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STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT G-02RD JBR 10/05/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Test Results TEST DATA Rig Rep:Joe Steiner / Ed CastagnOperator:Hilcorp Alaska, LLC Operator Rep:Karson Kozub / Ed Hooter Rig Owner/Rig No.:Hilcorp 404 PTD#:1820670 DATE:8/20/2022 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopLOL220926081338 Inspector Lou Laubenstein Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3.5 MASP: 1917 Sundry No: 322-425 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 11 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2-7/8" x 5-1/2 P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 2 2-1/16"P Kill Line Valves 2 2-1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1850 200 PSI Attained P20 Full Pressure Attained P84 Blind Switch Covers:Pyes Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2200 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P22 #1 Rams P6 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9 9 9 9 9 9 9 9 By Anne Prysunka at 9:22 am, Sep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y Meredith Guhl at 2:53 pm, Jul 19, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1 FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH SVL EMP 6HW D WHVW SDFNHU DW 0' DQG SUHVVXUH WHVW FDVLQJOLQHU WR SVL ; %-0 %23 WHVW WR SVL ; '/% ; '65 GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.07.27 16:53:33 -08'00' 5%'06 -6% tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗'ͲϬϮW/EƵŵďĞƌ͗ϱϬͲϳϯϯͲϮϬϬϯϴͲϬϭ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗ ^WWƌŽĚƵĐĞƌ>ĞŐ͗>ĞŐηϰ;^tĐŽƌŶĞƌͿ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ƵŐƵƐƚϳ͕ϮϬϮϮZŝŐ͗,<ϰϬϰ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌLJŽŶƚĂĐƚ͗:ƵĂŶŝƚĂ>ŽǀĞƚƚ;ϴϯϯϮͿWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϴϮͲϬϲϳ &ŝƌƐƚĂůů ŶŐŝŶĞĞƌ͗<ĂƚŚĞƌŝŶĞK͛ŽŶŶŽƌ;ϮϭϰͿϲϴϰͲϳϰϬϬ;DͿ ^ĞĐŽŶĚĂůů ŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶϵϬϳͲϮϮϵͲϰϴϮϰ;DͿ Current Bottom Hole Pressure: 2793 psi @ 8,761’ TVD 0.319 psi/ft based on ESP Gauge June 2022 Maximum Potential Surface Pressure: 1917 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) *** This is a no flow well 08/14/2013 ƌŝĞĨtĞůů^ƵŵŵĂƌLJ 'ͲϬϮŝƐĂĐŽŵŝŶŐůĞĚ'ͲŽŶĞĂŶĚ,ĞŵůŽĐŬ ^WƉƌŽĚƵĐĞƌ͘dŚĞĐƵƌƌĞŶƚ ^WǁĂƐŝŶƐƚĂůůĞĚŝŶϮϬϭϯ͘dŚĞ ^WĚŝĞĚƌĞĐĞŶƚůLJĂĨƚĞƌĂϵLJĞĂƌƌƵŶ ƚŝŵĞ͘tĞƉůĂŶƚŽƉƵůůĂŶĚƌĞƉůĂĐĞƚŚĞĐƵƌƌĞŶƚĐŽŵƉůĞƚŝŽŶ͘ >ĂƐƚĂƐŝŶŐWƌĞƐƐƵƌĞdĞƐƚ͗ ϬϳͬϭϭͬϮϬϭϯͲϮϬϬϬƉƐŝŐĂƚϳϱϲϱ͛ĂŶĚĐŚĂƌƚĞĚĨŽƌϯϬŵŝŶƵƚĞƐ͘ WƌŽĐĞĚƵƌĞ͗ ϭ͘D/Zh,<ϰϬϰ Ϯ͘ŝƌĐƵůĂƚĞƚŚĞǁĞůůƚŽƉƌŽĚƵĐƚŝŽŶ͘ Ă͘tŽƌŬŽǀĞƌĨůƵŝĚǁŝůůďĞĨŝůƚĞƌĞĚŝŶůĞƚǁĂƚĞƌ͘ ϯ͘^ĞƚWs͕EƚƌĞĞ͕EhKWĂŶĚƚĞƐƚƚŽϮϱϬƉƐŝ>ŽǁͬϮϱϬϬƉƐŝ,ŝŐŚͬϮϱϬϬƉƐŝŶŶƵůĂƌ Ă͘EŽƚĞ͗EŽƚŝĨLJK'ϰϴŚŽƵƌƐŝŶĂĚǀĂŶĐĞƚŽĂůůŽǁƚŚĞŵƚŽǁŝƚŶĞƐƐƚĞƐƚ ϰ͘DŽŶŝƚŽƌǁĞůůƚŽĞŶƐƵƌĞŝƚŝƐƐƚĂƚŝĐ͘ ϱ͘hŶƐĞĂƚŚĂŶŐĞƌĂŶĚWKK,ǁŝƚŚ ^WĐŽŵƉůĞƚŝŽŶ͘ ϲ͘Zh^>Z/,ĂŶĚƐĞƚƉůƵŐŝŶyŶŝƉƉůĞĂƚϵϱϴϯ͛D͘WdĐĂƐŝŶŐƚŽϮϬϬϬƉƐŝĂŶĚĐŚĂƌƚ͘WƵůůƉůƵŐ͘ ϳ͘Z/,ĂŶĚƚĂŐĨŝůů ϴ͘ΎŽŶƚŝŶŐĞŶƚĐůĞĂŶŽƵƚŝĨĨŝůůŝƐƚĂŐŐĞĚŚŝŐŚ Ă͘Z/,ǁŝƚŚĐůĞĂŶŽƵƚĂƐƐĞŵďůLJ͕ĐŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉ͕WKK, ď͘ΎKW͛ƐǁŝůůďĞĐůŽƐĞĚĂƐŶĞĞĚĞĚƚŽĐŝƌĐƵůĂƚĞƚŚĞǁĞůů ϵ͘Wh͕Z/,ǁŝƚŚ ^WĐŽŵƉůĞƚŝŽŶ͘ ϭϬ͘>ĂŶĚ ^WǁŝƚŚƚŚĞďŽƚƚŽŵŽĨƚŚĞĂƐƐĞŵďůLJĂƚцϳϰϵϯ͛͘ ϭϭ͘^ĞƚWs͕EKW͕EhƚƌĞĞĂŶĚƚĞƐƚ͘ ϭϮ͘dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ϭϯ͘ŽŶĚƵĐƚ^s^ƚĞƐƚŝŶŐƉĞƌK'ƌĞŐƵůĂƚŝŽŶƐ͘ ϭϰ͘/ĨĐůĞĂŶŽƵƚŝƐĐŽŶĚƵĐƚĞĚŝŶƐƚĞƉηϳͲŽŶĚƵĐƚĂŶŽͲĨůŽǁƉĞƌK'ƌĞŐƵůĂƚŝŽŶƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ ϯ͘ƵƌƌĞŶƚtĞůůŚĞĂĚŝĂŐƌĂŵ ϰ͘KWƌĂǁŝŶŐ ϱ͘&ůƵŝĚͬ&ůŽǁŝĂŐƌĂŵƐ ϲ͘ZtK^ƵŶĚƌLJŚĂŶŐĞ&Žƌŵ )OXVK K\GURFDUERQV IURP ZHOOERUH EHIRUH SXOOLQJ WXELQJ EMP 6HW WHVW SDFNHU DW 0' DQG SUHVVXUH WHVW FDVLQJ WR SVL EMP ! \HDUV VLQFH ODVW FDVLQJ WHVW '/% ^/ td 'Z KEE / dKW dD͘ ϭϯͲϯͬϴ͟ ϲϭ :Ͳϱϱ d ϭϮ͘ϱϭϱ ^ƵƌĨ͘ ϭ͕ϯϬϬΖ ϵͲϱͬϴ͟ ϰϳ EͲϴϬ d ϴ͘ϲϴϭ ^ƵƌĨ͘ ϲ͕ϬϬϬΖ ϳ͟ Ϯϵ EͲϴϬ͕WͲϭϭϬ d ϲ͘ϭϴϰ ϱ͕ϰϵϭΖ ϭϬ͕ϳϲϳΖ ϯͲϭͬϮΗ ϵ͘Ϯ >ͲϴϬ Zd^Ͳϴ Ϯ͘ϵϵϮΗ ^ƵƌĨ ϳ͕ϮϳϰΖ ϰϭͬϮΗ ϭϮ͘ϲη >ͲϴϬ /d ϯ͘ϵϱϴ ϳ͕ϱϰϱΖ ϵ͕ϱϵϲΖ EŽ͘ ĞƉƚŚ;DͿ ĞƉƚŚ;dsͿ K ϭ ϳ͕ϮϳϰΖ ϲ͕ϳϬϳΖ ϰ͘ϬϬΗ ϳ͕ϮϳϲΖ ϲ͕ϳϬϵΖ ϰ͘ϬϬΗ ϳ͕ϮϳϴΖ ϲ͕ϳϭϭΖ ϰ͘ϬϬϬΗ ϳ͕ϰϬϮΖ ϲ͕ϴϭϵΖ ϰ͘ϬϬϬΗ ϳ͕ϰϭϭΖ ϲ͕ϴϮϳΖ ϰ͘ϱϲϬΗ ϳ͕ϰϮϳΖ ϲ͕ϴϰϭΖ ϰ͘ϱϲϬΗ ϳ͕ϰϵϯΖ ϲ͕ϴϵϵΖ ϰ͘ϱϲϬΗ ϯ ϳ͕ϱϰϱΖ ϲ͕ϵϰϰΖ WĂĐŬĞƌ ϰ ϵ͕ϱϳϬΖ ϴ͕ϲϳϳΖ WĂĐŬĞƌ ϱ ϵ͕ϱϴϯΖ ϴ͕ϲϴϴΖ yEŝƉƉůĞ ϲ ϵ͕ϱϵϲΖ ϴ͕ϳϬϬΖ ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ŵƚ ĂƚĞ 'Ͳϭ ϵ͕ϲϲϰΖ ϵ͕ϲϲϳΖ ϴ͕ϳϲϭΖ ϴ͕ϳϲϰΖ ϯ ϳͬϳͬϮϬϭϯ 'ͲϮ ϵ͕ϳϬϵΖ ϵ͕ϳϭϮΖ ϴ͕ϴϬϭΖ ϴ͕ϴϬϰΖ ϯ ϳͬϳͬϮϬϭϯ 'ͲϬϯ ϵ͕ϳϲϬΖ ϵ͕ϳϵϮΖ ϴ͕ϴϰϳΖ ϴ͕ϴϳϱΖ ϯϮ ϳͬϳͬϮϬϭϯ 'ͲϬϰ ϵ͕ϴϭϰΖ ϵ͕ϴϱϳΖ ϴ͕ϴϵϱΖ ϴ͕ϵϯϯΖ ϰϯ ϳͬϳͬϮϬϭϯ ϵ͕ϴϲϲΖ ϵ͕ϴϴϬΖ ϴ͕ϵϰϭΖ ϴ͕ϵϱϰΖ ϭϰ ϳͬϳͬϮϬϭϯ 'ͲϬϱ ϵ͕ϵϯϮΖ ϭϬ͕ϬϭϬΖ ϵ͕ϬϬϬΖ ϵ͕ϬϲϴΖ ϳϴ ϳͬϳͬϮϬϭϯ 'ͲϬϲ ϭϬ͕ϬϲϵΖ ϭϬ͕ϬϵϲΖ ϵ͕ϭϭϵΖ ϵ͕ϭϰϯΖ Ϯϳ ϳͬϳͬϮϬϭϯ ,Ͳϭ ϭϬ͕ϭϲϰΖ ϭϬ͕ϭϵϰΖ ϵ͕ϮϬϭΖ ϵ͕ϮϮϳΖ ϯϬ ϯͬϭϮͬϭϵϵϯ ϭϬ͕ϭϳϰΖ ϭϬ͕ϮϬϰΖ ϵ͕ϮϭϬΖ ϵ͕ϮϯϲΖ ϯϬ ϳͬϳͬϮϬϭϯ ϭϬ͕ϭϳϰΖ ϭϬ͕ϭϳϲΖ ϵ͕ϮϭϬΖ ϵ͕ϮϭϮΖ Ϯ ϳͬϭϱͬϭϵϴϮ ϭϬ͕ϭϴϬΖ ϭϬ͕ϮϬϯΖ ϵ͕ϮϭϱΖ ϵ͕ϮϯϱΖ Ϯϯ ϭϮͬϮϭͬϭϵϵϬ ,ͲϮ ϭϬ͕ϮϯϬΖ ϭϬ͕ϮϲϬΖ ϵ͕ϮϱϴΖ ϵ͕ϮϴϯΖ ϯϬ ϭϬͬϳͬϭϵϴϲ ϭϬ͕ϮϲϮΖ ϭϬ͕ϮϲϰΖ ϵ͕ϮϴϱΖ ϵ͕ϮϴϳΖ Ϯ ϳͬϭϰͬϭϵϴϮ ,Ͳϯ ϭϬ͕ϯϰϯΖ ϭϬ͕ϯϰϱΖ ϵ͕ϯϱϰΖ ϵ͕ϯϱϱΖ Ϯ ϳͬϭϯͬϭϵϴϮ ϭϬ͕ϯϰϱΖ ϭϬ͕ϯϳϱΖ ϵ͕ϮϱϱΖ ϵ͕ϯϴϭΖ ϯϬ ϭϮͬϮϭͬϭϵϵϬ ,ͲϯΘϰ ϭϬ͕ϯϯϴΖ ϭϬ͕ϱϮϬΖ ϵ͕ϯϱϬΖ ϵ͕ϱϬϯΖ ϭϴϮ ϳͬϳͬϮϬϭϯ ϭϬ͕ϯϳϱΖ ϭϬ͕ϰϬϳΖ ϵ͕ϯϴϭΖ ϵ͕ϰϬϴΖ ϯϮ ϭϮͬϮϭͬϭϵϵϬ ϭϬ͕ϰϬϳΖ ϭϬ͕ϰϱϮΖ ϵ͕ϰϬϴΖ ϵ͕ϰϰϲΖ ϰϱ ϭϮͬϮϭͬϭϵϵϬ ϭϬ͕ϰϱϮΖ ϭϬ͕ϰϳϬΖ ϵ͕ϰϰϲΖ ϵ͕ϰϲϭΖ ϭϴ ϭϮͬϮϭͬϭϵϵϬ ,Ͳϱ ϭϬ͕ϱϰϬΖ ϭϬ͕ϱϴϳΖ ϵ͕ϱϮϬ ϵ͕ϱϲϬ ϰϳ ϳͬϳͬϮϬϭϯ ^/E' d/> dh/E' d/> : t >Zz d/>;dŽƉƚŽŽƚƚŽŵͿ Ϯ ,Ͳϰ /ƚĞŵ ŽůƚͲKŶŝƐĐŚĂƌŐĞ ϲͲƐĞĐƚŝŽŶWƵŵƉ͕ϲϯƐƚĂŐĞƐĞĂĐŚ͕ϱϴϬϬEyϲ WƵŵƉ/ŶƚĂŬĞ ^ĞĂůƐ dǁŽƐĞĐƚŝŽŶDŽƚŽƌʹϰϱϲ͕ϭϴ͕ϰϭϴϯDĂdžŝŵƵƐ͘ϮϳϬ ŚƉĞĂĐŚсϱϰϬŚƉƚŽƚĂů 'ĂƵŐĞͬĞŶƚƌĂůŝnjĞƌͬŶŽĚĞ W Z&KZd/KE d/> yͲKǀĞƌ͘ϰͲϭͬϮΗϴZĚyϯͲϭͬϮΗZd^Ͳϴ t> ' ^, Dd/ DĐƌƚŚƵƌZŝǀĞƌ&ŝĞůĚ͕dh tĞůů͗'ͲϬϮZ ƐŽŵƉůĞƚĞĚ͗ϳͬϭϲͬϮϬϭϯ 7DJJHGMXQN# ¶'30 7' ¶ 0D[KROHDQJOHLVq#¶ 2ULJLQDO5.% ¶ 72/# ¶ #¶ ´ #¶ ; ^/ td 'Z KEE / dKW dD͘ ϭϯͲϯͬϴ͟ ϲϭ :Ͳϱϱ d ϭϮ͘ϱϭϱ ^ƵƌĨ͘ ϭ͕ϯϬϬΖ ϵͲϱͬϴ͟ ϰϳ EͲϴϬ d ϴ͘ϲϴϭ ^ƵƌĨ͘ ϲ͕ϬϬϬΖ ϳ͟ Ϯϵ EͲϴϬ͕WͲϭϭϬ d ϲ͘ϭϴϰ ϱ͕ϰϵϭΖ ϭϬ͕ϳϲϳΖ ϯͲϭͬϮΗ Ϯ͘ϵϵϮΗ ^ƵƌĨ цϳ͕ϮϳϰΖ ϰϭͬϮΗ ϭϮ͘ϲη >ͲϴϬ /d ϯ͘ϵϱϴ ϳ͕ϱϰϱΖ ϵ͕ϱϵϲΖ EŽ͘ ĞƉƚŚ;DͿ ĞƉƚŚ;dsͿ K ϭ цϳ͕ϮϳϰΖ цϲ͕ϳϬϳ ϰ͘ϬϬΗ цϳ͕ϮϳϲΖ цϲ͕ϳϬϵ ͲͲ ͲͲ ͲͲ ͲͲ цϳ͕ϰϵϱΖ цϲ͕ϵϬϬ ϯ ϳ͕ϱϰϱΖ ϲ͕ϵϰϰΖ WĂĐŬĞƌ ϰ ϵ͕ϱϳϬΖ ϴ͕ϲϳϳΖ WĂĐŬĞƌ ϱ ϵ͕ϱϴϯΖ ϴ͕ϲϴϴΖ yEŝƉƉůĞ ϲ ϵ͕ϱϵϲΖ ϴ͕ϳϬϬΖ ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ŵƚ ĂƚĞ 'Ͳϭ ϵ͕ϲϲϰΖ ϵ͕ϲϲϳΖ ϴ͕ϳϲϭΖ ϴ͕ϳϲϰΖ ϯ ϳͬϳͬϮϬϭϯ 'ͲϮ ϵ͕ϳϬϵΖ ϵ͕ϳϭϮΖ ϴ͕ϴϬϭΖ ϴ͕ϴϬϰΖ ϯ ϳͬϳͬϮϬϭϯ 'ͲϬϯ ϵ͕ϳϲϬΖ ϵ͕ϳϵϮΖ ϴ͕ϴϰϳΖ ϴ͕ϴϳϱΖ ϯϮ ϳͬϳͬϮϬϭϯ 'ͲϬϰ ϵ͕ϴϭϰΖ ϵ͕ϴϱϳΖ ϴ͕ϴϵϱΖ ϴ͕ϵϯϯΖ ϰϯ ϳͬϳͬϮϬϭϯ ϵ͕ϴϲϲΖ ϵ͕ϴϴϬΖ ϴ͕ϵϰϭΖ ϴ͕ϵϱϰΖ ϭϰ ϳͬϳͬϮϬϭϯ 'ͲϬϱ ϵ͕ϵϯϮΖ ϭϬ͕ϬϭϬΖ ϵ͕ϬϬϬΖ ϵ͕ϬϲϴΖ ϳϴ ϳͬϳͬϮϬϭϯ 'ͲϬϲ ϭϬ͕ϬϲϵΖ ϭϬ͕ϬϵϲΖ ϵ͕ϭϭϵΖ ϵ͕ϭϰϯΖ Ϯϳ ϳͬϳͬϮϬϭϯ ,Ͳϭ ϭϬ͕ϭϲϰΖ ϭϬ͕ϭϵϰΖ ϵ͕ϮϬϭΖ ϵ͕ϮϮϳΖ ϯϬ ϯͬϭϮͬϭϵϵϯ ϭϬ͕ϭϳϰΖ ϭϬ͕ϮϬϰΖ ϵ͕ϮϭϬΖ ϵ͕ϮϯϲΖ ϯϬ ϳͬϳͬϮϬϭϯ ϭϬ͕ϭϳϰΖ ϭϬ͕ϭϳϲΖ ϵ͕ϮϭϬΖ ϵ͕ϮϭϮΖ Ϯ ϳͬϭϱͬϭϵϴϮ ϭϬ͕ϭϴϬΖ ϭϬ͕ϮϬϯΖ ϵ͕ϮϭϱΖ ϵ͕ϮϯϱΖ Ϯϯ ϭϮͬϮϭͬϭϵϵϬ ,ͲϮ ϭϬ͕ϮϯϬΖ ϭϬ͕ϮϲϬΖ ϵ͕ϮϱϴΖ ϵ͕ϮϴϯΖ ϯϬ ϭϬͬϳͬϭϵϴϲ ϭϬ͕ϮϲϮΖ ϭϬ͕ϮϲϰΖ ϵ͕ϮϴϱΖ ϵ͕ϮϴϳΖ Ϯ ϳͬϭϰͬϭϵϴϮ ,Ͳϯ ϭϬ͕ϯϰϯΖ ϭϬ͕ϯϰϱΖ ϵ͕ϯϱϰΖ ϵ͕ϯϱϱΖ Ϯ ϳͬϭϯͬϭϵϴϮ ϭϬ͕ϯϰϱΖ ϭϬ͕ϯϳϱΖ ϵ͕ϮϱϱΖ ϵ͕ϯϴϭΖ ϯϬ ϭϮͬϮϭͬϭϵϵϬ ,ͲϯΘϰ ϭϬ͕ϯϯϴΖ ϭϬ͕ϱϮϬΖ ϵ͕ϯϱϬΖ ϵ͕ϱϬϯΖ ϭϴϮ ϳͬϳͬϮϬϭϯ ϭϬ͕ϯϳϱΖ ϭϬ͕ϰϬϳΖ ϵ͕ϯϴϭΖ ϵ͕ϰϬϴΖ ϯϮ ϭϮͬϮϭͬϭϵϵϬ ϭϬ͕ϰϬϳΖ ϭϬ͕ϰϱϮΖ ϵ͕ϰϬϴΖ ϵ͕ϰϰϲΖ ϰϱ ϭϮͬϮϭͬϭϵϵϬ ϭϬ͕ϰϱϮΖ ϭϬ͕ϰϳϬΖ ϵ͕ϰϰϲΖ ϵ͕ϰϲϭΖ ϭϴ ϭϮͬϮϭͬϭϵϵϬ ,Ͳϱ ϭϬ͕ϱϰϬΖ ϭϬ͕ϱϴϳΖ ϵ͕ϱϮϬ ϵ͕ϱϲϬ ϰϳ ϳͬϳͬϮϬϭϯ ^/E' d/> dh/E' d/> : t >Zz d/>;dŽƉƚŽŽƚƚŽŵͿ Ϯ ,Ͳϰ /ƚĞŵ ŽůƚͲKŶŝƐĐŚĂƌŐĞ WƵŵƉ /ŶƚĂŬĞ ^ĞĂůƐ DŽƚŽƌ 'ĂƵŐĞͬĞŶƚƌĂůŝnjĞƌͬŶŽĚĞ W Z&KZd/KE d/> yͲKǀĞƌ t> ' WZKWK^ DĐƌƚŚƵƌZŝǀĞƌ&ŝĞůĚ͕dh tĞůů͗'ͲϬϮZ ƐŽŵƉůĞƚĞĚ͗&ƵƚƵƌĞ 7DJJHGMXQN# ¶'30 7' ¶ 0D[KROHDQJOHLVq#¶ 2ULJLQDO5.% ¶ 72/# ¶ #¶ ´ ; #¶ *UD\OLQJ3ODWIRUP *5'&XUUHQW dƵďŝŶŐŚĞĂĚ͕/tͲ͕ ϭϯϱͬϴϯDyϭϭϱD ǁͬ ϮͲ ϮϭͬϭϲϱD^^K͕ yďŽƚƚŽŵ 'ƌĂLJůŝŶŐWůĂƚĨŽƌŵ 'ͲϬϮZ ϭϯϯͬϴyϵϱͬϴyϯϭͬϮ sĂůǀĞ͕t<DͲD͕ϮϭͬϭϲϱD& ͕ ,tK͕ YƚLJϮ $GDSWHU&,:7RDGVWRRO0 6WGG;0)(SUHSSHGIRU ó(1QHFN òQSWFRQWLQXRXV FRQWUROOLQHSRUWV%,:SHQHWUDWRU SRUW dƵďŝŶŐŚĂŶŐĞƌ͕/tͲͲ ^W͕ ϭϭyϰЪ/důŝĨƚĂŶĚƐƵƐƉ͕ǁͬ ϰΖ͛ƚLJƉĞ,WsƉƌŽĨŝůĞ͕ϱЬ E͕ ϮͲ ϯͬϴĐŽŶƚŝŶƵŽƵƐĐŽŶƚƌŽůůŝŶĞ ƉŽƌƚƐ͕ƉƌĞƉƉĞĚĨŽƌ/t ƉĞŶĞƚƌĂƚŽƌ sĂůǀĞ͕ƐǁĂď͕t<DͲD͕ ϰϭͬϭϲϱD& ͕,tK͕ dͲϮϰ sĂůǀĞ͕ůŽǁĞƌŵĂƐƚĞƌ͕t<DͲD͕ ϰϭͬϭϲϱD& ͕,tK͕dͲϮϰ ,d͕ŽǁĞŶ͕ϰϭͬϭϲϱD& y ϳΖ͛Ͳϱ^ŽǁĞŶƚŽƉ ƌŽƐƐ͕ƐƚĚĚ͕ϰϭͬϭϲϱDy ϯϭͬϴϱDyϮϭͬϭϲϱD sĂůǀĞ͕ǁŝŶŐ͕t<DͲD͕ ϮϭͬϭϲϱD& ͕,tK͕ dͲϮϰ sĂůǀĞ͕t<DͲD͕ϯϭͬϴϱD& ͕ǁͬ DͲϭϲŽƉĞƌĂƚŽƌ ĂƐŝŶŐŚĞĂĚ͕ ^ŚĂĨĨĞƌ<͕ ϭϯϱͬϴϯDy ϭϯϯͬϴ^Kt͕ǁͬ ϮͲ ϮΖ͛ >WK͕ϮΖ͛>W/tďĂůůǀĂůǀĞ *UD\OLQJ3ODWIRUP %236WDFN +$. +,/&253$/$6.$//& 6ZDFR6XSHUFKRNH%ORRH\/LQH7R*DV%XVWHU/ŶůĞƚ +LOFRUS$ODVND//&+LOFRUS$ODVND//&Changes to Approved Rig Work Over Sundry Procedure6XEMHFW &KDQJHVWR$SSURYHG6XQGU\3URFHGXUHIRU:HOO 7UDGLQJ%D\8QLW*5' 37' 6XQGU\ ;;;;;;$Q\PRGLILFDWLRQVWRDQDSSURYHGVXQGU\ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQDSSURYHGVXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKHULJZRUNRYHU 5:2 ³ILUVWFDOO´HQJLQHHU$2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6HF 3DJH 'DWH 3URFHGXUH&KDQJH 1HZ5HTXLUHG"<1+$.3UHSDUHG%\ ,QLWLDOV +$.$SSURYHG%\ ,QLWLDOV $2*&&:ULWWHQ$SSURYDO5HFHLYHG 3HUVRQDQG'DWH $SSURYDO $VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH3UHSDUHG )LUVW&DOO2SHUDWLRQV(QJLQHHU 'DWH Ima.~roject Well History File Cover~Ige XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during aspecial rescan activity or are viewable by direct inspection of the file. / ~'~-- O~' Z Well History File Identifier Organizing RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: •//.Gr~yscale items: ~// Poor Quality Originals: [] Other: NOTES: BY; BEVERLY ROBIN [] Other, No/Type [] VINCENT SHERYL(~ WINDY Project Proofing BY; BEVERLY ROBIN Scanning Preparation Other items scannable by large scanner BY: OVERSIZED (NomScannable) [] Logs of various kinds [] Other DATE:~/~(~ IsI + BEVERLY ROBIN(~ SHERYL MARIA Production Scanning Stage Stage 2 Is~ TOTAL PAGES //J. WINDY DATE//{~ · /S//~ ( SCANNING IS COMPLETE AT TH~8 POINT UNLESS SPECIN. A'FTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ..~ YES NO BEVERL~INCENT SHERYL MARIA WINDYDATE:/--,L~S//' ~ IF NO ~N STAGE ~, PAGE(S) DISCREPANCIES WERE FOUND: ~- NO BEVERLY ROBIN DATE'/ / ~ ' . /SI III IIil1111111 II III ReScanned (individual page [.~pecial at~entio~] .~catmin~ compte~ed) RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IsI General Notes or Comments about this file: Quality Checked. (done) 12110102Rev3NOTScanned.wpd STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMISSION ;i�i., ) 1.1;:, REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Cl Repair Well ❑ Plug Perforations ❑ Perforate El • Other Fl. Run ESP Performed: Alter Casing ❑ Pull Tubing F ' Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory❑ 182-067 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphik❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20038-01 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit G-02RD • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools•• 11.Present Well Condition Summary: Total Depth measured 10,800 feet Plugs measured N/A feet true vertical 9,741 feet Junk measured 10,607 feet Effective Depth measured 10,745 feet Packer measured 7,545&9,570 feet true vertical 9,694 feet true vertical 6,944&8,677 feet Casing Length Size MD TVD Burst Collapse Structural 1,300' 13-3/8" 1,300' 1,300' 3,090 psi 1,540 psi Conductor Surface Intermediate Production 6,000' 9-5/8" 6,000' 5,583' 6,870 psi 4,760 psi Liner 5,276' 7" 10,767' 9,713' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet ��w�E True Vertical depth See Schematic feet QED r1,; q t , 4i Tubing(size,grade,measured and true vertical depth) 3-1/2" 29#,N-80!P-110 7,274'(MD) 6,707'(TVD) 7,545'(MD)6,944'(ND) Packers and SSSV(type,measured and true vertical depth) Packers: 9,570'(MD)8,677'(ND) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 84 23 1,507 1,444 102 Subsequent to operation: 196 84 5,371 110 130 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development IS • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil p• Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Numbe/r or N/A if C.O.Exempt: 312-454 ',/ Contact Dan Marlowe Email dmarlower'a)_hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature %j Phone (907)283-1329 Date 8!19/2013 ik Pc-/-/3 RBDMS AUG 2 0 ''1 ;..∎‘ Form 10-404 Revised 10/2012 ���r Original Only Il • • McArthur River Field, TBU Well: G-02RD SCHEMATIC As Completed: 7/16/2013 Hilcoru Alaska.1,1.0 CASING DETAIL Original RKB=38.30' SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 1-55 BTC 12.515 Surf. 1300' i IIMI 9-5/8" 47 N-80 BTC 8.681 Surf. 6000' 7" 29 N-80,P-110 BTC 6.184 5491' 10767' 13-318 TUBING DETAIL @ 1300' 3-1/2" 9.2 L-80 RTS-8 2.992" 0 7274' 41/2" 12.68 L-80 IBT 3.958 7545' 9596' JEWELRY DETAIL(Top to Bottom) No. Top Depth Btm Depth OD Item 1 7274' 7276' 4.00" X-Over. 4-1/2"8Rd X 3-1/2"RTS-8 2 7276' 7277' 4.00" Head: Bolt On Discharge 3 7277' 7278' 4.630" Discharge Pressure Sub 4 7278' 7402' 4.000" 6-section Pump,63 stages each,D5800N X 6 5 7402' 7411' 4.000" Pump Intake and AGH 6 7411' 7427' 4.560" Protectors(2) Two section Motor-456,18,4183 Maximus. 7 7427' 7491' 4.560" 270 hp each=540 hp total 9-518 TOI.a 5491' 8 7491' 7493' 4.50" Base Gauge-XT 150 Type I,Viton/Aflas 6000' 9 7493' 7495' 4.560" GLM Anode,Centralizer 10 7545' Packer 11 9570' Packer 12 9596' WLEG 1 2 PERFORATION DETAIL 3 4 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Date 5 0-1 9,664' 9,667' 8,761' 8,764' 3 7/7/2013 6 G-2 9,709' 9,712' 8,801' 8,804' 3 7/7/2013 7,8 d 0-03 9,760' 9,792' 8,847' 8,875' 32 7/7/2013 9 1S 10 0-04 9,814' 9,857' 8,895' 8,933' 43 7/7/2013 9,866' 9,880' 8,941' 8,954' 14 7/7/2013 G-05 9,932' 10,010' 9,000' 9,068' 78 7/7/2013 MC. g 11 0-06 10,069' 10,096' 9,119' 9,143' 27 7/7/2013 HB-1 10,164' 10,194' 9,201' 9,227' 30 3/12/1993 L 'i 12 10,174' 10,204' 9,210' 9,236' 30 7/7/2013 10,174' 10,176' 9,210' 9,212' 2 7/15/1982 10,180' 10,203' 9,215' 9,235' 23 12/21/1990 HB-2 10,230' 10,260' 9,258' 9,283' 30 10/7/1986 10,262' 10,264' 9,285' 9,287' 2 7/14/1982 1-1B-3 10,343' 10,345' 9,354' 9,355' 2 7/13/1982 10,345' 10,375' 9,255' 9,381' 30 12/21/1990 Tagged junk @ = HB-3&4 10,338' 10,520' 9,350' 9,503' 182 7/7/2013 10,607 DPM 10,375' 10,407' 9,381' 9,408' 32 12/21/1990 10,407' 10,452' 9,408' 9,446' 45 12/21/1990 L , H B-4 7 10,452' 10,470' 9,446' 9,461' 18 12/21/1990 H8-5 10,540' 10,587' 9,520 9,560 47 7/7/2013 TD=10,800' Max hole angle is 34.1°@ 8,400' r • S Hilcorp Alaska, LLC Hilcerp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 Daily Op -ations: 05/10/13-Friday Nipple Down Crown valve on tree and attempt to install BPV with out success due to scale inside of valves and connections on tree. Fluid level=1,100'.Soak master valve with acid. Attempt to set BPV w/o success due scale in BPV threads and seat. Soak BPV seat in hgr with acid. Set BPV and finish N/D tree,cleaning threads on hanger.N/U riser spools and BOP's. Skid Rig to G-02RD. Level derrick. Install BOP control line and function.Install pan and mud cross. Rigging up rig floor. Rigging up to test BOP's. 05/11/13-Saturday Continue rigging up to test BOP. M/U landing joint and x-overs.Screw into hanger&fill stack. Attempt to test annular&K-2 valve and found leak at uni-bolt connection on choke line.Change seal in in uni-bolt connection. Attempted to retest annular to 2500 psi and found 2 way check leaking in hanger.Pull test jt change out 2 way check.Run test jt.Screw into hanger. Test BOP's pipe&blind rams,manifolds,lines and safety valves to 250 psi low/3000 psi high of 5 min on chart.Tested annular to 250 psi low/2500 psi high on chart for 5 mins.(Had failure of seal on choke line,stem packing on well head&TIW valve,repaired all and final test good).Back out 2 way check(had gas trapped under valve).Open csg and circulate gas out of well(fluid level=1141')and bull head 85 bbls down tbg. Pull hanger&work tbg free with 150K (50K over pull). B/O hanger and continue POOH with production tbg. 05/12/13-Sunday Continue POOH with 3-1/2"production string and LO same. Recovered total of 265 jts&6 GLM. Cleaning handling tools and changing dies,strapping remaining fish. Attempt to set wear bushing unable to set. L/D same. Picking up BHA(cut lip guide over shot w/3.5 grapple,bumper jar,oil jar,4 4-3/4"Drill collars,slinger jar,x/o=163.66'). RIH picking 3.5 ph-6 work string. Fish left in hole 59 jts 3.5 9.2 buttress production tbg,5 glum's,sliding sleeve,pup jt,packer seals total of fish 1,860.51'.Est top of fish 8,197.67'. 05/13/13-Monday Continue in hole picking 3.5 work string tagging fish at 8,213'dpm. Latch fish and had discussion with ops team to pull w/overshot to make first recovery of fish. Engage fish setting down w/18k work pipe had 1.5 to 2k extra weight. POOH w/string and BHA. Pooh laying down fish having to cut connection w/air saws all(recovered 5 jts 3.5 Buttress tbg oval=152.61'.Cleaning up work area.Pick up BHA#2(Hollow mill dress off guide over shot w/3.5 grapple,bumper jar,oil jar,4 4-3/4"Drill collars,slinger jar,x/o=163.66').RIH to 5,639'.Continue in hole tagging fish at 8,365'. Latch fish at 8,365'dpm,picking up on fish in 5k intervals f/110k to 160k,working fish f/110k to 130k. Jar on fish at 30k over 5 times pipe came free,had 5k drag coming off btm.POOH work string and BHA,laying down fish. 05/14/13-Tuesday Laying down fish.Recovered 2 jts 3.5 buttress tbg-59.57 overall length. Clean slip dies.MU overshot BHA to make a E-line cut.RIH to 8,189',picking up singles to 8,315'until 120 ft above fish.Rig up stripping head,make up circ hose,break circ,washing down until 4 ft above fish at 3 bpm 300 psi. Circ tbg volume each jt wash down(getting back fine solids).Reverse circ until clean returns.Circ down tbg and wash over fish,had pressure increase,indicating getting over fish,had no over pull made 3 attempts to latch fish,had 15 k over pull on third attempt. Rig up Priority E-line w/2.25 tapered gauge. RIH tagging at 8,468 ELM 4 ft below GLM.Had to work thru top of fish w/gauge. POOH w/gauge. R/D E-line.Work tbg f/150K 50k over and down to 80k 20k dn.Tubing started moving up hole at 140k for 8 ft, then broke back to 110k,lay down tbg jt. Rigging down stripping head. Pooh w/work string. 05/15/13-Wednesday POOH w/work string. Lay down fish. Recovered 1 jt of tbg and GLM#5. P/U overshot BHA#4 and RIH. Work over fish and latch fish at 8,462'. Working and jarring up to 170k 63k over 40/50k dn,pipe moving up hole had 8k overpull. POOH w/work string and rack back BHA. Shuck and lay out overshot. Recovered 2 full jts tbg,collar looking up on fish. Clear pipe rack. RIH w/picking up BHA#5 (Ocean wave shoe,9 jts 5-3/4 x 5.125 wash pipe,canfield bushing,bumper jar,oil jar,4 4-3/4 D.C's,slinger jar,x/over= 448.70). RIH with work string. Fish left in hole 49 jts 3.5 9.2#buttress tbg,4 GLM,sliding sleeve,pup jt,baker locator jt,seal assembly=1549.61. ETOF 8,522'. 05/16/13-Thursday RIH t/TOF @ 8,522'dpm. Space out&P/U swivel. REV.CBU @ 3 bpm,400 psi. Wash down over fish f/8,522't/8,796'dpm,@ 3 bpm,400 psi,rot 60-80 rpm,tq off 4700,on 5900,rot wt 96k,up wt 103,dn 90,CBU till clean @ 3 bpm,400 psi. R/D swivel.Clear floor and move 4 stands in derrick. POOH w/wash pipe f/8,796'. POOH w/BHA. L/D shoe. ► • • Hilcorp Alaska, LLC Hileorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 Daily'Operations: 'we 05/17/13-Friday Prep&P/U BHA.Install wear bushing. Pump fluid from pits t/Trading Bay. Rig maintenance. M/U BHA,Rotary sub,4.75 od,2.81 id, washpipe drive sub,5.75 od,1.75 id,8 jts-254',5.75 washpipe 5.125 id,xo 5.75 od,4.875 id,Logan mechanical od cutter 5.625 od, 4.38 id,total BHA length 267.34'? RIH w/washpipe/cutter assy,slow down after liner lap to keep fluid from over-flowing from tubing.Rig up power swivel.Made cut on 3-1/2"buttress production at 8,781'. Rig down power swivel.POOH w/3-1/2"work string. Control valve on Foster tongs blew seals in valve bank,change out seals on valve bank controls,attempt to use tongs,blew seals when engaged controls.Change out foster tongs to McCoy tongs.POOH w/3.5 work string,tong dies on power tong would not cam over and bit tbg.Trouble shooting tongs,found small piece of metal in tong rollers,change tong dies,adjust brake bands,POOH w/work string t/BHA. 05/18/13-Saturday Break off w/p bushing,pull&I/d fish. Recover 8 jts&1 cut jt 9.3',total recovery length 249.83'leaving TOF @ 8,781'.Pull wear bushing&install test plug,(issues getting through annular element).M/U test jt, r/u test equip,Test BOP'S and related surface equipment to 250 psi low and 3,000 psi high w/water function from the koomey station holding each test 5 min. AOGCC witness was waived by Mr.Jim Regg on 5-17-2013. Conducted the Koomey test. Install wear bushing,slip and cut drill line 40 ft. Make up BHA and RIH w/2 stds 3.5 work string,McCoy tong not biting on 3.5 work string,change out to Foster tongs.Start to use tongs,blew valve bank on tongs. Rig up McCoy tongs,blew valve bank on tongs. Call for parts and mechanic,parts at dock. 05/19/13-Sunday Troubleshoot hydraulic system&repair,good.Repair valve bank on Foster tongs&test good.RIH w/overshot BHA,Xo,top sub,bowl ext,overshot bowl w/3.5 grapple,hollow mill dress off guide t/8,781'up wt 116,dn wt 85.Engage TOF @ 8,781',p/u 5k over.R/U e-line,RIH with 2.65 m/shoe gauge ring,spang jars,CCL,2"tools string tagging up at 8,840'ELM. RIH w/2.65"OD spectra cutter, log on depth,make cut at 8,820'ELM.POOH. R/d E-line. POOH to BHA w/fish. ETOF AT 8,820'. Fish in hole 40 jts 3.5 production tbg,3 GLM,sliding sleeve,pup,baker 80-40 seal assy=1,240 ft. 05/20/13-Monday L/D fish(36.62)2-cut jts&1 GLM. Clean&clear floor&catwalk. P/U BHA#8,washpipe assembly(Ocean wave shoe,12 jts 5-3/4 x 5.125 wash pipe,canfield bushing,bumper jar,oil jar,4ea 4-3/4 D.C's,slinger jar,x/over=543').RIH w/BHA#8 to 8,787'.R/U stripper rubber. P/U power swivel,washing over f/8,787'dpm reverse circ at 3.25 bpm w/550 psi,rotating down w/60 rpm w/ 5,200 ft lbs had to work spot at 8,930'to 8,945'getting some soft asphalt back across shakers at this depth.Continue washing over to 9,039'had 20k increase in p/u wt and 16k in slow wt torque at 7,000 ft lbs w/40 rpm- unable to rotate unless moving pipe. Mix 20 bbls of Bariod NXS-LUBE and started displacing same down work string at 1/2 bpm 1100 psi had no returns,pump 20 bbls hole appeared to have packed off,and pipe stuck,line up and reverse circ at 2 bpm jarring on pipe at 160k. 05/21/13-Tuesday Continue working stuck pipe @ 9,020',jarring @ 170 with movement starting up. Continue for 50'before weight drop.Continue dragging up w/20k over till free @ 8,930',up wt 116,dn wt 85.Continue CBU @ 3bpm,working pipe f/8,920't/8,950'. Wash down f/ 8,920't/9,015'where tq up t/7000k stall and take wt.unable to wk clean. Cir hole clean. Rig down power swivel. POOH w/work string. POOH w/BHA. Make up BHA and RIH w/same outside cutter,adapter,7 jt 5-3/4 x 5.125,canfield bushing,x/over =235.74'.RIH t/8,795'.Pick up power swivel,up wt 100k,93k dn wt.92 rot wt. RIH w/cutter over fish t/8,998 ft.making out side cut at 8,998'. 05/22/13-Wednesday Making outside cut on 3.5 Buttress production tbg w/BHA#9 at 8,998'(outside cutter,adapter,7 jt 5-3/4 x 5.125,canfield bushing, x/over=235.74'). Circ down tbg at 3 bpm"0"psi had no return.Lined up and reversed circ pump 11 bbls got full returns.Rigging down power swivel.POOH w/3.5 ph-6 work string. POOH w/BHA.Lay down fish recovered 5 full jts&2 cut peices of 3.5 buttress production tbg total footage 174.84 ft.Est top of fish at 8,998'.Fish left in hole(33 JTS TBG,3 GLM,sliding sleeve, pup jt, seal assembly,=1,056.93'). POOH w/wash pipe and lay down cutter.Clean handling tools and clear floor.M/U BHA(Ocean wave shoe w/ 6"smooth OD X 5"rough ID,6 jts(191.48 ft)5-3/4 x 5-1/4 ID wash pipe,canfield bushing,bumper jar,Oil jar,(4)4-3/4 drill collars, slinger jar,x/over =353.80'.Trip in hole w/3.5 PH-6 workstring.R/U power swivel and Hall's head. Washing over f/8,978'to 9,039' dpm at rpt time. • • Hilcorp Alaska, LLC • 11i1corp Alasska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 Daily Operations: 05/23/13-Thursday Continue washing over f/9,039'to 9,166'dpm,tagging up on GLM#3.Had tight spot at 9,081'to 9,102'worked thru and clean up same,RPM AT 80 W/3500 T/4000 FT LBS.Reverse out at 3 bpm at 260 psi losses while reversing circ at 70 bph and 30 bph while static,reverse circ until returns clean fluid.R/d power swivel,pups and 6 jts 3-1/2 ph6.POOH w/work string. Pick up BHA#11 (outside cutter,wp adapter,6 jts wash pipe,Canfield bushing,x/over =203.59'. Service rig. RIH w/workstring to 8,957'.Est top of fish at 8,998'. Fish left in hole (33 JTS TBG,3 GLM,sliding sleeve, pup jt, seal assembly=1056.93'.)R/U power swivel. 05/24/13-Friday Working cutter down over fish to 9,140'dpm.Break circ down tbg at 3 bpm at 40 psi,go returns,slow pump to 1/2 bpm,rotating at 60 rpm w/3200/4200 ft/lbs making outside cut on 3.5 production tbg at 9,152'.POOH w/cutter. POOH w/BHA. POOH laying down fish,recovered 4 full jts and two cut jts,total recovered 154.34'.P/U BHA#12(cut lip guide,overshot bowl w/3.5 normal catch basket grapple&mill contorl pack off,top extension,top sub,x/o=8.32'.)RIH w/3.5 ph6 work string.R/U E-line. RIH w/2.65 spectra cutter sat down at 9,144'ELM,top of fish.POOH.L/D 2.65 spector cutter.M/U and RIH w/2.50 swedge sat down on top of fish,made several attempts to get deeper w/no luck. POOH w/swedge gauge. 05/25/13-Saturday RIH w/2-1/8"swedge t/9,144'wlm,wk but unable to make progress.POOH. R/D E-line.R/U to circulate. Reverse circ.@ 3bpm,290 psi,CBU(through holes in tubing below overshot)small amount of solids came back.R/U E-line. RIH w/2-1/8"swedge t/9,148'wlm, unable to go farther. POOH.R/D E-line. Wk pipe f/neutral 95k t/160k multiple times,came free dragging up hole @ 118k pulling 15' wt dropped off t/108k. POOH,retrieve 59.19'fish,1-cut jt,1-GLM,1 full jt&1 collar.New TOF=9,211'.Rigging up manifold to test BOP's&pull wear bushing and installing test plug. Fill stack and flush thru lines. Test BOP's and related surface equipment to 250 psi low and 2500,3000 psi high,had one retest on low test for blind rams,pressure not stablized,bleed down and retest blinds(good test conduct Koomey test. AOGCC witness waived by Jim Regg on 5-24-13 @ 15:26 hrs.Pull test plug&install wear bushing.Change out hoist line. Rigging up&change out drill line. 05/26/13-Sunday Move pad eyes for tbg board chains on rig floor,and pumping oil out of fluid tank. P/U BHA (Ocean wave shoe w/6"smooth O.D.X 5.00 Rough I.D.,7 JTS.5.75 WP,Canfield bushing,bumper jar,oil jar,(4)4-3/4 drill collars,slinger jar,x/o=385.35'.)RIH w/work string. R/U power swivel and Halls head,washing over fish f/9,196'to 9,437',reverse circ at 3.5 bpm 360 psi rotating 60 rpm w/2800 /3500 ftlbs torque.Had tight spots at 9,296'and 9,406'getting scale back at shaker on each btm up.Circ hole clean. R/D power swivel and Halls head. POOH laying down 6 singles. 05/27/13-Monday Cont. POOH and stand back BHA.P/U up BHA#14(outside cutter,wp adapter,6 jts wash pipe,Canfield bushing,x/over =235.74'.) RIH t/9,211'. P/U swivel work do t/9,429'. Making outside cut on 3.5 buttress production tbg at 9,429'. L/D power swivel.POOH w/ workstring laying down 8 singles. Break out washpipe and strip over fish,laying down fish(recovered 7 jts&cut piece tbg=217.95'.) Est.top of fish 9,429'.POOH w/washpipe. L/D cutter. 