18 ceramic proppant into the formation, final pressure = 8900 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 638 305 0 1235 146 Subsequent to operation 1364 526 10 1243 151 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations I16. Status of well classification as: Oil _~X Gas _ Suspended _ Service _ 17. I hereby certify .that the f~egoing iA true and correct to the best of my knowledge. ,n_.,.,.~ /l l l ,~ ll ~ Title: Wells Superintendent Signed Form 10-404 R~I~ 06/15/88 Date SUBMIT IN DUPLICA ARCO Alaska, Inc. Post Office ', 100360 Anchorage, ,-,,aska 99510-0360 Telephone 907 276 1215 Date: February 26, 1987 Transmittal # 5926 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. and return one signed copy of this transmittal. 3Q-8 CBL 2-16-87 6195-9264 2H-6 CET 1-17-86 7400-8873 2H-5 CET 1-16-86 6525-7959 3F-13 CET 1-7-86 6160-7920 3F-12 CET 1-23-86 6946-7250 2H-8 CET 1-1-86 8000-8650 2H-7 CET 1-1-86 6800-7938 3F-14 CET 1-7-86 4700-6760 3K-5 CET 7-16-86 6988-7990 3K-3 CET 7-14-86 7595-8800 3K-4 CET 7-i4-86 7793-8787 3F-12 CET 1-7-86 6050-7416 Please acknowledge receipt An,,ho, a[Te Rec~e/iP. t Acknowledged.~~ ] , , Date= DIS~ NSK , Drilling State (+ sepia). BPAE Chevron SAPC Mobil Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary o1' AllanlicRJchfieldCompany 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-103 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21602 4. Location of well at surface 9. Unit or Lease Name 1384' FSL, 318' FWL, Sec.35, T13N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1438' FNL, 811' FEL, Sec.35, T13N, R9E, UM 3K-3 At Total Depth 11. Field and Pool 1225' FNL, 521' FEL, Sec.35, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 69' ADL 25519, ALK 2555 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 06/20/86 06/26/86 11/26/86'I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8900'MD 6941 'TVD 8798'MD 6858'TVD YES [~ NO [] 1822' feet MDI 1700' (Approx) 22. Type Electric or Other Logs Run D IL/SP/SFL, FDC/CNL/GR, Cal, CET/CCL/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 '110' 24" 1540# Pol eset 9-5/8" 36.0# J-55 Surf 4828' i2-1/4" 1400 sx AS Ill & 350 sx Class G 7" 26.0# J-55 Surf 8879' 8-1/2" 400 sx Class G & 175 sx AS I · _ 24. Perforations open to Production (MD+TVD of TOp and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 8338 ' 8311 ' 8533 'MD 6652'TVD 8602 'MD 6703'TVD 8541 'MD 6658'TVD 8614'-8626'MD 6712'-6721'TVD 8545 'MD 6661 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8581 'MD 6688'TVD Perforated DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached adden,Jum~ dated 01/29/87, 8591 'MD 6696'TVD w/1 spf, 120° Phasing 8593 'MD 6697'TVD for Fracture data. . 8598 'MD 6701 'TVD N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology' porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None REC IYE F 0 6 1987 Alaska Oil & Gas Cons. Commission *Note: Drilled RR 06/29/86. Perforated well & tubing run 08/28/86. Form 10-407 Rev. 7-1-80 STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION CL,'MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG WC2:014:DANI Submit in duplicate CONTINUED ON REVERSE SIDE . . ';~ ~', . ~., . ;. GEoLoGic-MARK~-~R~; --.' : ' ' .' 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 Kuparuk C 8331' 6501 ' N/A Base Kuparuk C 8401' 6553' Top Kuparuk A 8511' 6635' Base Kuparuk A 8674' 6758' 31. LIST OF ATTACHMENTS Addendum (dated 01/29/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~'~,/~' ~l,~2~jv - j-/-~'~ ?~-/' Title Associ ate 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". Form 10-407 ADDENDUM WELL: 7/18/86 11/26/86 3K-3 Rn CET/CCL/GR f/8800'-7595'. Rn gyro f/8751'-54'. Frac well per the following: Stage #1: Stage #2: Stage #3: Stage #4: Stage #5: Stage #6: Stage #7: Stage #8: Stage #9: 100 bbls gelled diesel pad @ 5950 psi 20 bbls gelled diesel Pad "A" @ 6570 psi 48 bbls gelled diesel 100 mesh @ 5450 psi 400 bbls gelled diesel Pad "B" @ 5300 psi 31 bbls gelled diesel 1 ppg @ 5170 psi 33 bbls gelled diesel 2 ppg @ 5040 psi 34 bbls gelled diesel 3 ppg @ 5270 psi 35 bbls gelled diesel 4 ppg, 5710 psi 37 bbls gelled diesel 5 ppg @ 4990 psi Stage #10: 38 bbls gelled diesel 6 ppg @ 4900 psi Stage #11: 34 bbls gelled diesel 8 ppg @ 6600 psi Stage #12: 53 bbls gelled diesel flush @ 6320 psi $ UB.$ URFA CE DIRECTIONAL SURVEY ['~UIDANCE [~ONTINUOUS [-~'] COL i~ECEIVC~D SEP 2 5 Alaska Oil & Gas Cons. Anchora~,.- Comparly ARCO ALASKA, INCORPORATED . Well Name 3K-3 (1384' FS..L~ 318' FWL~ S35~T13N?R9F,?UM) Field/Locat~orl KUPARUK? NORTH SLOPE ~ ALASKA Job Reference No. 71615 Log~3ed BT BARBA Date 15-JUL-86 Computed By: KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKAt INC. 3K-3 KUPARUK NORTH SLOPE~ALASKA SURVEY DATE: [5-JUL-86 ENGINEER: BARBA METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZo DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 58 DEG 18 MIN EAST ARCO ALASKAt INC. 3K-3 KUPARUK NORTH SLOPE,ALASKA TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG COMPUTATION DATE: 30-JUL-B6 PaGE 1 DATE OF SURVEY: 15-JUL-86' KELLY BUSHING ELEVATION: ENGINEER: BARBA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST.., AZIMUTH 69.00-FT lO00.O0 994.61 925.61 15 17 1100,00 1090.46 1021.46 17 55 1200.00 1184.63 1115.63 21 17 1300.00 1276.94 1207.94 23 57 1400.00 1367,16 1298,16 27 9 1500.00 1454.88 1385.88 30 11 1600.00 1539.81 1470.81 33 24 1700.00 1622.06 1553.06 35 35 1800.00 1701.56 1633.56 37 19 1900.00 1780.60 1711.60 40 15 N 69 49 E 58.05 N 72 40 E 85.81 N 75 10 E 118.04 N 70 38 E 155.20 N 68 43 E 197.50 N 68 38 E 244.71 N 69 I E 296.55 N 66 43 E 352.56 N 62 23 E 411.52 N 62 17 E 473.91 2000.00 1855.24 1786.24 42 57 2100.00 1927.09 1858o09 44 49 2200,00 1997,96 1928.96 44 32 2300.00 2069.66 2000.66 43 55 2400.00 2141.93 2072.93 43 54 2500.00 2213.08 2144.08 45 26 2600.00 2282,04 2213,04 47 25 2700,00 2349.02 2280.02 47 57 2800.00 2416.31 2347.31 47 26 2900.00 2484.27 2415o27 46 30 N 65 28 E 540.10 N 66 42 E 608.94 N 67 9 E 678.72 N 67 40 E 747.53 N 67 22 E 815.72 N 66 14 E 885.22 N 63 59 E 957.05 N 62 16 E 1031.08 N 62 19 E 1104.88 N 59 54 E 1178.10 3000.00 2553.94 2484.94 45 33 3100.00 2624.07 2555°07 45 14 3200.00 2694.99 2625.99 44 24 3300.00 2766.91 2697,91 43 38 