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197-076
KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϳͲĞĐͲϮϱ,ĂůůŝďƵƌƚŽŶ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵ͘tŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ ƚƚŶ͗͘EĂƚƵƌĂůZĞƐŽƵƌĐĞdĞĐŚŶŝĐŝĂŶƚƚŶ͗&ĂŶŶLJ,ĂƌŽƵŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬϲϵϬϬƌĐƚŝĐůǀĚ͘ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϭϴKĨĨŝĐĞ͗ϵϬϳͲϮϳϱͲϮϲϬϱ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵdŚĞƚĞĐŚŶŝĐĂůĚĂƚĂůŝƐƚĞĚďĞůŽǁŝƐďĞŝŶŐƐƵďŵŝƚƚĞĚŚĞƌĞǁŝƚŚ͘WůĞĂƐĞĂĚĚƌĞƐƐĂŶLJƉƌŽďůĞŵƐŽƌĐŽŶĐĞƌŶƐƚŽƚŚĞĂƚƚĞŶƚŝŽŶŽĨƚŚĞƐĞŶĚĞƌĂďŽǀĞt >>ED W/η ^ Zs/ KZ Zη &/ >ED :KdzW ddzW >K''/E'd WZ/Ed^η /'/d>η ^ dηϭ ϯ<ͲϯϮ ϱϬͲϬϮϵͲϮϮϳϲϯͲϬϬ ϵϭϬϰϳϰϯϬϭ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮͲĞĐͲϮϱ Ϭ ϭϮ ϯKͲϬϰ ϱϬͲϬϮϵͲϮϭϴϮϲͲϬϬ ŶͬĂ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϮͲEŽǀͲϮϱ Ϭ ϭϯϰϱϲϳϴϵϭϬW> ^ <EKt> ' Z /Wdz^/'E/E'EZ dhZE/E'KWzK&d, dZE^D/dd>> dd ZdKd, dd Ed/KEK&͗&ĂŶŶLJ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗T41208T41209197-076188-062Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.12.17 13:39:32 -09'00'197-07188 06ϭϯ<ͲϯϮϱϬͲϬϮϵͲϮϮϳϲϯͲϬϬ ϵϭϬϰϳϰϯϬϭ<ƵƉĂƌƵŬZŝǀĞƌWůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϮͲĞĐͲϮϱϬϭ KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϳͲĞĐͲϮϱ,ĂůůŝďƵƌƚŽŶ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵ͘tŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ ƚƚŶ͗͘EĂƚƵƌĂůZĞƐŽƵƌĐĞdĞĐŚŶŝĐŝĂŶƚƚŶ͗&ĂŶŶLJ,ĂƌŽƵŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬϲϵϬϬƌĐƚŝĐůǀĚ͘ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϭϴKĨĨŝĐĞ͗ϵϬϳͲϮϳϱͲϮϲϬϱ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵdŚĞƚĞĐŚŶŝĐĂůĚĂƚĂůŝƐƚĞĚďĞůŽǁŝƐďĞŝŶŐƐƵďŵŝƚƚĞĚŚĞƌĞǁŝƚŚ͘WůĞĂƐĞĂĚĚƌĞƐƐĂŶLJƉƌŽďůĞŵƐŽƌĐŽŶĐĞƌŶƐƚŽƚŚĞĂƚƚĞŶƚŝŽŶŽĨƚŚĞƐĞŶĚĞƌĂďŽǀĞt >>ED W/η ^ Zs/ KZ Zη &/ >ED :KdzW ddzW >K''/E'd WZ/Ed^η /'/d>η ^ dηϭ ϭͲϭϰ ϱϬͲϬϮϵͲϮϮϵϱϬͲϬϬ ϵϭϬϱϬϴϬϭϭ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϭͲĞĐͲϮϱ Ϭ ϭϮ ϭͲϭϯϬ ϱϬͲϬϮϵͲϮϮϴϭϱͲϬϬ ϵϭϬϰϳϰϬϵϵ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϳͲEŽǀͲϮϱ Ϭ ϭϯ ϭ ͲϬϯ ϱϬͲϬϮϵͲϮϬϰϳϳͲϬϬ ϵϭϬϰϯϮϬϱϱ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϮϭͲEŽǀͲϮϱ Ϭ ϭϰ ϭ ͲϬϯ ϱϬͲϬϮϵͲϮϬϰϳϳͲϬϬ ϵϭϬϰϯϮϬϱϱ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϯͲEŽǀͲϮϱ Ϭ ϭϱ ϭ ͲϬϰ ϱϬͲϬϮϵͲϮϬϰϳϴͲϬϬ ϵϭϬϰϯϮϭϱϰ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϵͲEŽǀͲϮϱ Ϭ ϭϲ ϭ Ͳϭϴ ϱϬͲϬϮϵͲϮϬϵϬϰͲϬϬ ϵϭϬϰϳϰϮϯϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϵͲĞĐͲϮϱ Ϭ ϭϳ ϭ'ͲϭϮ ϱϬͲϬϮϵͲϮϭϬϬϵͲϬϬ ϵϭϬϱϬϴϬϮϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϱͲĞĐͲϮϱ Ϭ ϭϴ ϯͲϭϴ ϱϬͲϬϮϵͲϮϮϲϵϮͲϬϬ ϵϭϬϰϳϯϯϲϴ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϵͲEŽǀͲϮϱ Ϭ ϭϵ ϯ<ͲϬϯ ϱϬͲϬϮϵͲϮϭϲϬϮͲϬϬ ϵϭϬϰϯϮϬϰϬ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϲͲEŽǀͲϮϱ Ϭ ϭϭϬ ϯ<ͲϯϮ ϱϬͲϬϮϵͲϮϮϳϲϯͲϬϬ ϵϭϬϰϳϰϯϬϭ <ƵƉĂƌƵŬZŝǀĞƌ >ĞĂŬĞƚĞĐƚ>ŽŐ &ŝĞůĚͲ&ŝŶĂů ϮͲĞĐͲϮϱ Ϭ ϭW> ^ <EKt> ' Z /Wdz^/'E/E'EZ dhZE/E'KWzK&d, dZE^D/dd>> dd ZdKd, dd Ed/KEK&͗&ĂŶŶLJ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗199-089197-183180-056180-057183-016183-132196-133186-103197-076T41200T41201T41202T41202T41203T41204T41205T41206T41207T41208Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.12.17 13:38:53 -09'00'197-076ϭϬ ϯ<ͲϯϮϱϬͲϬϮϵͲϮϮϳϲϯͲϬϬ ϵϭϬϰϳϰϯϬϭ<ƵƉĂƌƵŬZŝǀĞƌ>ĞĂŬĞƚĞĐƚ>ŽŐ&ŝĞůĚͲ&ŝŶĂůϮͲĞĐͲϮϱϬϭ Originated: Delivered to:9-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-422A 50-103-20400-01 910312860 Kuparuk River Multi Finger Caliper Field & Processed 23-Sep-25 0 12 2P-422A 50-103-20400-01 910313140 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-25 0 13 2X-12A 50-029-21189-01 910262801 Kuparuk River Leak Detect Log Field- Final 26-Aug-25 0 14 3G-07A 50-103-20127-01 910313294 Kuparuk RiverLeak Detect LogField- Final 14-Sep-25 0 15 3K-20 50-029-23019-00 910312855 Kuparuk River Multi Finger Caliper Field & Processed 26-Sep-25 0 16 3K-32 50-029-22763-00 910292590 Kuparuk River Multi Finger Caliper Field & Processed 31-Aug-25 0 17 3Q-07 50-029-21682-00 910313132 Kuparuk River Tubing Cut Record Field- Final 28-Sep-25 0 18 3Q-09 50-029-21674-00 910313102 Kuparuk River Plug Setting Record Field- Final 13-Sep-25 0 19 3T-617 50-103-20918-00 910346072 Kuparuk River Radial Bond Record Field & Processed 25-Sep-25 0 110 1B-10 50-029-20656-00 910325714 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 16-Sep-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40970202-067195-176190-085201-088197-076186-194186-186225-053181-135T40974T40974T40975T40976T40977T40978T40979T40980T409813K-3250-029-22763-00910292590Kuparuk RiverMulti Finger CaliperField & Processed31-Aug-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 13:02:18 -08'00' From:Well Integrity Specialist CPF1 & CPF3 To:Loepp, Victoria T (OGC) Cc:Earhart, Will C Subject:KRU 3K-32 (PTD 197-076) Report of IA Sustained Casing Pressure Date:Thursday, June 24, 2021 12:43:43 PM Attachments:3K-32.pdf Victoria, KRU 3K-32 (PTD 197-076) was reported by Operations to have 2100 psi on the IA. The 5.5”, 15.5 lb/ft, L-80 has a burst rating of 4810 psi (45% burst of the burst rating is 2165 psi). The well has been shut in since May 10, 2021 due to TxIA communication and is currently awaiting for Coil service to remove scale from the tubing to allow wellbore entry for Wireline diagnostics. Due to limited resources Coil may be a few weeks before getting to the well. CPAI plans to pump fluids to lower the IA pressure below DNE while waiting for the Coil work. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CTMD 10,803.0 10/26/2018 3K-32 raffep Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: CHANGED OUT OV 5/2/2021 3K-32 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 41.3 Set Depth (ftKB) 6,520.0 Set Depth (TVD) … 4,086.1 Wt/Len (l… 29.70 Grade L-80 Top Thread ABM-BTC Casing Description PRODUCTION 5.5x4.5"@10419' OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 38.8 Set Depth (ftKB) 10,923.0 Set Depth (TVD) … 6,978.4 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC-MOD Tubing Strings Tubing Description TUBING - WO 2015 - UPPER String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 36.9 Set Depth (ft… 6,781.6 Set Depth (TVD) (… 4,219.5 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 36.9 36.9 0.01 HANGER FMC TUBING HANGER 2.992 41.4 41.4 0.02 XO Reducing 3-1/2" x 2 7/8 9.3#, L-80, EUE 