05/28/13-Tuesday Continue L/D BHA.Repair air leak on D/W clutch.P/U BHA (Ocean wave shoe w/6"smooth O.D.X 5.00 Rough I.D.,6 JTS.5.75 WP, Canfield bushing,bumper jar,oil jar,(4)4-3/4 drill collars,slinger jar,x/o=351.73'.)RIH t/9,420'.Secure well&C/O brake bands on D/W. P/U swivel&get paramaters,Up wt.114,Dn wt 97,Rot wt.106,tq.2800-3200.Washed joint#289 down and circulate until returns clean.Continual scale in returns.Washed down jts.290&291.On jt.291 torque spikes from 2900/3200/4500.Washed down with jt.291 to 9,509'DPM.Continue to circulate,getting back increased amount of scale.Continue washing down with jts.292&293 with torque spikes from 2900/3200/4500.Washed down with jt.293 to 9,574'.Continue to circulate,getting back considerable increased amounts of scale.Will continue to circulate until clean.Continue to circulate,getting back large amounts of scale.Returns cleaned up,end reverse circulating.RD power swivel. Laid out 5 jts over top of fish.POOH. • • Hilcorp Alaska, LLC • Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 05/29/17 edne,da . � r, POOH with washover BHA.Lay down washover BHA.P/U outside cutter BHA.TIH w/outside cutter assembly and workstring.TIH to one joint above top of tubing stub @ approx.9,422'.Fill hole w/FIW.P/U power swivel.Establish parameters for making outside cut. Up wt.109,down wt.97,static rotating wt.103.Wash down over tubing stub 5 joints,circulating until hole clean on each joint to 9,566'.P/U on cutter to pull under tubing collar to shear cutter pin to engage knives,no extra weight on pull observed after several attempts.Lower down to top of GLM#2 @ 9,576'.Tagged and set down 2K.PU cutter and pulled slowly looking for engagement of spring cage on tubing collar.Still no overpull or P/U weight.RD swivel.POOH.Continue POOH while filling hole.Handle on rig tong broke.Shut in well.Welder to repair.Repair of rig tong complete.Continue POOH. 05/10/13 " i jr8t .. Finish POOH with outside cutter.Break out 3 joints washpipe.Lay down washpipe.Recovered 3 joints and partial joint 3 1/2"tubing. 114.8'Lay down balance of washpipe and break out outside cutter.Pick up overshot make up BHA with 1 joint washpipe.TIH,R/U power swivel.Fill hole.Establish work string/BHa parameters.S/o wt.97K,PU wt.112K.Continue in hole washing down over top of tubing stub @ 9,437'.Slack off over tubing stub and tag GLM with 3K down.P/U 115K/set down 5K.Continue twice more to confirm overshot engagement.Continue working overshot at increments of 5K to 140K total,28K overpull.Fish came free.P/U load showed 2K over string weight.R/D power swivel.POOH with small spikes on first 2 joints to 115K.Workstring pulling wet.Installed rig floor side wall on west side,picked up mud bucket due to fluid spray and winds.POOH slowed due to these conditions.Presently pulling drill collars and standing back. Finish laying down BHA.Recovered 95.63'fish.TOF 9,633'. Pick up new BHA consisting of 7 joints washpipe,jars.TIH with washpipe. State requested if possible to test BOPE on Friday instead of Sunday.Had inspector available immediately in Kenai on standby. Decided to test BOPE.POOH with washpipe and stand back,lay down jars.Prepare for BOPE testing.Test BOPE as per AOGCC.Test witnessed by John Crisp.Tested Annular to 250 low 2500 high. Annular failed first test.Flushed annular,checked all connections on safety valve and test joint.Retest Annular passed.Tested BOP rams and manifold to 250 low/3000 high.Pick up washpipe BHA,TIH. Finish TIH to 1 joint above tubing stub @ 9,633'.P/U power swivel,fill hole.Begin circulating.Currently washing down each joint washpipe,circulating clean after each joint. Y8 � Finished washing down 2 joints above TOF.Wash down over TOF @ 9,633'.Tagged partial coupling on top of tubing stub @ 9,633' from previous trip.Milled past coupling piece in approx.15 minutes.Finish washing down with washpipe jt.#1. Wash and rotate washpipe jt.#2 @80rpm's torque @3200-3800 ft.lbs.static rotating wt.100K,S/0 wt.90K,PU wt.111K. Continue to wash over with jts.#2-#5. After each joint circulate scale clean.Reverse circulating at 3.3 bpm at 350-400 psi.Average fluid losses 60-100 bph.End reverse circulating.On washpipe joint#5 while picking up swivel,crossover threads from swivel to work string were visually inspected and found to be gualled on pin end.Broke out crossover sub and replaced.Continue picking up swivel and washing over 3 1/2"tubing. Average losses 106-126 bph.Wash down with washpipe jt.#6-7.Increase rpm's to 110-120/torque @ 4000-5000 ft.lbs. Average losses 112-126 bph.Washed down to 9,858'and circulated BU.Rig down power swivel.POOH with washpipe assembly.Stand back washpipe/jar assembly.Break out shoe.Currently slipping drill line on rig.P/U outside cutter with 7 jts.washpipe.TIH. 06/0 ., unday ,` ; � '`_ Zz. Continue TIH with outside cutter and 7 jts.washpipe.PU/RU power swivel.Fill hole,establish hole parameters for outside cut. 50rpm's @ 2800-3000 ft.lbs.Static rotating wt.103K,rotating S/O wt.101K,nonrotating S/O wt.101K,nonrotating PU wt.111K. Circulation @ 1 bpm @ 100psi.Rotating over TOF,went over easy.Lowered 6 jts.over fish while circulating long way @ 1 bpm.P/U against tubing collar with 3K,slide down 7'to make cut @ 9,824'.rotate @ 60 rpm's @ 3200-4200.P/U cutter against coupling no overpull.Cut made.P/U wt.114K.Cutter and washpipe had covered 6 jts and 9'of tubing in cut.R/D power swivel. POOH with washpipe and outside cutter.Lay down washpipe BHA.Recovered 1 jt.tubing with no couplings on it.Inspect cutter,knives and spring dogs broken.PU/MU skirted spear assembly.TIH with spear to spear Id.Possible corroded coupling on top of loose tubing fish. Went with spear to engage ID. • Hilcorp Alaska, LLC • Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 Daily Operations: '. 06/03/13-Monday Continue TIH with skirted spear assembly to TOF @ 9,663'.With 3 stands above TOF observe hole parameters.PU 120K/S0 92K 2 stands above TOF-PU 120K/SO 93K 1 stand above TOF,PU 120K/SO 96K,At 20"down on top single of last stand above TOF get parameters.PU 121K/SO 96K Slack off tagged TOF @ 9,633'.Took wt.at 22'down on single taking wt.Put 5K down then P/U.Picking up 122K/set back down 10K then pick up @ 122K.POOH with skirted spear assembly.Layed down BHA.No recovery on spear assembly.No marks on grapple,had marks on end of shoe skirt.Discussed options again.P/U overshot with 3 1/2"dress-off guide. Begin TIH.15T YT elevators would not properly engage tubing under upset.Make repairs to YT elevators.Continue TIH.PU/RU power swivel.Fill hole.Will wash down to TOF @ 9,633'to engage then RU E-line. 06/04/13-Tuesday Finish TIH.Get hole parameters.P/U wt.111K,SO wt.89K.tagged TOF @ 9,666'.Set down 5k on fish made 4.5'more.P/U get 3K overpull set down and make 1/2'more.P/U with no overpull and no noticeable wt.P/U 15'. Lay down swivel. POOH with overshot. Break out overshot bha and lay out.Recovered 1 jt.tubing.TOF @ 9,696'.Will replace grapple and TIH to engage 3 1/2"tubing. 06/05/13-Wednesday PU overshot BHA,discussed further about 2 couplings corroded in hole stacked up. Layed down overshot BHA.PU skirted spear assembly skirted with one joint of washpipe and wavy bottom carbide shoe.TIH with 306 jts.RU swivel on jt.307,lower down to 9,696'TOF. Rotate over top of fish,encountered resistance from coupling obstruction.Finished clearing by TOF.Worked spear down to 9,726'.RD swivel POOH. POOH with skirted spear assembly.Lay down washpipe and one joint of tubing fish.Also one joint of tubing and coupling(possibly 2 couplings).Currently trying to work tubing and coupling junk from washpipe to confirm recovery.Total recovery 2 jts.and one coupling confirmed so far. 06/06/13-Thursday TIH with overshot to TOF @ 9,756'.PU power swivel,lower down to TOF,fan for 15 minute.Engage fish.POOH,OOH with overshot, recovered 2 jts.of 3 1/2"tubing.Release fish from overshot.Lay down same.TOF at 9,818'.TIH with overshot,engage fish at 9,818'. POOH. 06/07/13-Friday Continue POOH w/3-1/2"PH-6 work string and over shot. Shuck overshot from pipe.Recovered 1 jt of tbg,new top of fish at 9,849'. Clean rig floor,pull wiper bushing,make test plug and land same in hanger spool. Test BOP blind&pipe rams,lines,valves,manifolds &safety valves to 250 psi low&3000 high psi for 5 min on chart,test annular to 250 low 1500 high on chart for 5 min.No leaks all good test(State Witness waved by Jim Regg @11:30 6/6/13). Slip and cut 45'of drill line.Repair tongs. Pull test plug,install wear bushing. PU overshot and 15'extension BHA.TIH.Tag TOF @ 9,849'.Work over TOF to 15'over.Work twice more.POOH. 06/08/13-Saturday Service rig and adjust drive chain on draw works.Continue POOH with 3-1/2"work string and overshot assy.Lay out overshot and shuck same,recovered 1 jt of 3-1/2"production tbg.PU&MU wash over BHA,6"od wavy bottom shoe,(4jts)wash pipe,bumper sub &jars,3-1/2 PH-6 box X 3-1/2"IF pin x-over,total length=155.39'.RIH to 9,880',work washpipe over TOF.Wash down 3 jts.while circulating.Close Annular BOP while making connection to tighten Hall's head.At that time production alarm went off detecting gas in the pit area.Shut in well,stop pumping.Muster in galley.Discuss with production.Open hatch above pits on pipe rack.Start pump and circulate.Diverted returns through gas buster.No gas detected for rest of washpipe operation.Continue to wash down jt.4 while circulating.Wash down to 9,976'DPM+7'elevation.9,983'top of GLM.Circulate BU,prepare to POOH.Rig down power swivel. POOH slow to top of 7"liner top,continue POOH. • • • Hilcorp Alaska, LLC • Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 Daily Operations: 06/09/13-Sunday BO and LO washover BHA. PU and MU over shot assy. RIH with overshot assy and 3-1/2" PH-6 work string to 9,984'and latch fishing neck on bottom GLM. Jar on fish with 30 to 35K over PU wt.maximum pull on fish=40 to 45K over PU wt.(PU wt=130K,slack off= 90K).Pulled up hole with with 20K-30K overpull.POOH slow.Overpull drag dropped to 10K over.Continue POOH.OOH,lay down 4 jts.washpipe,recovered 3 jts.tubing,GLM,1 jt.tubing,sliding sleeve,1 jt.tubing,pup jt.,locater sub,seals,1 pup jt.,x-nipple,1 jt. tubing,mule shoe.Total recovered 226.77'.Clear washpipe and tubing from pipe deck.Prepare to PU milling shoe to mill over packer. 06/10/13-Monday PU Milling shoe assembly.6"OD x 4 3/4"rough ID shoe,5 3/4 top bushing,4 3/4"OD Bumper/Oil jars,4-4 3/4"OD drill collars,xo to work string.TIH to 2 jts.above packer.PU swivel,install stripper head.Wash down 2 jts.to top of packer @ 10,060'.PU 15'-establish milling parameters-S/0 wt.90K-P/U wt.120K-free rotating torque 4000 ft.lbs.Begin milling on Baker Model F-1 packer while reverse circulating.Packer fell free.Push packer to 10,119'.Packer tagged up on possible loose packer cuttings.Circulate BU.Lay down swivel,pull stripper head.POOH with 30K overpull for 4 stands.Overpull fell off.Continue POOH.Break out milling shoe and top bushing.PU 5 3/4"OD overshot dressed with 4 1/2"grapple. 06/11/13-Tuesday Continue in hole to 10,105'with 5.75"od overshot with 4.50"spiral grapple,4.75"od bumper sub&jars,(4)4.75"od collars,3.50" PH-6 box X 3.50"IF pin x-over.Total length=160.28'. PU power swivel slack off to 10,119'set down 15 k 3 while pumping @1-1/2 BPM with 200 psi,PU and had 10 to 12 k overpull and a pressure increase to 400 psi. LO power swivel and POOH with overshot and fish.Had 7-9K drag.Recovered 8lbs.of large packer chunks and large pieces of couplings inside overshot and overshot grapple.Did not appear mandrel was allowed to enter overshot due to junk.PU new 6"OD x 4 3/4"ID milling shoe,5 3/4"OD top bushing, Bumper/Oil jars,4-3/4"OD Drill Collars,xover to work string.TIH to mill on packer at 10,119'.Possible packer drug uphole some. Continue TIH with milling assembly.Currently at bottom hole assembly. 06/12/13-Wednesday Continue in hole to 10,100 with burning shoe assy.PU&MU power swivel.Slack off to 10,119 and mill and push packer to 10,218. Reverse bottoms up.Rig down swivel.Pull 2 stands to 10,090',spot 20 bbls salt pill on bottom.POOH to 3,162'&tooth in right angle gear box broke.Close in well.Remove gear box.Wait on new transfer case from Victoria,Tx. Estimate 24 hrs for repair. 06/13/13-Thursday Replace RAD.Repair drive chain and drive chain guard.State waived BOP witness.Test Choke manifold 250 low/3000 high.Will POOH to test Koomey/BOP/Annular and slip drill line.Fill hole.Prepare to finish POOH. 06/14/13-Friday Continue POOH with 3-1/2"PH-6 work string&Burning Shoe BHA.BO&LO 6"Burning shoe,recovered packer mandrel with shoe. Pull wear bushing. MU test plug and test joint,land plug run hold down pins,fill stack with FIW,flush system,Test BOP,rams,blinds safety valves&manifolds to 250 psi low&3000 psi high on chart for 5 mins.Test annular to 250 psi low&1500 high on chart for 5 min.1 failure on valve K-1,repacked stem on valve,retested same to 250 psi low,3000 psi for 5 min.Test accumulator. Run out hold down pins,pull test plug&LO same.Land wear bushing and prepare to RIH with wash over assy.PU/MU 6"OD Milling shoe,1 jt.5 3/4"OD washpipe,5 3/4"washpipe top bushing,4 3/4"OD bumper/oil jars,4-4 3/4"Od drill collars,x over to workstring.TIH to 10,178'.PU power swivel.Wash down 2 jts.tag fill @ 10,238 begin torqueing up.PU had 20K drag,work up and down to free torque and drag.Pull up to next connection.Circulate BU,break out single.PU and work,workstring freed up.Rotated and washed back to 10,238'.Shoe began torqueing again.PU/MU 12'(4'+8')pup joint.Milling through tight spot.PU break out pup jt.Circulate BU. PU single begin washing sand fill. Hilcorp Alaska, LLC • Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 Continue reversing out while mixing 10.5 ppg salt pill. LO power swivel and pull 2 stds.Broke circulation in reverse,swapped manifold and attempted to circulate salt pill down tbg.(pumped 20 bbl pill followed by 30 bbls of FIW)tbg plugged.Swapped manifold and reversed, bbls,swapped manifold back to tbg and attempted to circulate pill to bottom w/o success.Tubing pressured up to 1000 psi. Attempted to break bridge with 4000 psi w/o success.Rig down lines&stripping head. POOH found 1 long piece of metal in shoe, unplugged BHA from small band like pieces and sludge.TIH with 6"Od milling shoe, jt.of 5 3/4"washpipe,5 3/4"top bushing,4-4 3/4"OD drill collars,4 3/4"Od bumper/oil jars x over to workstring.PU power swivel to wash sand fill. /16/1 ., u fs Spot 20 bbl.salt pill at perfs,let set 30 minutes.Rig up stripper head and power swivel.Start washing down 3 its.above last tagged sand fill.Wash from 10,266'to 10,580'.Pressure increasing.Tubing plugging off.Continue to circulate reverse and go the long way in effort to clear blockage.Recovered+/-10 gallons of sand and scale almost immediately.Pump 20 barrels.Pipe unplugged.Reverse and wash down with 2.5 bpm at 250 psi.Tubing plugged off.Several attempts made to clear blockage.Unsuccessful.Decision to POOH.Rig down stripper and power swivel.POOH with wet string.OOH w/fishing assy.Lay down wash pipe.Wash pipe full of gun debris,sand and scale-approximately 3 gallons.Prepare to run back in hole. 0 3 t, ` ..;_ � Trip in hole with 5 3/4 shoe,top bushing,wash pipe extension/jars,drill collars,pump out sub with 2000 psi rupture,and workstring. TIH to 10,518'.PU pump in sub and displace 15bbl Hi Viscosity pill down workstring across perfs.Let sit for 1 hour.Reverse out pill at 3bpm and 250 psi.Small amount of debris returned.Total pumped-117 bbls.Rig up stripper head and power swivel,pick up singles wash down at 3 bpm and 250 psi.Tag at 10,580'.Power swivel stalled out at 7k ft/lbs of torque.Returns became intermittent.No change in pressure or rate.Pick up off bottom.Returns steady.Circulate bottoms up at 3 bpm and 250 psi.Start washing down.Tag at 10,580'.String continuing to stall out each time we tag. No progress.Break circulation down tubing at 3 bpm and 350 psi.Tubing pressure increased to 1200 psi at 1 bpm.Switch over to reverse.Reverse at 3 bpm and 250 psi.Monitor returns and measure loss rate.Loss rate at 52 bph.Circulate bottoms up.+/-1 gallon of debris returned.Attempt to wash down-3 bpm at 250 psi.Tag at 10,580'.Annulus pressure increased to 500 psi.Returns slowed.Pick up off bottom.Annulus pressure remained at 500 psi.Switch over and circulate down tubing.Circulate at 3 bpm at 250 psi.Switch back to reverse.Wash down.Tag at 10,580'.Annulus pressure increase to 500 psi.Pick up off bottom.Annulus remained at 500 psi.Break circulation down tubing at 3 bpm and 250 psi.Circulate down tubing at 3 bpm and 250 psi.Tag at 10,580'string continuing to stall out.Attempt to wash past 10,580'using aggressive tactics. Tubing continuing to stall.Unsuccessful after multiple attempts.Pump 10 bbl pill down annulus in attempt to sweep blockage up tubing.Annulus pressure increased to 700 psi.Returns reduced.Increased pressure to 1000 psi.Still reduced returns.Increased pressure to 1500 psi while aggressively working pipe up and down.Annulus pressure dropped to 250 psi.Attempt to wash down while reversing.Pressured up immediately.Pick up and clear debris by circulating down tubing.Attempt to mill/wash down sand fill. 0 9 8/ 4 4712V POOH with 6"Od milling shoe,5 3/4"OD 6'long extension,5 3/4"top bushing,bumper/oil jars,4-4 3/4"OD drill collars,x over to workstring.Lay down swivel/pull stripper head.Breakout shoe,extension and top bushing.Examine shoe,shoe had 40%carbide still, not rolled on outside edge,carbide still good inside.No marks on ID of extension or top bushing.Waiting on boat with 5 1/2"OD junk mill,6"OD string mill smooth on gage,x over subs.Will TIH with 5 1/2"OD bladed junk mill,6"OD string mill smooth gage,(2)boot baskets,x over to jars/drill collars.Will circulate the long way pumping 10bbI.Hi-Vis pills.Make up BHA-5 3/4 junk mill,Bit sub,6"OD String mill,2 ea.boot baskets,Bumper jar,Hydraulic fishing jar,drill collars and pump out sub with 3000 psi rupture disc.RIH. Rig up stripper and power swivel.Attempt to Break Circulation.Swivel packing leaking.Waiting on swivel packing and swivel washpipe replacement. • Hilcorp Alaska, LLC • Hilcorp Alaska,LLC: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 Daily Operationsi 06/19/13-Wednesday Lay out swivel.Swivel technician and replacement packing and swivel washpipe arrived.Repair swivel.PU swivel,begin circulating the long way and milling.High torque @ 7000K and slow milling.Continue to rotate,pump and work BHA for 3 1/2 hours.Mill broke through and made 20'.Pulled up and was stuck again.Bumper jar and oil jar do not show travel so junk is above jars.Work BHA for 4 hours with 40-50K overpull.Dragging up hole.At present pulled 5 joints with continued overpull.Continue to pull and drag up hole in 7"liner.Joint 325 pulled easier.Still a lot of drag but less pipe reciprocation to get it out.Joint 324 pulled with very little reciprocation. Still dragging.Joint 323 pulled with no reciprocation or rotation.Still dragging.Pulled 2 more joints with 40K overpull of string weight drag.Rig down swivel and stripper.Continue to POOH with diminishing over pull.Loose junk came free @ 2:30 am still in 7"liner @ 10,280'.Begin POOH at regular speed.Will lay down 5 1/2"mill,6"string mill.PU 6"OD conebuster mill,2- bootbaskets,bumper/oil jars,4-drill collars,xover to workstring. 06/20/13-Thursday POOH.Laid down BHA.Gun debris and scale in boot baskets.Make up BHA-5 3/4 wavy bottom rotary shoe with flapper,5 3/4 washpipe extension,washpipe drive sub,15 stands 3 1/2"PH-6 tubing,Bulldog bailer,and drain sub.RIH with BHa and 3 1/2"PH-6 workstring.Tag fill at 10,603 ft.Start bailing.Made 3'.Rig up power swivel.After picking up power swivel,the lower motor hosing seal went out.Ordered power swivel body only.Continue to bail sand. 06/21/13-Friday Continue to bail while waiting on swivel repair.Bail 4 more hours made 3'. Setting down on hard bottom.Setting down up to 30K-40K down on shoe while bailing.No success.POOH.Swivel repairs complete.OOH recovered 2 pieces of packer rubber.No rough marks on OD of shoe,extensions or bailer.Flapper still in good working condition.Shoe had no wear on carbide.Williams rig drill line had multiple frays.Went to slip and cut drill line,not enough line.Shut down waiting on new drum of 1"drill line.Estimated time is the 14:00 hr.boat on Saturday June 22.Test BOP 250 psi low/3,000 psi high. Witness of test waived by Jim Regg,AOGCC. 06/22/13-Saturday Waiting on new drill line for workover rig.Toolpusher called and got approval to use existing drill line after slip and cut.Pull 2,000'kill string.Pick up BHA-5 3/4 tooth type rotary shoe with flapper,5 3/4 washpipe extension and drive sub.RIH.Spot 20 bbl salt pill at 10,100'down annulus.Pick up single,start rotating and reverse circulating at 3 bpm/700 psi.At 10,603'pressure increase to 1,000 psi and returns stopped.Pipe torqued up.Worked pipe up and down to remove blockage.Begin dry milling.Made+/-1 foot.Pick up and re-establish circulation-3 bpm at 750 psi.Ease down while rotating and pumping.Pipe torqueing up short of the previously established mark.Work pipe up and down while rotating.Returns stopped.Dry mill.Not making any hole.Pick up and try to re- establish circulation.3 bpm at 750 psi.Very little returns.Stop pumping.Dry mill again.No progress made.Stop milling.Spud on debris.Rig down power swivel and stripper head.POOH. 06/23/13-Sunday POOH with 5 3/4"tooth type milling shoe with flapper,5 3/4"extension with flapper,extension,top bushing,x-over to 3 2/"PH-6 tubing.Break out BHA,clean metal cutting and sand.Recovered 2 gallons of small chip size metal cuttings and 5 gallons of sand on top of the metal cuttings.MU 6"OD Bear Claw full opening bit mill,bit sub to 3 1/2"tubing.TIH to 2,440'.Was notified by toolpusher that drill line had frayed areas.Shut in well.Secure kill/workstring.Shut down to inspect.Decision made to replace drill line and repair Lebus drum and inspect all components affecting drill line issues.Shut down on rig repairs. 06/24/13-Monday Shut down waiting on rig repair.Clean pits,inspect hoses,clean deck,organize pipe deck.Disassemble block for replacement.Prepare Lebus drum for replacement.Prepare for Dragon mechanic to arrive on next chopper this morning. • • Hilcorp Alaska, LLC . Hhlcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 Wy,Op erations;: 06/25/13-Tuesday Dragon rep arrived.Inspect drill line spool and Lebus.Called his office requesting diagrams,spec drawings and pictures of correctly assembled Lebus.Disassemble Lebus from drum.Reposition Lebus on drum.Weld in place.The new position of the Lebus requires trimming to allow the drill line lead to be attached and run up on the Lebus.Finished welding.Hook up drill line for test.Ran block up/down several times.No improvement.Still not wrapping properly.Waiting on new drill line.At the docks waiting on tide/boat @ 17:00. 06/26/13-Wednesday Waiting on new drill line. 06/27/13-Thursday String new drill line.Perform test to determine if line wrapping correctly.Drill line wrapping better but still not right.Install kick plate in an effort to fix it.Kick plate installed.First 2 rows look ok.3rd row not quite right.Williams ok to proceed with it.Pull out of hole. 06/28/13 Friday Pulled Wear bushing.Test BOP 250 psi low/3,000 psi high.Witness test waived by AOGCC-Jim Regg.Replace Hydril rubber.Hydril nippled back up.Test Hydril.Good test.Pull Test plug.Prepare to RIH. 06/29/13-Saturday Picking up BHA(cone buster type concaved mill,bit sub,bumper jar,hyd fishing jar,4 drill collars,pump out sub,x/over=154.49).RIH w/3.5 ph6 w/string to 10,570'.Wraps on third layer of drill line was pulling down between the wraps on the second layer of drill line after the hook load got above 140k,trouble shooting lebus grooving and line on drum.POOH with 7 stds of 3.5 tbg,to 10,130'.Btm layer drill line on drum had total of 15 wraps,slipped back 6 wraps of drill line leaving 9 wraps of line drum.Dressed off the weld at the kick plate to lebus grooving connection due to hump in weld.RIH,line spooling ok on drum.Install Hall's head&rigging up power swivel. Break circ w/30 bbls FIW.Shaker screen plugged.Clean shaker screen.Clean shaker screen.Break circulation.Pump 10 bbl pill.Spot in annulus above EOT.Measure pit volume-38.75"x 3 bbl per inch.116.25 bbls in it.RIH and tag at 10,603'with 2k down. Pick up,start reversing at 74 stk/min and 200 psi.Shut down pump.Pipe won't rotate.Lay out single.Pick up pup joint.Start reversing at 75 spm and 250 psi.Rotate and attempt to wash down.Lost circulation.Shut down pump.Reciprocate pipe to clear blockage.Start reversing at 75 spm and 250 psi.Begin rotating and washing down.Measure pit volume after 30 minutes.Lost 11.75"of volume.35 bbls lost in 30 minutes while reversing at 3 bpm.Getting sand back at the shaker at 2045hrs.Recovered 3-4 gallons of sand. Continue rotating and reversing.Swivel stalling out when tagging fill.Work pipe up/down.Recovered 2-3 lbs of metal from magnet.Made+/- 12"of hole.Continue to work pipe up/down and reverse at 3 bpm and 300 psi.Made+/-2ft for a total penetration of+/-3ft.EOT at 10,606'.Blew packoff.Pick up.Close hydril.Circulate bottoms up.Negligible amount of sand recovered.2-3 pounds of metal recovered from the magnet.Replaced packoff.Spot 10 bbl pill.Pressure increase to 1000 psi at 2bpm while pumping pill down tubing. Finish spotting pill.Shut down and check surface lines for blockage.Lines clear.Continue to reverse while milling. 06/30/13-Sunday Milling at 10,606'made 6".Pump pressure increase f/300 t/650 psi,stripper rubber leaking.Flush thru surface lines.Reverse out and btm up.Replace rubber in Hall's head.Pump 10 bbls plomer pill and spot on back side.Reverse out pill only got quart cup of metal. Mill on junk f/10,606.5 ft to 10,608'dpm, unable rotate due to high torque,losses at 54 bph,displace well fluid w/clean filtered inlet water,transferring dirty water to Trading Bay. Change out cuttings box.POOH. Lay down drill collars and BHA. 07/01/13-Monday Make up 6"bear claw bit,b/s 6"scrapper&RIH w/82 stds 3-1/2 ph6 w/string BHA=(Bear claw bit,7"casing scrapper 3.5 reg,bit sub 15.78 also the 9-5/8 assembly x/o, x/o,x/o,9-5/8 casing scrapper,bit sub=8.78). M/U 9-5/8 scrapper RIH w/same spotting scrapper at 5,447'ft.Tagged at 10,607'.Rig up and reverse circ clean filtered water,getting scale back on btm up. Continue circ,pumping 200 bbls to Trading Bay.Finished second stage of displacing well to clean water.Pumped 221 bbls fluid to Trading Bay.Displace hole with FIW.Pump 215 bbls to Trading Bay.Displace hole with FIW.226 bbls displaced.Fluid still cloudy/dingy.Pump fluid to Trading Bay.216 bbls pumped to Trading Bay.Displace hole to FIW.Transfer fluid to Trading Bay,pumping 200 bbls to Trading Bay. • Hilcorp Alaska, LLC • Hikorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 t _ 771,3 , ,.¢, - x, -' /02/1 esday ur Finish displacing well w/clean filtered Inlet water pumped total of 1,278 bbls. Pooh w/bit and scrappers and lay down same(note at 10:03 AM, Mr.Guy Schwartz,Senior Petroleum Engineer w/AOGCC granted approval to lower the 9-5/8"x 7"csg test pressure for Grayling G-2RD well sundry#312-454-PTD#182-067 f/2,800psi to 2,000psi). Trip in hole w/7"JS-3 Test packer on 3-1/2 ph-6 w/string setting packer at 9,767'. Pick up wt 115k/slack off wt 73k. Fill Hole. Set packer at 9,767'with 15k down. Close pipe rams. Test lines. Pressure up to 500psi on annulus/pressure bled off. Pressure again to 500psi/again it bled off. Pressure to 750psi. Observed leak at the stand pipe. Bleed off pressure. Isolate stand pipe from manifold. Pressure annulus to 500psi/pressure bled off. Isolate pump and manifold. Test to 2,000psi. Good test.Pressure annulus to 1,000psi. Pressure bled to zero in 5 minutes. Pull 80 stands. Pick up wt 62k/slack off wt 50k. Fill hole. Set packer with 15k down at 5,582'(91'below liner top). Close pipe rams. Pressure annulus to 2,000psi in 500psi stages. 