3400.00 2839,68 2770.68 42 59 3500.00 2913.29 2844.29 42 12 3600.00 2987.76 2918.76 41 34 3700.00 3062.80 2993.80 ~1 15 3800.00 3137.42 3068.42 42 29 3900.00 3211.04 3142.04 42 21 N 58 27 E 1249.83 N 58 51 E 1321.12 N 59 5 E 1391,61 N 58 59 E 1461.07 N 59 15 E 1529.66 N 59 37 E 1597.33 N 59 57 E 1664.05 N 60 25 E 1730.11 N 60 14 E 1796.63 N 60 26 E 1864.28 0.00 0.00 -69.00 0 0 N 0 0 E 100.00 100o00 31,00 0 15 N 29 31 E 200,00 200.00 131.00 0 19 N 9 24 E 300,00 '300.00 231.00 0 19 N 10 41 E 400'00 400,00 331o00 0 17 N 11 50 E 500.00 499.99 430,99 0 16 N 11 I E 600.00 599.99 530,99 0 51 N 43 0 E 700,00 699.89 630.89 4 8 N 70 34 E 800.00 799.24 730.24 8 38 N 75 44 E 900.00 897.52 828.52 12 13 N 71 11 E 0.00 0.00 0.00 N 0.00 E 0.14 0.31 0.13 N 0.09 E 0.54 0.15 0.65 N 0.24 E 0.92 0.06 1.21 N 0.33 E 1.30 0.24 1.76 N 0.44 E 1,63 0.07 2.22 N 0.55 E 2.22 2.20 2.88 N 0.84 E 6.21 3,89 4.70 N 4.40 E 16.96 4.16 7,76 N 15,14 E 34,69 2,79 12,98 N 32,76 E 2.50 3.45 3.02 3.58 3.04 3.32 2.98 2.89 2.96 3.97 3.19 0.88 1.08 0.66 1.37 1.88 3.61 0.41 0.61 3.54 0.37 0.90 0.94 0.6 0.8~ 0.70 0.51 0.66 1.12 0.71 0.00 N 0 0 E 0.15 N 33 48 E 0.69 N 20 Z7 E 1.26 N 15 10 E 1.81. N 14 8 E 2.29 N 13 49 E 3.00 N 16 13 E 6.4~ N 43 4 E 17.01 N 62 52 E 35.23 N 68 23 E 21.19 N 55.14 E 59.08 N 68 58 E 30.44 N 82.06 E 87.52 N 69 38 E 39.36 N 114.43 E 121,01 N 71 I E 50.54 N 151.19 E 159,42 N 71 30 E 65.84 N 191.47 E 202.47 N 71 I E 83.33 N 236.15 E 250.42 N 70 33 E 102.29 N 285.37 E 303.15 N 70 16 E 123.38 N 338.17 E 359.98 N 69 57 E 148,90 N 391.71 E 419.06 N 69 11 E 178.65 N 446.67 E 481,.07 N 68 12 E 207.93 N 506.39 E 547.42 N 67 40 E 235.62 N 570.19 E 616.96. N 67 32 E 263.47 N 635.01 E 687.50 N 67 27 E 290,14 N 699.42 E 757.21. N 67 28 E 316.39 N 763.36 E 826.32 N 67 29 E 344.14 N 827.90 E 896,57 N 67 25 E 374.14 N 893.79 E 968.94 N 67 17 E 408.22 N 959.76 E 1042.97 N 66 57 E 442.64 N 1025.24 E 1116.72 N 66 38 E 477.50 N 1089.77 E 1189.79 N 66 20 E 514.75 N 1151.07 E 1260.93 N 65 54 E 551.87 N 1211.93 E 1331.67 N 65 31 E 588.16 N 1272.38 E 1401.74 N 65 11 E 623.88 N 1331.95 E 1470.83 N 64 54 E 659,13 N 1390.80 E 1539,08 N 64 38 E 693.52 N 1449.09 E 1606.50 N 64 25 E 727.11 N 1506.76 E 1673.03 N 64 14 E 759.97 N 1564.12 E 1738.97 N 64 5 E 792.84 N 1622.00 E 1805.40 N 63 57 E 826.41 N 1680.77 E 1872.95 N 63 49 E FEET DEG/IO0 FEET FEET FEET.. DEG MIN COMPUTATION DATE: 30-JUL-86 PAGE 2 ARCO ALASKA. INC. 3K-3 KUPARUK NORTH SLOPEtALASKA DATE OF SURVEY: 15-JUL-86 KELLY BUSHING ELEVATION: ENGINEER= BARBA INTERPOLATED VALUES FOR EVEN 100 FEET OF NEASURED DEPTH 69.00-FT TRUE SUB-SEA COURSE qEASURED VERTICAL VERTZCAL DEVIATION AZIMUTH DEPTH. DEPTH DEPTH DEG MIN DEG 4000°00 3285.28 3216.28 41 49 4100.00 3359.99 3290.99 41 26 4200.00 3435.29 3366.29 40 53 4300.00 3510.94 3441.94 41 24 4400.00 3584.62 3515.62 43 22 4500.00 3656.79 3587.79 44 13 4600.00 3728.39 3659.39 43 58 4700.00 3800.77 3731.77 43 11 4800-00 3874.07 3805.07 42 33 4900.00 3948.25 3879.25 42 8 5000.00 4022.43 3953.43 41 54 5100.00 4096.77 4027.77 42 0 5200.00 4171.09 4102.09 41 56 5300.00 4245°55 4176.55 41 47 5400.00 4320.18 4251.18 41 32 5500.00 4395.28 4326.28 41 10 5600,00 4470.75 4401.75 40 51 5700.00 4546.65 4477.65 40 25 5800.00 4622.93 4553.93 40 18 5900.00 4698.86 4629.86 40 39 6000.00 4774.69 4705.69 40 46 6100.00 4850.29 4781.29 41 0 6200.00 4925.64 4856.64 41 10 6300.00 5001.05 4932.05 40 58 6400.00 5076.44 5007.44 41 35 6500.00 5150.74 5081.74 41 58 6600.00 5225.02 5156.02 42 8 6700.00 5299.25 5230.25 42 2 6800.00 5373.44 5304.44 42 11 6900.00 5447.47 5378.47 42 19 7000.00 5521.33 5451.33 42 24 7100.00 5595.04 5516.04 42 35 7200.00 5668.59 5599.59 42 41 7300.00 5741.98 5672.98 42 52 7400.00 5815.37 5746.37 42 47 7500.00 5888.69 5819.69 42 51 7600e00 5961o94 5892.94 42 57 7700.00 6035.05 5966.05 43 5 7800.00 6108.02 6039.02 43 9 7900.00 6181.51 6112.51 42 16 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST. DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ,MIN N 60 28 E 1931.21 N 61 11 E 1997.63 N 62 27 E 2063.30 N 63 13 E 2128.46 N 58 46 E 2195.96 N 57 29 E 2265.17 N 58 58 E 2334.97 N 60 55 E 2403.93 N 61 32 E 2471.85 N 60 57 E 2538.83 0.34 0.81 1.22 2.43 2.67 1.14 1.67 1.51 1.03 0.65 859.43 N 1739.06 E 1939.83 N 63 42 E 891.85 N 1797.09 E 2006.22 N 63 36 E 923.03 N 1855.02 E 2071.98 N 63 32 E 952.54 N 1913.38 E 2137.38 N 63 32 E 985.20 N 1972.54 E 2204.89 N 63 27 E 1022.10 N 2031.10 E 2273.78 N 63 17 E 1059.10 N 2090.29 E 2343.29 N 63 7 E 1093.58 N 2150.05 E 2412.18 N 63 Z E 1126.11 N 2209.79 E 2480.18 N 62 59 E 1158.36 N 2268.59 E 2547.21 N 62 57 E N 60 29 E 2605.83 N 60 20 E 2672.66 N 60' 10 E 2739.53 N 59 58 E 2806.25 N 59 36 E 2872.79 N 59 13 E 2938.81 N 58 47 E 3004.41 N 58 21 E 3069.52 N 58 I E 3134.18 N 58 2 E 3199.24 0.56 0.37 0.31 0.32 0.66 0.45 0.49 0.34 1.03 0.34 1191.15 N 2317.09 E 2614.22 N 62 53 E 1224.20 N 2385.23 E 2681.04 N 62 49 E 1257.38 N 2443.34 E 2747.89 N 62 46 .E 1290.67 N 2501.19 E 2814.57. N 62 42 E 1324.14 N 2558.72 E 2881.04 N 62 38 E 1357.74 N 2615.57 E 2946.97 N 62 33 E 1391.50 N 2671.82 E 3012.46 N 62 29 E 1425.47 N 2727.38 E 3077.42 N 62 24 E 1459.58 N 2782.30 E 3141.90 N 62 19 E 1494.03 N 2837.50 E 3206.79 N 62 13 E N 57 45 E 3264.44 N 57 35 E 3329.89 N 57 13 E 3395.63 N 56 30 E 3461.28 N 55 54 E 3526.93 N 55 15 E 3593.79 N 54 48 E 3660.63 N 54 38 E 3727.51 N 54 19 E 3794.41 N 53 52 E 3861.46 0.26 0.26 0.60 0.42 1.88 0.48 0.46 0.21 0.42 0.58 1528.64 N 2892.74 E 3271.81 N 62 8 E 1563.67 N 2948.04 E 3337.07 N 62 3 E 1599.05 N 3003.46 E 3402.61 N 61 58 E 1634.95 N 3058.45 E 3468.02 N 61 52 E 1671.45 N 3113.07 E 3533.40 N 61 46 E 1709.30 N 3168.28 E 3599.95 N 61 39 E 1747.69 N 3223.12 E 3666.46 N 61 31 E 1786.42 N 3277.81 E 3733.00 N 61 24 E 1825.33 N 3332.40 .E 3799.57 N 61 17 E 1864.77 N 3386.85 E 3866.28 N 61 9 E N 53 30 E 3928.6'4 N 53 8 E 3995.98 N 52 45 E 4063.44 N 52 35 E 4131.03 N 52 22 E 4198.60 N 52 11 E 4266.23 N 51 56 E 4333.91 N 51 42 E 4401.70 N 51 29 E 4469.61 N 51 12 E 4536.92 0.34 0.28 0.65 0.66 0.27 0.35 0.33 0.19 0.36 0.56 1904.69 N 3441.17 E 3933.12 N 61 2 E 1945.04 N 3495.39 E 4000.11 N 60 54 E 1985.86 N 3549.46 E 4067.23 N 60 46 E 2027.07 N 3603.46 E 4134.48 N 60 38 E 2068.43 N 3657.34 E 4201.73 N 60 30 E 2110.03 N 3711.13 E 4269.04 N 60 22 E 2151.86 N 3764.84 E 4336.42 N 60 14 E 2194.04 N 3818.46 E 4403.92 N 60 7 E 2236.50 N 3872.05 E 4471.55 N 59 59 E 2278.86 N 3925.02 E 4538.61 N 59 51 E ARCO ALASKAt INC. 3K-3 KUPARUK NORTH SLOPEtALASKA COMPUTATION DATE: 30-JJJ'L-86 PAGE DATE OF SURVEY: 15-JUL-86 KELLY BUSHING ELEVATION: ENGINEER: BARBA 69.00-FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE qEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST.,. AZIMUTH FEET DEG/IO0 FEET FEET FEET . D,EG MIN 8000.00 6255.46 6186.46 42 27 8[00.00 6329.31 6260.31 42 13 8200.00 6403.70 6334.70 41 43 8300,.00 6478.28 6409.28 41 47 ~8400.00 6552.62 6483.62 42 9 8500.00 6626.71 6557.7! 