8rd Mod Crossover sub 2.441 6,746.8 4,201.7 59.29 LOCATOR BAKER LOCATOR SUB 2.450 6,747.8 4,202.2 59.29 SEAL ASSY BAKER 80-32 SEAL ASSEMBLY 2.400 6,754.8 4,205.8 59.26 PBR BAKER 80-32 POLISH BORE RECEPTACLE 3.250 6,778.3 4,217.8 59.12 XO Enlarging 2-7/8" EUE box x 3-1/2" EUE pin crossover 2.420 6,779.9 4,218.6 59.11 ANCHOR BAKER KBH-22 ANCHOR SEAL ASSEMBLY 3.010 Tubing Description TUBING - WO 2015 - LOWER String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 6,780.5 Set Depth (ft… 9,878.0 Set Depth (TVD) (… 6,067.5 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,780.5 4,219.0 59.11 PACKER BAKER FA PACKER 3.650 6,784.8 4,221.1 59.08 XO Reducing 3-1/2" NU 10rd X 2-7/8" L-80 EUE 8rd Mod TBG XO joint 2.500 9,863.8 6,055.3 31.29 XO Enlarging 2-7/8" x 3-1/2" EUE 8rd Crossover Sub 2.430 9,865.3 6,056.7 31.28 LOCATOR BAKER LOCATOR SUB 2.430 9,866.2 6,057.4 31.27 SEAL ASSY BAKER GBH-22 BONDED 80-40 SEAL ASSEMBLY 2.990 Tubing Description TUBING - WO 2007 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 9,871.6 Set Depth (ft… 9,990.6 Set Depth (TVD) (… 6,164.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,871.6 6,062.0 31.23 PBR PBR 3.000 9,885.2 6,073.6 31.14 PACKER BAKER SABL-3 PACKER w/KBH-22 ANCHOR SEAL 2.780 9,936.0 6,117.2 30.86 NIPPLE OTIS 2.313" XN NIPPLE (2.205" No-Go) 2.205 9,984.9 6,159.2 30.44 OVERSHOT 3.5" POORBOY OVERSHOT - SWALLOWS 3.1' OF 3.5" TUBING STUB (3.10' over stub) 3.625 Tubing Description TUBING - ORIGINAL 1997 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 9,987.7 Set Depth (ft… 10,428.8 Set Depth (TVD) (… 6,544.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,419.1 6,536.3 28.68 NIPPLE CAMCO 'D' NIPPLE NO GO 2.250 10,426.8 6,543.1 28.68 LOCATOR BAKER LOCATOR 3.000 10,427.8 6,544.0 28.68 SEAL ASSY BAKER GBH-22 LOCATING SEAL ASSEMBLY w/17' SEALS 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN CSG PATCH SURFACE CASING PATCH: Install .375" SC patch that straddles SC collar. Total patch length from bottom of mandrel hanger to lower most wedding band is 10' 3"; ID 7.625" 9/15/2008 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,534.0 10,554.0 6,637.2 6,654.7 A-3, 3K-32 5/28/1997 4.0 IPERF 2 1/8" Big Hole EJ, 180 deg. phase 10,534.0 10,554.0 6,637.2 6,654.7 A-3, 3K-32 8/19/1997 4.0 RPERF 2 1/8" EnerJet, 180 deg. phase 10,572.0 10,592.0 6,670.5 6,688.0 A-2, 3K-32 4/21/2006 6.0 APERF 2 1/8" EnerJet, 45 deg. phase Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,032.1 2,433.6 62.08 CAMCO KBMM 4 3/4 GAS LIFT GLV BK-5 0.156 1,278.0 5/6/2018 2 5,461.4 3,569.3 62.25 CAMCO KBMM 4 3/4 GAS LIFT GLV BK-5 0.188 1,301.0 5/6/2018 3 6,691.7 4,173.5 59.29 CAMCO KBMM 4 3/4 GAS LIFT OV BK-5 0.188 0.0 4/30/2021 4 10,406.9 6,525.6 28.68 CAMCO KBMM 1 GAS LIFT DMY 0.000 0.0 5/17/1997 Notes: General & Safety End Date Annotation 5/2/2021 NOTE: Unable to stay latched up to Sta #2. Unbable to drift fullbore below GLM #3 7/26/2008 NOTE: VIEW SCHEMATIC w/9.0 3K-32, 5/3/2021 7:19:01 AM Vertical schematic (actual) PRODUCTION 5.5x4.5"@10419'; 38.8-10,923.0 APERF; 10,572.0-10,592.0 IPERF; 10,534.0-10,554.0 RPERF; 10,534.0-10,554.0 LOCATOR; 10,426.8 NIPPLE; 10,419.1 GAS LIFT; 10,406.9 OVERSHOT; 9,984.9 NIPPLE; 9,936.0 PACKER; 9,885.2 PBR; 9,871.6 SEAL ASSY; 9,866.2 LOCATOR; 9,865.3 PACKER; 6,780.5 ANCHOR; 6,779.9 XO Enlarging ; 6,778.3 PBR; 6,754.8 SEAL ASSY; 6,747.8 LOCATOR; 6,746.8 GAS LIFT; 6,691.7 SURFACE; 41.3-6,520.0 GAS LIFT; 5,461.4 GAS LIFT; 3,032.1 CONDUCTOR; 41.0-121.0 HANGER; 36.9 KUP PROD KB-Grd (ft) 41.02 Rig Release Date 5/29/1997 3K-32 ... TD Act Btm (ftKB) 10,944.