2,000psi test maintained for 30 minutes. Bleed off pressure. Open rams. POOH. POOH. Lay down 7"test packer. Pick up 7"retrievable bridge plaug and RIH. Pass through liner top with retrievable bridge plug. 7/3/2013-Wednesday w/50 bbls FIW. POOH w/running tool. RIH with 7 Finish TIH set the 7"29#RBP at 9,767'. Dump 5 sxs of sand down w/string&spot / / g test packer. Fill hole. Set packer at 7,565'with 15k down. Close pipe rams. Pressure annulus to 2,000psi in 500 psi stages. Held for 6 minutes. Good test. Bleed off pressure. Open rams. Unset packer. RIH 15 stands. Fill Hole. Set packer at 8,508'w/15k down. Close pipe rams.pressure annulus to 500psi.Leaking off/300psi in 5 min. Bleed off. Pressure up down tubing. 1,000psi bled off in 3 min. Pull 1 stand. Fill hole. Set packer at 8,445'w/15k down. Close pipe rams. Pressure annulus to 500psi. Bled off 300psi in 5 min..Bleed off pressure. Open pipe rams. Unset Packer. Pull 4 stands. Fill hole. Set packer at 8,193'w/15k down.Pressure annulus to 500psi. Fluid returns on tubing. Shut down pump. Bleed off. Open pipe rams. Unset packer.Re-position packer a couple of feet. Re-set packer w/15k down. Close pipe rams. Pressure annulus to 500psi.Leaking off. Bleed off pressure. Open rams. Unset packer. Pull 5 stands. Fill hole. Set packer at 7,879'w/15k down. Pressure annulus to 1,000psi. Very slow leak. Isolate pump. Still bleeding off. Bleed off pressure. Install lo-torque valve between pump and manifold. Test manifold to 2,000psi against lo-torque. Good test. Pressure annulus to 2,000psi. Chart recorder will not register above 1,800psi. Bleed off. Pressure again to 2,000psi. Chart recorder still not registering correctly. Bleed off pressure. Remove hoses and fittings from chart recorder. Clean hoses and fittings. Re- assemble. Pressure annulus to 2,000psi. Leaking off. Bleed off pressure. Open pipe rams.Close hydril. Pressure annulus to 2,000psi. Leaked off 100psi in 5 min. Bleed off pressure. Open hydril. Unset packer. Pull 5 stands. Test manifold to 2,000psi. Fill hole. Set packer at 7,565'with 15k down. Close rams.Pressure annulus to 2,000psi. Good test. Bleed off pressure. Open rams. Unset packer. RIH 1 stand. Fill hole. Set packer. Close pipe rams. Pressure annulus to 2,000psi. Pressure bleeding off very slowly-100psi in 9 minutes.Bleed off pressure. Open rams. Unset packer. RIH 20 stands. Pressure up down tubing. Bleed off immediately. RIH to bottom. Pressure test down tubing after each 5 stands run. testing each stop to 1,000psi. Test at 8,886',9,191',9,516'taking 1.5 minutes to bleed off 250psi. 7/4/2013-Thursday SET TRIPOINT 7"PACKER @ 9,516'&ATTEMPT TO PRESSURE UP&TEST CASING F/9,516'T/9,767'WITH NO SUCCESS. TIH TO 9,704' &SET 7"PACKER. ATTEMPT TO TEST CASING F/9,704'T/9,767'WITH NO SUCCESS. HANG OFF BLOCK,SLIP&CUT 75'OF DRILL-LINE. TIH TO 9,744'&TAG SAND FILL SAME. P/U TO 9,742',SET 7"PACKER&ATTEMPT TO TEST CASING WITH NO SUCCESS. P/U TO 9,737' &SET PACKER. ATTEMPT TO SET CASING WITH NO SUCCESS.PRESSURE BLEEDING OFF AT RATE OF 250PSI/MINUTE. UNSET PACKER &PREPARE TO POOH. POOH WITH 3-1/2"12.95#PH-6 TBG T/7,565'. SET 7"PACKER @ 7,565'&TEST CASING USING FIW F/7,565'- SURFACE TO 2,000PSI ON CHART FOR 30 MINUTES.(HELD SAME). RIG DOWNTIME:CHANGE OUT RIG MUD PUMP. POOH F/7,565' T/SURFACE.BREAK DOWN&LAY OUT TRIPOINT 7"PACKER. PACKER ELEMENT IN GOOD CONDITION&PACKER FUNCTIONING PROPERLY. P/U TRIPOINT "J"LATCH CIBP RETRIEVING TOOL(5-1/2"I.D.). TIH WITH 3-1/2"WORK STRING TO 9,727'. P/U POWER SWIVEL&M/U CIRCULATING LINES TO WASH. INSTALL STRIPPER RUBBER&BREAK CIRCULATION. WASH SAND F/9,746'T/9,767'& REVERSE CIRCULATE(2)TUBING VOLUMES. • • Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 Daily Operations: 7/5/2013-Friday RELEASE ON/OFF TOOL&REVERSE CIRCULATE 610 BBLS OF FIW THROUGHOUT HOLE @ 9,765'PUMPING UNFILTERED FLUID CAUGHT IN RIG TANK FROM HOLE OVER TO TRADING BAY FACILITY. REVERSE CIRCULATE 490 BBLS OF FIW THRU HOLE PUMPING OVER RETURNS TO TRADING BAY FACILITY. REVERSE OUT TOTAL OF 1,100 BBLS OF FIW.CLEAN RETURNS COMING OVER SHAKER. ENGAGE RBP @ 9,767',PUT 4 TURNS OF RIGHT HAND TORQUE&PULL 3K OVER STRING WT. RBP RELEASED SAME. WORK RBP TO RELAX SLIPS. REVERSE CIRCULATE ADDITIONAL TUBING CAPACITY TO ENSURE NO GAS INFLUX LEFT IN HOLE. L/D POWER SWIVEL& PREPARE TO POOH. POOH SLOWLY WITH 3-1/2"PH-6 TUBING. TOTAL OF 53 STANDS OUT OF HOLE,DEPTH @ 0600 HRS=6,370'. 7/6/2013-Saturday POOH W/TRIPOINT ON/OFF TOOL&RBP. BREAK DOWN RETRIEVING TOOL&L/D RBP. RETRIEVE WEAR BUSHING&M/U TEST ASSEMBLY WITH TEST PLUG. LAND TEST PLUG&PREPARE TO TEST BOP'S. TEST BOP'S PER ALASKA STATE REGULATIONS&HILCORP PROCEDURES. The witnessing of the test was waived by AOGCC Jim Reggs. TEST BLIND RAMS TO 250psi LOW&3,000psi HIGH, ANULAR WITH 3-1/2"&4-1/2"PIPE TO 250psi LOW&1,500psi HIGH,PIPE RAMS WITH 3-1/2"&4-1/2" PIPE TO 250psi LOW& 3,000psi HIGH.TEST HCR,MANUAL&SUPER CHOKE,IBOP,&TIW TO 250psi LOW&3,000psi HIGH. TIW SER.#QTI156696& QTI22733. IBOP SER.#QTI18139. FUNCTION TEST KOOMEY UNIT FROM MAIN STATION. 2 MINUTES&26 SECONDS FOR FULL CYCLE. HANG OFF TRAVELING BLOCKS,SLIP&CUT 75'OF DRILL-LINE. PULL TEST PLUG&L/D TEST ASSEMBLY. INSTALL WEAR BUSHING. HOLD PREJOB SAFETY MEETING&READ OVER JSA WITH RIG CREW&SCHLUMBERGER TCP PERSONEL. P/U(45)SCHLUMBERGER 4.50"5SPF 4505PJO TCP GUN ASSEMBLIES WITH RA TAG SUB&PUP JT. TIH WITH 71 STANDS OF 3-1/2"PH-6 TUBING.DEPTH @ 0600 HRS=5,321'. 7/7/2013-Sunday TIH WITH SCHLUMBERGER TCP ASSEMBLY&TAG @ 10,607'. P/U 3'OFF BOTTOM&HOLD MEETING ON R/U PRIORITY E-LINE. MOVE EQUIPMENT ON DECK,SPOT E-LINE UNIT. R/U E-LINE SHEAVES IN DERRICK.RIH&LOCATE RA TAG SUB. RUN LOGGING STRIP& CORELATE GUNS ON DEPTH. POOH SAME. SPACE OUT TUBING RA TAG SPOTTED 9,510'TO PERFORATE W/top shot at 9,664'btm shot at 10,587.44. R/D PRIORITY E-LINE. BREAK CIRCULATION DOWN TUBING WHILE CATCHING RETURNS FROM ANNULUS.LINE UP ANNULUS TO SUPER CHOKE.DROP 5/8"BALL&PUMP 24.5 BBLS @ 2BPM. BALL ON SEAT,PRESSURE UP TO 2,600PSI,GUNS FIRED SIMULTANEOUS FROM PRESSURE DROP.WELL ON IMMEDIATE VACUUM. MONITOR WELL FOR 30 MINUTES. FILL ANNULUS WITH 17.78 BBLS OF FIW(FLUID LEVEL @ 705'). WAIT 15 MINUTES&FILL CASING WITH 5.25 BBLS OF FIW. HOLE TAKING 21 BBLS OF FLUID PER HR. POOH SLOWLY WITH SPENT TCP GUNS,FILLING HOLE EVERY 10 STANDS. HOLE STILL TAKING 15 BPH IN EXCESS TO FILL. LAYING DOWN TCP GUNS. L/D SPENT TCP ASSEMBLY. 7/8/2013-Monday L/D REMAINDER OF SPENT SCHLUMBERGER 4-1/2"TCP GUNS. CLEAR OFF RIG FLOOR&LOAD OUT SCHLUMBERGER EQUIPMENT. R/U E-LINE&EQUIPMENT. LAY OUT,STRAP,&CALIPER TOOL ASSEMBLY.MU TOOL ASSEMBLY&TEST ON CATWALK. P/U EXPRO MULTIFINGER IMAGING TOOL WITH(2)PRODUCTION ROLLER CENTRALIZERS,&GAMMA RAY. RIH TO 9,664',SEND COMMAND DOWN HOLE&OPEN IMAGING TOOL. LOG FROM 9,664'TO 9,450'ELM.TOOL HUNG UP @ 9,450'. PULL WIRELINE TO 1,100 LBS OVER STRING WEIGHT&WORK IN DOWNWARD MOTION. SEND COMMANDS&CYCLE TOOL DOWNHOLE FROM OPEN TO CLOSE POSITION,WORK WIRELINE PULLING UP TO 2,100 OVER STRING WEIGHT. CONTINUE TO WORK E-LINE WHILE WAITING ON FISHING TOOLS. 7/9/2013-Tuesday HOLD 3,300 LBS TENSION ON E-LINE. ORDERED&RECEIVED WIRELINE STRIPPING KIT. WAITING ON 9/32"DIE INSERTS FOR T-BAR CLAMP. SLACK OFF E-LINE GIVE 20'OF SLACK LETTING WEIGHT HANG DOWNWARD ON DOWNHOLE TOOLS. AFTER 3 HOURS, GAINED WEIGHT. SLACK OFF DOWN HOLE TO 9,502'.P/U&HAD ALL WEIGHT. POOH WITH E-LINE SLOWLY. L/D CALIPER LOGGING TOOLS. HAD ONE BROKEN CENTRALIZER LEG. R/D E-LINE&PREPARE TO P/U 4-1/2"LINER. R/U ECKEL TONGS&LINER HANDLING TOOLS TO RUN 4-1/2"LINER. INSTALL X-O ON TIW. P/U TRIPOINT LOWER STIMTOP 7" PERMANENT PACKER FOR 26-32#CASING WITH IBT"X"LANDING NIPPLE,&IBT WLEG. CHECK ALL BREAKS&RIH SAME. STRAP,P/U,TIGHTEN,&TIH WITH 4-1/2"12.6#L-80 IBT LINER. • • Hilcorp Alaska, LLC • Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 Dail° ,,erations: 7/10/2013-Wednesday FINISH P/U 4-1/2"12.6#IBT LINER,TOTAL OF 65 JTS=2015.36'AND RIH.M/U TOP 7"26-32#SLIM TOP PERMANENT PACKER WITH 7"X4-1/2"TIEBACK SLEEVE.TIH WITH 109 JTS OF 3-1/2"TUBING,DRIFTING PIPE OUT OF DERRICK.TAG LINER TOP @ 5491'.ATTEMPT TO WORK STIMPACK ASSEMBLY INTO TOP OF LINER @ 5941'WITH NO SUCCESS.POOH LAYING DOWN 98 JOINTS OF 3-1/2"TUBING ONTO PIPE RACK.POOH RACKING BACK 4-1/2"LINER INTO DERRICK,TOTAL OF 34 STANDS RACKED IN DERRICK.REMOVE RE-ENTRY GUIDE FROM LOWER PACKER ASSEMBLY.HAD MARKS ON BOTTOM OF RE-ENTRY GUIDE FROM TAGGING ON LINER TOP.M/U TAPERED RE-ENTRY GUIDE WITH WELD ON CENTRALIZERS(5.90"O.D.).INSPECT LOWER STIMPACK ASSEMBLY&RIH.TIH WITH 68 JTS OF 4-1/2"LINER FROM DERRICK.P/U&RIH W/TOP STIMTOP PACKER ASSEMBLY.TIH WITH 3-1/2"PH-6 TUBING TO TOP OF LINER @ 5491'.WORK LOWER STIMPACK ASSEMBLY INTO TOP OF LINER @5491'. 7/11/2013-Thursday CONTINUE TO RIH W/STRADDLE PKR ASSEMBLY,WITH NO PROBLEMS AT LINER TOP AT 5491'W/TOP PACKER IN ASSEMBLY. CONTINUE IN HOLE TO 9524'TOTAL DEPTH.SPACE OUT W/PUPS,CONTINUE IN HOLE FROM 9524'TO 9561'(HAD TIGHT SPOT AT 9561'WORK THRU SAME)SPOTTING WLEG AT 9595.76,LOWER PACKER AT 9570',UPPER PACKER AT 7545.45 DPM. DROP BALL BAR, MAKE UP POWER SWIVEL. FILL W/30 BBLS FIW. PRESSURE UP ON TBG TO 3000 PSI IN 500 PSI INCREMENTS,SETTING THE UPPER AND LOWER 7"26-32#STIMTOP HYDRAULIC PERMANENT PACKER.HOLDING PRESSURE OF 15 MINUTES ON A CHART,PRESSURE BLEED OFF 20 PSI AND HOLDING GOOD TEST BLEED OFF PRESSURE. CLOSE PIPE RAMS AND TEST THE 7"26-32#STIMTOP HYDRAULIC PACKER AT 7545',7"LINER&LINER TOP&9-5/8 CSG TO 2000 PSI ON A CHART FOR 30 MINUTES(GOOD TEST). BLEED OFF PRESSURE, OPEN RAMS RELEASE F/PACKER ASSEMBLY W/15 ROUNDS OF RIGHT HAND TORQUE. RIG DOWN POWER SWIVEL.POOH LAYING DOWN THE 3-1/2 PH-6 WORK STRING. L/D TOTAL OF 241 JTS OF 3-1/2"TUBING WITH PACKER RUNNING TOOL. RIG UP SLICKLINE W/ PACKOFF LUBRICATOR. REHEAD LINE&P/U 2"JD OVERSHOT W/OIL JARS,SPANG JARS,1.75"BOW SPRING CENTRALIZER WITH 10' OF 1.75"STEM. RIH WITH SLICKLINE&2"JD OVERSHOT TO RETRIEVE DROP BAR. 7/12/2013-Friday RIH W/2"JD OVERSHOT ASSEMBLY ON SLICKLINE.LATCH ONTO DROP BAR @ 9583'.POOH&L/D OVERSHOT W/BAR.RIH&LOCATE PLUG @ 10596'.LATCH ONTO PLUG&POOH SAME.L/D PLUG&SLICKLINE ASSEMBLY.R/D SLICKLINE.ATTEMPT TO P/U 3-1/2"RTS-8 PRODUCTION TUBING USING RIG'S MCCOY TONGS.TONGS DAMAGING PIPE.R/D MCCOY TONGS&R/U FOSTER TONGS.UNABLE T/SET PROPER TORQUE WITH FOSTER TONGS.CALL OUT WEATHERFORD&PREPARE TO TEST BOP'S.PULL WEAR BUSHING.R/U 3- 1/2"TEST JOINTS WITH TEST PLUG,TEST PIPE,BLIND,CHOKE MANIFOLD,HCR,TIW,&IBOP TO 250 LOW&3000 HIGH.HAD(1) FAIL/PASS ON CHOKE MANIFOLD VALVES K1,5,&6.TEST HYDRIL TO 250 LOW&1500 HIGH.TEST SUPER CHOKE&MANUAL CHOKE T/250 LOW 1200 HIGH. RECORD ACCUMULATOR DRAW DOWN 21 SECONDS=200 PSI,123 SECONDS=3150 PSI.R/D TEST JOINTS& TEST PLUG.INSTALL WEAR BUSHING.SPOT&R/U WEATHERFORD ECKLE TONGS&POWER PACK.P/U&TIH WITH 3-1/2"RTS-8 PRODUCTION TUBING TORQUEING CONNECTION WITH WEATHERFORD TUBING TONGS. 7/13/2013-Saturday CONTINUE P/U 3-1/2"RTS-8 PRODUCTION TUBING&TIH.P/U TOTAL OF 228 JOINTS OF TUBING.POOH WITH 114 STANDS OF 3-1/2" PRODUCTION TUBING RACKING PIPE IN DERRICK.P/U TEST JOINT WITH WEAR BUSHING RETRIEVING TOOL.RETRIEVE WEAR BUSHING SAME&L/D TEST JOINT.SPOT TWO CONTROL LINE REELS. R/U SHEAVES IN DERRICK&PREPARE TO P/U ESP EQUIPMENT. P/U&RIH W/(2)MAXIMUS 540 HP MOTORS,GAS SEPERATOR,(6)400 D5800N 63 STAGE PUMPS&TIE IN ELECTRIC&CONTROL HEAD INTO PUMPS SAME.SURFACE TEST PUMPS,(TEST GOOD).TIH WITH 3-1/2"RTS-8 PRODUCTION TUBING,TORQUEING CONNECTIONS USING WEATHERFORD.BANDING CONTROL LINE CABLE TO PRODUCTION TUBING WITH SCHLUMBERGER&TESTING DOWNHOLE MOTOR EVERY 20 STANDS. • • Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-02RD 50-733-20038-01 182-067 5/10/2013 7/15/2013 DaI gerations: 7/14/2013-Sunday MAKE SPLICE ON ARMORED ELECTRIC LINE&CONTROL LINE @ 5043.19'.TIH WITH 3-1/2"9.3#RTS-8 L-80 PRODUCTION TUBING OUT OF DERRICK,BANDING CONTROL&ELECTRIC LINE TO TUBING WITH SCHLUMBERGER.TIH WITH TOTAL OF 231 JOINTS OF TUBING. TOTAL OF 119 COLLAR CLAMPS INSTALLED WITH(2)3/4"BANDS UNDER TUBING HANGER.INSTALL TUBING HANGER&MAKE FINAL TIE IN TO TUBING HANGER WITH ARMORED EMBILICAL CORD&CONTROL LINE.R/D SCHLUMBERGER SHEAVES OUT OF DERRICK. TEST TUBING HANGER VOID ON BOTH SIDES TO 5000 PSI&HOLD SAME FOR 15 MINUTES.TUBING P/U WEIGHT=93K,S/O WEIGHT= 64K.LAND OUT TUBING HANGER,HANGING OFF END OF TUBING PUMP @ 7495.25'.CHANGE OUT PACKING ON GLAND NUTS WITH CAMERON WELL HEAD TECH,BACK OUT&L/D LANDING JOINT.RUN IN HOLD DOWN PINS.R/D WIND WALLS,HAND RAILS,&RIG FLOOR.PREPARE TO N/D BOP'S.N/D DRIP PAN,HYDRIL,PIPE&BLIND RAMS,&11"5M RISER W/MUD CROSS.LAYOUT ON PIPE RACK WITH CRANE.REMOVE STUDS FROM 11"5M TUBING HEAD, DRESS TUBING HEAD WITH CAMERON WELL HEAD TECH,INSTALL 11" 5M X 4-1/16"5M ADAPTOR HEAD WITH ESP CABLE PORT. 7/15/2013-Monday INSTALL&TORQUE 11"5M X 4-1/16"5M ADAPTOR FLANGE WITH ESP IMBILICAL PORT.INSTALL 4-1/16"PRODUCTION TREE WITH SSV.ALIGN WING LINE TO FLOW LINE.TORQUE DOWN CONNECTIONS.TEST PRODUCTION TREE&ADAPTOR FLANGE TO 250 LOW& 5000 HIGH.HAD SLIGHT LEAK BELOW TIW X-O SUB.BLEED DOWN&RETEST.(TEST GOOD)ASSIST PRODUCTION ON FABRICATING, WELDING,&HOOKING UP 2-1/16"FLOW LINE.RUN&HOOK UP CHEMICAL INJECTION LINES.SCHUMBERGER ENGINEER& PLATFORM ELECTRICIAN HOOKING UP ELECTRICAL CORD TO MAIN PANEL ON PLATFORM.BREAK DOWN PUMP LINES&PREP RIG FOR SKID.ASSIST PRODUCTION IN MAKING FINAL INSPECTIONS FOR STARTUP ON G-2 WELL. Schwartz, Guy L(DOA) From: Schwartz, Guy L (DOA Sent: Friday, July 05, 2013 1:09 PM To: 'Ted Kramer'; Ferguson, Victoria L (DOA) Subject: RE: Grayling G-2RD Well Update - Sundry #312-4S4PTD#183-D67 Ted, As per our conversation you have verbal approval to run straddle patch and modify approved sundry 312-454 as shown below. Please chart the pressure test (after packers set) of the straddle assemble fnrlSnnin. Also , test annulus to200U psi as per your procedure. Guy Schwartz Senior Petro|eunnEngineer SCANNED JUL, 1 0 °pm=���r�°~° ~~^ 1 , _ AOGCC 907-444-3433 cell 907-793-1226 office From: Ted Kramer [mmj|bD:tk.tamD[ hkorp.c0[D] Sent: Friday, July 05, 2013 11:40 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Subject: Grayling G-2RD Well Update - Sundry # 312-454 PTD # 102-067 Guy and Victoria, We currently have a workover rig on the above well performing a re-completion. Overnight we ran in the well with a testing packer and pressure tested the casing inside of the 7" liner. Long story short, we were able to get a good pressure test from 7,565' up to surface. We could not get the casing to test below this depth and believe we have bad casing from this depth down. Hilcorp would like to propose the running of a straddle packer assembly (See Packer Schematic attached) from 9,750' (+/-) up to 7,560' (+/-). This straddle assembly will cover the bad section of casing and will provide a flow path to produce the well through. The ESP would then be set above the straddle assembly. The procedure to complete the well would be as follows: 1. PU RIH with TCP perforating guns on3'2/2" Work string. 2. RUE-|ine with GHtool. Locate RA Iocated sub and tie in TCP guns with Gamma Ray Iog and set guns on depth. POOH with E-Iine. 3. Pressure up on work string and fire guns. 4. monitor F|u|dlevel for 1hour shooting ciuid |evc|swit; =o/n7-te/ with TCPguns. k 5. PU R|H vxiihTripoin1Straddle Packer Assembly sot a�c�r�i��toTri�oin� �roce�ure3 (Nn��` �nt!omr pac �� 6���|ickUne R/H»v:1h nipp|e onwzrksrin@to]j0[0 for 3Onminu��n ;f— -Le . F • • 9. Rotate off of top packer with Work string, POOH laying down Work string. 10. PU Production tubing standing back in derrick. 11_ RU Schlumberger ESP running equipment. PU ESP building in hole. 12. Attach electrical cable. RIH with ESP on 3 -1/2" production tubing. Set bottom of ESP at 7,510' + / -. 13. Hang off tubing. 14. ND BOP, NU wellhead and test. 15. Turn well over to production. Please let me know if this is acceptable to the Commission. Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907- 777 -8420 C 985 - 867 -0665 2 y • • Trading Bay Unit SCHEMATIC Well No: G 2RD I ileor,1 16 HA: Completed: 7/21/82 API # 50- 733 - 20038 -01 CASING DETAIL RKB to Tb :. Hanger - 38.30" 1 Size Wt Grade Top Btm Length 2 13 -3/8" 61 J -55 Surf 1,300' (Top of Window) 3 9 - 5/8" 47 N -80 Surf 6,000' 6,000' 7 "Liner 29 N -80 5,491' 10,767' 5,276' TUBING DETAIL 3 - 1/2" 9.2 N - 80 I Surf 10,118' IIIMMo 4 JEWELRY DETAIL NO. Depth Item 1 38.30' 4 - 1/2" EUE TBG Hanger 2 39.30' 4 - 1/2" 8rd X 3 -1/2" Buttress X -over I ► 3 293.63' 3 - 1/2" Otis 'XEL' Ball Valve i 1 : 4 2,203.40' 3 -1/2" Camco Gas Lift Mandrel I I 1 l 5 3,889.68 3 -1/2" Camco Gas Lift Mandrel 1 i I 1 6 5,434.84' 3-1/2" Camco Gas Lift Mandrel 7 6,661.25' 3 - 1/2" Camco Gas Lift Mandrel _I 1 I (: ' 1 i 8 7,470.07' 3-1/2" Camco Gas Lift Mandrel i I i { 9 I 8,028.69' i 3 -1/2" Camco Gas Lift Mandrel 10 ! 8,463.94' 3 Camco Gas Litt Mandrel ! 11 I j 8,803.58' ' 3 -1/2" Camco Gas Lift Mandrel ;` 12 I 9,175.96' 3 -1/2" Carnco Gas Lift Mandrel { 13 9,576.69' 3 -1/2" Camco Gas Lift Mandrel 1 14 9,983.50' 3 -1/2" Cameo Gas Lift Mandrel -( I 1 15 10,020.89' I 3-1/2" Otis 'XA' Sliding Sleeve (2.75" ID) 1 ; S L! v 16 10,059.95' Baker Locator 1 - f � I � ! I 13 I 10,060.46' I Baker Model F -i Prod. Packer w/ 80-40 seal ! t. j assembly to 10,080.32' _..a t ' Gopa 1� 18 10,085.50' I Otis 'X' :fipple (2.75" ID) 19 i 10,117.82' I Bottom of 3 -112" Mule Shoe _ I �� 1 1/9/89 -23' of perf guns lost in well. Sitting on fill tagged on 1/8/89 @ 10,630' WLM. S L R nti 2/18/08 - Last tag @ 10,238' w/ 2.74" Gauge Ring. 1 in 11 I I •, 1 2 ?A r*ICs PERFORATION DETAIL 4 ! G,as I L 1 Zone 1 Top(MD) I Btm(MD) Top(TVD) I Btm(TVD) 1 SPF I Ft 1 Date I Comments 13 i 1310' I 7 312' 10 , f 1 zj i 4 r 2 5/25/1982 i Squeezed I 1,330' 1,332' 1,330` 1 1,332' I 4 , 2 ! 5/26/1982 I Squeezed ! I 1,350' 1,352' 1,350' 1 1,352' 1 4 ! 2 i Sn1' 982 1 Sque I + 4 I ! 1,365' - 1,367' I 1,365' I 1,367' I 4 ' ' 5 "5'1982 I Squeezed e nA 1_ 1 1,380' 1,382' 1,380' ' 1,382' 4 I z Sitz, w 2 j Squeezed j i f 1,39 1392' 1,390' 1 1,392' 4 I 2 5/21/1982 1982 I Squeezed ! 16 I 2,020' 2,022' 2.007' 2,009' 4 2 5/31/1982 Squeezed 1. 7 / COa + 2,100' 2,106' ! 2,082' 2,088' 4 6 6/1/1982 I Squeezed MI 18 I I 2,129' 2,131' 2,109' 4 2,111' I 4 12 I 5/31/1982 I Squeezed { i 1 10,164" 1(11`94 +3,201' l `9 22' _ - I 4 s2/ 3/12/1`9`93 i open _ - - 19 : : - . I I j 2/ a , 9, I _2' { I ; -, i i ..M a i i 10.180' i 10.203 9,215' I 9,235' f 2 0 ( 23 I 1 I Open /Re nerf F1 B 1 { 10,230' { 10,26C' { 9,258 9 83` 12 1 j 10/7{ 986 - Open /Re p, 1 12 J I__ , : ,:e 7F.7' :: _ 64 I S % s a R5 1 9 : - 4 -_ 7t 141 :- - _ . _ :at+iatl _.. i.� s { 4 _ .iv 3 ( - i 2 3 I iv t r A - 10,37S' .,.L.} �1' 1 t Open/Re per: I iv . ,.•J y t 4 - Rft a i - I 48 - 8 4 i 10,176' 1r14 i 9 i 408' I 4 1 37 t 17/7 t.9 -. i flru.n i F II B ` - _ 1 10,407' t 10,452' i 9,006 3 ' 1 446' 12 I 45 i 12(21/ 1990 , Opeu) Re per i i I 7 1 =_ 147' ' (} :f I 9/435: ,9,a 5e1 4 _ R }R 19]1 f 14(1 I knn - Revised By: TDF 9 -27 -2012 v • Company: Date: Casing Size: Casing Wgt: Casing Grade: Casing Thread. Depth: i Hilcorp Alaska, LLC 4- Jul -13 9 -5/8" 47# N -80 0' - 6,000' Lease/Field. Wet # Liner See. Liner Wgt: Liner Grade. Liner Thread: Top Of Leer' Trading Bay Unit G -2RD 7" 29# N -80 5,941' - 10,767' Offshore Block: Liner Size. Liner Wgt: Liner Grade' Liner Thread. Depth of Liner County / Parish State: Deviation. Tubing Size: Tubing Wgt: Tubing Grade Tubing Thread: PBTD: Kenai Peninsula Borough Alaska _ 0° Corrpletion Interval BHP' BHT: Fluid: Salesman: Pat Mulcahy Item Description O.D. I. D. Length Depth 1 7" x4 -1/2" Stimtop Tie -Back Sleeve 5.913 5.000 4.00 7,452.00 2 7" 26 -32# Stimtop Permanent Packer w/ 4 -1/2" LTC 5.875 4.000 5.00 7,456.00 3 X/0 4 -1/2" LTC Boxx4 -1/2" BTC Pin 5.000 4.000 1.00 7,461.00 4 4 -1/2" 12.60# L -80 IBT Casing 5.200 3.958 2300.00 7,462.00 1 5 X/0 4-1/2" IBT Boxx4 -1/2" LTC Pin 5.200 3.958 1.00 9,762.00 6 7" 26 -32# Stimtop Permanent Packer w/ 4 -1/2" LTC 5.875 4.000 5.00 9,763.00 7 X/0 4-1/2" LTC Box x 4 -1/2" BTC Pin 5.000 4.000 1.00 9,768.00 8 4 -1/2" 12.60# L -80 IBT Casing Joint 5.200 3.958 40.00 9,769.00 9 4 5'+• 9 4 -1/2" 12.60# IBT "X" Landing Nipple 5.200 1.00 9,809.00 10 4 -1/2" 12.60# L -80 IBT Casing Joint 5.200 3.958 40.00 9,810.00 2 11 4 -1/2" IBT WLEG 5.200 3.958 0.50 9,850.00 y F - - 3 1E1 I 1 5 111111 - - 411.3 r 6 - ii 7 1.__1 I 9 .imiii.. zi - Wie 1 i 1 1 _110 Service Contact: ` 11 —F Broussard, LA. (337) 492 -3464 I Victoria, 7X (36 1) 580-2207 Buckhannon, WV (304) 472 -5027 I--. 1 I Printed on 7/4/2013 L 2 :34 PM o Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, July 05, 2013 1:09 PM To: Ted Kramer'; Ferguson, Victoria L (DOA) Subject: RE: Grayling G-2RD Well Update - Sundry # 312-454 PTD # 182-067 Ted, As per our conversation you have verbal approval to run straddle patch and modify approved sundry 312-454 as shown below. Please chart the pressure test (after packers set) of the straddle assemble fnr15min. Also , test annulus toZOUO psi as per your procedure. Guy Schwartz Senior Petroleum Engineer SCANNED JUL. 1 ��O°3 °��n�v�ow�� .~ 1 , _ AD6[C 907-444-3433 cell 907-793-1226 office From: Ted Kranmer [Maiito:1Kramerc.hkOrp.cOC9] Sent: Friday, July 05, 2013 11:40 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Subject: Grayling G-2RD Well Update - Sundry # 312-454 PTD # 102-067 Guy and Victoria, We currently have a workover rig on the above well performing a re-completion. Overnight we ran in the well with a testing packer and pressure tested the casing inside of the 7" liner. Long story short, we were able to get a good pressure test from 7,565' up to surface. We could not get the casing to test below this depth and believe we have bad casing from this depth down. Hilcorp would like to propose the running of a straddle packer assembly (See Packer Schematic attached) from 9,750' (+/-) up1m7,5G0'(+/). This straddle assembly will cover the bad section of casing and will provide a flow path to produce the well through. The ESP would then be set above the straddle assembly. The procedure to complete the well would be as fotiows: 1. PU RIH with TCP perforating guns on3-1/2" Work string. 2. RUE'||ne with G0tool. Locate RA iocated sub and tie in TCP guns with Gamma Ray Iog and set guns on depth. POOH with E'|ine. 3. Pressure up on work string and fire guns. 4. xVionitorF|uid|eve|forlhour yhootingf|uid|eve|sxuit�echuhne�ei - Hu|d |ss�ab|e with T[P guns . 5. PUR|H with Thpuin1 Straddle PackerAs 0toTri�oic��rnc�6ure](�ote�b�!��noVa��r 37S" in X nipp|e Presauno upon vorksthn5i to3OOO psi ;or 3Qminutes _ ��i�ac�e�� ^' - _ • • 9. Rotate off of top packer with Work string, POOH laying down Work string. 10. PU Production tubing standing back in derrick. 11. RU Schlumberger ESP running equipment. PU ESP building in hole. 12. Attach electrical cable. RIH with ESP on 3 -1/2" production tubing. Set bottom of ESP at 7,510' + / -. 13. Hang off tubing. 14. ND BOP, NU wellhead and test. 15. Turn well over to production. Please let me know if this is acceptable to the Commission. Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907- 777 -8420 C 985- 867 -0665 2 4 Trading Bay Unit SCHEMATIC Well No: G -2RD liii. urp Alaska, LI "c Completed: 7/21/82 API # 50- 733 - 20038 -01 CASING DETAIL RKB to Tbg. Hanger - 38.30" 1 ••• Size Wt Grade Top Btm Length 2 13 -3/8" 61 J -55 Surf 1,300' (Top of Window) 3 9 -5/8" 47 N -80 Surf 6,000' 6,000' 7 "Liner 29 N -80 5,491' 10,767' 5,276' TUBING DETAIL 3 -1/2" 9.2 N -80 Surf 10,118' D 4 JEWELRY DETAIL L , NO. Depth Item 1 38.30' 4 -1/2" EUE TBG Hanger 2 39.30' 4 -1/2" 8rd X 3 -1/2" Buttress X -over '� 5 3 293.63' 3 -1/2" Otis 'XEL' Ball Valve - 4 2,203.40' 3 -1/2" Camco Gas Lift Mandrel 5 3,889.68 3 -1/2" Camco Gas Lift Mandrel 6 5,434.84' 3 -1/2" Camco Gas Lift Mandrel 7 6,661.25' 3 -1/2" Camco Gas Lift Mandrel 8 7,470.07' 3 -1/2" Camco Gas Lift Mandrel { 9 8,028.69' 3 -1/2" Camco Gas Lift Mandrel l i 10 8,463.94' 3 -1/2" Camco Gas Lift Mandrel i 1 t t 11 8,803.58' 3-1/2" Cameo Gas Lift Mandrel I� 12 9,175.96' 3 °1/2" Camco Gas Lift Mandrel i 13 9,576.69' 3 -1/2" Camco Gas Lift Mandrel E I 14 9,98350' 3 -1/2" Cameo Gas Lift Mandrel l s ! 15 i 10,020.89' i 3-1/2" Otis 'XA' Sliding Sleeve (2.75" ID) I � UQ I 16 10,059.95' I Baker Locator 17 10,060.46' I { I tt Baker Model F-1 Prod. Packer wJ 80-40 seal l y, assembly to 10,080.32 G� 18 l 10,085.50' Otis 'X' Nipple (2.75" ID) 1 19 ; 10,117.82' Bottom of 3 1/2" Mule Shoe P. L 111 I , 13 1/9/89 - 23' of pert guns lost in well. Sitting on fill tagged on 1/8/89 @ 10,630' WLM. �'' � 56. nti 2/18/08 - Last tag @ 10,238' w/ 2.74" Gauge Ring. 4 0. i 12 qA S ► 'i as PERFORATION DETAIL L I Zone I Top(MD) I Btm(MD) i Top(TVD) I Btm(TVD) I SPF I Ft I Date � Comments I 1,310. 1,312' 1 1' 1,312' 4 2 5/25/1a82 Squeezed ! r- j 1,330' 1,332' 1,330' I 1,332' i 4 12 i 5/26/1982 Squeezed t E 1z 1__ 1 1,352' I 1,350' I 1,352' } 4 ' 2 I 5/31/1982 Squeezed S I 1,365' 1,367' ! 1,365' I 1,367' I 4 2 1 5/25/1982 Squeezed I i ; t` 1 _ 1 ,380' i 382' y i 380' I 1,382 I 4 . 2` 5/22/1982 I Squeezed € 7t aTi � 1 1,390' 1,392' 1,390' 1,392' , 4 I 2 5/31/1982 Squeezed I 1 11 1 1 , 16 i 2,020' 2,022' i 2,007` 2,009' i 4 12 5/31/1982 Squeezed NM 17 /o /moo 2,100' 2,106' 2,082' 2,088' 4 ( 6 6/1/1982 t Squeezed I 11113111 18 I 2,129' I 2,131' I 2,109' I 2,111' I 4 12 I 5/31/1982 Squeezed f 10,164 I 10,194 ! 9,201 I 9,12 I 4 1 3u t 3/12/1993 Open 1 ! 19 r f a 1 1/ 9,210! I l 5/1092 q ( 1 I - 1 180' I 10.203' t 9,215' 9,235' 20 23 i 12/21/1990 F Open /Re pert i { HB - I 1 . _ ... 10 230` j 10 260' j 9,258' 9 83 ) 12 3C 1 _ i Gp a /Rep t �e r " ---- - { •'� ` I i 2 102E4! i 9285' 1 9 S 4 ' 2 , 7/14/1982 t - _ .eezed , I .1 3 4 _ ? 1 1 ! ' t 5' i x 354' I t 2 7 - y 1! ie _ � - - .. 4 e Squeezed . '' 3., ,3 _ lU..W3 -3 t HR - R, 4 10 175' ! 1 i f' 407 9,181' 1 e 4.!R' 4 1 3 7 I 1 /7 /1990 °n s en f _ { -'Y I IU / -.W 1V,4J 7,4(A j 9,446' 12 I 45 I 1/(LY%197V uptIl /nC pet, ■ 1 i 7 - `ria 3.0457` e 470 ' g 41F' q.:.,:' 4 i 18 1 12i21/199p :.inn Revised By: TDF 9 -27 -2012 ' Tri i tit LLC • Company. Date: Casing Si ze Casing Wgt Casing Grade: Casing Thread: Depth Hilcorp Alaska, LLC 4- Jul -13 9 -5/8" 47# N -80 0' - 6,000' Lease /Field: Well # Liner Sr ze Liner Wgt: Liner Grade: Liner Thread: Top Of Liner: Trading Bay Unit G -2RD 7" 29# N -80 5,941' - 10,767' Offshore Block Liner Si ze: Liner Wgt: Liner Grade: Liner Thread: Depth of Liner County / Parish State: Deviation: Tubing Size: Tutang Wgt: Tubing Grade: Toting Thread: PBTD Kenai Peninsula Borough Alaska 0 Corrptehon Interval BHP: BHT Fluid: Salesnon. Pat Mulcahy Item Description O.D. I. D. Length Depth 1 7" x 4 -1/2" Stimtop Tie -Back Sleeve 5.913 5.000 4.00 7,452.00 2 7" 26 -32# Stimtop Permanent Packer w/ 4 -1/2" LTC 5,875 4.000 5.00 7,456.00 3 X/0 4 -1/2" LTC Box x 4 -1/2" BTC Pin 5.000 4.000 1.00 7,461.00 4 4 -1/2" 12.60# L -80 IBT Casing 5.200 3.958 2300.00 7,462.00 1 5 X/O 4-1/2" IBT Box x 4 -1/2" LTC Pin 5.200 3.958 1.00 9,762.00 6 7" 26 -32# Stimtop Permanent Packer w/ 4 -1/2" LTC 5.875 4.000 5.00 9,763.00 —....., 7 X/O 4-1/2" LTC Box x 4 -1/2" BTC Pin 5.000 4.000 1.00 9,768.00 8 4 -1/2" 12.60# L -80 IBT Casing Joint 5.200 3.958 40.00 9,769.00 J 1 B 5 , 9 4 -1/2" 12.60# IBT "X" Landing Nipple 5.200 1.00 9,809.00 is 10 4 -1/2" 12.60# L -80 IBT Casing Joint 5.200 3.958 40.00 9,810.00 2 E. 11 4 -1/2" IBT WLEG 5.200 3.958 0.50 9,850.00 ', II IF 3 1 ■I I 4 5 1 1 f 1. i 4713 . I ' - 6 _ 1 8 I I ' _ 10 Service Contact: 11 I j Broussard, LA. (337) 492 -5464 Victoria, TX (361) 680 -2207 Buckhannon, WV (304) 472 -5027 ^ 1 1 Printed on 7/4/201 3 % 2.34 PM Page _1 of 1 or 77 s , THE STATE Alaska Oil and Gas vilt, °f l L l Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 �F e, g ALAS�� Main: 907.279.1433 SCANNED JAN 2 3 2013 Fax: 907.276.7542 Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock & Middle Kenai G Oil Pool, TBU G -02RD Sundry Number: 312 -454 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4 :30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this / day of December, 2012. Encl. , III • 41/4„,/ ,„,-tk RECEIVED STATE OF ALASKA %~ NOV �01 �� ALASKA OIL AND GAS CONSERVATION COMMISSION /771 )2//211c., APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate El Pun Tubing El - Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Aker Casing ❑ Other. Run ESP G 2. Operator Name: 4. Current Wen Class: 5. Permit to Drift Number: Hilcorp Alaska, LLC Exploratory ❑ Development p • - 182 -067 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service El 6. API Number. Anchorage, AK 99503 50- 733 - 20038 -01 • 7. If perforating: 8. We Name and Number: What Regulation or Conservation Order govems well spacing in this pool? 20 AAC 25.055 (a) Will planned perforations require a spacing exception? Yes 0 • No ❑ Trading Bay Unit G -02RD 9. Property Designation (Lease Number): 10. Field /Pool(s): / ADL0017594 0 ' McArthur River Field / Hemlock Oil Pool & Middle Kenai G Pool ✓ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,800 J 9,741 • - 10,745 • 9,694 N/A 10,630 Casing Length Size MD TVD Burst Collapse Structural 1,300' 13 -3/8" 1,300 1,300' 3,090 psi 1,540 psi Conductor Surface Intermediate Production 6,000' 9 -5/8" 6,000' 5,583' 6,870 psi 4,760 psi Liner 5,276' 7" 10,767' 9,713' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic • See Schematic • 3 -1/2" N -80 9.2# 10,118 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker F -1 Packer and Otis 'XEL' Ball Valve Packer 10,080' (MD) 9,129' (TVD) and Otis 'XEL' Ball Valve 294' (MD) 294'(TVD) 12. Attachments: Description Summary of Proposal O • 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 • Exploratory ❑ Stratigraphic ❑ Development 12 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 1/5/2013 • • Commencing Operations: Oil 0 • . Gas ❑ WDSPL ❑ Suspended El 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer@.hilcorD.