42 15 8600.00 670[.29 6632.29 40 52 8700.00 6778.67 6709.67 37 22 8800.00 6859.74 6790.74 35 19 8900.00 6941.32 6872°32 35 19 N 51 4 E 4603.70 N 51 25 E 4670.61 N 52 4 E 4737.01 N 52 16 E 4803.25 N 52 23 E 4869.78 N 52 13 E 4936.57 N 51 53 E 5002.78 N 53 56 E 5065.78 N 56 49 E 5124.25 N 56 49 E 5182.06 0.32 0.53 0.66 0.27 0.12 0.6! 2.54 3.88 0.00 0.00 2321.15 N 3977.38 E 4605.14 N 59 43 E 2363.36 N 4029.96 E 4671.83 N 59 36 E 2404.78 N 4082.43 E 4738.05 N 59 29 E 2445.55 N 4135.10 E 4804.1&, N 59 23 E 2486.39 N 4188.06 E 4870.52, N 59 18 E ~ 2527.42 N 4241.22 E'4937.19~ N 59 12 E 2568.41 N 4293.73 E 5003.29 N 59 6 E 2606.89 N 4344.01 E 5066.19 N 59 I E 2639°66 N 4392.50 E 5124.63 N 58 59 E 2671.30 N 4440.90 E 5182.41 N 58 58 E ARCO ALASKAt INC. 3K-3 KUPARUK NORTH SLOPEsALASKA COMPUTATION DATE: 30-JUL-86 TRUE SUB-SEA COURSE qEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG HIM PAGE DATE OF SURVEY: 15-JUL-86 KELLY BUSHING ELEVATION: 69oO0~FT ENGINEER: BARBA INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPT VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0o00 0o00 -69°00 0 0 N 0 0 E 0o00 1000.00 994.61 925o61 15 17 N 69 49 E 58°05 2000.00 1855.24 1786-24 42 57 N 65 28 E 540o10 3000.00 2553.94 248~o9~ 45 33 N 58 27 E 1249.83 4000°00 3285°28 3216o28 4! 49 ,N 60 28 E 1931o21 5000°00 4022°43 3953°43 4! 54 N 60 29 E 2605°83 6000°00 4774°69 4705.69 40 46 N 57 45, E 3264°44 7000°00 5521o33 5452o33 42 24 N 53 30 E 3928.64 8000°00 6255°46 618&-46 42 27 N 5! 4 E 4603°70 0.00 2°$0 3°[9 0.37 0.34 0.56 0.26 0°32 0.00 N 0.00 E 0o00 N 0 0 E 2[°[9 N 55o14 E 59.08 N 68 58 E 207.93 N 506.39 E 547.42 N 67 40 E 514o75 N ~I5~.07 E ~260o93 N 65 54 E 859°43 N 1739.06 E 1939.83 N 63 42 E ~291o~5 N 2327°09 E 2614o22 N 62 53 E 1528.64 N 2892°7~ E 3271.81 N' 62 8 E 190~o69 N 3441.17 E 3933.12 N 61 2 E 2321.15 N 3977.38 E 4605.14 N 59 43 E COMPUTATION DATE: 30-JUL-86 PAGE 5 ARCO ALASKA, INC. 3K-3 ~KUPARUK NORTH SLOPEsALASKA DATE OF SURVEY: 15-JUL-86 KELLY BUSHING ELEVATION: ENGINEER: BARBA INTERPOLATEDrVALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE qEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 69.00_ F.T 0.00 0.00 -69.00 0 0 N 0 0 E 69.00 69.00 0.00 0 10 N 35 39 E 169.00 169.00 100.00 0 18 N 12 15 E 269.00 269.00 200.00 g 19 N 9 53 E 369°00 369.00 300.00 0 18 N 11 18 E 469.01 469.00 400.00 0 16 N 12 I E 569o01 569.00 500.00 0 28 N 24 8 E 669°04 669.00 600.00 2 55 N 65 I E 769'46 769°00 700.00 ? 24 N 74 59 E 870.87 869.00 800.00 11 Z! N 72 38 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST .DIST. AZIMUTH 973~47 969.00 900.00 14 33 1077.48 1069o00 1000.00 17 13 1183.27 1169.00 1100o00 20 46 1291.30 1269o00 1200.00 23 41 1402.06 1369.00 1300.00 27 13 1516.36 1469.00 1400.00 30 45 1635.20 1569.00 1500o00 34 19 1758.04 1669o00 1600o00 36 3 1884.76 1769.00 1700.00 39 46 2018.90 1869.00 1800.00 43 23 FEET DEG/IO0 FEET FEET FEET DEG, MIN 2159.26 1969.00 1900.00 44 50 2299.09 2069.00 2000.00 43 56 2437~73 2169.00 2100.00 44 24 2580.82 2269.00 2200.00 47 3 2729.80 2369.00 2300.00 47 49 2877.72 2469.00 2400.00 46 55 3021.~9 2569.00 2500o00 45 30 3163.52 2669.00 2600.00 44 43 3302..88 2769.00 2700.00 43 37 3439.99 2869.00 2800.00 42 40 0.00 0.00 0.00 N 0.00 E 0.04 0.29 0.03 N 0.02 E 0.43 0.11 0.48 N 0.21 E 0.80 0.13 1.04 N 0.30 E 1.19 0.05 1.59 N 0.41 E 1.53 0'03 2.08 N 0.52 E 1.92 0.86 2.60 N 0.65 E 4.33 3.90 4.00 N 2.62 E 12.88 4.90 6.70 N '11.00 E 28.91 3.33 11.13 N 27-11 E 3574.92 2969.00 2900.00 41 42 3708.24 3069.00 3000.00 41 17 3842.97 3169.00 3100.00 42 39 3978.14 3269.00 3200.00 41 54 4112.04 3369.00 3300.00 41 22 4244.51 3469.00 3400.00 40 48 4378,50 3569.00 3500.00 43 6 4517.10 3669.00 3600.00 44 18 4656.26 3769.00 3700.00 43 35 4793.10 3869.00 3800.00 42 36 N 69 34 E 51.28 N 71 48 E 79.21 N 75 10 E 112.34 N 70 59 E 151.72 N 68 43 E 198.41 N 68 42 E 252.83 N 68 36 E 315.88 N 64 6 E 386.43 N 61 46 E 464.04 N 65 57 E 552'95 N 66 45 E 650.39 N 67 40 E 746.91 N 66 53 E 841.68 N 64 39 E 943.07 N 62 14 E 1053.14 N 60 50 E 1161.88 N 58 30 E 1265.16 N 59 3 E 1366.01 N 58 59 E 1463.06 N 59 25 E 1556.85 N 59 51 E 1647.41 N 60 26 E 1735.53 N 60 12 E 1825.76 N 60 27 E 1916.63 N 61 15 E 2005.60 N 63 8 E 2092.28 N 59 35 E 2181.17 N 57 34 E 2277.14 N 60 8 E 2373.90 N 61 32 E 2467.18 3.27 2.96 3.22 3.67 3.02 3.66 2.58 3.23 4.04 3.00 1.01 0.65 1.80 3.43 0.50 3.61 0.31 0.83 0.69 0.90 0.78 0.77 0.50 0.42 0.94 1.14 4.23 1.06 1.53 0.90 18.78 N 48.67 E 28..37 N 75.58 E 0.00 N 0 0 E 0.04 N 36 11 E 0.52 N 23 32 E 1.08 N 15 58 E 1.64 N 14 28 E ' Z.14 N 13 58 E 2.68 N 14 1 E 4.78 N 33 11 E 2.88 N 58 39 E 9.31 N 67' 40 E 52.17 N 68 54 E 80.73 N 69 25 E 37*88 N 108.65 E 115.06 N 70 46 E 49.34 N 147.85 E 155.86 N 71 32 E' 66.18 N 192.33 E 203.40 N ?1 0 E 86.34 N 243.84 E 258.67 N 70 30 E 109.37 N 303.72 E 322.81 N 70 Il E 137.54 N 369.25 E 394.03 N 69 34 E 174.08 N 437.90 E 471.23 N 68 19 E 213.19 N 518.23 E 560.37 N 67 38 E 252.24 N 608.65 E 658.84 N 67 29 E 289.90 N 698.83 E 756.58 N 67 28 E 326.58 N 787.57 E 852.60 N 67. 