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292276300 Wellbore Status PROD Max Angle & MD Incl (°) 64.95 MD (ftKB) 2,750.00 WELLNAME WELLBORE3K-32 Annotation Last WO: End Date 6/26/2015 H2S (ppm) 120 Date 10/14/2016 Comment SSSV: NONE P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ,HAY t 3 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations o n ❑ Performed: Suspend El Perforate El Other Stimulate El Alter Casing 11 Change Approved rogram ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Conductor Extension I] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ Stratigraphic ❑ Service ❑ 1 197-076 3. Address: 6. API Number: P.O.Box 100360, Anchorage, Alaska 99510 1 50-029-22763-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025519, ADL0025628, ADL0025629 KRU 3K-32 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Kuparuk River/Kuparuk River Oil 11. Present Well Condition Summary: Total Depth measured 10923 feet Plugs measured feet true vertical 5679 feet Junk measured feet Effective Depth measured 10923 feet Packer measured feet true vertical 5679 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 121' 121' Surface 6479' 7.625" 6520' 4086' Production 10388' 5.5" 10429' 5529' Production 496' 4.5" 10923' 5679' Liner Perforation depth Measured depth 10534 to 10554 feet 10572 to 10592 True Vertical depth 5561 to 5567 feet 5573 to 5579 Tubing (size, grade, measured and true vertical depth) 2.875", L-80, 9878' Packers and SSSV (type, measured and true vertical depth) Baker FA packer 6781 MD, 4219 TVD Baker GBH -22 Bonded 80-40 Seal Assembly 9866 MD, 6057 TVD 12. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-McfWater-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 121 Exploratory ❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil [0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-556 Authorized Name: Roger Winter Contact Name: Roger Winter/Roger Mouser Authorized Title: WI Field Supervisor Contact Email: N1927roDconocoohillios.com r Authorized Signature: Dab 5/9/2019 Contact Phone: 659-7506 Form 10-404 Revised 4/2017 R13DMSIE-4 /MAY 131019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 09, 2019 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7h Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 Sundry from ConocoPhillips Alaska, Inc. well 3K-32, PTD# 197-076, Sundry # 318-556 for conductor extension. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor Summary of work 4/27/2019 Weld 10" of 16" .375 wall pipe to existing conductor. I 404' r "Copyright 2019. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by other party is prohibited without the express consent of ConocoPhillips Alaska, Inc." �. �• \ .