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature ,ice Phone 907 - 777 -8420 Date 11/30/2012 !/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number; -(.,/ L Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ ( ^✓(�/ Other: 3 ) e3- Pp - r; - :,1--- 1 Spacing Exception Required? Yes No ❑ Subsequent Form Required: C a — LiQy ®mS tia 0 APPROVED BY 21/2_ ) Approved by: , COMMISSIONER THE COMMISSION Date: l c I Z..� 7‘ /1. -ta ' ' r ��/0�2 � r QOOL.1SN4) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate !\�" • • Well Work Prognosis Well: G -02RD Hilcorp Alaska, LLC Application Date: 11/30/2012 Well Name: G -02RD API Number: 50- 733 - 20038 -01 Current Status: Oil Producer Leg: Leg #4 (SW corner) Estimated Start Date: January 5, 2013 • Rig: Williams Rig 404 Reg. Approval Req'd: 10 -403 Date 10-403 submitted: 11 -30 -12 Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 182 -067 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) AFE Number: 1221774 Budgeted Cost: Pressures: Bottom Hole Pressure (BHP); Maximum Potential Surface Pressure (MPSP) Current BHP: — 2,894 psi @ 9,344' TVD* .31 psi /ft. = 5.95 ppg Max. Expected BHP: — 2,861 psi @ 9,269' TVD* MPSP: 2,805 psi ** Using 0.1 psi /ft. of True Vertical Depth *based on 2009 shut -in pressure survey correlated to the D -31 RD. *"Based on deepest known gas correlated from Resistivity logs and G -11 offset. Status: Active producer. Making 2,600 bfpd, 90 bopd. Taking "'2 MMscfpd lift gas. Objective: Pull GL completion, Clean out to PBD, Re -perf HB and perf G -zone, Run ESP Rig Scope: 1. NU BOP. Test same using Attachment #1. ( Note: Notify AOGCC 48 hours in advance of BOP Test for possible witness). 2. RU SL, perform scale check, dummy run as necessary to cut tubing above packer 3. RIH w/ tubing cutter, cut tubing above seal assembly. Circulate FIW around. 4. Pull hanger, SSSV, and tubing string from cut. LD same. Send to shore. 5. Overshot and grab seal assembly stub looking up. POOH. LD seal assembly 6. PU burning shoe, mill, retrieve packer. 7. Make 8 -1/2" bit /scraper run to PBD and CBU with clean FIW. / 8. Run test packer to just above top perf, test backside to 2,800 psi. POOH 9. Re- perforate HB and perforate G- zone 10. Run ESP, 3 -1/2" tubing, ESP sized for 7,500 bfpd. 11. ND BOP. NU well head and test. • ' Well Work Prognosis Well: G -02RD Hilcorp Alaska, LLC Application Date: 11/30/2012 As -built (Old) Wellbore Schematic API# 50-733- 20038 -01 CASING DETAIL RKBtoTb•_. Han•_er 38.30' - 1 Size Wt Grade Top Btm Length 1 13 -3/8" 51 7-55 Surf 1,300' (Top of Window( 3 9-sir 47 N-80 Surf 6,000' 6,000' 7'Liner 29 N-80 5,491' 10,767' 5,276' TUBING DETAIL 3 I 9.2 I N I Surf I 10,118' 4 JEWELRY DETAIL NO. Depth Item 1 38.30' 4-1/2" EUE T8G Hanger 2 39.30' 4-1/2" 8rd X3 -1/2" Buttress X-over 5 3 293.63' 3-1/2" Otis 'XEL' Ball Valve I 4 2,203.40' 3-1/2" Camco Gas Lift Mandrel 5 3,889.68 3-1)2" Camco Gas Lift Mandrel 6 5,434.84' 3-1/2" Camco Gas Lift Mandrel Camco 6,661.25' 3-1/2" Cam Gas Lift Mandrel b 8 7,470.07' 3-1/2" Camco Gas Lift Mandrel 9 8,028.69' 3-1/2" Camco Gas Lift Mandrel 10 8,463.94' 3.1/2" Comm Gas Lift Mandrel 11. 8,803.58' 3-1/2" Can= Gas Lift Mandrel ma ,.•> 7 12 9,175.96' 3-1/2" Carom Gas Lift Mandrel I 13 9,576.69' 3-1/2" Camp Gas Lift Mandrel 14 9,983.50' 1 Camco Gas Lift Mandrel 8 15 10,020.89' 3-112" Otis 'XA' Sliding Sleeve (2.75" ID) - . ..-. 16 10,059.95' Baker Locator 17 10,060.46' Baker Model F -1 Prod. Packer w/ 80-40 seal , assembly to f0,080.32' • 5 10,085.50' Otis '7C Nipple (2.75" ID) 1 19 10,117.82' Bottom of 3-1/2" Mule Shoe 11 _.'? 23' of perf guns lost in well. Sitting on fill tagged on 1/8/89 @ 10,630' WLM. M I :::9133 - Last tag @ 10,238' w/ 2.74" Gauge Ring. MN - 12 PERFORATION DETAIL II _ _ _ Btm(MD) Top(TVDI Btm(TVD) SPF Ft Date Comments 13 1,310' 1,312' 1,310' 1,312' 4 2 5/25/1982 Squeezed y 1,330' 1,332' 1,330' 1,332' 4 2 5128/1982 Squeezed 14 7...11 1,350' 1,352' 1.350' 1,352' 4 2 5/31/1932 Squeeze= 41 .' 9 " , Y 1,365' 1.67' 1,365' 1,367' 4 2 5/25/1982 Squeezed 1$ 1,380' 1,382' 1,380' 1,382' 4 2 5/22/1982 'Squeezed 1.390' 1,392' 1,390' 1,392' 4 2 5/31/1982 Squeezed 16 21' 20' 2,022' 2,007' 2,009' 4 2 5/31/1982 Sq eezed ®.7. _ _ 17 2.100' 2,106' 2.082' 2,088' 4 5 6/1/1982 Squeezed II® 18 2,129' 2,131' 2,109' 2,111' 4 2 5/31/1992 Squeezed 10,154' 10,194' 9201' 9,227' 4 30 3/12/1993 Open . 19 H 8-1 10,174' 10,175' 9210' 9212' 4 2 7115 /1982 Squeezed 10,180' 10203' 9,215' 9235' 20 23 12/21/1990 Open /Re - pert HB -( 10,230' 10,260' 9,258' 9253' 12 30 10/7/1906 Open /'Re - perf H8 10262' 10,264' 9,285' 9,287' 4 2 7/14/1952 Squeezed HB -_ 10,343' 10,345' 9.354' 9,355' 4 2 7/13/1982 Squeezed H15 HB 10945' 10,375' 9255 9,381' 18 30 12/21/1990 Open /R.e - perf - 1.3 8._ - 3.375' 10.447' 9,351' 9,408' 4 32 12/21/1990 Open HB -4 1:467' 10,452' 9 ,408 9,446' 12 45 12/21/1990 Open /Re -pert H6-4 =3452' _ 10 ,470' 9.445 9461' 4 18 12/21/1990 Doan / - TD = 10,800' /PBTD = 10.745' Max angle = 34.1° @ 8,400' • • III Well Work Prognosis Well: G -02RD Hi !carp Alaska, LLC Application Date: 11/30/2012 Proposed (New) Wellbore Schematic API4 50- 733- 20038 -01 CASING DETAIL RKB to Tbg. Hanger - 38.30" Size W Grade Top .131150. Length 1 1 13 -3/8" 61 J -55 Surf 1,300' (Top of Window) 9 -5/8" 47 N-80 Surf 6,000' 6,000' 7 "Liner 29 N-80 5,491' 10,767' 5,276' TUBING DETAIL 1 3 -1/2" 1 9.2 1 N-80 1 Surf 1 ±9,492' 1 ± 9,492' 1 JEWELRY DETAIL NO. Depth Item } 1 38.30' 3 -1/2" TBG Hangar 2 ±9,133' Top ESP 3 ±9,139' Top of Pump -SLB D5800N 4 ±9,239' Top of Motor - 5LB456,18,4183 Maximus 5 ±9,356' Bottom ESP I PERFORATION DETAIL Zone Top(MD) j (MD) Topi,TVD' ftpp,(TVD) SF'F Ft Date Comore .',: 1,310' 1,312' 1,310' 1,312' 4 2 5/25/1982 Squeezed - 1,330' 1,332' 1,330' 1,332' 4 2 5/26/1982 Squeezed E-2 E 1.350' 1,352' 1,350' 1,352' 4 2 5/31/1982 Squeezed , 1,365' 1,367' 1,365' 1,367' 4 2 5/25/1982 Squeezed 1,380' 1,382' 1,383' 1,382' 4 2 5/22/1982 Squeezed 1,390' 1,392' 1,399' 1,392' - - 5/31/1982 Squeezed 2,020' 2,022' 2,397' 2,009' - 2 5/31/1982 Squeezed 2,100' 2,106' 2,082 2,088' 4 6 6/1/1982 Squeezed 2,129' 2,131' 2,103' 2,111' - 2 5;31/1982 Squeezed 0 -33 ±9,760' ±9,792' ±3,1 -. ±8,876' 5 32 Future Future 2 (x-04 1:_9,814' ±9,852' ±8,895 ±8,929' 5 3S Future Future ' 3 ±9,868' ±9,880' ±8,943 ±8,954' 5 12 Future Future 0 -35 ±9,932' ±10,004' ±9,003 ±9,063' 5 72 Future Future G -06 ^_,0,069' ±10,091' ±9,129 ±9,139' 5 22 Future Future -4 10,164' 10,194' 9,201' 9,227' 4 33 3/12/1993 Open 4 HB t -3,172 _ ±10,204 `3,205 ±9,236' 5 32 Future Future CC77 10,174' 10,176' 9,210' 9,212' 4 2 7/15/1982 Squeezed 5 13,139' 10,203' 9,215' 9,235' 5 23 12/21 +1990 Open /Re - perf HB-2 10 ,2 3 3' 10,260' 9,258' 9,283' 5 33 10/7/1986 Open /Re -perf 10,262' 13,264' 9,285' 9,287' 4 2 7/14/1982 Squeezed " G -5 10,343' 10,345' 9,354' 9,355' 4 2 7/13/1982 Squeezed _" 6 H &3 10,345' 10,375' 9, 9,381' 16 33 12/21/1990 Open /Re -pert - HB-1 HB-3 & -1 ^0,338' ±10,518' ±9,353 ±9,501' 5 130 Future Future " " - H8-2 4 10,375' 10,407' 9,381' 9,408' 4 32 12/21/1990 Open ;HB -3 H8-4 10,407' 10,452' 9,408' 9,446' 12 45 12/21/1990 Open /Re -pert =HB-4 10,452' 10,470' 9,446' 9,461' - 1S 12/21/1990 Open HB-5 HE - ±10,549' ±10,650' ±9,527 ±9,622' 5 ... Future Future ` HB 6 HE - 6 1 ±10,742' ±9,662 ±9,692' 5 35 Future Future . . _ 'G = 13,803' Curt. Ret =10,745' Max angle = 34.1' f., 8,400' • Well Work Prognosis Well: G -02RD Application Date: 11/30/2012 FS I I ,r Weatherford Rental BOP nhde, n'6 3.74 Wi g 1-t 7'008 Shaffer 13 5/8 5M Ittifttlittif 1' 1 � • Shaffer LWS - Total BOP height above drill deck _ 9.48' min ng 3.00 o th s — — . ® ' 11.48' mu W dtl c b dv 2 72' Width across flanged 4 outlets 00' r = �• — Weig _ C 9.00' f,) 'I ' I -4 Mud Cross 135/85MX � fi t 28501bs w/ valves 0 31/8 5M EFO {HF[�(itip Ir ©'I 1.74' 4 Riser above drill deck This number will vary ��I from well to well 1.00'to 3.00' 9 Drill Deck 13 5/8 SM Riser 85oolbs 15.00' III III Spacer Spool 135/85M X 13 5/8 5M 1.95' 18001bs Crossover Spool 135/85MX115M 1800Ibs 2.83' II Top of Wellhead Well Work Prognosis Well: G -02RD Hilcorp Alaska, LLC Application Date: 11/30/2012 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Williams Rig 404, Grayling WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND /NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and /or corroded and BPV cannot be set with tree on, Profile and /or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. ' 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift- threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift- threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) • Well Work Prognosis Well: G-02RD Hacarp Alaska, LLC Application Date: 11/30/2012 d) Hold a constant pressure on the equipment and monitor the fluid /pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger /BPV profile wouldn't hold ressure and rolling test was performed on BOP Equipment and list items, p g p pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard p g g ( p g) g procedure. p p Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C -1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C -1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. • • . .. Well Work Prognosis Well: G -02RD Hilcorp Alaska, LLC Application Date: 11/30/2012 ii) Valves, 3, 4, 9. After test, open valves 3 & 4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C -2. This is the HCR (the hydraulic controlled remote) valve just outside C -1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C -1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K -1, K -2, and K -3 on the kill (pump -in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure ". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2' set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi "). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut -off after the pressure to builds back to original pressure ( +/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto ", not "Manual" so the pumps will kick -off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10 -424) in Excel Format and e-mail to AOGCC and Juanita Lovett. • • • Well Work Prognosis Well: G -02RD Hileorp Alaska, LLC Application Date: 11/30/2012 Diagram A -1: Grayling BOP stack and Riser Arrangement — Typical for Single Completion Williams Workover Rig Grayling Platform BOP 2012 Q 0 1 1 Weatherford Rental BOP Width 4.16 3. 74' Shaffer 18W/M 111 111 iii iii 111 - Shaper LWS 13 5/8 6M LWS -. -... 136/8 SIN dimensions Length 7.73' _ 3.00 Width across body 2.72' . ' Width across flanged outlets 4.00' = ,/rrt}�� — l Il 1 I • C4%r y y� ft- : /l� w. r F. 1.74 l• 1 _ ) i ;,0 +� III 111' 10 K3 11 K -2 K -1 C -1 C- 2'HCR" Mud Cross Riser above drill deck This number will vary from well to well 1 00 00' Dnll Deck 13 6/8 6M Riser 8500lbs 135/85MX ` 15.00 3 1/8 5M EFO I11 I1 111 III Spacer X 1p Spool 13 6 aM 1 of 6M 1.95' 18001bs 111 1/ 111 III Crossover Spool 135/85M X115M 1800lbs 2.83' 111 I Top of Wellhead • • • Well Work Prognosis Well: G -02RD Hilcorp Alaska, LLf. Application Date: 11/30/2012 Diagram A -2: Grayling BOP stack and Riser Arrangement — Typical for Dual Completion Williams Workover Rig Grayling Platform BOP 2012 — 1.44' III II 1111 200' III II[ III111 III i O • - . I II Weatherford Rental BOP Width 4.16' 3.74' Shaffer 13Lg8 IIIe1IlcI11 III III L ' - Shaffer t36/86M lWS t36/86M dM _ dimensions © __— Length 7.73' 3 Width across body 2.72' Width across flanged o u0 tlet s 4.000' _ - —_- _ — ;47,1/2I i 40 2 1 •1 if ' III I�1 aiA K - K. K - C -1 C- 2 Mud Cross Riser above drill deck This number will vary from well to well 1.00' to 3.00' D011 Deck 13 6/8 6M Riser 8600lbs 135/85MX 1500' 3 1/8 5M EFO i IiI III II Spacer Spool 136/86M X 135/86M 1.95' 1800186 It Ii III III Crossover Spool 13 6/8 6M X116M 1800186 2.83' III I Top of Wellhead /I • • • Well Work Prognosis Well: G -02RD Hilcarp Alaska, LLC Application Date: 11/30/2012 Diagram B: Grayling Choke Manifold To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ball valves Jme.*L_ - c IB w w "' "' Chokes are 90 degrees off ` in drawing in order to show / 1 detail il , I Z h :1 , r , F. i 1/1 E. F. i : : 1 6 1 11 4 li 1 61 rgli ' i ll itlis I 4) Swaco „ :II \ 6 . 11 . i 161— 1 11141111 1 0 Ct .0 - 11 011 III II ilt III ■ III il ; ' From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3 1 /4" Ball port, 6000psi working pressure #2 National Ball Valve B3260, 3'/4" Ball port, 6000psi working pressure #3 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #4 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #6 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #9 National Ball Valve B3260, 3'/4' Ball port, 6000psi working pressure #10 National Ball Valve B1560, 1 1 /2" Ball port, 6000psi working pressure ' WILLIAMS RIG #404 A F." FLUID FLOW DIAGRAM m NORMAL OPERATIONS CIRCULATING DOWN CASING, UP TUBING "REVERSE CIRCULATING" STANDPIPE / . / I P -raIC '', LINE ❑ • , e i 1 I ii o � AD �- STR, IP PER N E ar pa --- c� O BOP MANUAL AUTO 4ATIC • gi O STACK CHOKE CMOIE 0 C : C 0 I lt,01 -1 =1 1 MUCi i l PIJMP —0. xx 111 - PUMP - 1 MANIFOLD 111 \- 14C R VALVE 5� C "�" LP GAS U SUCT BLISTERT\ LINE I'1 • -rl FLUID TANK /PIT \ -a v CD CD W \ A C 07 N et � a o I- O N A- N O 73 v ° v o ri• Op 0 H • F 8 41 WILLIAMS RIG #404 ( m FLUID FLOW DIAGRAM r NORMAL OPERATIONS n CIRCULATING DOWN TUBING, UP CASING ANNULAS THE LONG WAY" STANDPIPE i P LINE r 1 • ii• ,,.. •. : I y �STRM PER HEAD EBOP • MAN UAL AUTO MATG a0 °oc. _T �• CHOKE CHOKE ► 44 -04 O. oC C e0 0 1 =_I 1 =1 MUD I }E 1=1- PIMP le — I —an— - PUMP MANIFOLD C LP ,UCTIOP1 a L1•' . TEP LINE • 416 FLUID T., 'Ik:rPIT \, (D (D W o Fl* N , +. 6" O O N O N x N v G C ( - D MQ 3 O a • • • Trading Bay Unit PROPOSED Well No: G -2RD Hilcorp Alaska, LLC Completed: 7/21/82 API # 50- 733 - 20038 -01 CASING DETAIL RKB to Tb:. Hanger - 38.30" Size Wt Grade Top Btm Length 1 13 -3/8" 61 J -55 Surf 1,300' (Top of Window) 9 -5/8" 47 N -80 Surf 6,000' 6,000' 7 "Liner 29 N -80 5,491' 10,767' 5,276' TUBING DETAIL I 3 - 1/2" I 9.2 I N - 80 I Surf I ±9,492' I ± 9,492' JEWELRY DETAIL NO. Depth Item 13 -3/� 1 38.30' 3 -1/2" TBG Hangar 2 ±9,138' Top ESP 3 ±9,139' Top of Pump -SLB D5800N 4 +9 289 Top of Motor - SLB 456, 18, 4183 Maximus 5 ±9,356' Bottom ESP PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Date Comments 1,310' 1,312' 1,310' 1,312' 4 2 5/25/1982 Squeezed - - 1,330' 1,332' 1,330' 1,332' 4 2 5/26/1982 Squeezed 9 -5/$ 1,350' 1,352' 1,350' 1,352' 4 2 5/31/1982 Squeezed LJ , 1,365' 1,367' 1,365' 1,367' 4 2 5/25/1982 Squeezed 1,380' 1,382' 1,380' 1,382' 4 2 5/22/1982 Squeezed 1,390' 1,392' 1,390' 1,392' 4 2 5/31/1982 Squeezed 2,020' 2,022' 2,007' 2,009' 4 2 5/31/1982 Squeezed 2,100' 2,106' 2,082' 2,088' 4 6 6/1/1982 Squeezed 2,129' 2,131' 2,109' 2,111' 4 2 5/31/1982 Squeezed G -03 ±9,760' ±9,792' ±8,847' ±8,876' 5 32 Future Future ,... 2 ±9,814' ±9,852' ±8,895' ±8,929' 5 38 Future Future II G -04 ±9,868' ±9,880' ±8,943' ±8,954' 5 12 Future Future 3 G -05 ±9,932' ±10,004' ±9,000' ±9,063' 5 72 Future Future G -06 ±10,069' ±10,091' ±9,119' ±9,139' 5 22 Future Future ..w 10,164' 10,194' 9,201' 9,227' 4 30 3/12/1993 Open a 4 ±10,172' ±10,204' ±9,208' ±9,236' 5 32 Future Future as ' HB -1 10,174' 10,176' 9,210' 9,212' 4 2 7/15/1982 Squeezed 5 10,180' 10,203' 9,215' 9,235' 5 23 12/21/1990 Open/Re-perf G - 10,230' 10,260' 9,258' 9,283' 5 30 10/7/1986 Open/Re-perf HB 2 G - 10,262' 10,264' 9,285' 9,287' 4 2 7/14/1982 Squeezed G - HB 3 10,343' 10,345' 9,354' 9,355' 4 2 7/13/1982 Squeezed G - 10,345' 10,375' 9,255' 9,381' 16 30 12/21/1990 Open/Re-perf HB - HB -3 & ±10,338' ±10,518' ±9,350' ±9,501' 5 180 Future Future = - 4 10,375' 10,407' 9,381' 9,408' 4 32 12/21/1990 Open =HB - HB 4 10,407' 10,452' 9,408' 9,446' 12 45 12/21/1990 Open/Re-perf - - 10,452' 10,470' 9,446' 9,461' 4 18 12/21/1990 Open HB - HB -5 ±10,549' ±10,660' ±9,527' ±9,622' 5 111 Future Future 7" HB 6 HB -6 ±10,707' ±10,742' ±9,662' ±9,692' 5 35 Future Future TD = 10,800' Cmt. Ret = 10,745' Max angle = 34.1° @ 8,400' Revised By: JLL 11/30/2012 • • 0 Trading Bay Unit • SCHEMATIC Well No: G -2RD Hilcorp Alaska, LLC Completed: 7/21/82 API # 50- 733 - 20038 -01 CASING DETAIL RKBtoTb•. Han :er - 38.30" 1 Size Wt Grade Top Btm Length 2 13 -3/8" 61 1 -55 Surf 1,300' (Top of Window) I OM. 3 9 -5/8" 47 N -80 Surf 6,000' 6,000' I 7 "Liner 29 N -80 5,491' 10,767' 5,276' TUBING DETAIL 3 - 1/2" 9.2 N - 80 Surf 10,118' 4 JEWELRY DETAIL L , NO. Depth Item 1 38.30' 4 -1/2" EUE TBG Hanger 2 39.30' 4 -1/2" 8rd X 3 -1/2" Buttress X -over 5 3 293.63' 3 -1/2" Otis 'XEL' Ball Valve 4 2,203.40' 3 -1/2" Camco Gas Lift Mandrel 5 3,889.68 3 -1/2" Camco Gas Lift Mandrel 6 5,434.84' 3 -1/2" Camco Gas Lift Mandrel 7 6,661.25' 3 -1/2" Camco Gas Lift Mandrel .y ° 6 8 7,470.07' 3 -1/2" Camco Gas Lift Mandrel 9 8,028.69' 3 -1/2" Camco Gas Lift Mandrel 10 8,463.94' 3 -1/2" Camco Gas Lift Mandrel 11 8,803.58' 3 -1/2" Camco Gas Lift Mandrel 7 12 9,175.96' 3 -1/2" Camco Gas Lift Mandrel 13 9,576.69' 3 -1/2" Camco Gas Lift Mandrel 14 9,983.50' 3 -1/2" Camco Gas Lift Mandrel 8 15 10,020.89' 3 -1/2" Otis 'XA' Sliding Sleeve (2.75" ID) - ill - 16 10,059.95' Baker Locator 17 10,060.46' Baker Model F -1 Prod. Packer w/ 80 -40 seal A 9 assembly to 10,080.32' 18 10,085.50' Otis 'X' Nipple (2.75" ID) 10 19 10,117.82' Bottom of 3 -1/2" Mule Shoe 1/9/89 - 23' of pert guns lost in well. Sitting on fill tagged on 1/8/89 @ 10,630' WLM. 11 2/18/08 - Last tag @ 10,238' w/ 2.74" Gauge Ring. 12 PERFORATION DETAIL M r Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Date Comments 13 1,310' 1,312' 1,310' 1,312' 4 2 5/25/1982 Squeezed 1 1,330' 1,332' 1,330' 1,332' 4 2 5/26/1982 Squeezed 14 1,350' 1,352' 1,350' 1,352' 4 2 5/31/1982 Squeezed AEI 1,365' 1,367' 1,365' 1,367' 4 2 5/25/1982 Squeezed lil 15 1,380' 1,382' 1,380' 1,382' 4 2 5/22/1982 Squeezed 1,390' 1,392' 1,390' 1,392' 4 2 5/31/1982 Squeezed 16 2,020' 2,022' 2,007' 2,009' 4 2 5/31/1982 Squeezed li alli 17 2,100' 2,106' 2,082' 2,088' 4 6 6/1/1982 Squeezed M 18 2,129' 2,131' 2,109' 2,111' 4 2 5/31/1982 Squeezed 10,164' 10,194' 9,201' 9,227' 4 30 3/12/1993 Open 19 HB -1 10,174' 10,176' 9,210' 9,212' 4 2 7/15/1982 Squeezed 10,180' 10,203' 9,215' 9,235' 20 23 12/21/1990 Open/Re HB-1 10,230' 10,260' 9,258' 9,283' 12 30 10/7/1986 Open /Re -perf HB-2 10,262' 10,264' 9,285' 9,287' 4 2 7/14/1982 Squeezed HB -2 10,343' 10,345' 9,354' 9,355' 4 2 7/13/1982 Squeezed HB -3 HB 3 10,345' 10,375' 9,255' 9,381' 16 30 12/21/1990 Open/Re-perf HB -3 & 4 10,375' 10,407' 9,381' 9,408' 4 32 12/21/1990 Open HB -4 HB-4 10,407' 10,452' 9,408' 9,446' 12 45 12/21/1990 Open/Re-perf An 10,452' 10,470' 9,446' 9,461' 4 18 12/21/1990 Open I ■ TD = 10,800' /PBTD = 10,745' Max angle = 34.1 @ 8,400' Revised By: TDF 9 -27 -2012 • • Bettis, Patricia K (DOA) From: Judy Stanek [jstanek @hilcorp.com] Sent: Thursday, December 06, 2012 8:41 AM To: Bettis, Patricia K (DOA) Cc: Ted Kramer Subject: RE: Application for Sundry Approval: TBU G -02RD Attachments: GO2RD_MAP_HEMLOCK.pdf; GO2RD_MAP_GZONE.pdf Patricia, Please see the attached maps showing the wells capable of producing within the 1000ft radius of the producing zones in the Hemlock and Middle Kenai G pools. Hope this answers your questions pertaining to the spacing exception. Judy Judy Stanek, CPL Landman Hilcorp Alaska LLC Ph: 907.777.8341 From: Bettis, Patricia K (DOA) [ mailto :patricia.bettis@alaska.gov] Sent: Wednesday, December 05, 2012 12:06 PM To: Judy Stanek Subject: Re: Application for Sundry Approval: TBU G -02RD Judy, Per our telephone conversation this morning, the following is a list of the wellbores, API #'s, that are located within or cross the NE1 /4 Section 32, Township 9 N, Range 13 W, S.M. 507332004901 507332004900 507332027200 507332041200 507332011500 507332021300 507332003801 (TBU G -02RD) 507332058700 507332004900 507332042101 507332029510 507332026900 507332040700 507332028600 507332029500 507332029501. Thanks, Patricia 1 • Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793 -1238 2 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, December 04, 2012 11:37 AM To: 'tkramer @hilcorp.com' Subject: Applicatin for Sundry Approval: TBU G -02RD Good morning Ted, I started to review Hilcorp's sundry application for the TBU G -02RD well this morning. From the application, Hilcorp plans to perforate new zones from the G -03 through HB -6. I would appreciate receiving a map of the Hemlock oil pool reservoir in the NE1 /4 Section 32, Township 9 N, Range 13 West, S.M. that shows the wellbore trace and perforation intervals of wells completed or capable of producing in the same pool as TBU G -02RD within that governmental quarter section. If you have any questions, please do not hesitate to call me. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793 -1238 1 n~-' t ~) ~ '" r;' I ¡II \ I ILl\ i 1\ \ -:::::1 LJ L¡ FRANK H. MURKOWSKI, GOVERNOR Jt 1,A.SIiA OIL AND GAS CONSERVATI ON COMMISSION 333 W. -,m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 23,2004 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification Trading Bay Unit G-01RD, PTD 191-139 G-02RD, PTD 182-067 G-17RD, PTD 178-003 G-28RD, PTD 200-038 Dear Mr. Johnson: On May 27, 2004, AOGCC Petroleum Inspector John Spaulding witnessed "no flow tests" at Unocal's Grayling platform, Trading Bay Unit, Wells G-01RD (short and long string completions), G-02RD, G-17RD, and G-28RD. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. An immeasurable flow of gas and no liquid hydrocarbons were produced to surface during the test. The subsurface safety valve may be removed from service in each of the wells listed above based on the no-flow test results. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in each well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, /. ~ \) <J~ D. ) "" r?a Co James B. Regg 77 Petroleum Inspection Supervisor cc: Bob Fleckenstein Pïb - i ø"~.. Db 7 ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg . KCdt1 b/;;zJetr P. I. Supervisor {( DATE: June 22, 2004 FROM: John Spaulding, Petroleum Inspector \~d-~ o~ 7 SUBJECT: "No Flows" Unocal Grayling Platform 5 wells June 15, 2004: I traveled to Unocal's Grayling platform to witness "No Flows" on 5 wells, defined as follows. The platform was shut in for some upgrades while I was there. All wells were ready to commence testing upon my arrival. The same bleeding and testing procedures were used on all 5 wells. G-2RD: Well was bled to the well clean tank and after sufficient bled was then vented to atmosphere. Gas flow was positive but not measurable, no fluids observed. Recommend for no flow status. 11'2>~-Cú3 G-17RD: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. '2eo-D'3'D G-28RD: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. ,~ 1- (39 G-1 RDL: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. G-1 RDS: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. SUMMARY; I witnessed the successful no flow tests on the Grayling Platform Attachments: none NON-CONFIDENTIAL 2004-0615 _no _flows- TBU - Grayli ng( Swells ).doc ALAS~ OIL AND GAS C ONSERYATI ON COHHISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 23, 1996 - Chuck Beaucamp Field Superintendent UNOCAL 260 Caviar Street Kenai, Alaska 99611 No-Flow Verification TBU Well G-26 and TBF Well No. A-21. Dear Mr. Beaucamp: On June 11 and 13, 1996, our inspectors witnessed "no-flow" tests on two of UNOCAL's Trading Bay Unit wells and one Trading Bay Field well with results as follows; Well Name PTI) No. Comments and Observations TBF A-21 70-047 Monitored well 8 hrs. - will not flow unassisted; k can be classified '~qo-flow". TBU G-26 76-066 Monitored well 7 hrs - well will not flow unassisted; it can be classified '~lo-flow". TBU Well showed signs of flowing unassisted and should remain classified as a flowing well. Trading Bay Field well A-21 and Trading Bay Unit well G-26 meet the criteria of a "no-flow" performance test and as such are considered incapable of flow to the surface. Under the authority of 20 AAC 25.265(A), they are not required to have a fail safe automatic SSSV; however, the pilot and surface safety valve must be maintained in good condition and, if for any reason, the well(s) again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be reinstalled and maintained in good working condition. Sincerely, Blair E. Wondzel~' PI Supervisor CC'. John Spaulding Lou Grimaldi bew/nfun2ciw MEMORANDUM TO: David 'J Chairmar~' State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 11, 1996 THRU: Blair wondzell, .~~ P. ! Supervisor FROM: Lou Grimaidi, ~.o~-- SUBJECT: Petroleum Inspector FILE NO: 4U9JFKDD.DOC No Flow tests Unocal well #G-26 & G-2 Grayling platform McArthur river field PTD # G '?-RD ~9 ~-O¢= 7' Tuesday, June 1!, '1996: ! witnessed the No Flow tests on Unocals wells #G-26 & G-2 aboard the Grayling platform in the McArthur River field. The tests were performed while I was onboard for the Safety Valve System's tests. The well G-26 was routed to the well clean tank (+2 psi) for four hours then to atmosphere for a additional two hours. G-26 produced no fluids and a slight amount of gas which would stop and start irregularly. I had Tony James (Unocal Operator) install a 100 psi gauge on the tree and the well was shut-in for one hour. The tubing pressure built up to seven psi and when the well was bled the pressure dropped quickly and showed no signs of building back up within ten minutes. G-26 is scheduled for wireline work and the safety valve will be reinstalled after this is accomplished. G-2 was also tested for No-Flow today and although it did not produce fluids to the well clean tank, when opened to atmosphere it started producing slowly and seemed to gain momentum. We put the well back on production after it reached a steady stream of OilNVater mix. G-2 has a scaled up SSSV that is due a acid job in attempts to pull it. I recommend that well G-26 be granted a No-Flo_w sta,t,u% G-2 should remain classified as a flowing well and have its SSSV repaired. 