28 E 368.12 N 881.08 E 954.89 N 67 19 E 418.52 N 979.33 E 1065.01 N 66 51 E 469.46 N 1075.68 E 1173.66 N 66 25 E 522.77 N 1164.13 E 1276.13 N 65 49 E 575.00 N 1250.41 E 1376.28 N 65 18 E 624.90 N 1333.66 E 1472.80 N 64 53 E 672.99 N 1414.20 E 1566.17 N 64 33 E 718.77 N 1492.36 E 1656.43 N 64 16 E 762.63 N 1568.84 E 1744.38 N 64 4 E 807.34 N 1647.28 E 1834.48 N 63 53 E 852.22 N 1726.37 E 1925.26 N 63 43 E 895.70 N 1804.08 E 2014.19 N 63 35 E 936.30 N 1880.89 E 2101.05 N 63 32 E 977.48 N 1959.93 E 2190.16 N 63 29 E 1028.55 N 2041.19 E 2285.69 N 63 15 E 1078.82 N 2123.87 E 2382.15 N 63 4 E 1123.89 N 2205.67 E 2~75.51 N 62 59 E COMPUTATION DATE: 30-JUL-86 6 ARCO ALASKAs INC. 3K-3 KUPARUK NORTH SLOPEs ALASKA PAGE DATE OF SURVEY: 15-JUL-86 KELLY BUSHING ELEVATZON: 69.00., FT ENGINEER: BARBA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG 4928~02 3969.00 3900.00 42 11 5062.58 4069.00 4000.00 42 1 5197.20 4169.0.0 4100.00 41 56 5331.43 4269.00 4200.00 41 45 5465.05 4369.00 4300.00 41 16 5597.69 4469.00 4400.00 40 51 5729.35 4569.00 4500.00 40 21 5860.61 4669.00 4600.00 40 39 5992.49 4769.00 4700.00 40 45 DEG MIN FEET DEG/IO0 FEET :FEET FEET DEG MIN N 60 49 E 2557.64 N 60 21 E 2647.60 N 60 10 E 2737.66 N S9 52 E 2827.18 N 59 21 E 2915.77 N 58 48 E 3002.90 N 58.13 E 3088.54 N 58 ' 2 E 3173.57 N 57 46 E 3259.54 6124.80 4869.00 4800.00 41 2 N 57 31 E 3346.18 N 56 48 E 3433.47 N 55 58 E 3520.41 N 55 7 E 3610'17 N 54 40 E 3700.27 N 54 21 E 3790.39 N 53 45 E 3881.05 N 53 17 E 3972.15 N 52 45 E 4063.81 N 52 31 E 4155.92 N 52 1S E 4248.07 6257.56 4969.00 4900.00 41 0 6390.10 5069.00 5000.00 41 27 6524.55 5169.00 5100.00 41 57 6659.26 5269.00 5200.00 42 2 6794.01 5369.00 5300.00 42 10 6929.15 5469.00 5400.00 42 22 7064.64 5569.00 5500.00 42 33 7200.56 5669.00 5600.00 42 41 7336.82 5769.00 5700.00 42 46 7473.14 5869.00 5800.00 42 51 N 51 55 E 4340.45 N 51 37 E 4433.27 N 51 15 E 4525.63 N 51 7 E 4616.01 N 51 43 E 4706.19 N 52 16 E 4795.00 N 52 Z2 E 4884.5Z N 52 0 E 4974.52 N 53 34 E 5058.31 N 56 49 E 5130.81 7609.65 5969.00 5900.00 42 58 7746.51 6069.00 6000.00 .43 7 7883.08 6169.00 6100.00 42 21 8018.37 6269.00 6200.00 42 28 8153.46 6369.00 6300.00 41 54 8287.56 6469.00 6400.00 41 47 8422.09 6569.00 6500.00 42 7 8556.97 6669.00 6600.00 41 41 8687.76 6769.00 6700.00 37 50 8811.35 6869.00 6800.00 35 19 8900.00 6941.32 6872.32 35 19 N 56 49 E 5182.06 0.67 0.30 0.35 0.25 0.33 0.46 0.38 0.42 0.25 1167.52 N 2285.04 E 2566.03 N 62 56 E 1211.80 N 2363.43 E 2655.99 N 62 51 E 1256.45 N 2441.72 E 2746.02 N 62 46 E 1301.16 N 2519.31 E 2835.48 N 62 41 E 1345.97 N 2595.76 E 2923.97 N 62 35 E '" 1390.72 N 2670.53 E 3010.95 N 62 29 E 1435.46 N 2743.56 E 3096.39 N 62 22 E 1480.45 N 2815.71 E 3181.18 N 62 15 E 1526.03 N 2888.60 E 3266.92 N 62 9 E 0.28 ;1572.41 N 2961.79 E 3353.30 N 62 2 E 0.65 1.65 0.47 0.16 0.38 0.58 0.34 0.65 0.31 0.24 0.26 0.23 0.55 0.35 0.73 0.19 0.14 1.57 4.31 0.00 0.00 1619.64 N 3035.22 E 3440.32 N 61 54 E 1667.80 N 3107.65 E 3526.90 N 61 46 E 1718.66 N 3181.74 E 3616.25 N 61 37 E 1770.63 N 3255.55 E 3705.90 N 61 27 E 1822.99 N 3329.13 E 3795.58 N 61 17 E 1876.37 N 3402.71 E 3885.77 N 61 7 E 1930.71 N 3476.23 E 3976.41 N 60 57 E 1986.09 N 3549.76 E 4067.60 N 60 46 E 2042.28 N 3623.32 E 4159.25 N 60 35 E 2098.84 N 3696.69 E 4250.96 N 60 24 E 2155.93 N 3770.02 E 4342.93 N 60 14 E 2213.76 N 3843.40 E 4435.36 N 60 3 E 2271.74 N 3916.14 E 4527.35 N 59 52 E 2328.95 N 3987.03 E 4617.41 N 59 42 E 2385.65 N 4058.01 E 4707.31 N 59 32 E 2440.47 N 4128.54 E 4795.91 N 59 24 E 2495.44 N 4199.80 E 4885.24 N 59 16 E 2550.86 N 4271.35 E 4975.07 N 59 9 E 2602.44 N 4337.98 E 5058.73 N 59 2 E 2643.25 N 4397.99 E 5131.19 N 58 59 E 2671*30 N 4440.90 E 5182.4i' N 58 58 E ARCO ALASKAt INC. .qK~3 KUPARUK NORTH SLOPEtALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COHPUTATION DATE: 30-JUL-86 INTERPOLATED VALUES FOR CHOSEN HORIZONS PAGE DATE OF SURVEY: IS-JUL-86 KELLY BUSHING ELEVATION: ENGINEER: 8ARBA 69.0o "~T MEASURED DEPTH BELOW KB 8331.00 8401.00 8511.00 8674.00 8798.00 8900.00 SURFACE LOCATION AT ORIGIN= 1384 FSLt'' 318 FWL, SEC 35, TI3N, RgE, DM TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST. 6501.42 6432°42 2458.18 N 4151.43 E 6553.36 6484.36 2486.80 N 4188.59 E 6634.85 6565.85 2531.96 N 4247.07 E 6758.12 6689.12 2597.43 N 4331.20 E 6858.11 6789.11 2639.02 N 4391.53 E 6941.32 6872.32 2671.30 N 4440.90 E ARCO ALASKA, INC. 3K-3 KUPARUK NORTH SLOPE,ALASKA MARKER 'TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE: 30-JUL-86 PAGE DATE OF SURVEY: 15-JU'L-86 KELLY BUSHING ELEVATION: ENGINEER: 8ARBA 69,.00 .~F'T ~*~**00~*** STRATIGRAPHIC MEASURED DEPTH BELOW KB 8331.00 8401.00 8511.00 8674.00 8798.00 8900.00 SUMMARY ~000~0~*~ SURFACE LOCATION AT. ORIGIN= 1384 FSLs 318 FNL~ SEC 35s T13N~ RgE~ UR TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/~EST 6501.42 6432.42 2458.18 N 4151.43 E 6553.36 6484.36 2486.80 N 4188.59 E 6634.85 6565.85 2531.96 N 4247.07 E 6758.12 6689.12 2597.43 N 433.1oZ0 E 6858.11 6789.11 2639.02 N 4391.53 E 6941.32 6872.32 2671.30 N 444.0.90 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 8900.00 6941.32 6872.32 5182.41 N 58 58 E SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3K-3 FIELD KUPARUK COUNTRY USA RUN 1 DATE LOOOEO 1S - dUL - 86 REFERENCE 00007181S WELL' 3K-3 (1384' FSL, 318' FWL, S35,T13N,R9E,UM) HORIZONTAL PROJECTION NORTH SO00 REF 00007 ! 6 ! 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SCALEO IN VERTICAL DEPTHS HORIZ SCALE = 1/]OOO IN/FT ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 17, 1986 Transmittal #5832 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please receipt and return one signed copy of this transmittal. acknowledge Open Hole Fin al Logs: 3N-18x~2'' DIL-SFL-GR 6-2-86 2000-10608 ~5" DIL-SFL-GR 6-2-86 2000-10608 '2" FDC Porosity 6-2-86 8400-10582 x~.l~ FDC Porosity 6-2-86 8400-10582 FDC Raw 6-2-86 8400-10582 '5" FDC Raw 6-2-86 8400-10582 XCyberlook 6-2-86 9600-10550 3K-3~2'' DIL-SFL-GR 6-27-86 200-8894 ~-5" DIL-SFL-GR 6-27-86 200-8894 '-2" FDC Porosity 6-27-86 4835-8869 ~5" FDC Porosity 6-27-86 4835-8869 ~ 2" FDC Raw 6-27-86 4835-8869 "5" FDC Raw 6-27-86 4835-8869 ~yberl ook 6-27-86 8200-8869 2T-1J~ 2" DIL-SFL-GR 6-18-86 '- 5" DIL-SFL-GR 6-18-86 ~2" FDC Porosity 6-18-86 -~'~5" FDC Porosity 6-18-86 ~ 2" FDC Raw 6-18-86 "5" FDC Raw 6-18-86 '~ Cyberl ook 6-18-86 1000-8248 1000-8248 3300-8222 3300-8222 3300-8222 330O-8222 7650-8200 Receipt Acknowledged: Date: Distribution: NSK D & M Vault (1 film) Drilling Rathmell State of Alaska (1 bl + 1 se) ARCO Alaska. Inc. is a Subs~cliary ol AHanticRichfieldCornpany STATE OF ALASKA ALASK .,)IL AND GAS CONSERVATION COMb ,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown ~ Stimulate ~ Plugging ~ Perforate E~ Pull tubing Alter Casing ~ Other .