4U9JFKDD.DOC pa~e 2 SUMMARY: I witnessed the successful No Flow test on Unocals well #G-26 and the unsuccessful No Flow test on G-2 aboard the Grayling platform in the McArthur River field. Attachments: NONE cc; Chuck Beaucamp (Area Supervisor) NON-CONFIDENTIAL STATE OF ALASKA ALASKA ii[ AND GAS CONSERVATION COIV~'SSION APPLICA1 ION FOR SUNDRY APF .{OVALS 4 1. Type of request: Abandon __ Suapend __ Alter o.ing__ Repair well Change approved program __ Operatione ~hutdown __ Re-enter euapended well__ Plugging __ Time extension __ 8tlmulate __ Pull tubing __ Vmlance __ Perforate X_ Other__ 2. Name of Operator Union Oil Company of California 3. Address P.O. Box 196247, Anchorage, Alaska 99519-6247 4. Location of well at surface Leg #4, Conductor #20 1829' N and 1480' Wof SE CDr., Sec. 29, T9N, R13W, SM At top of productive Interval 2003' S and 793' W of NW Con, Sac. 32, T9N, R13W, SM At effactive depth At total depth 2330' FNL and 765' FEL, Sec. 32, T9N, R13W, SM 5. Type of Well: ~X_ 6. Datum elevation (DF or KB) KB: 103' 7. Unit or Property name Trading Bay Unit 8. Well number G-2RD 9. Permit number 82-67 10. APl number 50-733-20038-1 11. Field/Pool McArthur River/Hemlock feet 12. Present well condition summary Total depth: measured true vertical 10,800' feet 9741' feet Effective depth: measured · 10745 · feet true vertical 9694' feet Plugs (measured) Junk (measured) ORIGINAL Casing Length Size Structural Conductor Surface 1300' 13 3/8" Intermediate Cemented Measured depth True vertical depth 1300' Production 6000' 9 5/8' 1900 sx 6000' Uner 5276' 7' 1030 sx 10,76T Perforation depth: measured 10,180'-10,203'; 10,230'-10260'; 10,345'-10,375'; 10,407'-10,452' true vertical 9125-9235', 9258'-9283', 9356'-9381', 9408'-9446' Tubing (size, grade, and measured depth) 3 1/2', N-80, 9.2# @ 10,118' Packers and SSSV (type and measured depth) Baker F1 @ 10,080' 3 1/2' Otis XEL BV @ 294' RECEIVED SEP 2 3 1994 Alaska 0il & Gas Cons. C0mmis, Anch0ra~e 13. Attachments Description summary of proposal __ Detailed operations program X BOP sketch Questions? Call Hal Martin @ 263-7675 or Ralph Holman (~ 263-7838 14. Estimated date for commencing operation ri 5. status of well classirK:ation as: October 11, 1994 .J 16. If proposal was verbally approved J Oil X_ Gas __ Suspended __ / Name of approver Date approved J Service 17. I hereScer~/that t~r~oi?~ ~corract to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Location clearance Machanical Integrity Test__ ~'~bsequent form required ~'~- Approved by the order of the Commission Original Signed By r)avid W. Johnston Form 10-403 Rev 06/15/88 /.-/'//. commissioner Approved Copy Returned , JApproval No. . SUBMIT IN TRIhUC.~TE ~ion Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 September 20, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to perforate the following intervals in well G-2RD (API# 50-733-20038-01) on the Grayling platform. BENCH, TOP (MD) BO'[TOM (MD) FEET HBI 10164 '/ 10194 30 H~3 1034~ 1037~ 30 HB4 1040~ 10452v/ 45 T~ 105' Sincerely~ RECEIVED SEP 2~ 1994 Oil & Gas Cons. Commission Anchorage September 20, 1994 Gra_vling Hafform. Well G-2 Perforating Procedure 1. Hold safety meeting. 2. Rig up electric line unit. Pressure test lubricator as directed by Unocal witness for five minutes. Note: A pump-in sub with a valve is required. 4. Shut down all welding and radio transmissions. e Run in hole and perforate intervals as instructed by Unocal wire.ss. (When gun is 200' below surface, welding and radio transmissions may resume.) . Pull out of hole. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL FEET HB1 10164-10194 30 HB3 10345-10375 30 HB4 10407-10452 45 TOTAL: 105 R£¢ iV'ED SEP 2 3 1994 Alaska Oil & Gas Cons. Commission Anchoraue STATE OF ALASKA , ALASK( 3IL AND GAS CONSERVATION C~'~ MISSION REPOR' , OF SUNDRY WELL OF_RATIONS 1. Operations performed: Oper~on shutdown Stimulate Plugging Perforate X Pull tubing Nte, oasing Repair well Pull tubing Other 2. Name of Operator -- -- J5. TYpe of W~: , -- 6. Datum e~vation (DF or KB~)//J Union Oil Company of Califomia (Unocal) I Uevaopment~ KB: 103' ' ' I ~to,V fe§t I 3. Address ' ! --_ P.O. Box 196247, Anchorage, Alaska 99519-6247 J se,vice __ Trading Bay Unit 4. Location of well at su'face Grayling Platform, Leg #4, Conductor #20 1829' N and 1480' W of SE Cor., Sec. 29, T9N, R13W, SM At top of productive interval 2003' S and 793' W of NW COr., Sec. 32, T9N, R13W, SM At effective depth At to~ depth 2330' FNL and 765' FEL, Sec. 32, T9N, R13W, SM 8. Well number G-2RD 9. Permit number/approval number 82-67 10. APl number 50-733 -20038 -01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured 10,800 feet true vertical 9741 feet Plugs (measured) Effective depth: measured 10,745. feet true vertical 9694 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: meastxed Length Size Cemented Measured depth True vertical depth 1300' 13 3/8' 1300' 1300' 6000' 9 5/8" 1900 SX 6000' 5582' 5276' 7" 1000 SX 10,767' 9690' 10,180'-10,203'; 10,230'-10,~60'; 10,345' -10,376'; 10,407'-10,452' 13. true vertical 9125'-9235', 9258'-9283', 9356'-9381 ', 9408'-9446' Tubing (size, grade, and measured depth) 3 1/2", N-80, 9.2# @ 10,118' Packers and SSSV (type and measured depth) Baker F1 @ 10,080' 3 1/2' Otis XEL BY @ 294' Stimulation or cement squeeze summary Intervals lreated (measured) Treatment description including volumes used and final pressure MAR 0 Alaska Oil & Gas Cons. 'Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 290 275 3006 1340 285/~ 295 3071 1365 Tubing Pressure 140 150 15. Attachments Copies of Logs and Surveys run__ Dally Report of Well Operations 17. I hereb~e~fy t~true and Signed / 0L['~ 16. Status of well classification as: Oil X Gas Suspended Service x)rrect to the best of my knowledge. Form 10-404 Rev 06/16/88 SUBMIT IN DUPLICATE · STATE OF ALASKA ALASI~ ~IL AND GAS CONSERVATION C(~-""MISSlON . APPLICN,,'ION FOR SUNDRY Ai _ ROVALS ~. Type 6f request: Abandon __ Suspend __ Operations shutdown __ Re-enter suspended well__ Alter casing__ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing__ Variance __ Perforate X_ Other__ -2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California Devek~,~e~ X_ KB: 103' Expk~t~ __ feet ~. Address S~graphic __ 7. Unit or Property name P.O. Box 196247, Anchorage, Naska 99S19-6247 Serv~e __ Trading Bay Unit ~t. Location of well at surface Leg #4, Conductor #20 8. Well number 1829' N and 1480' Wof SE Cor., Sec. 29, T9N, R13W, SM G-2RD At top of productive interval 9. Permit number 2003' S and 793' W of NW Cor., Sec. 32, T9N, R13W, SM 82-67 At effective depth 10. APl number 50-733-20038-1 At total depth 11. Field/Pool 2330' FNL and 765' FEL, Sec. 32, T9N, R13W, SM McArthur River/Hemlock ":12. Present well condition summary Total depth: measured 10,800' feet Plugs (measured) true vertical 9741' feet Effective depth: measured 10745 feet Junk (measured) true vertical 9694' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1300' 13 3/8" 1300' 1300' Intermediate Production 6000' 9 5/8' 1900 sx 6000' 5582' Liner 5276' 7' 1000 sx 10,767' 9690' Perforation depth: measured 10,180'-10,203'; 10,230'-10260'; 10,345'-10,375'; 10,407'-10,452' true vertical 9125-9235',9258'-9283', 9356'-9381',9408'-9446'R E £ ElM E D Tubing (size, grade, and measured depth) 31/2", N-80, 9.2# ~ 10,118' M/~ 0 ~ !~qJg~ Packers and SSSV (type and measured depth) Baker F1 @ 10,080' Alaska 0ii & Gas C0r~s. 3 1/2' Otis XEL BV @ 294' Anchorage 'i3. Attachments Description summary of proposal__ Detailed operations program X BOP sketch __ 'i4. Estimated date for commencing operation 15. Status of well classification as: March 8, 1993 "i6. If proposal was verbally approved Oil X_ Gas __ Suspended __ Name of approver Date approved Service 17' I here~/~jP~t~ ~ng is true and c°rrect t° the best of my kn°wledg°' FOR COMMISSION USE ONLY '"Conditions of approval: Notify Commission so representative may witness N Plug Integrity BOP Test __ Location clearance ..... .,,~ ~i"-.~: Mechanical lntegrity Test Subsequent form required l0 ~'~*/-'" ~-~7';!'?~'V3~'~ David We Johnston :Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE February 26, 1993 Graylin.q, Well G-2RD perforatin,q procedure 1. Hold safety meeting. 2. RU electric line unit. 3. Pressure test lubricator to 2500 psi for five minutes. 4. Shut down all welding and radio transmissions. 5. RIH and perforate intervals as instructed by Unocal (When gun is 200' below surface, welding and radio transmissions may resume.) 6. POOH. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH MEASURED TRUE VERTICAL TOTAL FEET HB1 10,173'-10,203' 9202'-9228' 30' TOTAL: 30' STATE OF ALASKA REP OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Mugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator [ 5. Type of Well: Development Union Oil Co. of Calif. CUNOCAL~ ! Exptoratory~__ 3. Address I StratigralmiC_ POB 190247, Anch, AK., 99519-0247 I Service__ Pedorate Pull tubing 4. Location of well at surface Conductor #20, Leg #4 1829'N & 1480' W of SE Cor., Sec. 29, T9N, R13W, SM At top of productive interval 2003' S & 790' W of NW Cor., Sec. 32, T9N, R13W, SM At effective depth At total depth 2380' S & 765' W of NE Cor., Sec. 32, T9N, R13W, SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: f~t Plugs(measured) 10,800' f~t 9,741' 10,745' feet Junk(measured) 9,694' f~t Length Size Cemented Other 6. Datum elevation (DF or KB) RT 99 ' M.qT. 7. Unit or Property name Tradinq Bay Unit 8. Well number ~_-- ') I~ ]"'t 9. Permit number/approval number 67-48 10. APl number 50-- 733-20038-01 feet 11. Field/Pool ,~ ~~, ~/~_ _~Heml oc MAR - 6 t991 Alaska 0il & Gas Cons. Anchorage Measured depth True vertical depth 1,300' 13 3/8" 1,300' 6,000' 9 5/8" 1,900 SXS 6,000' 5,582' 5,276' 7" 1,000 SXS 10,767' 9,690' measured 10,180'-10,203', 10,230'-10,260', 10,345'-10,470' truevertical 9,215'-9,235' 9 258'-9 283' 9 355'-9 461' Tubing (size, grade, and measured depth) 3 1/2", 09.2# , N-80 @ 10,118 ' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Baker Fi @ 10,080' 3 1/2" , ',, Otis XEL BV @ 293.6' , Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 260 365 1960 1410 Tubing Pressure 110 360 500 2970 1440 150 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil ~ Gas __ Suspended __ 17. I hereby certify th/~the foregoing is true and correct to the best of rny knowledge. Gar~~~· ~~ Signed Y~. ~ TitleRegional Drilling Manager Form 10-404 Rev 06/15/88 Date ~ SUBMIT IN DUPLICATE · STATE OF ALASKA AL{' \ OIL AND GAS CONSERVATION COMMI( APPLIC flON FOR SUNDRY 1. Type of Request: Abandon __ Suspend m Alter casing __ Repair well Change approved program m Development ..Z. Exploratory ~ Stratigraphic ~ Service ~ Operation shutdown __. Re-enter suspended ~ ...._ Plugging m Time extension __ .~mulate m Pull tubing __ Variance _._ Perforate ~ Other _.. & Datum elevation (DF or KB) RT 99' MSL 7. Unit or Property name TRADING BAY UNIT 2. Name of Operator I Union Oil Company of California (Unocal) P.O. Box 190247, Anchorage, AK 99519 ~Locafionofw~lmsudace Conductor #20, Leg #4 1829' N and 1480' W of SE Cor. Sec. 29, T9N, Rt3W, SM 2003' S and 793' W of NW Cor., Sec. 32, T9N, R13W, SM' At effective depth At tow dep_~ ' 2330' S and 765''W of-NE Cor. .. feet Plugs (measured) feet 12. Present well condition summary Total depth: measured 10,800 true vertical 9,7 41 Effective depth: 8. Well number G-2RD 9. Permit number 10. APl number 50-- 733-20038-01 11. Field/Pool McArthur River/Hemlock measured 10,745 feet Junk(measured) true vertical 9,694 feet Length Size Cemented Measured depth True vertical depth 1300' 13 3/8" 1300' 6000' 9 5/8" 1900 sx 6000' 5582' 5276' 7" 1000 sx 10,767' 9690' 10,230-10,260 Casing Structural Conductor Surface Intermediate Production Uner Perforation ?~t,hi measured 80-10,203 10,345-10,375 10,407-10,452 RE true vertical CEIVED 9215-9235 9258-9283 9356-9381 9408-9446 Tubing (size, grade, and measured depth) 3 ½", N-80, 9.2# @ 10,118' Packers and SSSV (type and measured depth) Baker Fi @ 10,880' 3½" Otis ZEL BV @ 293.63' 13. Attachments Description summary of proposal _... Detailed operations program X_... feet BOP sketch _._ 14. Estimated date for commencing operation 15. Status of well classification as: December 17, 1990 16. If proposal was verbally approved Oil ~ Gas __ Suspended __ Name of approver Date approved Service 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. JSigned Gary S. Bus~~. (~~ TiaeRegional Drilling Manager ..',~- r~. ' ' FOIl COMMISSION USEONLY Conditions of approval: Notit~:om~ission so representative may witness Plug integrity m BOP Test Mechanical IntegrityTest~ Subsequent form required 10- ~ . ORIGINAL SIGNED BY- Commissioner Approved Copy Returned/ LONNIE C. SMITH Approved by order of the Commission Form 10-403 Rev 06/15/88 Date (z - i,,-[ -.,~, o I Approva, No. 9~ "/~',~ ? SUBMIT IN TRIPLICATE ..~..~, ~ecember i O. '!, 990 RE: G-2RD perforating procedure !. P..U slick tine, run ctauo, e and t.=a bottom. ~_."~ Hold safety meeting. 3. RU electric line unit. 4. Pressure test lubricator to 2500 psi for five minutes. 5. Shut clown all weidin._o, and radio transmissions. 6. RtH and perf'or:=~te ir:,tervais as instructed by Unocal re?resentative. (¥¥hen [jun is 200' below surface, welding and radio transmissions may resume.) 7. POOH. ~When cjun is 200' below surface., shut dowT~ ail weidin9 and radio transmissions.) 8. Repeat steps 5, 6 and 7 as needed to peal'orate the fotlowin9 inter/als: BENCH MEASURED TRUE VERTIC^L TOTAL FT. HB1 ! 0,170 - 10,203 9,207 - 9,235 33 HB2 10...230 - 10...306 9,2.58 - 9,323 76 HB3t4 10,345 - 10,470 9,356- 9,461 125 TOTAL NOTE: After the above pedorations have been completed, the well will be put on production and a .c_fas lift survey will be run to determine if the completion 5trin9 has' excess capacity., if additional capacity exists, the foilowin(! intervals will be perforated usin._q the above procedure: BENCH MEASURED ECEIVED TRUE VERTICAL TOTAL FT. HB4 ! 0,483 - i 0,525 42 HB5 10,570 - 10,640 7O TOTAL 112 'I .f. I , ./ / STATE OF ALASKA REPORT OF SUNDRY WELL OPEF TIONS 1. Operations performed: Operation shutdown m Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well m Pull tubing __ Name of to · 2Union ~1~ bompany of California ,,,~5~o, fWell: ! Exploratory 9 40 2 4 7 Stratigraphic ~.(~r. es~Box 190247, Ancn., AK, 9951 ._ Service I Perforate x Other 6. I~ ~l~viatio~D~ or KB) 7. ~l:/rNli~rtBr~i"~ e UN I T '~.~gt~r~c.e LEG 4. 1829' N & SECTION 29, T9N, R13W, SM Att°o0fP,.~d~xcti~n~er~valw OF NN CORNER, 2003 At effective depth 2Aj~ld~pt~ 765' W OF NE CORNER 1480' W OF SE SEC. 32, T9N, R13W, S 8. Well numll;l~2RD ~9. Permit nub~e_r~jv._al(~r~er 10. APl numl~ 3- 2 0 0 3 8 50-- 11. Field~~Sc~IVER feet ,= 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,800 feet Plugs (measured) 9,741 feet 10,745 feet Junk(measured) 9,694 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 1300' 13-3/8" 1300' 6000' 9-5/8" 1900 SX 6000' 5582' 5276' 7" 1000 SX 10767' 9690' measured 10,173'-10,203', 10,222'-10,306', 10,345'-10,525' 10,538'-10,677', 10,702'-10,736' true vertical 9209'-9235', 9658'-9687' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 9251'-9401' , 9355'-9470', 9569'-9636' 3-1/2" 9 2# N-80 @ 10117 82' , I ' I ' Baker F-1 @ 10080' 3-1/2" OTIS XEL BALL VALVE @ 293.63' KIc: t:l vcu 14. Intervalstreated(measured) NOV ~' 1 1990 Treatment description including volumes used and final pressure Nasl 0il & 6as 0ohs. Representative Daily Average Production or Injection Data ~t'll;h~i'&§~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil ~ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-4(~ev 06/15/88 Title Date //,/~//'~ SUBMIT IN DUPLICATE November 21, 1990 RE: G-2RD perforating procedure 1. RU slick line, run gauge and tag bottom. 2. RU electric line unit and pressure test lubricator. 3. RIH and perforate the following intervals using 2 1/8" strip guns loaded at 4 SPF: HB1 10,173'- 10,203' 30' HB2 10,222' - 10,306' 84' HB3/4 10,345' - 10,525' 180' HB5 10,538' - 10,677' 139' HB6 10,702'- 10,736' 34' TOTAL 467' 4. POOH, RD REtSEIVED NOV 2 1 1990 Alaska 0il & Gas Cons. ~mmtSSiOn /~nchorage Aj~,,,A OIL AND GAS CONSERVATION COMMIS-(]. 3N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging __ Pedorate ~ Pull tubing ~ Alter casing ~ Repair well __ Pull tubing __ Other 2. Name of Operator / 5. Type of Well: Union 0il Company of' Ca.l. if'ornia (UNOCAL) Devel.opment__ _.~ ! Exl~oratory 3. ~aaress | Stratigraphic P.0. Box 190247, Anch, Ak., 99519-11247 Service / 4. Location of well at surface Conductor f~ 20, Leg 4, 1829' N & 1480 W of SE i n 2 .TgN R13W SM At top O~l~rCo~ub~ve ,n~a, ' ' 2003' S & 793' W of NW Corner, Sec. 32, TgN, R13W, SM At effective depth At total depth 2330 S & 765' W of NE Corner 6. Datum elevation (DF or KB) RT 99' MSL 7. Unit_or Prql~erty n~ame /raazng ~ay Unit 8. Well~u~r 9. Permit number/approval number 67-48/9-O27 10. APl number 50-- 733-20038 11. Field/Pool Hemlock %' feet 12. Present well condition summary Total depth: measured true vertical 10800 ' feet 9741 ' feet Plugs (measured) Effective depth: measured true vertical 10745 ' feet 9694' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size measured 1300' 13 3/8" Cemented 6000 9 5/8' 1900 sx 5276' 7" 1000 sx 10180 - 10203 Measured depth True vertical depth 1300' 10345 - 10375 6000' 5582' 10767' 9690' 10407 - 10452 true vertical 9215 - 9235 9356 - 9381 Tubing (size, grade, and measured depth) 3 1/2", 9.21f, N-80 $ lOll7.82 ' 9408 - 9446 PackersandSSSV(typeandmeasuredde~ker F-1 $ 10080'. 3 1/2" Otis XEL Ball Valve $ 293.63' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED .AJaska 0il & Gas ~ns. Com~[ssio~ ' "' ~choBge 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 198 73 1340 1330 Tubing Pressure 130 602 189 2110 1380 185 16. Status~wellclassificationas: Oil~' Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Environmental Engineer Form 10-404 Rev 06/15/88 Date 02/25/89 SUBMIT IN DUPLICATE G-2 RD Perforating Report PROCEDURE: The following intervals were perforated with Hollow Carrier Guns ~ 4SPF: 10,407' - 10,452' MD DIL (Bench 4) 10,345' - 10,375 MD DIL (Bench 3) lO,180' - 10,203' MD DIL (Bench l) 2617p/117 RECEIVED i&iaska_.. Oil .& Gas Cons..Conami~log , ~nchorage ~ Perforation Depth G-2 RD Measured 1365-1367' 1310-1312' 1330-1332' 2020-2022' 2129-2131' 1390-1392' 1350-1352' 2100-2106 10262-10264' 10343-10345' 10174-10176' 10345-10375' 10230-10260' 10180-10203' 10407-10452' (test squeezed) II II II II 11 I1 II I! ( squeezed ) (bench 3 open) (bench 2 open) (bench 1 open) (bench 4 open) Vertical 1365-1367' 1310-1312' 1330-1332' 2007-2009' 2109-2111' 1390-1392' 1350-1352' 2082-2088' 9281-9283' 9353-9355' 9202-9204' 9251-9279' 9207-9224' 9374-9408' 2617p/118 STATE OF ALASKA COM M~..,~ON AI~,,.,KA OIL AN D GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing Change approved program 2. Name of Operator ! 5. Type of Well: Development Union Oil Company of California (UNO~AL) Exploratory 3. Address P.O. BOX 190247 4. Location of well at surface Conductor # 20, Leg 4, 182~' N & 1480 W of SE ,~torne, r.. Sectioo 29 T9N R13W, SH top o~ proauctlve ~n[erval 2003' S & 793 ' W of NW Corn, Sec 32, TgN,R13W, SM At effective depth At total depth 2330 S & 765' W of NE Corner Operation shutdown ~ Re-enter suspended well __ Plugging ~ Time extension ~ Stimulate t Perforate L Other 6. Datum elevation (DF or KB) RT 99' HSL 7. Unit or Property name Trading Bay Unit 8. Well number G-2 RD 9. Permit number 67-48 lO. APInumber 50-- 733-20038 11. Field/Pool Hemlock Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical '10800 ' feet 9741 ' feet 10745 ' feet 9694 ' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 1300' 13 3/8" 6000' 9 5/8" 5276' 7" measumd See Attached truevertical Plugs (measure Junk(measured) · . Cemented , ~,~M~ad~oth 1300' True vertical depth 1900 sx 6000' 5582' 1000 sx 10767' 9690' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3 1/2", 9.2#, N-80 $ 10117.82' Baker F-1 $ 10080' 3 1/2" Otis XEL Ball Valve $ 293.63' 13. Attachments Description summary of proposal,~ Detailed operations program BOP sketch __ 14. Estimated date for commencing operation 1 / 9 / 89 115. Status of well classification as: 16. If proposal was verbally approvedI Oil Name of approver Mike ~inde r 1 / 9 / ~gate approved Service . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~. _-/Roy D, Ro~e~_ ~~ X T'"" Environmental Engineer ~,gneR ~.,{¢~..(.~'~,/'~, ../~c~¢~.~ .... ) ' ' /~0R COMMISSION USE ONLY Conditions of approval: N~y Commi~ion~presentative may witness Plug integrity ~ BOP T~f~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ~po~oved Copy Rett:?ned O'RIGIN~.[ Approved byorder of the Commissioner LONNIE C. SMITH Commissioner Suspended Dme 1/9/89 IAppr°val N°' f--"O<52~ Date Form 10-403 Rev 06/15/88 SuBsequent Work B,eported on _ _..SUBMIT IN TRIPLICATE G-2 RD PROCEDURE: 1. R. U. slickline unit and pull Oall valve. 2. Run 2.5" gauge ring to E.T.D. (10,745'~) A 2.?35" swedge was run to the tail in 1988. 3. R. U. electric line unit and perforate as follows: 4 SRF, Hollow Carrier Guns 10,407' - 10,452' MD DIL (Bench 4) 10,345' - 10,375 MD DIL (Bench 3) lO,180' - 10,203' MD DIL (Bench l) 4. Return well to production and get a stabilized rate. NOTE: All perforations to be shot under drawdown conditions. Maximum anticipated SBHR is 4000 psi. 261Yp/106 Perforation Depth G-2 RD Measured 1365-1367' 1310-1312' 1330-1332' 2020-2022' 2129-2131' 1390-1392' 1350-1352' 2100-2106 10262-10264' 10343-10345' lOl?4-101?6' 10345-10375' 10230-10260' 10180-10203' 10407-10452' (test squeezed) ,! II ,! ,! II II ,, ,! II ( squeezed ) (bench 3 open) (bench 2 open) (bench i open) (bench 4 open) Vertical 1365-1367' 1310-1312' 1330-1332' 2007-2009' 2109-2111' 1390-1392' 1350-1352' 2082-2088' 9353-9355' 9202-9204' 9355-9380' 9251-9279' 9207-9224' 9374-9408' 2617p/107 STATE OF ALASKA ~.~ ALA ~ . OIL AND GAS CONSERVATION CO $SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown f--i Stimulate [] Plugging ~ Perforate ~ Pull tubing Fi Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) RT 99' MSL Feet 3. A~dr, ess_ 6. UlUlating ¢~a~ r~zet ~'.u. uox 190247, Anch, Ak., 99519-0247 itc Prop rt 4. Location of well at surfacigond #20, Leg 4, 1829' N & 1480' W of SE Corner, Section 29, TgN, R13W, SM 7. Well number 6;-2 RD At top of productive interv~D03, S & 793' W of NW Corn, Sec 32, TgN, R13W, SH At effective depth At total depth 2330' S & 765' W of NE Corner 8' A P P r°val n~c~,~b,.~ r( 9. APl number 50-- 733-20038 10. Pool -- Hemlock Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10800 feet feet 9741 10745 feet 9694 feet Casing Length Size Structural Conductor 1300 ' 13 3/8" Surface Intermediate 6000 ' 9 5/8" Production 5276 ' 7" Liner Perforation depth: measured See Attached true vertical Plugs (measured) Junk (measured) Cemented ' Measured depth 1300' 1900 SX 6000' 1000 SX 10767' True Vertical depth 5582' " 9690' Tubing (size, grade and measured depth) 3 1/2" 9 2#, N-80 8 10117 82' , · · Packers and SSSV (type and measured depth) Baker F-1 3 1/2" Otis XEL Ball Valve 8 293.63' 12. Stimulation or cement squeeze summary k 13. Intervals treated (measured) OCT 2 1 1986 Treatment description including volumes used and final pressure ,,.,,o~.. nil & G~s Cons. Commission Representative Daily Average Produ~i~"~'-o~ Inj~e"tC~r~'ta OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 284 572 Subsequent to operation ~bing Pressure 396 1539 1120 120 0 1981 1140 160 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge~lf~-'~!! ~ --.-. ~4v ,.~ ,-~-"ZJ--"~/~ Signed Ro.y~¢), Roberts Form 10-404 Rev. 12-1-85 Titl~nyironm¢ntal Engineer ~0/17/86 Submit in Duplicate Perforation Depth G-2 RD Measured 1365-1367' 1310-1312' 1330-1332' 2020-2022' 2129-2131' 1390-1392' 1350-1352' 2100-2106' 10343-10345' 10262-10264' 10174-10176' 10345-10375' 10230-10260' 10180-10203' Vertical 1365-1367' 1310-1312' 1330-1332' 2007-2009' 2109-2111' 1390-1392' 1350-1352' 2082-2088' 9353-9355' 9281-9283' 9202-9204' 9355-9380' 9251-9279' 9207-9224' #14. DAILY REPORT OF WELL OPERATIONS 10/6/86 RU Schlumberger. Perforate Bench #4 (10407-10452'). 10/7/86 Rerforate Bench #2 (10280-10260') and Bench #1 (10180-10203'). RD Schlumberger. STATE Of ALASKA ALA ..-, OIL AND GAS CONSERVATION CO .,SSION 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 [] Pull tubing [] Amend order [] Perforate 5~ Other 2. Name of Operator Union Oil Company of California (UNOCAL) 3' Ad~[r.el~.S Box 190247, Anch, Ak., 99519-0247 4. Location of well at surface Conductor #20, 'Leg 4, 1829' N & 1480' W of SE Corner, Section 29, T9N R13W, SH At top of productive interval ' 2003' S & 793' W of NW Corn, Sec 32, T9N, R13W, SM At effective depth · At ~;~l(~el~h& 76.5' W of' NE Corner 5. Datum elevation (DF or KB) RT 99' MSL 6. U~t or ,P. ropeLty na, me.. lraozng uay unit 7. Well number G-2 RD 8. Permit numbe[,,., 9. APl number 50-- 733-20038 10. Pool Hemlock Pool feet 11. Present well condition summary Total depth: measured true vertical 10800 feet Plugs (measured) 9741 feet Effective depth: measured 10745 feet Junk (measured) true vertical 9694 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface 1300' 13 3/8" - 1300' - Intermediate ., Production 6000' 9 5/8" 1900 sx 6000 '~ 5582' Liner .5276' 7" 1000 sx 10767 i' 9690 ' .. Perforation depth: measured See Attached p,E[ElVEI)" true vertical Tubing (size, grade and measured depth) 3 1/2", 9.2#, N-80 ~ 10117.82' Al~.ska 0il & Gas Cons. Packers and SSSV (type and measured depth) Baker F-1 ~ 10080' Anchorage 3 1/2" Otis XEL Ball Valve ~ 293.63' !986 12.Attachments See Attached Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 10/6/86 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~(;~cert~ t.,~l~_ t, the,foregoing ,l ~t,, Signed R~W'~o ~ is true and correct t~ the best of my knowledge Title Environmental Engineer Commission Use Only Date 10/2/86 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance I Approval No. Z:/~D by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate #12. Description Summary of Proposal G-2 RD PROCEDURE: 1. R.U. slickline unit and pull ball valve. 2. Run 2.5" gauge ring to T.D. (+ 10,745'). 3. R.U. electric line unit and perforate bench 4 interval (10,407'-10,452'). 4. Return well to production and get a stabilized rate. 5. If well has a substantial increase in production, P.D. wireline and rerun ball valve. 6. If no production increase is seen perforate Hemlock benches i (10180-10203') and 2 (10280-10260'). 