~ Com_p'lete 2. Name of Operator ARCO Alaska, ln~, 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1384'FSL, 318'FWL, Sec.35, T13N, R9E, UM At top of productive interval 1438'FNL, 811'FEL, Sec.35, T13N, R9E, UM At effective depth 1257'FNL, 570'FEL, Sec.35, T13N, R9E, UM At total depth 1225'FNL, 521'FEL, Sec.35, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 69 ' 6. Unit or Property name Kuparuk River Unit 7. Well number ~,K-'~ 8. Approval number 257 9. APl number 50-- 029-21602 10. Pool Kuparuk River Oil Pool Feet'¢ 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 8900'MD 6941'TVD 8798'MD 6858'TVD Production Length Size 80' 16" 4791 ' 9-5/8" 8879 ' 7" feet feet feet feet Plugs (measured)None Junk (measured) None Cemented 1540# Pol eset 1400 sx AS III & 350 sx Class G 400 sx Class G Measured depth 1lO'MD 4828 'MD 8879 'MD Rue Vertical depth 110'TVD 3969'TVD 6925'TVD Perforation depth: measured 8533 ' MD 8541 'MD true vertical 6652'TVD 6658 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail t~ 8338' Packers and SSSV (type and measured depth) HR-1-SP pkr @ 8311' & TRDP-1A SSSV ~ 1822' 8545 'MD 8591 'MD 8598'MD 8581 'MD 8593 'MD 8602 'MD 6661'TVD 6696'TVD 6701'TVD 6688'TVD 6697'TVD 6703'TVD 8614 ' -8626 'MD 6712'-6721 'TVD E£EIYED 12. Stimulation or cement squeeze summary InNt/eArvals treated (measured) Treatment description including volumes used and final pressure SEP 2 5 1986 Nask~ 0ii & Gas Cons. Comm[ssi~ 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History w/Addendum, dated 7/21/86) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~× Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title A,%,%oci ate Engineer (DAM) SW0/097 Date Submit in Duplicate 'ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after ailowable has been assigned or well is Plugged, Abandoned. or Sold. "Fl'nat Report" should be submitted also when operations are susoended for an indefinite or appreciable iength of time. On workovers when an official test is not required upon completion, report completion and representa;=~e test =a;a in blocks provided. The "Final Report" form may be used for reporting the entire Operation if space is available. DistrictAlaska County or Parish Field Lease or Unit Kuparuk River Auth. or W.O. no. T t e AFE AK1355 NOrdic #1 North Slope Borough Accounting cost center code State Alaska ADL 25519 JWeH no, 3K-3 Completion API 50-029-21602 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete A.R.Co. W.I. 56.24% Date 8/27/86 I'Total number of wells (active or inactive) on this cost center prior to plugging and I abandonment of this well Hour Prior status il a W.O. 1645 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 8/28/86 8/29/86 7" @ 8879' 8798' PBTD, Rn 2-7/8" compl 10.0 ppg NaC1 Accept rig @ 1645 hrs, 8/27/86. ND tree, NU & tst BOPE. Tstd csg to 2500 psi - ok. RU GO, perf@ 1SPF, 120° phasing f/8614'-8626', 8593', 8598', 8602', 8581', 8591', 8533', 8541' & 8545'. RD GO. RU & rn 262 its, 2-7/8" CA. 7" @ 8879' 8798' PBTD, Rn 2-7/8" compl 10.0 ppg NaC1 Rn 262 jts, 2-7/8" compl, set pkr @ 8311' SSSV @ 1822'& lnd tbg @ 8338'. Tst pkr & SSSV. ND BOPE, NU & tst tree to 5000 psi. Displ well w/diesel. RR @ 1545 hrs, 8/23/86. Complete work on windwalls & insulation prior to moving rig to 2T-13. RECEIVED SEP 2 5 198 ; Alas~ Oil & Gas Cons. t,0mnlissi~ Old TD J Ne','; TD PB Depth Released rig/ Date Kind of rig 1545 hrs. 8/23/86 Classifications (oil, gas, etc.) Type completion (single. dual. etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 8798 ' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test 1~rne :Production · O,I on test Gas per day Pump size, SPM X length Choke size T P. C.P. Water % GOR Gravity Allowable : Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Tide Drilling Supervisor WELL: 7/18/86 ADDENDUM 3K-3 Rn CET/CCL/GR f/8800'-7595'. Rn gyrof/8751'-54,. RECEI¥ D SEP 2 5 198~ Rlaska Oil & Gas Cons. Anchorc~r~' Drilling Supervisor Date ARCO Alaska. In(' Post Office ,.,~,x 100360 Anchorage. Alaska 99510-0360 Telel~one 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 07-30-86 TRANSMITTAL # 5727 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes Plus Listings. Schl' 2T-8' 07-21-86 Run #1 ~2T-9 w 07-03-86 Run #3 ~2T-12Aw/07-12-86 Run #1 ~ 3K-3f 06-27-86 Run #1 ~3K-4/ 07-04-86 Run #1 --'~3K-5/ 07-12-86 Run #1 0097.5-7669.0 3300.0-6389.0 4885.5-6756.0 0187.0-8929.0 2992.0-8937.5 2388.5-8168.5 One copy of each EDIT EDIT EDIT EDIT Receipt Acknowledged: . State of Alaska Date: ARCO AIIIkl. InC. ~1 · Subs~l,ar¥ of AlllrttlcR,cllftel~COml~en~, STATE OF ALASKA ALASE ,)IL AND GAS CONSERVATION COMN, 31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown~ Re-enter suspended well ~- Alter casing Time extension ~ Change approved program ~ Plugging :~ Stimulate r- Pull tubing- Amend order r_ Perforate-- Other '-' 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 69'RKB feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, AK 99510 Kuparuk River Unit 4. Location of well at surface 1384'FSL, 318'FWL, Sec.35, T13N, R9E, UM At top of productive interval 1378'FNL, 886'FEL, 5ec.35, T13N, R9E, UM (approx.) At effective depth 1205'FNL, 594' FEL, Sec.35, T13N, R9E, UM (approx.) At total depth l163'FNL, 540'FEL, Sec.35, T13N, R9E, UM (approx.) 7. Well number 8. Permit number 86-103 9. APl number 50-- 029-21602 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8900 feet feet 6927 8798 6852 Casing Length Size Conductor - 80 ' 1 6" Surface 4791 ' 9-5/8" P r oducti on 8879 ' 7" feet feet Plugs (measured) None Junk (measured) None Cemented 1540# Poleset 1400 sx AS Ill 350 sx Class G 400 sx Class G Measured depth 1lO'MD & 4828'MD True Vertical depth 110'TVD 3909 ' TVD 8879'MD 6911 'TVD Perforation depth: measured None true vertical N o n e Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Well Hi story Description summary of proPosal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation September~ 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,0~ ~J.