7. Rerun ball valve and return well to production. NOTE: All perforations to be shot under drawdown conditions. Perforation Depth G-2 RD Heasured 1365-1367' 1310-1312' 1330-13~2' 2020-2022' 2129-2131' 1350-1~52' 2100-2106' 10343-10345' 10262-10264' 10174-10176' 10345-10375' 10230-10260' 10180-10203' Vertical 1365-1367' 1310-1312' 1~30-1332' 2007-2009' 2109-2111' 1390-1392' 1350-1352' 2082-2088' 9353-9355' 9281-9283' 9202-9204' 9355-9380' 9251-9279' 9207-9224' Union Oil Company.el California Alaska Explo~ ion District unm n DOCUMENT TRANSMITTAL HAND DELIVERY September 23, 1982 TO: State of Alaska Oil & Gas Conservation Commissi on 3001 Porcupine Anchorage, Alaska ATTN: Wm. Van Allen FROM: R. C. Warthen Union Oil Co. P.O. Box 6247 Anchorage, Alaska REF: G-2RD 1 Blueline & 1 Sepia each of the following: DIL - 5" & 2" BHC-Sonic - 5" & 2" FDC Runs 1 & 2 - 5" FDC Run 2 - 2" CNL-FDC Runs 1 & 2 - 5" CNL-FDC Run 2 - 2" CBL Pass 2 - 5" CBL Pass 3 - 5" CBL-VDL - 5" Bond Index - WF - 5" VDL - 5" MSNL - 5" CDL-GR- 5" CDL-CN-GR- 5" Dir. Surveys: Tang, Rad of Curv & Ave Angle 1 -_~S Tape #65323 /'~/Please acknowledge receipt by signing and C/ ~°h~returgi~g c~py. of.this~.document SEP "Z 'S 198'Z Nms~ 0~ I,, Gms, Oons. oommlmmlofl ~' ",~ STATE OF ALASKA D CONSE,V^ ION 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 .:Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA 82-67 3. Address 8. APl Number PO BOX 6247 · ANCHORAGE AK 99502 s0733-20038-01 4. Location of well at surface 9. Unit or Lease Name Cond. 20, Leg 4, 1829' N & 1480' W of SE Cot, Sec 29 TRADING BAY UNIT · s.., r'roouc~rCg Interva~ 10. Well Number 2003' S & 793' W of N~ Cot Sec 32, * TBUS 6-2RD 2AtTotal~e 765I ~ of NE Cot Sec 32, * 330! p~h 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. McArthur River Field RT 99' MSL] ADL-17594 Hemlock Formation 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 6/06/82 7/06/82 7/21/82 143 feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10800' & 9741' 10745 & 9694 YES [] NO [] 294 feet MD ..... 22. Type Electric or Other Logs Run DIL-BH£-Sonie-GR. DIL-Sonic-GR. FDC-CNL-GR. CBL-VDL-GR · , . __ 23. CASING, LINER AND CEMENTING RECORD ....... SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8 ...... 0 1300 --- ' ...... 9 5/8 47 N-u0 0 6000 12 1/4 15;00 sxs --- 7 25; N-80 545;1 10767 , 8 1/2 IUUU sxs --- ' - · 24. Perforations open to Production (MD+TVD o~..Top and Bottom and 25. TUBING RECORD · :interval, size and number) .. S ZE DEPTH SET (MD) PACKER SET (MD) HB# MD TVD HPF 3 1/2" 10118 10068 1 10180-10203 9207'-9224' 8 .., ~......... 2 10230-10260 9251-9279' 8 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ... 3.. 10345,10375 9355-9~80!. . 8 · , .' · --DEPTH' INTERVAL, (MD) AMOUNT & KIND OF MATERIAL· USED 10745-TD ' 100 sxs , 10343-10345 100 sxs ~ '' ' .' : I , P 10262-10264 100 sXS ... '10174,1'0176 200 sxs - , , 27. PRODUCTION TEST Date~F'i~.~it Production , :: 7/21/82 ' ~'I Method, .of Operation (Flowing, gas lift, etc.) GaS lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF' WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/21/82 . ' :.24 TEST PERtOD I~... 3467 . 692 . 13 --- 200 Flow, Tub ng Casing Pressure CALCULATED OI!~-BBL : GAStMCF WATER-BBL OIL GRAVITY-APl (corr) Press.·.. 325.. ,. 1080 : 24~HOUR E{ATE ]]]~ 3467 692 13 33.1 28. CORE DATA NONE '- . . . ,.: ,.. AUG - 5 1982 : ' Alaska Oil & Gas Cons. Cornm~,ssi~n .. .~ ~. .; : ..... . . · Anchorage , · Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29.~ 30. GEOLOGIC MARKERS ~ : .~,;: ;..:;, ;'i~;".: : ~_~, ;'_. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. F/"D" Zone 4506 4298 HB (13=1600 BPD w/ 0% cut. T/"G" Zone 9329 8465 HB fl2 & 3=2500 BPD w/ 0.5% cut T/Hemlock 10,163 9194 HB #1, 2 & 3=2800 BPD w/ 0.5% cut B/Hemlock 10,745 9694 Final Rate=3500 BRD w/ 0.5% cut 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 sta*~e 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 LEASE Trading Bay Unit WELL NO. FIELD McArthur River Field UNION OIL COMPANY OF CALIFORNIA WELL RECORD LOCATION: G-2 RD Conductor #20, Leg #4, 1829'N & 1480'W of SE corner, Section 29~ TgN, R13W, SM. PERMIT NO. 82-67 SERIAL NO. ADL 17594 TD 10800' MD TVD 9741' DEVIATION (BHL) COMPANY ENGINEER Graham~ McAllister~ Bush SHEET A PAGE NO. SPUD DATE 6/6/82 CONTRACTOR Parker Drlq TYPE UNIT National 1320 COMP. DATE RIG NO. 7/21/82 DRILL PIPE DESCRIPTION 5" E & S-135 55 ELEVATIONS: WATER DEPTH 143' MSL RT TO OCEAN FLOOR RT TO MLLW 99' MSL RT TO DR~'L~,DECK RT TO PRODUCTIO~ D~CK ~ /2/~ ,~ . APRROVE~ CASING & TUBING RECORD SIZE ' WEIGHT THREAD GRADE DEPTH REMARKS 3/8" 61# Buttress 0-55 1300' Cmt'd w/ 2000 sxs cl "G" cmt. - 9 5/8" ' 47# Buttress N-80 6000' Cmt'd w/ 1850 sxs cmt. 7" 29# Buttress N-80 10767' Cmt'd w/ 1000 sxs cmt. 1/2" 9.2# Buttress N-80 Top 5491' 10117' Sinqle in "F-i" pkr ~ 10060'. PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 7/13/82 10343-10345' 10745' (ret) BS #5 7/14/82 10262-10264' 7/15/82 10174-10176' 7/19/82 10345-10375' Schlum 4" csq.guns Sqz'd w/ 100 sxs cmt. Schlum 4" csq quns Sqz'd w/ 100 sxs cmt. Schlum 4" csq guns Sqz'd w/ 200 sxs cmt. Hemlock Bench #3 Open 2 5/8" slimkone -7/20/82 10230-10260' " " Hemlock Bench #2 " " 10180-10203' " " Hemlock Bench #1 " " 10345-10375' " " Reperf HB #3 " 4 HRF " 10230-10260' " " Reperf HB #2 " " 7/71/82 10180-10203' " " Reperf HB #1 " " 10324' (ret) BS #6 10218' (ret) BS #7 10745' (ret) Rroduction INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS 7/20/82 10345-10375' 1600 0 Hemlock Bench " 10230-10260' 2488 .5% HB #2 & #3 " 10180-10203' 2800 .5% HB #1, #2, & #3 WE!L HEAD ASSEMBLY TYPE: CIW CASING HEAD: 12" 3000 x i3 3/8" SOW CASING HANGER: CASING SPOOL: TUBING HEAD: 12" 3000 x 10" 5000 DCB TUBING HANGER: Single 4 1/2" TUBING HEAD TOP: MASTER VALVES: CHRISTMAS TREE TOP CONN: LEASE .Trading Bay Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. G-2 RD FIELD SHEET D PAGE NO. McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9 5/8" CASING DETAIL OTS DESCRIPTION LENGTH BTM ,,, TOP ,,, 18 2O 2O 2O 59 9 5/8" B&W Float Shoe 9 5/8" 47# N-80 Butt Csg 9 5/8" B&W Float Collar 9 5/8" 47(! N-80 Butt Csg 9 5/8" Butt Pup 9 5/8" 47# N-80 Butt Csg 9 5/8" Butt Pup 9 5/8" 47# N-80 Butt Csg 9 5/8" Butt Pup 9 5/8" 47# N-80 Butt Csg 9 5/8" Butt Pup 9 5/8" 47# N-80 Butt Csg 9 5/8" Butt Cut-off Landed Below KB 1.58' 85.07' 1.68' 747.94 ' 23.43' 841.82' 7.30' 8~2.74' 843.57 ' 23.18' 2476.56 ' 33.84 ' 40.36' 6000.00' 5998.42' 5913.35' 5911.67 ' 5163.73 ' 5140.30 ' 4298.48' 4291.18 ' 3448.44' 3417.51 ' 2573.94' 2550.76' 74.20 ' 40.36 ' 5998.42 ' 5913.35 ' 5911.67' 5153.73 ' 5140.30 ' 4298.48 ' 4291.18' 3448.44 ' 3417.51 ' 2573.94 ' 2550.76 ' 74.20' 40.36' 0 5/8" landed on slips w/ 200,000#. LEASE Trading Bay Unit UNION OIL COMRANY OF CALIFORNIA WELL, RECORD WELL NO. G-2 RD FIELD SHEET D PAGE NO. McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 7" LINER DETAIL OTS DESCRIPTION LENGTH BTM TOP lO lO 88 7" Baker Float Shoe 7" 29# N-80 Butt Csg 7" Baker Float Collar 7" Baker Plug Landing Collar 7" 29# N-80 Butt Csg 7" Butt Pup 7" 29# N-80 Butt Csg 7" Butt Pup 7" 29# N-80 Butt Csg 7" Butt Pup 7" 29# N-80 Butt Csg XO Baker Tie-back Sleeve 7" Baker Liner Hanger 1.72' 45.33 ' 1.65' 1.35' 395.94 ' 22.05 ' 444.66' 15.83' 438.19' 16.00' 3884.78' .91' 5.70' 2.10' 10767.31 ' 10765.59 ' 10720.26' 10718.61 ' 10717.26' 10321.32' 10299.27' 9854.61 ' 9838.78' 9400.59' 9384.59' 5499.81 ' 5498.90' 5493.20' 10765.59' 10720.26' 10718.61 ' 10717.26' 10321.32' 10299.27' 9854.61' 9838.78' 9400.59' 9384.59' 5499.81' 5498.90' 5493.20' 5491.10' UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 17594 WELL NO. TBU G-2 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 12/7/81 10156' TD 9 5/8" C. 9453' 7" L 10155' TOP $ 9204' · FIW DAILY COST: $ 21,890 ACC COST: $ 21,890 AFE AMT: $ 225,000 2 12/8/81 10156' TD 9 5/8" C. 9453' 7" L 10155' TOP $ 9204' · , FIW DAILY COST: $ 16,610 ACC COST: $ 38,500 AFE AMT: $ 225,000 3 12/9/81 DAILY COST: ACC COST: AFE AMT: 4 12/10/81 DAILY COST: ACC COST: AFE AMT: ,, 10156' TD 9 5/8" C. 9453' 7" L 10155' TOP $ 9204' · , FIW $ 20,625 $ 59,125 $ 225,000 10156' TD 9 5/8" C. 9453' 7" L. 10155' TOP $ 9204' FIW $ 16,775 $ 75,900 $ 225,000 RU over TBUS G-2, conductor #2. Filled annulus & DP w/ FIW. Off- loaded DR, dialog unit, &misc piping off boat. RU Myer's WL. Pressure tested lub to 3000 psi. RIH w/ gauge cutter to 299' POOH. Retrieved tbg safety bali v~lve f/ 299'. RIH w/ 3 3/4" OD shifting tool. Hole was tight f/ 6000' to 6777' - could not get below 6777'. POOH. POOH w/ shifting tool. RIH w/ 3 1/2" swage - could not get below 8932'. POOH. RD Myer's WL. RU Dialog & RIH w/ 1 3/4" tbg perf gun. Perfed 5 holes in tbg ~ 8955' WLM (8975' tbg meas). Circ to kill well. Circ well w/ FIW to kill. Installed BPV's, removed tree, installed & tested BORE to 3000 psi. Pulled up to 167M# on tbg - would not pull loose. Attempted to pull BPV - could not. Removed BOPs, re- moved BPV, reinstalled & tested BOPs. RU Dialog & RIH w/ 3 11/16" tbg cutter - could not get below 6773'. Attempted to cut tbg ~ 6705' - no cut. POOH - cutter hung up ~ 5710'. Pulled out of rope socket. RIH w/ 2nd cutter & tagged ~ 5710'. Attempted to cut tbg ~ 5696' - tbg would not part. Ran 2 15/16" 4 1/2" DP Cutter & cut tbg ® 5698'. POOH & LD tbg. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 17594 WELL NO. TBU G-2 FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 12/11/81 DAILY COST: ACC COST: AFE AMT: 6 12/12/81 DAILY COST: ACC COST: AFE AMT: 7 12/13/81 DAILY COST: ACC COST: 10156' TD 9 5/8" C. 9453' 7" L. 10155', TOP ~ 9204' FIW $ 34,309 $ 110,209 $ 225,000 10156' TD 6450' ETD (Sd) 9 5/8" C. 9453' 7" L. 10155', TOP ~ 9204' FIW $ 25,113 $ 135,322 $ 225,000 10156' TD 6450' ETD (SAND) 9 5/8" C. 9453' 7" L. 10155', TOP ~ 9204' FIW $ 18,645 $ 153,967 RIH w/ fishing tools (overshot w/ 4 1/2" grapple & mill control, 3' extension, bumper sub, jars, i stand of 6 1/2" DC's) while pick- ing up 5" DP. Milled on top of tbg ~ 5705' DRM. Latched onto fish & jarred one time - grapple pulled off of fish. Could not latch onto fish. POOH. Chgd grapple & RIH. Latched onto fish & tripped jars ~ 125,000#- fish pulled loose. ROOH - pkr was dragging. POOH & LD fishing tools & 4 1/2" tbg (total tbg recovered was 9491'). RIH w/ RBP & set ~ 6498'. Spotted sd on top. Tagged sd ~ 6450'. Tested csg to 3000 psi. Had some gas in 9 5/8" X 13 3/8" annulus. Held 1500 psi on 9 5/8" csg while testing annulus to 2000 psi - ok. Picked up BOP & removed DC8 spool. Reinstalled 80P. Set 9 5/8" csg spear & pulled up on 9 5/8" csg. Removed csg slips. RU Dialog & ran freepoint on 9 5/8" csg. Found csg free e 1445', stuck ~ 1500'. Rehung 9 5/8" csg. Replaced DCB spool & tree. Rrep to move rig to TBUS G-5. AFE AMT: $ 225,000 4 SHEET D UNION OIL COMPANY OF CALIFORNIA WELL RECORD PAGE NO. 1 LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 1 5/19/82 10155 ' TD 6450' ETD (SAND) 9 5/8" C. 9454' 7" L. 9205-10155' DAILY COST: $ 30,121 ACC COST: $ 30,121 AFE AMT: $3,350,000 2 5/20/82 DAILY COST: ACC COST: AFE AMT: 10155' TD 9150' ETD (RET) 13 3/8" C. 2011' 9 5/8" C. 9454' 7" L. 10155-9205' $ 35,690 $ 65,811 $3,350,000 5/21/82 10155' TD 9150' ETD (Ret.) 13 3/8" C. 2011' 9 5/8" C. 9454', top $ 1400' ~IW DAILY COST: $ 41,807 ACC COST: $ 107,618 AFE AMT: $3,350,000 CO on TBUS G-2 RD $12:01 hrs. RU Rig 55 over G-2 (leg #4 conductor #20). Removed tree & DCB spool. NU 13 5/8" 3000# stack. Tested blind rams to 1500 psi. MU BR OS. RIH RU 5" DR. Tagged sand on BR ~ 6450' (BP $ 6498'). Comp testing BORE stack & csg to 1500 psi - ok. Rev out snd f/ 6450' to BP ~ 6498'. LatChed onto BP & POOH. RIH w/ 8 1/2" bit & 9 5/8" csg scrpr to TOL ~ 9205'. Circ'd. RIH w/ Howco E-Z drill cmt ret on 5" DP. Set ret $ 9150'. Pumped into Hemlock parrs ~ 18 CFM. Form held 1050 psi w/ pumps off. 'Sqz'd perfs f/ 9505-9535', 9560-9685' & 9705- 9818' W/ 200 sxs cmt. Sqz held 4500 psi w/ pumps off. POOH & LD excess DR. Completed laying down excess 5" d.p. RIH w/ 9 5/8" Tri-State mechanical cutter on 5" d.p. and cut 9 5/8" csg. $ 1400'. POOH. Latched onto 9 5/8" csg w/ spear and pulled up to 14OM# (5OM# over anticipated pick-up)-csg would not pull loose. Released spear and RIH w/ csg cutter. Attempted to cut csg $ 1405'. R00H-cutter knives had not opened. Latched onto csg w/ spear while waiting for hydraulic cutter. Worked 9 5/8" csg. loose. Broke circ. 'and circulated fluffy, viscous mud. POOH and laid down 32 jts. plus 2 cutoffs(1361.54') of 9 5/8" csg. RIH w/ 12 1/4" bit and 13 3/8" csg scraper and tagged 9 5/8" csg stub ~ 1400' Circ and POOH. R.~. Dresser At~as and ran CBL/VDL/GR log F/1400' to surface. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4 5/22/82 10155' TD 1370' ETD (Ret.) 13 3/8" C. 2011' 9 5/8" C. 9454', top ~ 1400'(Stub) 112 PCF 45 SEC DAILY COST: $ 91,372 ACC COST: $ 198,990 AFE AHT: $3,350,000 .5/23/82 10155' TD 1300' ETD (Est. TOC) 13 3/8" C. 2011' 9 5/8" C. 9454', top ~ 1400' (Stub) 108 PCF 38 SEC DAILY COST: ACC COST: $ 75,758 $ 274,748 AFE AMT: $3,350,000 Completed running CBL/VDL/GR log F/1400' to surface. RIH w/ squeeze gun and perf'd 4-1/2" HRF F/ 1380'---~"- to 1382' DIL. Well began to flow. Shut well in after W.L. out of hole. Had 4 bbl. gain and 500 psi on csg. (Indicating 1114 psi formation pressure). Bled pressure to 400 psi Shut well in and pressure built to 540 psi indicating gas migration. Pumped 20 Bbls. of FIW ~ 5.67 BPN 800 psi. Shut in pressure 'dropped to 490 psi. Continued to pump 20 Bbl. slugs of FIW when pressure increased to 540 psi. (Pumped a total of 80 Bbls). Pumped 50 Bbls of 120 pcf mud. Shut in pressure dropped F/ 540 psi to 490 psi. Opened choke and vented gas for 3 1/2 hrs. Pressure dropped from 490 psi to 100 psi. Pumped 242 Bbls, of 112 pcf mud down hole in 20 min. Had final shut in pressure of 0 psi, Opened blind rams and RIH w/ 13 3/8" cmt. ret, on W,L, Set ret ~ 1370' WL~, POOH w/ W,L. RIH w/ stinger on d.p. and tagged ret 1373' DPt, Circ. and cond mud above ret, Circ and displaced FIW w/ 112 pcf mud. Stabbed into ret. and pressured up to 400 psi-annulus remained full. Bled pressure off of d.p. and annulus began taking fluid. Unstabbed from ret. and circulated well-losing fluid. Bullheaded enough fluid to totally displace well (235 bbls) to ret. Well was quiet. POOH. RIH w/ RTTS on d.p. Attempted to locate csg. leak isolated leak between 1353' and 1373'. Set RTTS ~ 1241' and sqz'd csg leak w/ 300 sx cl "G" w/ 2% CaC12. Had a final rate of i BPN ~ 875 psi. Sqz held 750 psi after 4 min. CIP ~ 13:40 Hrs. Held pressure on sqz. 4 hrs. Released pkr and had gas breaking to surface. Cite well clean. Reset RTTS ~ 1241' and pressured up to 800 psi. Monitored pressure-had fallen to 250 psi ~ 24:00 Hrs. UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE ADL 17594 WELL NO. G-2 RD SHEET D PAGE NO. FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIPTIONS & RESULTS 6 5/24/82 10155' TD Cont to monitor DP press. Rress 1373' ETD (RET) bled f/ 800 psi to 45 psi. Released 13 3/8" C. 2011' RTTS & ROOH. RIH w/ 12 1/4" bit & 9 5/8" C. 9454', tagged TOC 8 1292'. CO soft omt f/ top 8 1400' (Stub) 1292' to 1320' & firm omt f/ 1320' lO1RCF 38 SEC to 1373'. C&C mud. ROOH. RIH w/ DALLY COST: $ 39,008 ACC COST: $ 313,756 AFE AMT: $3,350,000 13 3/8" RTTS w/ tail. Set RTTS $ 1350' tail ~ 1367' Put 650 psi on DP & 710 psi on ann to test sqz. DR press incr to 710 psi in 2 hrs while ann press remained constant. Released press & displ DR w/ FIW. Monitored press - DP press incr f/ 0 psi to 240 psi in 30 min. Opened well to prod. Rress fell to 0 psi & had no flow. Shut well in to monitor press. 7 5/25/82 DAILY COST: ACC COST: AFE AMT: 8 5/26/82 DAILY COST: ACC COST: AFE AMT: 10155 ' TD 1280' ETD (Est. TOC) 13 3/8" C. 2011' 9 5/8" C. 9454', TOp ~ 1400' (Stub) 101 PCF 38 SEC $ 60,425 $ 379,181 $3,350,000 10155' TD 1373' ETD (RET) 13 3/8" C. 2011' 9 5/8" C. 9454', TOp ~ 1400' (Stub) 98 RCF 41 SEC $ 35,314 $ 409,495 $3,350,000 Cont to monitor DP press - incr to 190 psi in 2 hrs. Filled DP w/ mud & reset RTTS ~ 1233' tail 8 1250'' ! · RU DA. Attempted to RIH w/ 2.6" perf gun - had restriction in lub. Replaced restriction w/ larger ID & RIH w/ 2.6" guns. Rerfed 4 1/2" HRF f/ 1365' to 1367' WLM to test BS #2. Had no press incr on DP. Press up DR to 620.psi & press bled to 610 psi in 20 min & stabilized. RU & RIH w/ 2.6" gun - could not get thru tbg tail. ROOH. RIH w/ 2 1/8" gun & perfed 4 HRF f/ 1310' to 1312' WLM for BS #3. ROOH w/ perf gun. Had no press incr. RD DA. Pumped into BS #3 hole w/ 35 CFM 8 600 psi. Form held 40 psi after 5 min. Mixed & sqz'd w/ 300 sxs cl "G" w/ 2% CaCL2. DisPl 278 sxs behind perfs w/ a final rate of 4 CFM ~ 750 psi. CIR 8 16:40 hrs. Held press on sqz & WOC. Cont to hold press on BS #3. Had final press of 250 psi. Filled DR w/ mud & ROOH. RIH w/ 12 1/4" bit & csg scraper & tagged TOC ~ 1286'. CO soft cmt to 1295'. WOC 3 hrs. CO med soft cmt f/ 1295' to 1310' & drld firm cmt f/ 1310' to 1325'. RIH to 1373' & CAC mud. POOH. RIH w/ 13 3/8" RTTS on 5" DR & set 8 1225', tail 8 1241'. Displ DR w/ FIW. Monitored DR press. Press incr f/ 345 psi to 440 psi in 15 min. Bled press to 0 Psi. Press built to 260 psi in i 1/2 hrs. Bled press to 0 psi. Press built to 70 psi in i hr (probably heat expansion). RU DA & RIH w/ 2 1/8" perf gun. Perfed 4 HRF f/ 1330' to 1332' & monitored press. Had no press incr. POOH w/ WL. POOH w/ RTTS. UNION OIL CONPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9 5/27/82 DAILY COST: ACC COST: AFE AMT: 10 5/28/82 DAILY COST: ACC COST: AFE AMT: 11 5/29/82 DAILY COST: ACC COST: AFE AMT: 10155' TD 1383' ETD (CMT) 13 3/8" C. 2011' 9 5/8" C. 9454', Top ~ 1400' (Stub) 98 PCF 40 SEC $ 26,339 $ 435,834 $3,350,000 10155' TD 1340' ETD (CMT) 13 3/8" C. 2011' 9 5/8" C. 9454', Top ~ 1400' (Stub) 96 PCF 40 SEC $ 41,026 $ 476,860 $3,350,000 10155' TD 1384' ETD (CMT) 13 3/8" C. 2011' 9 5/8" C. 9454', Top ® 1400' (Stub) 95 RCF 41 SEC $ 30,129 $ 506,989 $3,350,000 RIH w/ 11 3/4" X 10 1/4" BO shoe on jars & 8" DC's. Tagged ret ~ 1373'. BO ret 22". POOH. RIH w/ short catch OS w/ 4 3/8" grapple - POOH w/ no rec. Reran OS & attempted to catch fish - no rec. RIH w/ ll 3/4" OS w/ l0 1/8" grapple. Attempted to latch body of ret - no rec. Revampd BO shoe to have l0 1/8" ID. RIH & BO ret 22". POOH & rec 80% of ret. RIH w/ ll 3/4" X l0 1/8" shoe & BO remainder of ret. POOH & rec 10% of ret. RIH w/ BO shoe & rec 5% of fish. RIH w/ BO shoe & rec remaining 5% of fish & some cmt. RIH w/ 12 1/4" bit & drld cmt f/ 1377' to 1383'. (Note: Apparently the ret had failed during BS #2). Drld frm cmt f/ 1383-1387'. RIH & tagged stub $ 1399'. Circ & POOH. RIH w/ 13 3/8" RTTS. Displ DP w/ FIW w/ RTTS $ 1278' tail $ 1292' , · RTTS set while pumping & press incr to 1500 psi. Bled off press- had gas bubbling in ann. Shut well in & DP press incr. Discovered RTTS not set. Reset RTTS & DP press incr to 500 psi in 20 min. Bled off press quickly· Opened bypass & circ ann. Reset RTTS $ 1382' (could~ not get tail into csg stub). Had no flow in DP. Reset RTTS $ 1282' - had entry to DP Reset RTTS $ 1324' · , 1340' & 1370' - had entry to DP each time. RIH & worked tail into stub. Reset RTTS $ 1399' - had no entry· Circ mud & reset RTTS $ 1340'. Pumped into perfs (f/ 1380-1382' & 1365-1367' WLM) w/ 28 CFM $ 850 psi Reset RTTS $ 1275' · , tail $ 1289'. Mixed & sqz'd w~_100_~ sxs cl "G" w/ 2% CaCL2, CIP $ 23:25 hfs 5/28/82. Held press on cmt for 9 hrs. Press bled to 350 psi (from 800 psi). Re- leased RTTS & circ clean. POOH. RIH w/ 12 1/4" bit & 13 3/8" csg scrpr. Tagged TOC $ 1314' CO green cmt f/ 1314' to 1321;. WOC. CO soft cmt f/ 1321-1340'. WOC. CO soft cmt f/ 1340-1344' - WOC. C&C mud. Drld firm cmt f/ 1344' to 1384'. RIH to 1399'. C&C mud. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 12 5/30/82 DAILY COST: ACC COST: AFE AMT: 5/31/82 DAILY COST: ACC COST: AFE AMT: 14 6/1/82 DAILY COST: ACC COST: AFE AMT: 10155' TD 9150' ETD (RET) 13 3/8" C. 2011' 9 5/8" C. 9454', Top $ 1400' (Stub) 90 PCF 58 SEC $ 51,897 $ 558,886 10155' TD 9150' ETD (RET) 13 3/8" C. 2011' 9 5/8" C. 9454', TOp $ 1400' (Stub) 90 PCF 45 SEC $ 26,376 $ 582,864 $3,350,000 10155' TD 9150' ETD (RET) 13 3/8"'C. 2011' 9 5/8" C. 9454', Top ~ 1400' (Stub) 88 PCF 45 SEC $ 48,455 $ 631,319 $3,350,000 C&C mud. POOH. RIH w/ RTTS to 1270' Displ DP w/ FIW & set RTTS. Bled ~ff press in DP-- had no entry. Press up DP to 700 psi (.95 psi/ft grad) - held ok. Rev circ FIW out of DP & POOH. RIH w/ 8 1/2" bit to 1958' - DP was flowing back. Circ & POOH. Installed float. RIH to 5000'. C&C mud. POOH. RIH w/ 9 5/8" RTTS to 1922'. Displ DR w/ FIW. Set RTTS $ 1922'. RU test manifold & lub. RIH w/ 2' of 2 1/8" perf gun & perf f/ 2020' to 2022' WLM (below 13 3/8" shoe). Had no apparent entry. Released RTTS & rev out FIW. Displ DR w/ gas & reset RTTS. Bled off DR press - had no entry. Filled DR w/ mud & press up to 1150 psi (1.2 psi/ft grad) - would not take fluid. RU DA &perfed f/ 2129' to 2131' WLM - had no entry. Press up DR to 1500 psi (1.33 psi/ft grad) - would not break down. POOH w/ RTTS. RIH w/ 13 3/8" RTTS to 1271'. Displ DP w/ FIW & set RTTS. RIH w/ 2' of 2 1/8" guns & perfed 4 HPF f/ 1390' to 1392' WLM - had no entry. Broke down holes w/ 1450 psi. Pumped in w/ 6 CFM ~ 1300 psi (a total of 100 cf of fluid pumped). Press bled to 750 psi in 5 min. Bled press to 0 psi. Released RTTS & rev out FIW. Displ DR w/ gas & reset RTTS. Bled press to 0 psi - had no press buildup. Opened well & had weak blow to bubble bucket. RIH w/ 2' of 2 1/8" perf guns & perfed f/ 1350-1352' WLM. Cont to have weak blow. Monitor well for flow - had weak blow. Rev circ FIW out of DP. POOH RU DA & RIH w/ 4" csg gun. Perf 4 1/2" HPF f/ 2100' to 2106' WLM - no entry. POOH w/ WL. RIH w/ 9 5/8" RTTS & set ~ 1953'. Displ DP w/ gas. Bleed off press & moni- tor flow - had no entry. Open by- pass & displ DP w/ mud. Press up & broke down perfs w/ 850 psi. Pumped in w/ 12 CFM $ 1150 psi. Put 50 CF of mud away. Press bled to 600 psi in 10 min. Displ DP w/ gas. Bled off press & had light blow. SI well for 1 hr - had no press incr. Opened bypass & rev circ mud. POOH w/ RTTS. RU DA. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 15 6/2/82 DAILY COST: ACC COST: AFE AMT: 613182 10155' TD 9100' ETD (CMT) 13 3/8" C. 2011' 9 5/8" C. 9454', TOp ~ 1400' (Stub) 88 PCF 68 SEC $ 27,601 $ 661,318 $3,350,000 1 O155 ' TD 9100' ETD (CMT) 13 3/8" C. 2011' 13 3/8" W. 1300-1326' 9 5/8" C. 9454', TOp 8 1400' (Stub) 87 PCF 360 SEC DAILY COST: $ 43,569 ACC COST: $ 704,887 AFE AMT: $3,350,000 17 6/4/82 10155' TD 9100' ETD (CMT) 13 3/8" C. 2011' 13 3/8" W. 1300-1360' 9 5/8" C. 9454', TOp $ 1400' (Stub) 87 PCF 340 SEC DAILY COST: $ 39,642 ACC COST: $ 744,529 AFE AMT: $3,350,000 18 6/5/82 DAILY COST: ACC COST: AFE AMT: 10155' TD 1260' ETD (CMT) 13 3/8" C. 1300' (Top of Window) 87 RCF 123 SEC $ 42,960 $ 787,489 $3,350,000 DA ran FDC-CNL-GR log f/ 3000-1000'. ROOH - pulled out of rope socket while pulling into lub. Tool fell down hole. Reheaded line and ran GR-CCL log f/ 3000-1000'. RIH w/ 8" OS w/ 2 3/8" grapple on WL - worked over & engauged fish ~ 8998'. POOH & LD fish. RIH w/ 2' of 4" csg guns & perfed 4-1/2" HPF f/ 1390-1392' CBL. POOH & RD WL. RIH W/ 13 3/8" RTTS on 5" DP & set RTTS ~ 1274', tail ~ 1287'. Opened bypass & displ DP w/ gas to 1120'. Closed bypass & opened well to bleed off. Had light blow into bubble bucket. Shut in & press built to 2 psi in 1 hr. Filled DP w/ mud. Released RTTS & rev circ clean. C&C mud for section milling. C&C mud. POOH. RIH w/ 13 3/8" sec- tion mill & cut out ~ 1300'. Milled window in 13 3/8" csg f/ 1300, to 1326' · Cont to mill window in 13 3/8" csg f/ 1326-1339'. Tools began to torque up. POOH - found btm stabi- lizer loose. RIH w/ mill #2 & cut window in 13 3/8" csg f/ 1339-1360'. Circ clean & POOH. POOH w/ section mill. RIH w/ 3 1/2" tbg tail on 5" DP & hung ~ 1475'. Mixed & equalized in 200 sxs of cl "G" w/ 2% CaCL2 and 10% sd. CIP ~ 02:15 hrs. ROOH & WOC. RIH w/ 12 1/4" bit & tagged cmt after 14 hrs ~ 1206'. CO soft to med cmt f/ 1206- 1250'. WOC. Drld frm cmt f/ 1250- 1260'. WOC. UNION OIL COMRANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DAlE ETD DETAILS OF OPERATIONS, DESCRIRTIONS & RESULTS 19 616182 1407'/102' 1305' KOP 13 3/8" Window 1300-1360' 13 3/8" C. 1300' 86 PCF 72 SEC DAILY COST: $ 37,010 ACC COST: $ 824,499 AFE AMT: $3,350,000 20 6/7/82 DAILY COST: ACC COST: AFE AMT: 21 6/8/82 DAILY COST: ACC COST: AFE AMT: 22 6/9/82 DAILY COST: ACC COST: AFE AMT: 1701 '/294' 1305' KOP 13 3/8" C. 1300' (Top of Window) 86 PCF 55 SEC $ 55,506 $ 880,005 $3,350,000 2388'/687' 1305' KOP 13 3/8" C. 1300' 86 PCF 65 SEC $ 37,650 $ 917,655 $3,350,000 2417'/29' 13 3/8" C. 1300' 86 PCF 60 SEC $ 37,389 $ 955,044 $3,350,000 Cont to WOC. Drld hrd cmt f/ 1260'- 1305'. Circ & POOH. RIH w/ bit #2 on BHA #1 for Dyna-drill run #1. Oriented tool w/ Sperry Sun gyro. Dyna-drilled 12 1/4" hole f/ 1305'- 1407'. Dyna drld 12 1/4" f/ 1407-1601' (used gyTo to 1455' then used steer- ing tool). Plugged dyna drl w/ fine coal twice & had to trip to CO. ROOH w/ dyna drl. RIH w/ bit #3 on BHA #2 (90' belly) & reamed dyna- drl run f/ 1305-1601'. Dir drld 12 1/4" hole f/ 1601-1701'. Surveys: 1437' 3° 15' S32E 1495' 6° 15' S22E 1543' 7° 30' S10E 1591' 8° 30' S22E 1671' 10° 30' S22E Dir drld 12 1/4" hole f/ 1701-2388'. Last surv showed magnetic interfer- ence. Re~iLsurv - would not check. TBUS Ci~-C--CI~6-~'~-O1/~e tm wait on gyro surveys. Trip out was ged. RIH & circ mud - rec larg~- a~nts of clay in large chunks. RJlled ball valve in G-3. RU Sperry Sun & ran gyro survey to 5000'. Gyro surveyed TBUS G-3 to 5000' & G-2 to 2365'. Gyro revealed a 220' correction in well location on G-3 ~& bit #3RR1 (60' pendulum dropping assy). Dir drld 12 1/4" hole f/ 2388-2417'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 23 6/10/82 DAILY COST: ACC COST: AFE AMT: 24 6/11/82 DAILY COST: ACC COST: AFE AMT: 25 6/12/82 DAILY COST: ACC COST: AFE AMT: 3017'/600' 13 3/8" C. 1300' 86 PCF 81 SEC $ 46,826 $1,001,870 $3,350,000 Single shot gyros: 3930'/913' 13 3/8" C. 1300' 88 PCF 64 SEC $ 49,734 $1,051,604 $3,350,000 4235'/305' 13 3/8" C. 1300' 88 PCF 68 SEC $ 44,420 $1,096,024 $3,350,000 26 6/13/82 4715'/480' 13 3/8" C. 1300' 86 PCF 55 SEC DAILY COST: $ 48,425 ACC COST: $1,144,449 AFE AMT: $3,350,000 Dir drld 12 1/4" hole f/ 2417' to 2455' using 20M# & 50 RPM. POOH. RIM w/ bit #4 on BHA #4 (locked up w/ 10' lead collar). Reamed f/ 2440-2455'. Dir drld 12 1/4" hole f/ 2455' to 3017'. Circ& POOH. Surveys: Use.multishot gyro down to 2365'. 2432' 26° 15' S26E 2527' 25° S23E 2651' 24° 45' S21E 2835' 24° 30' S21E (magnetic) 2977' 24° S22E (magnetic) Trip for bit change. RIH w/ bit #5 on BHA #4 & reamed f/ 2977' to 3017. Dir drld 12 1/4" hole f/ 3017' to 3597'. POOH. RIH w/ bit #6 on BHA #5 (30' belly) & dir drld 12 1/4" hole f/ 3597' to 3930'. Surveys: 3180' 23° 30' S23E 3368' 23° S23E 3557' 22° 30' S23E 3668' 22° 45' S22E 3865' 22° S22E Dir drld 12 1/4" hole f/ 3930' to 4142' ROOH. RIH w/ bit #7 on BHA #6 fo~ Dyne drill run #2. Oriented to 50° rt of high side & dyne drld 12 1/4" hole f/ 4142' to 4235'. ROOH. Surveys: 3989' 22° S21E 4112' 21° S19E 4195' 22° S20E Completed ROOH w/ dyne drl. RIH w/ bit #8 on BHA #7 (60' belly). Reamed f/ 4142' to 4235' & dir drld 12 1/4" hole f/ 4235' to 4609'. ROOH. RIH w/ bit #9 on BHA #8 (30' belly) & reamed f/ 4579' to 4609'. Dir drld 12 1/4" hole f/ 4609' to 4715'. Had slow penetration w/ new bit. Circ& POOH. Surveys: 4195' 22° S20E 4298' 23° S13E 4392' 25° Si2E 4485' 27° Sll 1/2E 4597' 29° Sll 1/2E 4685' 30° Sll 1/2E UNION OIL COWPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 27 6/14/82 DAILY COST: ACC COST: AFE ANT: 28 6/15/82 DAILY COST: ACC COST: AFE ANT: 29 6/16/82 DAILY COST: ACC COST: AFE ANT: 30 6/17/82 DAILY COST: ACC COST: AFE ANT: 31 6/18/82 DAILY COST: ACC COST: AFE ANT: 5167 '/452 ' 13 3/8" C. 1300' 87 PCF 105 SEC $ 36,148 $1,180,597 $3,350,000 5660'/493' 13 3/8" C. 1300' 88 PCF 90 SEC $ 47,127 $1,227,724 $3,350,000 5993'/333' 13 3/8" C. 1300' 87 PCF 69 SEC $ 36,395 $1,264,119 $3,350,000 6000'/7' 13 3/8" C. 1300' 87 PCF 76 SEC $ 88,250 $1,352,369 $3,350,000 6000'/0' 13 3/8" C. 1300' 9 5/8" C. 6000' 87 PCF 70 SEC $ 321,297 $1,673,666 $3,350,000 ROOH for bit change. RIH w/ bit #10 ~x on BHA #8. Reamed f/ 4655' to 4715'. Dir drld 12 1/4" hole f/ 4715' to 5063'. (Note: Began to GL G-3 & had communication to G-2 RD. Bled off G-3). ROOH. RIH w/ bit #11 on BHA #9 (locked up assy) & reamed f/ 4999' to 5063'. Dir drld 12 1/4" hole f/ 5063' to 5167'. Surveys: 4838' 31° S 11 1/2E 4994' 31° 30' SllE Directionally drilled 12 1/4" hole f/ 5167' to 5451'. Trip for bit change. RIH w/ bit #12 on BHA #9 and reamed f/ 5421' to 5451' Directionally drilled 12 1/4~' hole f/ 5451' to 5660'. Surveys: 5152' 31° 30'S 12 1/2E 5343' 31° 30' S 12 1/2E 5532' 31° S 12E 5646' 30° 30' S 11 1/2E Dir drld 12 1/4" hole f/ 5660-5796'. Trip for bit change. RIH w/ bit #13 on BHA #9 & reamed f/ 5751-5796'. Dir drld 12 1/4" hole f/ 5796-5993'. Surveys: 5751' 300 15' SllE 5873' 29° 45' SlOE 5955' 29° 30' SlOE Oir drld 12 1/4" hole f/ 5993' to 6000'. Circ & POOH. RU Schlum & ran DIL-BHC-Sonic-GR log f/ 6000' to 1300'. Ran FDC-CNL-GR log f/ 6000' to 1300'. RD Schlum. RIH w/ bit #13 on BHA #9 to 6000'. CAC ~hole for 9 5/8" csg. ROOH. In- stalled 9 5/8" pipe rams. RU to run 9 5/8" csg. RU to run csg. Ran 141 jts & 4 pups of 9 5/8" 47# N-80 butt csg. Landed w/ FS ~ 6000' FC ~ 5912' Circ , · hole 4 hrs. Lead w/ 100 F3 caus- tic water & 100 F3 of fresh water ahead of 1350 sxs cl "G" w/ 2 1/2~ prehydrated gel & 550 sxs cl "G" w/ 1% CFR-2. Dropped the top plug & displ w/ 100 F-3 of fresh water & 2440 F3 of mud to bump plug w/ 2500 psi. Floats held ok & had good cmt returns to surf. CIR ~ 17:40 hrs. Lifted BOPE & landed csg on slips w/ 200,000#. Cut off excess csg & began installing DCB ~nnnl. UNION OIL COMRANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 10 LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 32 6/19/82 DAILY COST: ACC COST: AFE AMT: 33 6/20/82 6010'/10' 13 3/8" C. 1300' 9 5/8" C. 6000' 64 PCF 48 SEC $ 35,999 $1,709,665 $3,350,000 6356 '/346' 13 3/8" C. 1300' 9 5/8" C. 6000' 68 PCF 65 SEC DAILY COST: $ 70,188 ACC COST: $1,779,853 AFE AMT: $3,350,000 34 6/21/82 DAILY COST: ACC COST: AFE AMT: 35 6/22/82 6547'/191' 13 3/8" C. 1300' 9 5/8" C. 6000' 70 PCF 63 SEC $ 53,222 $1,838,075 $3,350,000 7090'/543' 13 3/8" C. 1300' 9 5/8" C. 6000' 70 PCF 74 SEC DAILY COST: $ 32,539 ACC COST: $1,865,614 AFE AMT: $3,350,000 36 6/23/82 DAILY COST: ACC COST: AFE AMT: 7538'/448' 13 3/8" C. 1300' 9 5/8" C. 6000' 70 PCF 67 SEC $ 38,735 $1,904,349 $3,350,000 Cont to install~X 10" 5M CIW DCB s]~;:~:~]--.~t 1~ ~m~h~d down csg while~~ BOPE & tested blind rams & surf equip. RIH w/ 8 1/2" magnet on DP to 3000'. POOH to remove float - found hammer head on magnet. RIH w/ bit #14 on~BHA #10 (slick CO assy) to 5900'. Tested BOPE to 3000 psi - test WAA by OGCC. Drld out FC ~ 5912' & cmt to 5985'. Tested 9 5/8" csg to 3000 psi - ok. Drld out FS ~ 6000' & 10' of new hole to 6010'. Performed leakoff test - shoe held 96 RCF mud equiv. Circ & build new mud system. Old system contaminated by solids & cmt. ROOH. RIH w/ bit #15 on BHA #11 & dir drld 8 1/2" hole f/ 6010' to 6356'. Survey: 6096' 28° 45' S 8 1/2E 6249' 26° 30' S6E 6311' 26° 15' S4E POOH. 'RIH w/ bit #16 on BHA #12 for Dyna drill run #3. RU w/ steering tool & oriented dyna-drill 70° left of high side. Dyna-drld 8 1/2" hole f/ 6356' to 6428'. ROOH. RIH w/ bit #17 on BHA #13 (30' belly). Reamed f/ 6356' to 6428' & dir drld 8 1/2" hole f/ 6428' to 6547'. Survey: '6517' 28o 45' S15E Compl trip out of hole. RIH w/ bit #18 on BHA #14 (locked up assy) & dir drld 8 1/2" hole f/ 6547' to 6949'. POOH. RIH w/ bit #19 on BHA #15 (tandem NB stab w/ 30' belly). Dir drld 8 1/2" hole f/ 6949 -7090 . Surveys: 6621' 29° S16E 6904' 28° S13E Dir drld 8 1/2" hole f/ 7090-7199'. Trip for bit change. RIH w/ bit #20 on BHA #15 & reamed f/ 7149' to 7199'. Dir drld 8 1/2" hole f/ 7199' to 7486'. Trip for bit chng. RIH w/ bit #21 on BHA #15 & reamed f/ 7347' to 7486'. Dir drld 8 1/2" hole f/ 7486' to 7538'. Surveys: 7164' 27° 30' SllE 7451' 28° 30' S12E 7633' 28° 30' S13E UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 11 LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 37 6/24/82 7869'/331' 13 3/8" C. 1300' 9 5/8" C. 6000' 70 PCF 66 SEC DAILY COST: $ 42,768 ACC COST: $1,947,117 AFE AMT: $3,350,000 38 6/25/82 DAILY COST: ACC COST: AFE AMT: 39 6/26/82 DAILY COST: ACC COST: AFE AMT: 40 6/27/82 DAILY COST: ACC COST: AFE AMT: 41 6/28/82 DAILY COST: ACC COST: 8124'/255' 13 3/8" C. 1300' 9 5/8" C. 6000' 71PCF 58 SEC $ 34,731 $1,981,848 $3,350,000 8427'/303' 13 3/8" C. 1300' 9 5/8" C. 6000' 72 PCF 62 SEC $ 37,871 $2,019,719 $3,350,000 8734'/307' 13 3/8" C. 1300' 9 5/8" C. 6000' 74 PCF 51 SEC $ 39,668 $2,059,387 $3,350,000 8965'/231' 13 3/8" C. 1300' 9 5/8" C. 6000' 75 PCF 57 SEC $ 34,024 $2,093,411 Dir drld 8 1/2" hole f/ 7538-7668'. POOH. RIH w/ bit #22 on BHA #15. C0 bridge ~ 7360'. Reamed f/ 7608' to 7668'. Dir drld 8 1/2" hole f/ 7668' to 7869'. Circ& POOH. Survey: 7834' 29° S12E RIH w/ bit #23 on BHA #15. Ream tight spot ® 7465'. Dir drl 8 1/2" hole f/ 7869' to 8012'. Survey & POOH. RIH w/ bit #24 on BHA #16. Ream f/ 7933' to 8012'. Dir drill 8 1/2" hole f/ 8012' to 8124'. Surv & POOH. POOH. RIH w/ bit #25 on BHA #16. Ream to btm f/ 8094' to 8124'. Dir drld 8 1/2" hole f/ 8124' to 8325'. Survey & POOH. Tight on trip out ~ +8139' (15OM# over PU). RIH w/ bit #26 on BHA #17. Ream to btm f/ 8287 to 8325'. Dir drld 8 1/2" hole f/ 8325' to 8427'. Survey & POOH. POOH. RIH w/ bit #27 on BHA #18. Ream f/ 8367' to 8427'. Dir drl 8 1/2" hole f/ 8427' to 8632'. Sur- vey & POOH. RIH w/ bit #28 on BHA #18. Ream f/ 8592' to 8632'. Dir drl 8 1/2" hole f/ 8632' to 8734'. Dir drld 8 1/2" hole f/ 8734' to 8772'. Surv & POOH. RIH w/ bit #29 on 8HA #19. Ream f/ 8652' to 8772'. Dir drld 8 1/2" hole f/ 8772-8965'. Surv & POOH. RIH w/ bit #30 on BHA #20 for dyna drill run #4. AFE AMT: $3,350,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 12 LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 42 6/29/82 DAILY COST: ACC COST: AFE AMT: 43 6130182 9123'/158' 13 3/8" C. 1300' 9 5/8" C. 6000' 73 PCF 45 SEC $ 52,433 $2,145,844 $3,350,000 9512'/389' 13 3/8" C. 1300' 9 5/8" C. 6000' 72 PCF 59 SEC DAILY COST: $ 27,705 ACC COST: $2,173,549 AFE AMT: $3,350,000 44 7/1/82 DAILY COST: ACC COST: AFE AMT: 45 7/2/82 9727'/215' 13 3/8" C. 1300' 9 5/8" C. 6000' 71PCF 67 SEC $ 33,596 $2,207,145 $3,350,000 10028'/301' 13 3/8" C. 1300' 9 5/8" C. 6000' 72 PCF 62 SEC DAILY COST: $ 32,500 ACC COST: $2,239,645 AFE AMT: $3,350,000 46 7/3/82 10227'/199' 13 3/8" C. 1300' 9 5/8" C. 6000' 72 PCF 64 SEC DAILY COST: $ 42,204 ACC COST: $2,281,849 AFE AMT: $3,350,000 47 7/4/82 DAILY COST: ACC COST: 10430'/203' 13 3/8" C. 1300' 9 5/8" C. 6000' 72 PCF 68 SEC $ 33,014 $2,314,863 Orient dyna drl 90°rt of HS for rt hand turn. Dyna drl run #4: dyna drld f/ 8965-9026' (lost elec power for 1/2 hr while dyna drlg e 9001' & could not move pipe - had no prob RU DR after power resumed). POOH. RIH w/ bit #31 on BHA #21 (down for 3 1/2 hfs working on elect power to rotary). Reamed dyne drill run f/ 8965' to 9026'. Dir drld 8 1/2" hole f/ 9026'-9123'. POOH. RIH w/ bit #32 on BHA #22. RIH w/ bit #32 on BHA #22. Reamed f/ 9070' to 9123'. Dir drld 8 1/2" hole f/ 9123' to 9512'. Dir drld 8 1/2" hole f/ 9512' to 9527'. Survey & POOH. RIH w/ bit #33 on BHA #22. Reamed 45' to btm. Dir drld 8 1/2" hole f/ 9527' to 9727'. Dir drld 8 1/2" hole f/ 9727' to 9776'. Survey & POOH. RIH w/ bit #34 on BHA #23. Reamed 20' to btm. Dir drld 8 1/2" hole f/ 9776' to 10028'. Dir drld 8 1/2" hole f/ 10028' to lOll3'. Survey & POOH. RIH w/ bit #35 on BHA #24. Dir drld 8 1/2" hole f/ lOll3' to 10227'. Dir drld 8 1/2" hole f/ 10227' to 10430'. Survey & POOH. RIH w/ bit #36 on 8HA #25. Spot reamed f/ 10200' to 10391'. AFE AMT: $3.350.000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 13 LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 48 7/5/82 10736'/306' 13 3/8" C. 1300' 9 5/8" C. 6000' 71PCF 81 SEC DAILY COST: $ 30,219 ACC COST: $2,345,082 AFE AMT: $3,350,000 49 7/6/82 10800' TD 13 3/8" C. 1300' 9 5/8" C. 6000' 72 PCF 74 SEC DAILY COST: $ 26,299 ACC COST: $2,371,381 AFE AMT: $3,350,000 50 7/7/82 10800' TD 10737' ETD (JUNK) 13 3/8" C. 1300' 9 5/8" C. 6000' 72 PCF 80 SEC DAILY COST: $ 35,863 ACC COST: $2,407,244 AFE AMT: $3,350,000 51 7/8/82 DAILY COST: ACC COST: AFE AMT: 52 7/9/82 DAILY COST: ACC COST: AFE AMT: 10800' TD 10770' ETD (JUNK) 13 3/8" C. 1300' 9 5/8" C. 6000' 73 PCF 83 SEC $ 26,391 $2,433,635 $3,350,000 10800' TD 5083' ETD (tOC) 9 5/8" C. 6000' 7" L. 5491' to 10767' 72 PCF 54 SEC $ 193,049 $2,626,684 $3,350,000 Reamed f/ 10391' to 10430'. Dir drl 8 1/2" hole f/ 10430' to 10736'. Drld 8 1/2" hole f/ 10736-10800'. Made short trip to shoe. Prep to log. RIH w/ DIL-Sonic & GR. Logged f/ 6000-10800' (10793' WLM). Ran back to btm & started logging out. Stuck tool ~ 10664', btm ® 10727'. Worked WL. PU OS & grapple on 5" DP. RIH using clamp to strip over WL. Locate top of fish 8 10737'. ROOH cutting WL. Lost clamp 7 stds off btm - rec same l0 stds off btm. Fin ROOH cutting line - no fish rec. Rec all WL. RIH w/ 3 5/8" grapple. Locate fish 8 10750'. Unable to swallow into grapple. C&C mud, ROOH. RIH w/ bit. Tag fish 8 10770'. RU to run 7" liner. 8~]L29# N-80 butt liner. Circ & prep to cmt while reciprocating liner. Cmt'd 7" liner w/ 1000 sxs "G" w/ 6% KCL, .6% Halad 22A & 1.0% CFR-2. Reciprocated liner until drag increased. Landed liner w/ shoe 8 10767' & top of tie back sleeve 8 5491%. Displ cmt w/ mud & bumped plug. CIR 8 12:00 hrs. ROOH. RIH w/ 8 1/2" bit & 9 5/8" csg scraper. Tagged omt 8 4907'. CO cmt stringer f/ 4907' to 5083'. UNION OIL COMRANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 14 LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 53 7/10/82 10800' TD 10745' ETD (TOC) 9 5/8" C. 6000' 7" L. 5491' to 10767' 69 PCF 49 SEC DAILY COST: $ 24,659 ACC COST: $2,651,343 AFE AMI: $3,350,000 54 7/11/82 10800' TD 10745' ETD (TOC) 9 5/8" C. 6000' 7" L. 10767, Top ~ 5491' 69 PCF 48 SEC DAILY COST: $ 32,664 ACC COST: $2,684,007 AFE AMT: $3,350,000 55 7/12/82 DAILY COST: ACC COST: AFE AMT: 56 7/13/82 DAILY COST: ACC COST: AFE AMT: 10800' ID 10745' ETD (C~T) 9 5/8" C. 6000' 7" L. 10767', TOp ~ 5491' 69 PCF 44 SEC $ 22,452 $2,706,459 $3,350,000 10800' TD 10305' ETD (CMT RET) 9 5/8" C. 6000' 7" L. 10767', TOp ~ 5491' 69 PCF 42 SEC $ 21,389 $2,727,848 CO cmt f/ 5083' to TOL ~ 5491'. ROOH. RIH w/ 6" bit & 7"~csg scrpr. C0 7" liner to 10717' FC. Drld FC ~ 10717' & C0 cmt to 10745' ETD. Circ clean & R00H. Ran Schlum FDC-CNL-GR log f/ 5705' to 10745'. Compl running CBL log. RIH w/ gyro surv - tool stopped ~ 7500'. ROOH & changed centralizer. RIH & ran gyro surv f/ 10745' to surf. RD Sperry Sun. RIH w/ 7" retrv pkr & stimula- tion valve on dry DR. Set pkr ~ 5462'. Load DR w/ 1300 psi gas press. Opened stimulation valve & bled off gas to 0 psi - had vigorous blow. Released pkr. ROOH w/ dry test tools. Rress charts were inoperative after stimulation valve was opened. RU Schlum. RIH w/ CBL-VDL-GR log - stopped ~ 9385'. ~00H. RIH w/ 6" bit on 7" csg scrpr on 3 1/2" DP to 10745'. Circ clean & POOH. Reran CBL-VDL-GR log f/ 10745' to 5400'. Ran GR & OB to 10745'. Basket rec some wiper plug junk. RD Schlum. RIH w/ 7" Baker retry w/ stimulation valve. Set pkr ~ 10688'. Rress up backside to 3000 psi for 15 min. Held ok. RU test manifold. Loaded DP w/ 1300 psi gas. Bled off gas in DP to dry test liner shoe - had vigorous blow in 15 min. Released pkr & rev out l0 bbls of oil contam fluid. Rress up to 3000 psi - bled to 2500 psi in l0 min. Reset pkr & broke dwn shoe w/ 3600 psi. Rumped in w/ 3.6 BPM ~ 3000 psi. Rress bled to llSO psi in l0 min. Released pkr & ROOH. RIH & set cmt ret on DR ~ 10745'. Broke down shoe w/ 3000 psi. RI w/ 1.25 BPM ~ 3050 psi. Form held 2300 psi w/ pumps off 8 min. Mixed & sqz'd w/ 100 sxs cl "G" w/ 1% CFR-2, .3% Helad 22A & 3% KCL. Displ 74 sxs below ret w/ a final rate of .25 BPN ~ 4200 psi. Sqz held 4000 psi w/ pumps off l0 min. CIR ~ 15:lO hrs. Rev out 26 sxs & ROOH. RU Schlum & perfed 4-1/2" HRF using 4" csg guns f/ 10343' to 10345' DIL. RD Schlum. RIH & set cmt ret ~ 10305'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 15 LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 57 7/14/82 10800' TD Broke down perfs f/ 10343-10345' DIL 10199' ETD (CMT RET) w/ 5000 psi. Rumped in w/ i BRM 8 9 5/8" C. 6000' 3800 psi. Form held 2350 psi w/ 7" L. 10767', Top ® 5491' pumps off 7 min. Mixed & sqz'd for. 69 RCF 42 SEC isolation BS #5 w/ 100 sx cl "G" w/ $ 25,620 $2,753,468 DAILY COST: ACC COST: AFE AMT: $3,350,000 1% CFR-2, .3% Halad 22A and 3% KCL. Displ 24 sxs below ret w/ a final rate of .125 BRM 8 5000 psi. Sqz held 4850 psi w/ pumps off l0 min. CIR 8 01:45 hrs. Rev out 76 sxs cmt. POOH & WOC 8 hrs. RU Schlum & perfed 4-1/2" HPF f/ 10262-10264' DIL for BS #6. RIH -& set cmt ret on WL ~ 10218' DIL. RD Schlum. RIH w/ stinger on DR & tagged ret ¢ 10199' DRM. Stabbed into ret & broke down perfs w/ 4500 psi. Rumped io w/ 2.5 BRM ~ 3200 psi. Form held 550 psi after 12 min. Mixed & sqz'd w/ 100 sxs cl "G" w/ 1% CFR-2, .3% Halad 22A, and 3% KCL. Displ 34 sxs below ret w/ a final rate of .125 BRM ~ 5400 psi. Sqz held 5250 psi after 6 min. CIR ~ 18:20 hrs. Rev out 66 sxs cmt. ROOH & WOC 8 hrs. 58 7/15/82 10800' TD 10199' ETD (CMT RET) 9 5/8" C. 6000' 7" L. 10767', Top ~ 5491' 67 PCF 36 SEC DAILY COST: ACC COST: $ 192,497 $2,945,965 AFE AMT: $3,350,000 RU Schlum & perfed 4-1/2" HPF f/ 10174-10176' DIL for BS #7. RD Schlum. RIH & set cmt ret on DR ~ 10088' DPM. Broke down perfs w/ 4000 psi. Rumped in w. 3.5 BRM ~ 3000 psi. Form held 1000 psi in 5 min. Mixed & sqz'd w/ 200 sxs cl "G" w/ 1% CFR-2, .3% Halad 22A & 3% KCL. Displ 157 sxs below ret w/ a final rate of .125 BRM ~ 5000 psi. Sqz held 4900 psi after l0 min. CIR ~ 07:30 hrs. Rev out 43 sxs cmt. ROOH. RIH w/ 9 5/8" retrv pkr & stim valve. Set pkr ~ 5406'. Loaded DR w/ 1400 psi of gas. Opened stim valve & bled off gas. Had no entry after I hr test. Rev out & ROOH. RIH w/ 6" bit w/ 2 junk subs. Drld ret ~ 10088' & firm cmt f/ 10088-10199'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 16 LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 59 7/16/82 DAILY COST: ACC COST: AFE AMT: 60 7/17/82 DAILY COST: ACC COST: AFE AMT: 61 7/18/82 10800' TD 10745' ETD (Cmt Ret) 9 5/8" C. 6000' 7" L. 10767', Top $ 5491' 67 PCF 36 SEC $ 27,264 $2,973,229 10800' TD 10745' ETD (Cmt Ret) 9 5/8" C. 6000' 7" L. 10767', TOp $ 5491' FIW 57,428 030,657 10800' TO 10745' ETD (Cmt Ret) 9 5/8" C. 6000' 7" L. 10767', Top $ 5491' FIW DAILY COST: $ 267,966 ACC COST: $3,298,623 AFE AMT: $3,350,000 62 7/19/82 DAILY COST: ACC COST: AFE AMT: 10800' TD 10745' ETD (Cmt Ret) 9 5/8" C. 6000' 7" L. 10767', Top $ 5491' $ 44,660 $3,343,283 #3,350,000 Drld ret $10199' & firm cmt to 10288'. RIH & drld ret ~ 10305' & cmt to 10387'. RIH to 10745'. Circ & pumped hi-vis sweep. POOH. RIH w/ 6" bit on 7" csg scrpr to 10745'. Circ & POOH. RIH w/ 7" retry pkr & stim valve on dry DP. Set pkr ~ 10090' & loaded DP w/ 1300 psi gas. Opened stim valve - had no press incr after 1 hr. Released pkr & rev circ clean - rec film of oil. POOH w/ test tools. RU Sehlum to run CBL-VDL-GR log. Ran CBL-¥DL-GR log f/ 10745'-7700'. POOH w/ WL. RIH w/ 6" bit to 10740' & chgd hole over to FIW. Mixed & spotted KCL-CaC03 (6% KCL, 10 ppb CaC03, 1/4 ppb XC) f/ 10740'-10100'. POOH w/ DP. RIH w/ GR & 08 to 10200'. RIH w/ Baker 7" model "F-I" pkr on WL & set pkr $ 10068' DIL. RD Schlum. RIH w/ 2' of seals on DP & stabbed into pkr ~ 10053' DPN. Tested pkr to 900 psi - ok. POOH & LD 5" & 3 1/2" DP. RU & ran 3 1/2" single tbg string. Stabbed into & tested pkr to 1000 psi. Spaced out & landed tbg. Re- tested pkr - ok. Removed BOPE. In- stalled & tested tree -ok. PUlled BPV & ball valve. Began to GL tbg. Cont to GL G-2 RD. Well began pro- ducing oil after 500 bbl produced. Well was making 888 BPD w/ 4% cut. RU DA & ran Temp log w/ spinner sur- vey. Spinner survey did not func- tion properly but Temp log showed entry coming from BS #5 perfs f/ 10343' to 10345' DIL. POOH w/ sur- vey tools. RIH w/ 30' of 2 5/8" Slimkone perf gun. Rerfed HB #3 f/ 10345' to 10375' DIL w/ 4 HRF on 0° phasing. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 17 LEASE ADL 17594 WELL NO. G-2 RD FIELD McArthur River Field DATE ETD , DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS . 63 7/20/82 DALLY COST: ACC COST: AFE AMT: 64 7/21/82 DAILY COST: ACC COST: AFE AMT: 10800' TD 10745' ETD (Cmt Ret) 9 5/8" C. 6000' 7" L. 10767', Top ~ 5491' $ 127,147 $3,470,430 $3,350,000 10800' TO 10745' ETD (Cmt Ret) 9 5/8" C. 6000' 7" L. 10767', Top ~ 5491' $ 40,568 $3,510,998 $3,350,000 Tested HB #3 f/ 10345-10375' DIL. Rate stabilized ~ 1600 BPD w/ 0% cut. POOH w/ WL. RIH w/ 30' of 2 5/8" Slimkone perf gun & perfed HB #2 f/ 10230-10260' DIL w/ 4 HPF on 0° phasing. Tested HB #2 & #3 ~ a stabilized rate of 2500 BPD w/ .5% cut. POOH w/ WL, RIH w/ 23' of 2 5/8" Slimkone perf gun & perfed HB #1 f/ lO180' to 10203' DIL w/ 4 HPF on 0o phasing. Tested all 3 benches together & had a stabilized rate of 2800 BPD w/ ,5% cut. POOH w/ WL. Reperfed HB #3 f/ 10345' to 10375' DIL w/ 4 HPF on 180° 0 - had some trouble pulling perf gun thru "X" nipple in tbg tail, Reperfed HB #2 f/ 10230' to 10260' DIL. Stuck perf gun ~ 10018' (XA sleeve) while POOH, Worked perf gun & pulled free after 2 1/2 hrs. POOH w/ WL. POOH w/ WL & produced well to clear any debris f/ tbg. Well stabilized ® 3200 BPD ~ .5% cut. RIH w/ 23' of 2 5/8" Slimkone perf guns & reperfed H8 #1 f/ 10180-10203' DIL w/ 4 HPF on 0°~. POOH w/ WL. Put well on produdtion.-Had stabilized rate of 3500 BPD w/ .5% cut. Released rig to deactivation ~ 24:00 hfs 7/21/82. LEASE TradinQ Bay Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. G-2 RD FIELD SHEET D PAGE NO. McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3 1/2" TUBING DETAIL JTS DESCRIPTION LENGTH BTM ,,,, TOP 13 13 12 ll 14 18 3 1/2" Mule Shoe 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Otis "X" Nipple 3 1/2" Butt Pup Baker 80-40 Seal Assy Baker Model "F-l" Prod Packer $10060' CBL Baker Locator 3 1/2" Butt Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" "XA" Sleeve 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Camco GLM .67' 30.21 ' 1.44' 5.18' 19.86' .51' 4.52' 30.64' 3.90' 31.24' 6.15' 400.66' 6.15' 394.50' 6.23' 366.18' 6.20' 333.51 ' 6.13' 428.90' 6.35' 552.47' 6.15' 10117.82' 10117.15' 10086.94' 10085.50' 10080.32' 10060.46' 10059.95' 10055.43' 10024.79' 10020.89' 9989.65' 9983.509' 9582.84' 9576.69' 9182.19' 9175.96' 8809.78' 8803.58' 8470.07' 8463.94' 8035.04' 8028.69' 7476.22' 10117.15' 10086.94' 10085.50' 10080.32' 10060.46' 10059.95' 10055.43' 10024.79' 10020.89' 9989.65' 9983.50' 9582.84' 9576.69' 9182.19' 9175.96' 8809.78' 8803.58' 8470.07' 8463.94' 8035.04' 8028.69' 7476.22' 7470.07' LEASE Trading Bay Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. G-2 RD FIELD SHEET D PAGE NO. McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3 1/2" TUBING DETAIL (cont.) OTS DESCRIPTION LENGTH BTM ,,. TOP 26 40 5O 55 62 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Camco GLM 3 1/2" 9.2# N-80 BUtt Tbg 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Camco GLM 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Ottx XEL Ball Valve 3 1/2" 9.2# N-80 Butt Tbg XO 3 1/2" Butt to 4 1/2" 8RD 4 1/2" Tbg Hanger Landed Below KB 802.67' 6.15' ' 1220.26' 6.15' 1538.87' 6.29' 1680.08 ' 6.20' 1907.84 ' 1.93' 253.73 ' .60' 1.00' 38.30 ' 7470.07' 6667.40' 6661.25' 5440.99' 5434.84' 3895.97' 3889.68' 2209.60' 2203.40 ' 295.56 ' 293.63 ' 39.90' 39.30' 38.30' 6667.40' 6661.25' 5440.99' 5434.84' 3895.97' 3889.68' 2209.60' 2203.40' 295.56' 293.63' 39.90' 39.30' 38.30' 0 July 13, 1982 Mr. Gary Bush Union Oil of California P. O. Box 6247 Anchorage, Alaska 99502 Re: JUL 1 b ~ Our Boss GyrosCOpic Survey. Job No. Boss-16080 Well: G-2 RD (SEC29 T09N R13W) Trading Bay Unit Kenai, Alaska Survey Date: July 11, 1982 Operator: John Coogle Please find enclosed eight (8) "Originals" and five (5) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. E~dh folder presents the survey in Radius of Curvature, Average Angle, Tangential, and Trapezoidal Calculations. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager KB/pr Enclosures RECEIVED SEP 2 1982 Oil & GU Cons. C, onun~ TRADZNG BAY LINIT ,JLiLY ~2, ~'~82 dOB NLIMBER BOSS .... ~6080 ALASKA I<EL.L.Y BI_I'.E;HING E'LEV. = · : : :. :: · :::~ · . ::: :: :::::::::::::::::::::::::::::::::::.::::::::::::::::::::::::::: :::::.:::::::'::::::'::::::. ~::::~:~:.:. ::: .~:~::: ~ .:~: :3 :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ======================================================================================================= .::~: :::::~F~ ~::~ f~P~: J~ IT~ ~ t.*~.~l~ ~T~ ]~ ::: :,:: ::.. ~. ·: ;:: ,: .~:h~~ :: h:,:: :.: ~: :.:::, J:::~:~:~" ::: :'J ~L:.: :' : · , ::.::::: :::. : :::::VER]: I ! MEASURED VERT Z CAL VER'T ] CAL ] NCL Z NAT I l~]ti~ [I ] [~EI':T ] ON '":'t::" ¢c-'~-, ...... ]~TH DE'PTH DEF'TH DEG -M Z N DEGREES DEEG/100 NCIRTH/SI]LtTH EAS]"/NES'T' SEC"F)7 ON ' : 2:00 :300. O0 20I. 00 0 20 S 5.50 E (). 14 (). 68 S 0.02 W (),, 67 400 :3 ? ?, '::~ ':} :300 99 0 40 c. :~: ~ '~) W 0:3~; :1. ~:'" "" C, ~ 07 t/,I 1 '::: 2 : · ... 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"T '~ *'~' .t. ~ ~-~-..~ L.. ~ .d...~ w i..j ,..~ 2200 2175.33 20'76. :3:3 22 33 S 20. i '~/ E 2 ,, 4'7. i ~', 1.51 .~; 6:3 ,, 76 E i :~:3'~. 72 '~' '~* f"l f'l*~ '~/- /. : ':.: ~'~ ,-' :'~:::: :::::::::::::::::::::: :~ ~:'~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: --2700 2628 ~'"' ,:,.:, ~._,~;, ,:,c~ 24 6 S 20.3'P E O. 7~ 978.48 S I37 '=~'~' E :::~S,'6 ""'""' . 280C) 2720. I:3 262i. 1:3 24 :3 S 2(). 60 E 0.09 4i,3.71 S l~:Si. :~3:E: E 4:36.4'3) .... ~:~} :: ~2 .. : : : ': : ::':: ::::ii:: ::i ::::i i::i :! i:: ::::': i:i/.::: ii::::i?":-::~F~::: ~:~;)i~' iii ':i~: :'?:~';< :i,~:~,:' i' :.!!!!:':.i: ::!:i.':!:i ;:~ i::':: :::::::::::::::::::::::i:::::!i':'. :: ':' ::: ~ :: :, i ~.:: ,',:,':ili:ii:::::.:i!:i i::' 'i :;!ii'if':;: 'I'R~:~D I NGBf:~Y LiN :[ T ,jLiLY ~ :2~ ~ ?0'2 ,JCIE~ NUHBE:F~' BOSS-.-:[ 60:30 F~LA$1.:(F~ KELLY BUSF'I~NG E:L,E~. = 'Pg. 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E.!'t~ff,~tEA :obE{'~;:,E~::: DEF: ::t:H..: ::: · : : : 'rNa;: : : TRUE N~RTH Union Oil of California' Our Boss Gyroscopic sUrVey jOb No. Boss-16080 Well: G-2 RD (SEC29 T09N R13W) Trading Bay Unit Kenai, Alaska Survey Date: July 11, 1982 Operator: John Coogle Scale: 1" = 1000' Method of Calculation': Radius of Curvature -10~o.00 Surface Location (1829FSL 1480FEL) 0 O0 o0 --3000. 4167.32' @ S09° 48'E --4000. O0 10700 --5000. O0 HORIZONTRL PROJECTION Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16080 Well: G-2 RD (SEC29 T09N R13W) Trading '~ay Unit Kenai, Alaska Survey Date: July 11, 1982 Operator: John Coogle Scale: 1" = 2000' Method of Calculation: Radius of Curvature 0.00 2000.00 4000,00 6000.00 8000.00 10000.00~ 4167.32' @ S09° 48'E 10700 SEP 2 3 1982 Nasl~ 0ti & 6as Cons. Commission Anchomp VERT!CRL PROJECTION ! :3 O0 S 6 2 ,, 5 Ii!!: 0 2:2 .t 4 0 0 C,; :iii:2 ,, !5 Iii:: ,% 2 il. :!, 2 9 5) ,: 9 7 1:2: 9'ii:' ,. 8 2 L. :.'::', ¥ i T U L')ii=J }" E- !2. I B ri :=; :::;-- i (5 '.? 8 () ,_li_.l,.'_._V :L !: i 9:32 ':" 'i;"P I:E ., '"' I' ,::, 6:i: ';:!:.ill' .... ,, '77: 8,:'.i., E '? :i:. 3 () ii.--_ :!. 21 ,, 82 :2~ ::..'.-:9 :i 5:'::, 8 9 21, :Z; 4 i 89. '7 .t. 2.47 2::.:'9. :'27 2.40 2'7 '[ ,, 8:3 .I.. ~:.]'.~' 7..:" .5." 8 ,, ,:2,'5. 0,3:0 8 t :?. 8 {5 c:,, <.'. 0 '=i .4 ,::'., (5':=: (-) £-'.7.-' DEF:'TH .EJ E Li:~ TTM ..... i'd" 4700 S 8,,5 E{ :?0 22 4 .... 8 (3,:".~ '.:'E;,_,c' ,, :3 ii.':: :.-::.... ,'",.....a, 2 4 9 00 E; 7, 9 E' :3 .t :3 t V ~:'i{ i:.R T ! F:/'-, t D Fi F:' T'.4 /.~ 46 E";~ '?:34 4 Fi Y:-i :[ ,, 5;',5 z~.,,.:.,:3.7 5.1.. ':50~ 05 S ? 22 ,, 0 ::.:.; 4. 08 ,, 54 54 'i;;'![fi :, :..i' 5 71 E, S. 7"i,7 7252. ?2 ?i 0,, Sd:, 'iii; 7.:".".~. 6,~. E, 7 E: i::: E:' Z ]" :i: 29, 2',.:i', ii[..'. :3 :':i: ,'"-', ,, :ii', i:-'7- E :3:2 ().~ 5'7 :35;'.¢, 5;' i '~07 ,:.';,-z ~::: .5 ."% 5. 554..-. 5,!,:3., :i; 7' S'.;.:. C T i ON 5'17 6:3 .n =,~ 7' 5 2 ,, i 9 2.8 t '.:;"::"::' 5';'~i ,:'2.6 j. O'.'?.:'P. i 73.05 i :328~ 2:3 O, .t '? .i. :::? 80 ,, 4, :3 O, 32 :i,, 4::ii;2 ,, 4 6 O. 18 .,. ,.,.,::,.',= 4 :ir O, :3 J. :,.'. :5:3 d', ,, :'::': 0 O, 0 8 i :3:3 8. i '.5 O= 5;'& J. 885 ,, 98 0.53 :i. 9:32, I. 7 i. 77 :[ '::?'7 E, ,, 6, 6, ! ,, 0,5, 2021 .~ ,"3,,:!:, :i:, :i: :1. -.';-5 ,, 4.7 0 = :-3 9 :2!:'-;':)::: ,. [{::.5 (7.:,, S::5 4.' ::}: ~. :i:2: i... i :i: '5' i. "::'c') C', ' :::7 ,:ct. i = '2:5.: :-.~ ,, 68 :ii: 5 0 0 8 6 0 0 8 ¥ 0 0 '::." (,) () (.) 'P .I O0 'i.::' 200 9:300 'F' 400 95 (),:..':.'. 'P &, 0 ,:3 5:: 70 () 'F' 8 ,:"..) 0 '.:::"PO 0 ". 000. 0 i -':'-.~ :[:. 00 ! 020(_') J. 05:00 1!. 0 ,:i- 00 J. :3 0 e, 2 ~, t zi.0,4. 0 :3 :[ :1. '7 , ..... :::,0 0. :31 ::ii: i71 ,, 5;' I! ,, 23 ::':.':::'-2 r':.';, :3:3 0 ,, :3 ::3 32'77 ,, 97 0 ,, 7 :;? 3 7 0 {,.';'. 7,::!- C:,, 7 7 :':ir 7.t'5 4, ::5 6: :i ,, ::? 4 :3802. :[ :il: 2.07 :38{51 ,, :ii:::3 '.'.'). ? 4 :3 9 02 ,, S 7 (),, 7 2 :3 9 !5 4., ,5:3 .i. ,, 18 ,:'=': 0,.'1:, 8 ,, :L :[ C:,, 'i:," 0 RECEIVED SEP 2 3 Ak,qka Oil & Gu Cons, Comml#ion Anchorage Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16080 · Well: G-2 RD (SEC29 T09N R13W) Trading Bay Unit Kenai, Alaska Survey Date: July 11, 1982 Operator: John Coogle scale: 1" = 1000' Method of Calculation: Trapezoidal TRUE NSRTH Surface Location (1829FSL 1480FEL) '0.00 ~ O. O0 200 --3000.'0 --4000.00 4167.24' @ S09° 48'E 10700 --5000.00 HORIZONTAL PROJECTION union oil of California our Boss Gyroscopic Survey Job No. Boss-16080 Well: G-2 RD (S~C29 T09N R13W) Trading Bay Unit Kenai, Alaska Survey Date: July 11, 1982 Operator: John Coogle Scale: 1" = 2000' Method of Calculation: Trapezoidal 0.00 2000.00 4000.00 6000.00 8000.00 RECEIVED SEP 2 :~ 1982 Akslm Oil & Gas Cons. Commission lO00O. O0~ 4167.24' @ S09° 48'E 10700 I 20~0. O0 4000. O0 VERTICRL 6'0~0. O0 PROJECTION L[~ATE THr~T D£T"~I IS RAMS AS '1 i Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. operanor, ~ell ame and Number -. Reports and Materials to be received by: Required Date Received Remarks Completion Report Yes ~Well History ' ~'~? Yes ' , ,, ,. Core inscription ,~ff /7/ Registered ~ey Plat ~P y'e~ Inclination Su~ey ~,,'~ .. Drill Stm Test Re. ms ~d~'G.. W "', , ,, , ~s R~. Yes / .: STATE OF ALASKA °" '"' ALASKA~ ~ AND GAS CONSERVATION CC' ')/llSSION ~'~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~' Workover operation [] 2. Name of operator 7. Permit No. - J UNION 0TL COMPANY OF CALIFORNIA 82-67 I 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface Conductor #20, Leg #4, 1829'N & 1480'W of SE corner, Sec. 