~ Title Associate Engineer Commission Use Only ( DAH ) Date SA/077 Conditions of approval Approved by Notify commission so representative may witness .rq Plug integrity G BOP Test [] Location clearance ~ ~ -~-¢~;-'-~ '-. -: . · Commissioner by order of the commission Date '? '~// ~P~ Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska County. parish or borough North Slope Borough Lease or Unit ADL 25519 Tte Drill Kuparuk River IState Alaska JWell no. 3K-3 Auth. or W.O. no. AFE AK1355 Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. begun API 50-029-21602 ARCO W.I. Prior status if a W.O. Spudded JOate JHour 6/20/86 Complete record for each day reported 6/21/86 thru 6/23/86 1830 hrs. Date and depth as of 8:00 a.m. 6/24/86 6/25/86 6/26/86 16" @ 110'/9-5/8" @ 4828' 4848', (4738'), Cmt'g 9-5/8" Wt. 9.4, PV 17, YP 10, PH 9.5, WL 12.8, Sol 8 Accept rig @ 1630 hrs, 6/20/86. NU diverter sys. Spud well @ 1830 hrs, 6/20/86. Drl to 612', DD & surv to 4828', short trip, C&C, POOH. RU & rn 121 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 4848', FC @ 4747'. 756', 6.8°, N76.4E, 754.99 TVD, 16.21VS, 4.01N, 16.57E 1224', 21.9°, N74.9E,1205.98 TVD, 135.46 VS, 42.09N, 133.22E 1692', 35.7°, N66.0E,1615.32 TVD, 356.78 VS, 125.96N, 341.55E 2105', 45.3°, N64.8E,1931.21TVD, 621.19 VS, 247.12N, 577.49E 2482', 44.7°, N64.8E,2197.79 TVD, 886.05 VS, 360.62N, 818.70E 3585', 41.7°, N60.2E,2986.78 TVD, 1656.03 VS, 741.45N, 1488.50E 4405', 43.7°, N57.5E,3600.26 TVD, 2199.55 VS, 1007.01N,1963.32E 56.24% 9-5/8" @ 4828' 5896', (1048'), Drlg Wt. 9.0, PV 4, YP 1, PH 9.5, WL 10.4, Sol 5 Cmt w/1400 sx AS III, followed by 350 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. CIP @ 0845 hrs, 6/23/86. ND diverter, NU & tst BOPE. TIH w/8½" BHA to~4746"',~- ~ . tst csg to 2000 psi. DO flt equip, cmt & formation to ~-858~. i: Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole to 5896'. 5343' 41 9°,N59 1E, 4291.10 TVD, 2819.32 VS,1323 14N, 24~96~52.E ' ' ' ' . · '.:.~ 7408', (1512'), Drlg Wt. 9.1, PV 3, YP 2, PH 9.5, WL 8.8, Sol 6 .... Drl & surv 18½" hole to 7408', 5911', 41.1°, N56.4E, 4716.51TVD, 3195.67 VS, 1523.98N, 2814.83E 6479', 42.2°, N54.7E, 5140.93 TVD, 3572.72 VS, 1737.52N, 3126.11E 7010', 42.4°, N53.4E, 5533.67 TVD, 3929.11VS, 1947.32N, 3415.41E 9-5/8" @ 4828' 8530', (1122'), POOH Wt. 9.8, PV 17, YP 9, PH 8.5, WL 4.8, Sol 11 Drl & surv 8½" hole to 8530'. 7328', 43.1°, N52.0E, 5767.18 TVD, 4143.94 VS, 2078.13N, 3587.12E 7895', 42.7°, N51.0E, 6182.53 TVD, 4527.20 VS, 2318.40N, 3889.18E 8271', 41.9°, N53.0E, 6460.63 TVD, 4778.73 VS, 2474.19N, 4088.59E 8450', 42.2°, N51.4E, 6593.55 TVD, 4897.94 VS, 2547.67N, 4183.32E The above is correct see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instruclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. DistrictAlaska County or Parish Field Lease or Unit Kuparuk River Auth. or w.o.AEgnO. A_K1355 T tie Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 6/27/86 Date and depth as of 8:00 a.m. 6/28/86 thru 6/29/86 A.R.Co. W.I. Date Complete record for each day reported Accounting cost center code State North Slope Borough Alaska ADL 25519 Drill API 50-029-21602 rTotal number of wells (active or inactive) on this 56.24% Icost center prior to plugging and I labandonment of this well IHour I Prior status if a W,O. 6/20/86 / 1830 hrs. I / 9-5/8" @ 4828' 8900', (370'), TIH Wt. 9.9, PV 13, YP 7, PH 9.0, WL 4.2, Sol 11 Drl & surv 8½" hole to 8900', short trip, C&C, POOH, LD BHA. RU Schl, rn DIL/SFL/SP/CAL/GR/FOC/CNL; unable to get below 8510', POOH, RD Schl. RIH f/cond'g trip. 8900', 42.0°, N53.0E, 6927.44 TVD, 5197.93 VS, 2732.58N, 4421.70E 7" @ 8879' 8900' TD, 8798' PBTD, RR 10.0 ppg Brine TIH, rm 8500'-8600', C&C, POOH. RU Schl, rn DIL/SP/SFL/FDC/CNL/GR/CAL f/8900'-4835', RD Schl. RIH, rm 8660'-8900', C&C, POOH, LD DP. Chg rams to 7" & tst. RU & rn 217 jts, 7", 26#, J-55 BTC csg w/FS @ 8879', FC @ 8798'. Cmt w/lO0 sx C1 "G" w/4% D-20 & .2% D-46, followed by 300 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/10.0 ppg brine, bump plug. ND BOPE, NU packoff & tbg head w/seal assy, tst to 3000 psi. RR @ 0400 hrs, 6/29/86. 8900', 42.0°, N53.0, 6927.44 TVD, 5197.93 VS, 2732.58N, 4421.70E Did TD New TD 8798 ' PBTD Released rig Date 0400 hrs. Classifications (oil, gas, etc.) I Oil I' Single Producing method Official rese~oir name(s) Flowing Kuparuk Sands PB Depth 8900 ' TD Kind of Hg 6/29/86 I Type completion (single, dual, etc.) Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective dale corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle Drilling Supervisor MEMORANPUM State of Alaska TT ALASKA 0~,~ A!%~ GAS CONSE~J~ATION COMI~ISSI~,~,,, C. V. Cha Chairman DATE: June 25, 1986 FILE NO.: D.ADA. 27 THRU: FROM: Lonnie C. Smith~?<~ Commissioner Doug Amos Petroleum Inspector TELEPHONE NO.' SUBJECT: BOP Test ARCO KRU 3K-3 Permit No. 86-103 Kuparuk River Field Monday, June 23, 1986: After witnessing the test at KRU 2T-9 I tra'$eled to KRU 3KZ3--well to witness the BOP test. The test commenced at 1:30 p.m. and was concluded at 2:30 p.m. There were no failures, and I filled out an AOGCC BOP inspection report which is attached. In summary, I witnessed the successful BOP test at ARCO's KRU 3K-3 well. 02-001 A ( Rev 10-84) · ::.? 5/84 ' ~ -'. .... STATE OF ALASKA .. ALASKA 0IL & GAS CONSERVATION COMMISSION · B.O.P.E. Inspection Report Operator ~~ "' Well ~~ ~-~ Location:_ Sec-~' ' T~ R-~ M ~.~. . ... ...... Drillin~ Contractor ~~o~ Ri ~I ~ . . --v. Location,. General O~ Well Sign ~ "_. ~.General Housekeeping 'OK Rig 7~TReserve Pit Mud Systems Trip Tank . Pit Gauge Flow Monitor Gas Detectors ., Visual Audio Date Well Representative Pe~it ~ ~Casing Set Representative ACC~ATOR SYST~ BOPE Stack ~nu'li~P revent er ~ Pipe Rams ~'L Blind Rams Choke Line Valves~f H.C.R. Valve Check Valve Test Results: Failures Test Pressure tl Full Charge Pressure ~/~ Pressure After Closure I~o~ Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: ' I ; Controls: Master O~ psig ,~.~::~ psig rain ~ sec. ~/__ rain ~sec. psig .~ Remote Kelly and Floor Safety Valves Upper Kelly~' I Lower Kelly~w I Ball Type ~/ [ Inside BOP ~ I Choke Manifold No. Valves Test Pressure Test Pressure Test Pressure No. flanges Repair or Replacement of failed equipment to be made within Test pressure ~ Test Pressure Adjustable Chokes ~ Hvdrauically operated choke ~ Test Time ~ hrs. ~0 days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector June 3, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy.' (907) 276-7542 Re: 3K-3 ARCO Alaska, Inc. Permit No. 86-103 Sur. Loc. 1384.'FSL, 318'FWL, Sec. 35, T13N, R9E, UM. Btmhole Loc. !191'FNL, 583'FEL, Sec. 35, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other goverr~ental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, t~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~ t~u~j~Y~O~.U~ rs~ / ~. V. ChattertOn Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COb~:IiSSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA _ .L AND GAS CONSERVATION CL .!MISSION PERMIT TO DRILL 20 AAC 25.OO5 I la. Type of work Drill ~ Redrill ~1 lb. Type of well. Exploratory Re-Entry © Deepen[]1 Service [] Developement Gas ~ Single Zone ~ Multiple Zone !} 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69', PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oi] Poo P.O. Box 100360 Anchorage, AK 99510 ADL 25519 ALK 2555 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25,025) 1384'FSL, 318'FWL, Sec.35, T13N, R9E, UN Kuparuk River Unit tatewide At top of productive interval 8. Well nu ,mber Number 1378'FNL, 886'FEL, 5ec.35, T13N, R9E, UN 3K-3 ~8088-26-27 At total depth 9. Approximate spud date Amount 1191'FNL, 583'FEL, Sec.35, T13N, R9E, UM 06/24/86 500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth iMu and TVD) property line 8853 ' MD 318' ¢ surface feet :~K-2 25'¢ surface feet 2560 (6906'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 600 feet Maximum hole angle43 0 Maximum surface 23 23 psig At total depth [fVD) 3447 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 6" 52.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12:~"--- 7-5/8" ~6.0# J-55 BTC 4754' 35' 35' 4789' 3924' 1390 sx AS I I I & HF-ER~/ 305 sx Class G blend 8½" ?" ~_6.0# J-55 BTC 8819' 34' 34' 8853' 6906' 200 sx Class G(minimum HI--~_h~N IUC .bUt; ' above top ol- Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth' measured true vertical 20. Attachments Filing fee '.~ Property plat ~ BOP Sketch Drilling fluid program ~ Timevs depth plot [] Refraction analysis Z Seabed report © 20 AAC25.050 requirements -- 21. I hereby ce,.r,t~Y~at the foregoing i.s.. true and correct to the best of my knowledge Signed .' /.~._.¢¢~,,f.¢¢../...., ..:z.~/,c~c.~AA~_, Title Regi cna 1 Dr i lli ng Engineer //' ~' ~.' %. - Commission Use Only (HRF) pD/PD267 Permit Nurr~ber "I I I · . ,--_.- APl number Approval date See cover letter ~'~'(~ '-[ ~{!? 50- ~ ~i?i ~ ~[ (~;. ~ :~ 06/03/86 for other requirements Conditions of approval Samples required ~ Yes ,~.,No Mud Icg required ~ Yes ~,,No Hydrogen sulfide measures ~ Yes I~, No Directi0n~tl survey required ,~',~Yes ~ No R equiredworki~~Jr~,f ~~~5M; ~ 10M; ~ 15M Other: . by order of Approved by ~x,~.~_... ,_/,. ~,~ ~'~o~,/~~ Commissioner the commission Date. , Form 10-401 Rev. 12-1-85 ! Sub/~i I triplicate - STATE OF ALASKA ALASKA IL AND GAS CONSERVATION C ,'1MISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ~ Redrill EI lb. Type of well. Exploratory ~. Stratigraphic Test '- Development Oil Re-Entry ~ Deepen©l Service ~ Developement Gas - Single Zone ,-- Multiple Zone - 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69', PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Poo P.O. Box 100360 Anchorage, AK 99510 ADL 25519 ALK 2555 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 1384'FSL, 318'FWL, 5ec.35, T13N, R9E, UM Kuparuk River Unit ~tatewide At top of productive interval 8. Well nu ,mber Number 1378'FNL, 886'FEL, Sec.35, T13N, R9E, UN 3K-3 ~/8088-26-27 At total depth 9. Approximate spud date Amount 1191'FNL, 583'FEL, Sec.35, T13N, R9E, UN 06/24/86 I;500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 8853 ' MD ~318' ~ surface feet ~K-2 25'~ surface feet ;~560 (6906'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 600 feet Maximum hole angle43 0 Maximum surface 2323 psig At total depth (TVD) 3447 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 6" i2.5# H-40 Weld 80' ~5' ~5' 115' 115' +200 cf 12~" )-5/8" ;6.0# J-55 BTC 4754' 95' 35' 4789' 3924' 1390 sx AS I I I & HF-ERt/ 305 sx Class G blend 8~" 7" ~6.0# J-55 BTC 8819' 34' 34' 8853' 6906' 200 sx Class G(rninimum IHl'-~-~(/t IUC I)UL ' above top ot KuparuK 19. TO be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured . true vertical 20. Attachments Filing fee '~. Property plat ~ BOP Sketch '~ Diverter Sketch Drilling fluid program ~ Time vs depth plot F-;., Refraction analysis F~ Seabed report F~ 20 AAC 25.050 requirements - 21. I hereby ce,f, fi~y-"~at the foregoing is. true and correct to the best of my knowledge Signed'/ .//'~~j,~./'/. ,/,_,/ ~/ffx~/~/~,-~, ¢.~ ~_. ~-~--- Title R egi on al Drilling E ngi n eer Date,.5 --//-'~-~/"~"/ "-- Commission Use Only Permit Num"ber ~//' I APl number ] Approval date See cover letter 86-103 I 50- 029-21602 I 06/03/86 I for other requirements Conditions of approval Samples required ~ Yes ~ No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures ~ Yes.,_..m No Directional survey required ~ Yes ~m No working ure f B ~ ; ' 3M' ~ 5M ,~ 10M; © 15M Other: - by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 / // Sue q triplicate / PAD 3K. WELL HO~ 3'.-PROPOSED ;-. i::-:;'; / { ~ .': .. ! ~ i . ....... ' _ K_U?_A_RUK F[_ELD__~j_-NORTH SL~E, ~_~_$~1~'~: ._:F_:_-"~___:_'. 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XVD~6~ T~ ~0 -DEP-0 ........................... ~ ......... ~ .....~ ..... ...... ..... ~ ......... { ...... ] ......... ~ ................ ~ . . . ..... _ . _ ~ ..... ~ -+ 3 .. ~ .: .... ~ _ ~_ ~. F ....... ~ ....... :~_: ..... ~, .... ~ ......... ~ .....~ ... ~ ...... ..... ~ . ~ : _ _ : . _ : .... I__ . ~ ............ [ ........ ~ ........~ ....... ] ...... : .......] ......~ ..... { -- - ~r ..... ~t : ~ ~ ............ ~ I" ............... { . ]~ ..... ;{ ..... :~ ..... ~ -- ~ - . c ....... ~ ....... ] ...... ~ ....... ~ ...... ~ - ~ ..... ,. - _ _133 B~E PERHAFROST -~'.:: VD=I _ __ { : ~oo I. KUPRRUK R I VER UN I T 20" O I VERTER SCHEMRT I C DESCR I PT I ON 1 . 1. 1G" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOWER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI DRILLING SPOOL W/lO" OUTLETS. 7. 