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RT 99' NSL ADL 17594 8. APl Number 50- 733-20038-01 9. Unit or Lease Name TRADING BAY UNIT 10. Well No. TBUS G-2 RD 11. Field and Pool McARTHUR RIVER FIELD For the Month of Suly ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Drilled to 10,800 TMD Top of Fish ~ 10,770' - unable to recover (Fish consists of DIL-Sonic-GR tool) Released Rig ® 24:00 hrs 7-21-82 13. Casing or liner run and quantities of cement, results of pressurs tests Ran 7" 29 # N-80 butt liner f/ 10,767' to 5491' - cmt'd w/ 1000 sxs Set pkr ~ 10,068' w/ 3 1/2" tbg string 14. Coring resume and brief description None 15. Logs run and depth where run DIL-Sonic-GR f/ 6000'-10,800' FDC-CNL-GR f/ 5705'-10,745' CBL-VDL-GR f/ 10,745'-5400' CBL-VDL-GR f/ 10,745'-7700' Gas, Cons. 1 6. DST data, perforating data, shows of H2S, miscellaneous data Sqz'd shoe w/100 sxs Perf'd for stabilization & Sqz'd Perf'd for production 10343-10345 100 sxs 10,345-10,375 w/ 8 HPF 10262-10264 100 10,230-10,260 8 10174-10176 200 10,180-10,203 8 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~'I~,.~_ _ _ t~'~,. 0,~(~0,--~a,~._ _ __ _ J~-~R_ -__ TITLE gIST DRLG SUPT DATE 7/27/82 NOTE--Repo~ on this form is required for ~ach ~lendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA MON i. HLY ALASKA ~"~L AND GAS CONSERVATION C~ ,)MISSION ' ~ REPORT OF DRILLING AND WORKOVER OPERA?lO ,1. Drilling well [] Workover operation [] 2. Name of operator UNION 0IL COMPANY OF CALIFORNIA 3. Address , P0 BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface 7. Permit No. 82-67 8. APl Number 50- 7~7-200~8-01 9. Unit or Lease Name TRADING BAY UNIT Conductor #20, Leg #4, 1829'N & 1480'W of SE corner, Sec. 29, T9N, Ri~W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Des io~.)~l~.~ria, No. RT 99' MSL 10. Well No, TBUS G-2 RD 11. Field and Pool McARTHUR RIVER FIELD For the Month of. 3une ,1982 .. 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Milled window f/ 1300-1360' & cmt'd w/ 200 sxs for kickoff plug Drilled f/ 1305-9512' on 6/30/82 13. Casing or liner run and quantities of cement, results of pressure tests Ran 6000' of 9 5/8" 47# N-80 csg to 6000' - cmt w/ 1900 sxs - tested to 3000 psi - ok 14. Coring resume and brief description None 15. Logs run and depth where run FDC-CNL-GR f/ 3000-1000' GR-CCL f/ 3000-1000' DIL-BHC-Sonic-GR f/ 6000-1300' FDC-CNL-GR f/ 6000-1300' 16. DST data, perforating data, shows of H2S, miscellaneous data Perf f/ 2100-2106' 1390-1392' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED.- ~i ~. ~. (5~_--ZS~.. T,TL[ DIST ORLG SUPT OATE 7/1/4/82 . NoTE--ReporUon this form is required for eiil~h ~,en~ar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless.otherwise directed. .~. Form 10~04 Submit in duplicate Rev. 7-1 ~0 ' ALASKA · LAND GAS CONSERVATION Ct, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER J~ 2. Name of Operator UNION 0IL COHPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 Cond. 20, Leg 4, 1825;'N & 1480'W of SE corner, 4. Location of Well Section 25;, TgN, R13W, Slvl. 7. Permit No. I 6 . Lease Designation and Serial No. ADL 1759a 67-48 8. APl Number 50- 73~-:~0038 9. Unit or Lease Name TRADING BAY lJNTT 10. Well Number TRU~ G-2 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) RT 5;5; ' MSL 12. Check APpropriate Box To Indicate Nature of Notice, Report, or Other Data McArth,jr River Field NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ', Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). · 4. .5. 6. 7. 8. 9. 10. 11. 12 Rigged up over TBUS G-2. Set retainer at 9150' and sqz'd perfs f/ 9505-9535', 9560-9685', and 9705-9818' w/ 200 sxs thru ret. Cut and retrieved csg f/ 1400'. Ran CBL-VDL-GR logs f/ 1400' to surface. Perfed 4 HPF f/ 1380-1382' and sqz'd w/ 300 sxs for csg stabilization. Perfed 4 HPF f/ 1365-1367' and 1310-1312' and sqz'd w/ 300 sxs. Perfed 4 HPF f/ 1330-1332' and checked for flow. Resqz'd perfs f/ 1380-1382', 1365-1367' and 1330-1332' w/ 100 sxs. Perfed 4 HPF f/ 2020-2022', 2129-2131', 1390-1~92', 1350-1352' and 2100-2106' - checked for flow. Ran FDC-CNL-GR and GR-CCL logs f/ 3000-1000'. Reperfed 4 HPF f/'1390-1~92'. Milled window f/ 1300-1360'. Abandon w/ 200 sxs cmt (top of cmt e 1206'). RECEIVED J U L 1 9 ]982 Alaska 0ii & 6as Cons. C0mrnJsswn Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~t~,~ (~",,. e~ ooo~~ /~-~ Title The s.~c';'" bt~w for CommissiOn-use j -~4.~ ............. Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMOR , IDUM TO: THRU: Sta, b of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION C. torton DATE: June 21, 1982 Lonnie C. Smith Commi s s±one r FILE NO: 108A/Z TELEPHONE NO: FROM: Harold R. Hawkins Petrole~ Inspector SUBJECT: Witness BOPE Test Union Oil, G-2 RD Grayling Platform Sec. 32, T19~', R2W, S.~i. Permit No. 82-67 ..Fr.iday.~. June !8,__!98~- I left Anchorage at 1:00 p.m. by AAI to Kenai arriving at 1:30 p.m. and arrived on the Grayling Platform at 3:45 p.m. Cementing was just finished and~.nippling down was in the process. Sa tu-r.day,~ J~ne_ 19_, 1982- I witnessed the BOPE test, there w~s one failure. The kill line floor shut'in valve to the choke manifold leaked. I filled out an A.O.G,C.C. report which is attached. In summary I witnessed the BOPE test on the Grayling Platform for Union Oil redrill G-2 RD. When the BOPE tests were completed they ~re performed satisfactorily. 02-00IA(Rev.10/79) O&G #4 4/80 STATE OF ALASKA · ALASKA OiL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date Well Operator Well Location: Drilling Representative Permit # ~. Casing Set Rig # _%- Representative Location, General ~// Well Sign ~/~ General Housekeeping . ~/~. Reserve pit . ~ )'~ Rig ~Q/~ BOPE 'Stack Annular Preventer Pipe Rams Bi ind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pres sure ~/6) 6) psig · Pressure After Closure / ~69 psig 200 psig Above Precharge Attained: -- min~ sec Full Charge Pressure Attained: ~ min ~ sec Controls: Master 6~/~ Remote Fg/.T' Blinds switch cover W~,~' Kelly and Floor Safety Valves. Upper Kelly. Test Pressure ~&~/d~ Lowe~ Kelly Ball Type Inside BOp Choke Manifold No. Valves ~ No. flanges ....... .~ ~ Adjustable Chokes (9/~ ~ ..... Hydrauically operated choke Test Pressure Test Pressure Test Pres sure Test Pressure .~,,~¢:~ days and Test Results: Failures . ~7'.Z-'_Z~ Test Time ~ hrs. Repair or Replacement of failed equipment to be made within .... Inspector/Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector STATE OF ALASKA ALASKA ...... ")AND GAS CONSERVATION C~ .... ')IISSION //~/~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. UNTON OTL COMPANY OF CALTFORNIA 67-48 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20038 4. Location of Well at surface Conductor ¢f20, Leg ¢f4, 1829' N & 1480' W of SE corner, Sec. 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RT 99' MSL ADL 17594 9. Unit or Lease Name TRADING BAY UNIT 10. Well No. TBUS G-2 RD 11. Field and Pool NcARTHUR RIVER FIELD For the Month of NAY ,1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations ® 12:01 hrs 5/19/82 Cut 9 5/8" casing $ 1400' & recovered 1361.5' of 9 5/8" csg 13. Casing or liner run and quantities of cement, results of pressur9 tests None 14. Coring resume and brief description None RECEIVED 15. Logs run and depth where run CBL-VDL-GR f/ 1400' to surface JUN 1 6 1982 Alaska Oil & Gas Cons. ¢omrnlaslon Anchorage 6. DST data, perforating data, shows of H2S, miscellaneous data Sqz'd perfs: 9505-9535' Rerfed & sqz'd: 9560-9685' 9705-9818' 1380-1382' Rerfed 1365-1367' & dry 1310-1312' tested: 1330-1332' 2020-2022' 2129-2131' 1390-1392' 1350-1352' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-~Re~lort on this form is required for ea~'~h calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1 ~0 April 30. 1982 ~ir. Robert T. Anderson District Land Manager Union Oil Company of California P. O. {{ox 6247 Anchorage, Alaska 99502 Trad tn{f Bay Un i t TBUS (I- Union Oil Company of CalifOrnia Peru~i t No. {{2-6? Sur. Loc. 1829'N, 1480'W of SE er Sec 29, T9N, RI3~, Btmhole Loc. ~23~5'S, ~495'~ of NB e~, Sec 3~, T9~, RI3W, Dear Mr. Anderston~ Enclosed is the approved application for permit to drill the above referenced we!l, Well smnples, and a mud log are not required. A continuous directional survey is 'required as per 20 AAC 25.050(b)(§). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadro~ous fish. Operations in these areas are subject to AS I$.05.$70 and the regulations promulgated thereunder (Title 5, Alaska Administrative ~e). Prior to commencing operations you may be contacted by the ltabitat Coordinator*s Office, Department of Fish and Game., Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article.? and the regulations promulgated thereunder (Title 15, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to eor~ncing operations you ~ay be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is Araalng ~ay omit spudded. ~ would also like to be notified so that a representative of the Commission may be present to witness testtn6 of blowout preventer equipment before surfaoe easin~ shoe is drilled. In the event of suspension or abandomnent, please give this office ade~ate advance notification so that we may have a witness present. Very truly C. V. Chatterton Chairman of BV 0~,~ o~ Alaska Oil and Gas Conservation ~isston Eric 1 o sure Department of Fish & Game, Habitat ~eetion w/o enel. l)epart=ent of Environmental Conset'vatton w/o enel. ~C = be , ..j G- `54 RD I -2100 2 -2199 ,5 - Z299 4 - 2. 499 5 - 2799 6 -3199 7 - `5999 3 - 4299 9 - 4499 I0 -4599 I -4798 2 - 5298 3 -5773 4 -5975 5 -6176 6; -6;305 ~LOT 9G- 34 SLOT 2 I- 65555 2- 850 55- 1197 4- 1945 5-2071 6-2131 7- 228 I 8- 2455555 - 800 - I 300 - ZOO0 - 25500 -2599 -2498 - 2596 -2692 -2788 -2884 -2979 -3073 -3'5164 SLOT 3 SLOT 4 SLOT 5 SLOT 6 I- 999 I - 700 I - 800 2 - 1099 Z - 799 2 - 1300 .5- !199 3 - 898 3'5 -1600 4- 1299 4 - 997 4 -1700 5- 1397 5 -1096 5 - 1799 6-149.5 6 - I 194 6 -1898 7- 15955 7 -12_91 7 -1997 8- 16;88 8 -15588 8 -2094 9-178-'5 9 -1484 9 -2192 0 -2288 I - 25855 I - I000 2 - 1400 `5 - 1800 4 -,2099 5 -2199 6 - 2297 7 -2394 8 -2490 9 -2584 0 -2677 I -2769 2 -2859 3 - 2948 4 -55036 SLOT 8G SLOT I0 SLOT II - 200 - 298 - 5596 - 495. - 590 - 685 - 779 - 871 - 960 - Z046 -21 29 'SLOT 14.G I- 642 I- 998 2- 699 2- 15529 55 - 764 3 - 2077 __ 4- 8255 4 -21 15 5-; 967 5-2178 6- 1146; 6-2239 7- 12__67 7-25570 8 -1427' 8-2461 __ 9- 1513 9-26;13 I0-'16;78 I0- 2818 , II - 2986 12- 3076 I- 637 2- 789 3,- 943 4-1016 5 - 1046 6- 1077 7.- 1167 8- 1227 9- 1286 I0 - .I 3 46 II - 1405 12 1463 155- 161~ 1701 I - 1200 2 - 1299 55 -1399 4 - 1498 5 - I 597 6 - I 6955 7 - I 788 16 G- l - 8'84 I- 7155 2- 946 2- 776 3, - 1099 3 - 807 4 -1287 4- 837 5-1581 5- 1211 6; - 1370 I - 646 2 - 862 3 1104 4 - 1350 5 - 21 21 6- 245555 7- 2961 8- 55065 9- 3126 9 I0- 55276 0 I- 55490 2 - 3698 55- 55787 LEG 4 SLOT 17 G-5 I - 507 2- 620 55- 739 4- 807. 5 - 1055 6; - 15500 7- 1735 8- 2073 - 600 - 3O0 - 500 - 598 - 696 - 794 - 890 - 985 -2080 -2173. ,SLOT 18 I - 505 2 - 757 3 - I101 4 - 1476 5- 1538 6- 16655 7- 1786 8- 1906 9- 206;3 13-55 188 NY .ATFORM SLOT 21 G-II SLOT22G-I( SLOT 2`5 G-17 SLOT 24 G I- 990 I- 15595 I - 612 I - 864 2 -1037 2- 1458 2- 737 2- 970 3- 116;2 55- 1667 55- 829 ,5-2481 4- 1254 4- 1819 4- 1004 4 -2826 5- 1316 5 2016 5 - 1219 5-55485 6'- 14 I0 6- 23 I0 7 - 2543 I - I 000 2_ -I100 55 -1199 4.- 1299 5 - I 5596; 6 - 149:5 7 -1589 SLOT 20 G-; I' - 726 2 - 915 3 - 1072 4- 1281 5 - 1800 6 - 1984 7- 2086 8- 2242 9 - 240 I I0- 2587 II - 2866 12 - 2992 · I I . ! ; /,, Robert T. Anderson District Land Manager Union Oil and Gas("-'vison: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union April 22, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska HcArthur River Field Application to Drill and Complete TBUS ~-2 Redrill (ADL-17594) Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to redrill, complete and produce Trading Bay Unit State ~-2 Rd. in the Hemlock Oil Pool pursuant to Rule 5, Conservation Order No. 80.G-- This proposed completion at a crestal final withdrawal point will result in additional recovery of Hemlock Production. Your approval of this request will be appreciated. Very truly yours, sk cc: C. Case R. Warthen Union Oil and Gas,,C'~vison: Western Region [: Union Oil CompanY/~,f California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl, n Robert T. Anderson District Land Manager April ~2, 1982 Hr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 WEST FORELAND AREA State of Alaska HcArthur River Field ~ Dolly Varden Platform, TBUS~-2 Rd. ADL-17594 (8-86-71-5575-60134~) Dear Hr. Chatterton: Enclosed for your approval are three (3) fully executed copies of the above captioned Permit to Drill TBUS ~-__2 Rd. for the Dolly Varden Platform. Also enclosed is our Check No. 19193~in the amount of $100'00 to cover filing fees. sk Enclosures (4) Very truly yours, obert . n~ cc: O. R. Callender A. Lannin-LA Office I ECEiVED APR 21982 Oil & ~a~ Cons. Corn. mis, ion April 22, 1982 ~A__DM:~,L.NL I S T R A T I V E A P P R O V A L NO. 80.42 Re: Application of ,Union Oil Company of California, operator of the Trading Bay Unit, to redrtll, complete and produce the T~.a..y. Unit G-21qD~ well as part of the pressure main- ena~ ~'0J~-t-~-p-P~{Ved by Conservation Order'No. 80. Mr. Robert .T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear ~r. Anderson: The referenced application was received on' April 22, 1982 and stated that the drilling, completion and production of the Trading BaY Unit G-2HD well will provide a creStal final with- drawal point in the Hemlock Pool. The Alaska Oil and Gas Conservation Commission hereby authoriZes the drilling, completion and production of the referenced well pursuant to Rule 5 of Conservation Order No. 80. Yours very 'truly, Harry W. I<ugler, Con~ i ss i oner BY OPd)ER OF THE OOMr;fI SS ION t:t,~¥K: be STATE OF ALASKA ALASKA{,L AND GAS CONSERVATION C(~..,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~(~, MULTIPLE ZONE [] 2. Name of operator JNION 0IL COHPANY OF CALIFORNIA 3. Address ~0 BOX 6247, ANCHORAGE, ALASKA 99502 4. Location of well at surface Cond. 20, Leg 4, 1829'N & 1480'W of SE cor S.29 TgN R13W SM At top of proposed producing interval +2100'S & 550'W of NE corner, S.32 TgN R13W SM. At total depth +2375'S & +495'W of NE corner, S.32 TgN R13W SH. 5. Elevation in feet (indicate KB, DF etc.) KB 99' MSL 6. Lease designation and serial no. ADL 17594 9. Unit or lease name TRADING BAY UNIT 10. Well number TBUS G-2 RD 11. Field and pool McARTHUR RIVER FIELD 12. Bond information (see 20 AAC 25.025) National Fire Insurance Company of Type Statewide Surety and/or number Hartford (B5534278) Amount $200,000.00 15. Distance to nearest drilling or completed welt +llO0 ! feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line ~Ou~EhwP~st 57 1/2 miles +_.~95 ! ' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 1 ]~[']~ I ~ 10300 ! feet 5116 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1310 feet. MAXIMUM HOLE ANGLE 30° l (see 20 AAC 25'035 (c) (2) 18. Approximate spud date ig@ Surface ~ psig@ 9175ft. TD(TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Hole / Casing Weight / 7" 29# 22. Describe proposed program: CASING AND LINER Grade Coupling N-80 I ~]uU~ N-80 See attached Length 6O0O SETTING DEPTH MD TOP Surf I TVD 5350 5500 ~ 5000 MD BOTTOM TVD 6000 5500 I QUANTITY OF CEMENT (include stage data) +15oo sxs to surf +750 sxs ECEiVED Naska 0il & Gas Cons, 23. I hereb~y ce~ego~e~a n/~ o~rr2.~he The space below for Commission use / best of my knowledge TITLE District Land Mgr DATE CONDITIONS OF APPROVAL , Samples required Mud Icg required []YES '~NO I-lYES I~NO Permit number Approval date Form 10-401 Rev. 7-1-80 Directional Survey required C~YES I-INn APl number 50- '77~ oo ,~$-ot SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER by order of the Commission DATE April 30, 1982 Submit in triplicate PERMIT TO DRILL TBUS G-2 RD 22. Proposed Program: . . 3. 4. 5. 6. '.7. 10. 11. 12. 13. 14. 15. 16. Move Rig #55 over conductor #20, leg #4, TBUS G-2 & rig up. Install and test BOPE. Cut and recover 9 5/8" csg f/ 1400'. Mill window in 13 3/8" csg f/ +1300' to 1360'. Spot KO plug across window and dress off to 1310'. Kick off and directionally drill 12 1/4" hole f/ +1310' to +6000' MD. Run logs. ~ Run and cement 9 5/8" casing to 6000'%" Clean out and directionally drill 8 1/2" hole f/ 6000' to 10850'. Run logs. Run and cement 7" liner to 10850'. Run CBL-VDL-GR log and gyro survey. Squeeze well as required. Complete well as dictated by logs. Install BPV, remove BOPE, install and test tree. Inflow perforate Hemlock zones and place on production. ~ HYDfllL .. £LIND P,'At, I$ ~ CHECK V.~L tie G,~ T£ VA I' V£ · . RECE'i'VED 'AP~ f~ 2 198~ " Oil & Gas Cons, Commissio Anchorag~ · HYL~?AULIg OPEtNT£D VALVE .. / · ZO-TOt~U£ A~ CHANGES MUST HAVE ~R~T.T~N A~PROV~L BY THE D~STR~CT OR~LL~NG SUPERINTENDENT l_ CASING AND TUBING DESIGN FIELD %Ac P~T~,3e. Q~,,~V-- . . E ~. I 8S~ ~D GR. i..%opsi/ft= E ~T. II qz ~. ~D. GR. II .5o psi/ft. M.S.P. j. INTERVAL Bottom Top Wt. DESCRIPTION ',~IGHT TENSION ~[[ NI-.MIR4 TDF COLLAPSE COLLAPSE CDF BUP~? II:TERNAL W/ BF -top of STRENG~K PRESS. @ PZSIST. PRESSURE Grade ~'nread W/O Bc~-~ section TENSION bottom tension YIELD lbs lbs 1000 lbs .'psi psi psi psi BDF P?_vCE PER PT. COS? Y=Tensile Lpad/Pipe Yield Strength Formulae: Calculations: Total Co~t Collapse resistance in tension = X (Collapse pressure ratify) Burst Pressure = ~P + Depth ( Nya. Gr. II --.5) BF (Bouyancy Factor) = ~.00- (o.0~53 x ~m~ wt. ~) TtO TO 12,900 · 5 VD 9669 , G-5 ,o ,, G-32 ~ ~ T 0 ~1,570 a G-'~ vD ~ TV~~IO,312 TO 1~164 G-18 IO,155 VO 9704 5 6390 ' 5 4 e va ~510 29 ~ ~ Z 4 5 .5 4 6 5 6. G-2 TO 10,1.56 TO IO,79 O VD IO,24- I G-20 TD 10,642 O 97197 ~,o'rz 10,3,4,1 [ $, 10,310 I % ~7 ~ S I0 9TD 11,160 VD 97 I I 9 ~ ~o T/HEML: 0 VD 10,328 9 ~o, I 0~115' MD G-Z2 G-II o 9,175' VD , RD ' 8RD TO 11,335 TD 10,84-6 ~v~ TD Ii 05( _~ TD 1t,750 VD 9982 VD 9870 ~/~ BHL: VD ~'~7.~ ~'~ VD ~2 ~ ~ ~'% 10,750' TMD . /TD 12,455 ~ ~ / ~ ~ / U ll~ TD II 751 ~ ~'~ .~ ~'30 ~o ~'- ~-II ,~ ~,,~,~,o . /vo :o,o. ,o/ va 0~-4;~ ~, / ~'1" ~:'~/~.~ Alaska District ,,, / ~ // ~~'~~:~m~ ..... / ~ '/(g~-, uNION OPERATED T 9 N, R I~ W , ~_ '__ $R '3 ~~~~~__-'~"~°Jl~]~oo ~RADING BAY UNIT '? T 8 N / R I~ w '~/~~~~ ~---- ~fi~Ot~',~~' O0t~ARTHUR RIVER FIELD / ' :/ ~:~7 ~ ' ' ~ '~'* ~ RD - . , ~2 (42 32) VD 9'805 e TO I0 628 - , . / /,:,ooo . / '~/./ / ,/ .~/ ..... ,, FEET -J .. " TUBING DETAIL !. OTIS XEL BALL VALVE AT 293.63' 2-12 CAMCO GAS LIFT MANDRELS AT: 2- 2203.40'~ 3- 3889.68', 4- 5434.84'~5-6661.25' 6-7470.07; 7- 8028.69'~ 8- 8463.9419- 88o3.58' I0-9175.96', II- 9576.69', 12-9983.50' 13.0TIS XA SLIDING SLEEVE AT 10~020.89' 14. BAKER LOCATOR AT 10,059.95' 15. MODEL F-I PKR. W/80-40 SEAL ASSY. FROM 10~060.46 TO 10~080.32' t6 OTIS X NIPPLE AT 10,085.50' 17 MULE SHOE AT 10,117.15' PERFORATION RECORD D. tTE 611182 7113/82 7/14/82 7/~5/82 7/19/82 7/20/82 II IIYTEA?.tL O01YDITIOlY 1365'- 1367' TEST 4 H.PF 1310'- 1312' 1330'- 1332' " " 2020' - 2022' " " 2129'- 2131 1390'--1392' .... 1350'-1352 ..... 2100' - 2106' " 10,343'-~0,,345' " 10,262'-10,,264' " 10,174'-10,176' SQZ 10~345'-10,375' PRODU,,CTION, 4 H.P.E 10,230'- 10,260' " 10,180'- 10,203 ..... 6-2 RD ,0' :58..':50' 153/8" CASING AT 1,500' TOP OF 7" LINER AT 5491.10' 9~B", 47~ N-80 CASING AT 6,000' /¢/OTE: 3 I/2" TUBING PLUG AT 10,745' 7'; 29~ N-80 LINER AT 10,767' union G-2RD WELL SCHEMATIC COMPLETED = 7/21/82 Well G-2RD ]Field McARTHUR R. County KENAIIDate 2/'2/'83 Drawn ByB. W. IChecked By _ Approved By Scale NONE, [Page I Of,,,, I CHECK LIST FOR NEW WELL PERMITS IT~ APPROVE DATE (1) Fee (2) Loc thru 8) 3. :~c~ V~ ~7-'~n.~. 4. 5. 6. 7. 8. (4) Casg~? thru 20) (5) BOPE~__ ~-22'~ Company (6) Is the permit fee attached,.........--...., ........... :-. Is well to be located in a defined°l. po ......... . Is well located proper distance fr°m property line .......... Is well located proper distance from other wells ............ Is sufficient undedicated acreage available in this pool .... Is well to be deviated and is well bore· plat included ....... Is operator the only affected party ......................... Can permit be approved before ten-day wait .................. Lease & Well No. 7J>, ff/~', YES NO ...®... ......®. 'REMARKs 12. 13. 14. 15. 16. 17; 18. 19. 20. 21. 22. 23. 24. 25. Does operator have a bond in force . · Is a conservation order needed .... ''.'''''''''''''''''.''''''''''''' Is administrative approval needed ...................... , ............ Is conductor string provided ....................................... Is enough cement used to circulate on conductor and surface ........ Will cement tie in surface and intermediate .or production strings ... Will ·cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ........... Is adequate well bore separation proposed .......................... Is a diverter system required ............ Are necessary diagrams of dive~;~ ~;~'~;~ eq~ip~;~ a~a~e~ 1.~.~ Does BOPE have sufficient pressure rating - Test to ._~)O~ psig .~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional. requirements ............................................. Additional Re~.arks: 9~'' [_~ ~.~/¢' ~/~L~ ~: - ~-~.~ - Geology: Engineering: WVA ' J I~~'RAD ~ rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information: of this nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. .o LVP OiO.HO1 VERIFICATION LISTING ** REEL HEADER SERVICE NA~E DATE :82/07/28 ORIGIN : REEL NAME :REEL ID CONTINUATION # :01 PRE¥IOUS REEL COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAME :SERVIC DATE :82/07/28 ORIGIN :1087 CONTINUATION :01 P~EVIOUS TAPE ** FILE HEADER FILE NAME :SERVIC,O0~ SERVICE NAME : VERSION # : DATE : ~AXIMUM L~NGTH : 1024 FILE TYPE PREVIOUS FILE ** INFORMATION Rf:CORDS ** MNEM CONTENTS CN : UNION WN : G-2 RD FN : MCARTHUR RIVER RANG: 13W TOWN: 9N SECT: 29 COUN: KENAI STAT: ALASKA CTRY: U.S.A. MNEM CONTENTS PRES: DILOOIE ** R bVP O~.O.M01 VERIFICATION LISTING : ALASKA COMPUTING CENTER · COMPANY = UNION ;' ~ :'~ :';::~ ~.~' .: ..;~ ~-:;~ WELL = G-2 RD FIELD = MCARTHUR RIVER ~; ~: ~: '~: /~'"~':~ :~: ~ - COUNTY = KENAI STATE = -ALASKA _ .: .>.: _ ~_ ::..,- .:z_ >V'. :::{:.>:3_ 3 -- ~::: - - ; : JOB NUMBER AT ACC: 10707,65323 LDPI jR/RIK ~ DRHO.FDN DOES NOT APPEAR ON RUN ~2, DATE 5OGGEDI 6 JULY 82 BOTTOM DEPTH ~ ~0787 FT. TOP DEPTH = 6006 FT. : CASING = 9 5/8 IN. 6000 FT, TYPE FSUID = DUOVIS GEL LVP O.t0.H01 V~RIFICATION LISTING DENSITY VISCOSITY PM FLUID bOSS RM R~F RN AT BHT MATRIX THIS LISTING REPRESENTS A ME GED .PRODUCT-, RUN-S~:...~I~_A~.D~#2 , _ ~ ..... ..... :.-:~:~ . _ - ======================================================= BOTTOM DEPTW TOP DEPTH CASING flit SIZE TYPE FLUID DENSITY VISCOSITY PH FLUID LOSS R~ 6000 FT. 1300 FT 13.37 I~, 12,25 IN. GEL 87,0 LB/G 77,0 S 9,4 7.6 C3 3,710 ~ 56,0 DF bVP OlO.HO1 VERIFICATION LISTING RMF RMC RM AT BHT MATRIX SANDSTONE 0,748 ~ 56,0 DF 2,070 ~ 56.0 DF 1.869 8 118. DF ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE 4 9 0 ID DEPT SFLU DIL IbM DIL ILD DIL SP DIL GR RHOB FDN GR FDN CALI FDN DRHO FDN NRAT FDN NCNL FDN FCNL FDN DT BHC GR BHC ORDER FT OHMM OHMM ~V GAPI PO , p LOG ]'Y~£ CbASS MOD 0 0 0 ~0 ~ : 0:~: 4:0 ::: -: :1' ':~:" "~ :' - 7 7 7 7 ] 1 32 : 0_ ~ 0 4 _ 42 68 2 O- 0 G/C] 42 GAPI 42 IN 42 G/C3 42 42 42 G~PI 60 34 93 0 0.: 4 .... 0 l 68 3.1 32 DATA ** DEPT SP NCNL 10765.0000 SFLU -999.2500 GR -999.2500 CALl -999,25o0 FCNL bVP DEPT SP NCNL DEPT SP GR NCNb DEPT SP GR NCNb DEPT SP NCNb DEPT SP GR NCNb OiO.HO1 VERIFICATION LISTING 10700. 0000 SFbU -999 2500 GR 44".4688 CALl 2338,0000 FCNL 10600.0000 SFLU -999.2500 GR 29 5625 CAbI 3446:0000 FCNb 10500.0000 SFLU -999 2500 GR 34~9062 CALI 2996.0000 FCNL 400 0000 SFLU 29.4844 CALI 2802.0000 FCNL 10300.0000 SFbU -999,2500 GR 30.1406 CAb! 2824,0000 FCNL DEPT 1~200 0000 MFDU SP -999:2500 GR GR 71,2500 CAb! NCNb 1418.0000 FCNL DEPT SP GR NCNb DEPT SP GR NCNb DEPT SP GR NCNb DEPT SP GR NCNb I0100.0000 SFLU -999,2500 GR 67.6875 CALl 1631,0000 FCNL .ooo :oooo 99 2500 0R 36,5938 CAL! 2692,0000 FCNL 9900.0000 SFLU -999,2500 GR 25.3594 CALI 1141,0000 FCNL 9800,0000 &FLU -999,2500 GR 1980 938 rCNb 9700.0000 SFLU -999 2500 GR 48:8516 CALl ~.235.5ooo FCNL, DEPT SP GR NCNb 6 , b250 -NPH! . 19,5313:. RHOB 2.6855 6,0'547 DRHO -:- ::~ 0~0~000: -;:':: T::'-':'-'~ 923.5000 DT ~, .... 7-5.3-,?50 ......... GR ..... ,,. 61.625,0 ' -: / ':, :,': / :~' ;::j~ :' :L '.'"j:'~:::': 66,9375 IB[4 33.::343.8 .IbD ,:: 46.:687.5 38. 9375 NPHI · -::: 10~:~980:. :::R:H'OB: .... '::..:~ ,.~ 6.0039 DRHO ...... 0..0000 N~AT:. - 1.7969 1805 ;0000 DT:- - ':- '60~ ::--?:GR:' :.::~' ';-:': -: ":: :'~38'~9' 40,5625: NPHI~ .-:. 8.8867-: ~.RHOB 2.785...2 6; 0273? ~:D::R HO ~ ::''~ -:'NRAT:::.' ::- 1742.0.000 _ : ...:~: :.63..3750 GR . 40.5.625 43.9]75 I5~- ~ 25.953:1:.- I.hD 43.6250 37' 4063 NPHI: - :: 6.02~3 . DRHO .?? .... 0.0000 .NRAT. ...... i'8.t.45 1440.0000 :DT-: : ?' :68:'*:I'87:5::'~R-~:~:::-. ' 37.5625- -~- .::12'35.35 ........ RHO:B -2..:984~ 6,0820 DRH.O :':?''':.::: O:.: T:~ .:'c ?:- ::::::: ~: 1421,0000 DT ,~ 8 0.:., ~500 .... GR 37'5625 . ._ :~ .~.~ i:: .,.: >::.~:::~ :/~.:::.. _::i: :A:.: .? _: :..-?~ .:__....,~_.::.:::::~ .27:~:~:;.: 45,28 ~3 IbM ..... ~,..~ 32,5625 .... IbD ~4,2813 NPMI';: :: ~ ~-'38:~ 0'::~:' OB::': ;'''::'-':~: ::::::;:~2'::;' ', 0547 DRHO ..... ~:~ - .O'OQOQ.:, :..NRAT -~? ?~,8~25- N.PHI. - · ...... -32.6-660 ..... RHOB 2'6699 ,04 ~:0 'DRMO '::~;~ :." :':~:0~;: :::::NRA ::::'::j::~;: 506 7500 DT . %.~..- 74,Q000:,: :.GR ...... ...: ..~.. 13,6406 ,!bM t:0:.234.4~ ILD..._ ~1-,234.~ 39.6563" :::.N PH:~::-~0;:: ~::"'~R: 95~. 05.47: DR_H.O - : ...... ..O.O..O00.::. :NRA~ ......... .0000-' :DT ::::'::: :::' ::GR-/~:'' 559.0000 ~'-b~:: :_ ; '::' 27 . 48 44 .NPHt:~.. 6.4.30.66 RHOB ..... : ...... 2::. 3926 6.0391~ DRHO'~: '::~ ::::~ ::: :'~0::~0:: 215,5000 DT :.-~ .: : ........... 27.,..:48.:.4..~. 62,9687' :'NPMi:~: :: ::~: 6,050~ D-RHO _ ..... Q'~0.O0:0 · . .NRA~ ..... :2,- 823~7 668,-921 'DT :' ::- --: ':::~ ::~i02:~: L::: :: ::: : : ::::::: :::::::::::: :::: :::::::: : 75,8750 .NPMI: :: 2-i,.6211::: RHOB .... - 2,.:7703 , P781 DRHO .' ::: - :::: AT'::::":::': :' /' :?::- B12.250.0 DT 74.]7..50~ GR 75.8750 bVP 010,HO1 VERIFICATION DEPT 9600.0000 SFLU SP -999.2500 GR GR 76,3125 CALl NCNb 1866. 0000 FCNL DEFT SP GR NCNb DEFT SP GR NCNb DEFT SP NCNb DEFT SP NCNb DEFT GR NCNb DEFT GR NCNb DEPT SP GR NCNL DEFT SP GR NCNb DEPT SP NCNb O£PT SP GR 9500.0000 SFLU -999,2500 GR 39.8184 CALI 2876,1250 FCNL .9400 0000 SFLU ]4,0625 CALI 2234,0000 FCNL 9300.0000 SFLU -999.2500 GR 33,0000 CALI 1711,0000 FCNL 9200.0000 SFLU -999.2500 GR 47.7188 CALI 2074.0000 FCNb gl00. 0000 SFLU 096 CALI 2383,3750 FCNL ~000 0000 SFLU 999:2500 G~ 35,7500 CALl 1810,0000 FCNL 8900.0000 SFLU -999,2500 GR 38.7188 CALl 2190.0000 FCNL 8800.0000 SFLU -999,2500 OR O:o8 7 1699 000 FCNL 8700.0000 SFLU =999.2500 GR 27.0156 CAb! 1090.0000 FCNL 00,0000 SFLU -8~99.2500 GR 70.7500 CALI LISTING - PAGE . 14.6641 IbM ~ 11.,.6250.: .IbD ~ 13.2891 84,3t25 NPHi- -:'~-:28~O273':-RHOB--. 6. 0781 DRHO. : O.,O000 NRAT 2,9395 7,0469 0. 92~9 NPHI ~- 12.7617 ~RHQB 2,8499 1385,7500 DT 4,9062 I~M ~ 2,~3926. t.LD ~ ] 8,0313 NPHI' ~ ':~' '19-~ RHOB' '.-- >"2-i~9~J5 6 0625 ~RHO ~ .~ O,:0000 NRAT 886:0000 'PT'~ ~ ~80.;5625':~:GR- 6 564,5000 DT -= ::. 80~.,..000~0. 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