10" HCR BALL VALVES W/lO" DIVERTER LINES, A SINGLE' VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC25.035; (bi MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW A I R THROUGH D I VERTER L I NES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRI ATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN NELL UNDER ANY CIRCUMSTANCES: ! SI 0084002 RI(] J [ I J KILL LIhF_S 6. 1~-~/8' - ,~ PSI D~ RAM W/PIPE P,~ CN T~, 7. 1~8' - ~ ~I ~ ,.A.C~ATOR CAPACITY TE~ST 1. C]-ECK AhD FILL ACC~TC~R R~OIR TO LEVEL WITH HYDRAULIC FLUID. 2. A,~ THAT AC~TOR PRE~ IS ~ PSI WITH ~. C~ TINE[, 'I't-E2N CLOSE ALL UNITS SII,I/.TAhEC~Y ALL l~TS ARE CLOSED WITH (~ING PLIvP CFF. 4. I:~CC/:~ CIN NADC Rf~PCRT, T~ ACTABLE LOAE~R LIMIT IS 45 SEC~ CLOSIh~ TI~E AND 1200 PSI RE~INING " PRE~. · · I F- 13-~/8" BOP STACK TEST I. FILL BOP STAO< AAD CNO<E MANIFO_D WITH ARCTIC . DIESEL. 2. C~(~ THAT ALL LO~ DO~ S~ IN ~Ei_LFF_AD AR~ F1JLLY RETRACTEd. SF_AT T~ST PLUG IN ~]_L.~ WITH RUNNING J~ Ah~ RUN IN LO~ SC~. LIh~ VALVES ADJA(~ TO E~ STAC~ ALL 0T~ 4. PRES,~ UP TO 250 PSI AN:) HOD FC~ I0 MIN. IN- CRE.~ PRES,.~ TO 3000 PSI AhD NCLD F(3R I0 MIN. BL~-~- r~ PRESSL~ TO 0 PSI. 5. ~ AN~ PREVENTER AAD MAh~AL KILL AAD LIh~ VALVES. CLOSE TOP PIPE RAMS Aha) NCR VALVES ON KILL AAD CHO<E LI~ES. 6: TEST TO 250 PSI Aha) 3000 PSI AS IN STEP 4. 7. CON'TIh~ TESTING ALL VALVES, LIhF_S, AAD C~S WITH A 2.50 PSI LO/~ AAD 3000 PSI NIGH. TEST AS IN STEP 4. DO NOT ~:~ TEST ANY ~ THAT NOT ~ FULL CLOS~N~ POSITIVE SEAL CHO<E, CN_¥ ~I'ON lgST O-K:KE$ THAT DO NOT FLLLY CLOSE. 8. O:~ TCI~ PIPE RA~ AhD CL__O_:~'__ BOTTOM PIPE RAMS. TEST BOTTOM PIPE RAMS TO 250 PSI ~ 3000 PSI. 9, O:~ BO'~OM PIPE R/~, BACX OJT RUNNING JT AN:) .10. CLOSE BLIh~ RAMS A~ TEST TO 250 PSI AAD .3000 PSI, 11. (~ BLIND RAMS AhD RETRIEVE TEST PLUG. MAKE SURE MANIFO_D AND LIAES ARE FULL. O:' NC~RFF'TING- FLUID. SET ALL VALVES IN DRILLING POSITICt~L 12. TEST STAN]PIPE VALVES, KELLY, KELLY COSXS, DRILL' PIPE SAFETY VALVE, AAD INSIDE BCP TO 2.~ PSI Ah~ 3000 PSI. I~. RE(~ TEST IhF(]I~MATIcN C~ BLC~ /:~ TEST FCIC, SIGN, A~D SEN:) TO DRILLING SI~ISCR. 14. PERFO:~ COVl~TE BO:~ TEST AFTER NIPPLING LP W~F_KLY TNE,~EAFTF_R FI~IONALLY CPEAATE BCPE DAILY. 510084001 REV. 2 ...... GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. ,j 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKER5 -~ DEGASSER j CLEANER ST R ~e--~. STIR ---I~ STIR CLEANER TYPICAL HUD SYSTEH SCHEHATIC LWK4/ih DRILLING FLUID PROGRAM Density PV YP ViScosity Initial Gel 10 Minute Gel Filtrate API pH % Solids Spud to ~ 9-5/8" SUrface Casing 9.6-9.8 15-30 20-40 50-100 5-15 15-30 2O 9-10 10_+ Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 · 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 6 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid Practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average)'and a gas. gradient of ,111psi/ft. This shows that formatiOn breakdown-would occur"before.a 'surface pressure of 3000 psi could be reached.' Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proPosed well. ~ nW /±h ARCO Alaska, inc..~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 3K Pad (~/ells 1 - 18) Dear Hr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/12 Encl o sure If ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ~~/..oCATEo I# Pf~OTRACTED .~--~. 2.7 ~ LOCATED IN PROTRACTED LOCATED IN PRbTRACTED SECTION 55, T. 15N.~ R. gE.~U.M. SECTION 55, %15N.~ R. gE.~U.M. 8 - Y - 6,~,253.70 ~T. 70'~'02.0~ Z7 - y . 6,007,978.8Z ~T. 70'25'~.355~" X- 6~,~6.92 L~G. ~49045'~.~" x" 529,~5.73 L~G. [49'45'~.~77" NOTES I. ALL COORDINATES ARE A.S.E, ZONE4. ~ALL DISTANCES SHOWN ARE TRUE. ~.HO~IZONTAL POSITIONS BASED ON ~K CONTROL MONUMENTS PER LHD 4. VERTICAL ~OSiTIONS BASED 'ON 5K TBM No. 4 ~ TBM N0.5 PER LHD ~ flSS~. 5.0.6. ELEVATIoNs INTERPOLATED FROM S/C DRAWING CED-RIXX-3070 rev.~ IL CER~FICA~ OF SURVEYOR: I HEREgY C~TI~ THAT I AM PROPERLY REGISTERED ANO LICENSED ~ PRACTICE LAND ~RVEYIN~ IN ~E STAT[ OF AL&SKA ~D THAT ~. -- ~ THIS PLAT REPRESENT~ & LOCATION SURVEY M&O[ BY ME OR UN~R MY SUPERVISION, AND ~ -- E n~ ~~ THAT ALL DIMENSIONS AND OTHER DETAILS ¢~ ~ ~' ' SURVEYED FOR: ~ ARCO Alaska, Inc. 5 ~~ ~5 Arct~ ~uleva~, Su~e 201, Anchorage, Alaska 99503"IIS~E NOT T0 SCALE j 'CHECK LIST FOR NEW WELL PERMITS ' Company' ITEM APPROVE DATE (1) Fee (2) (2 thru 8) (3) Admin (4) .Casg ~'.~,~. ,~"~/' ~/~ (14 thru 22) (23 thru 28) Ii ~ Lease & Well No. YES. NO Is the permit fee attached .......................................... ~ -- · 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells ...~ ................. $. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before ten-day wait .......................... ge 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~/~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate/on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is.this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 .......... '.. Is adequate wellbore separation proposed ............................ .,! , Is a diverter system required ....................................... Is the drilling fluid program, schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOO psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. REMARKS (6) OTHER /~. ~, (6) Add: (29 thru 31) For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirement~ ............................................. Geology~L HWK .'~ WVA ~ JAL ~.-'~ En g~in.eering: LCS ~ B~W MTM~ HJH~ rev: 04/03/86 I / INITIAL . POOL CLASS STATUS 'J~Otoo ~ ~.- v ~-o;, ,, GEO. AREA UNIT NO. o~/o~ SHORE Additional Remarks:-/-~:~ u~-~llJoo~z=- m,~v'~ ,,d~J~;~ ~,' Roe. ~ 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. , V E2 1 F: Z C.a'T Z'.SN LZSTZNG </ll/oo S E R V '",.,'- E t',~ ~ M E : E 2 ©.~Tf_ 185107/ 7 ,'£!RiGIN : ~: ,:' E L N~ME :149316 CORiTidU,{T:2N ,~ ':0! PREVIOUS REEL CgMM =NTS :L!EP, SERVICE NA~,~E : !EDIT OATE :88/07/ 7 3RiGIN :O00O TAPE i',J~ME :155'7 CDNTINU&T'ON ~ :Of PR.EVi3US T~F:'~ ,: C,'3M~t=NTS :LISRZ~R.Y TAPE SERVICE N;~M~ : VERSION ~ : DATE : ".,~AXi~'.,!U!4 LEN,%TH : F I L E T Y :;: = : PREVIOUS FIL~ : i024 I'.' ?'i E ?! '- 2 !'.i T = i"~ T S ,ES = Ty p,z OOO 300 CO0 33'D ,30:3 ,3 O TyD- 30 '3 300 '3..,"' 0 3 '20 ¥ '~, SIZE "3,34 0O2 012 0C3 0 O1 065 055 0 5 f C 55 06E LV$~ C'!O.H02 V~'qZ,--TCATiC'N LZST~.N'G? Pa, GE. =~' JG5 NUMBER ,'AT ACLC: 71~67 LOP: RICK K~UWE~L ,E. ?.: T 'S T. 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