{4� vk� Y 1 "Copyright 201-9. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by other party is prohibited without the express consent of ConocoPhillips Alaska, Inc." STATE OF ALASKA ' • AL A OIL AND GAS CONSERVATION COM ,SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed' Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well R Re-enter Susp Well r Other: Stacked packer F.)- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development Exploratory r 197-076 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r • 50-029-22763-00 7.Property Designation(Lease Number): 8.Well Name and Number: v ADL 25519,25629,25628 " KRU 3K-32 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): ? none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10944 feet Plugs(measured) 9936 true vertical 6997 feet Junk(measured) none Effective Depth measured 9878 feet Packer(measured) 6781, 9885 true vertical 6046 feet (true vertical) 4221,6074 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 6479 7.625 6520 4086 PRODUCTION 10884 5.5 10923 6978 BEDEWED AUG 2 6 2015 Perforation depth: Measured depth: 10534'-10554', 10572-10592 True Vertical Depth: 6637'-6655',6671'-6688' Q�pp••pp AO G CC SChN$E 11 Tubing(size,grade,MD,and TVD) 2.875, L-80, 9872 MD,6062 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FA PACKER @ 6781 MD and 4221 ND PACKER-BAKER SABL-3 PACKER W/KBH-22 ANCHOR SEAL @ 9885 MD and 6074 ND no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 96 370 2305 124 167 14.Attachments(required per 20 AAC 25.070 315-253 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r , Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: - Oil P Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-352 Contact Janelle Nesvold @ 263-4641 Email Janelle.R.Nesvold@conocophillips.com Printed Name Janelle Nesvold Title Wells Engineer Signature g- / geir-k-rePhone:263-4641 Date 81/2,51`5 V7L 41/2//5- RBDMSJ 6 2 6 2016 Form 10-404 Revised5/20 5 Submit Original Only " KUP PROD 3K-32 ConocoPhillips & ` Well Attributes Max Angle&MD TD A.1Sk2-1 i{,. Wellbore API/UWI Fold Name Wellbore Status ncl(°) MD(ftKB) Act Ben(ftKB) Ocnoo41,4elpc. 500292276300 KUPARUK RIVER UNIT PROD 64.95 2,750.00 10,944.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 3K-32,8/10/2015 2:47:25 PM SSSV:NONE 130 12/24/2012 Last WO: 6/26/2015 41.02 5/29/1997 Vertical schematic(actual) Annotation Depth(MB) End Date Annotation Last Mod By End Date HANGER;36.9 •=fill Tag:SLM 9,834.0 7/18/2015 Rev Reason:WORKOVER,PULL PLUG& smsmith 8/7/2015 le:)till CATCHER Casing Strings , ,„ , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR ir 16 15.062 41.0 121.0 121.0 62.50 H-40 WELDED r' NI, CasingDesciptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread -JIJa111 / SURFACE 75/8 6.875 41.3 6,520.0 4,086.1 29.70 L-80 ABM-BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread r PRODUCTION 5 1/2 4.950 38.8 10,923.0 6,978.4 15.50 L-80 LTC-MOD 5.5x4.5"@10419' Tubing Strings CONDUCTOR;41.0-121.0-‘ ' Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING-W02015- 27/8 2.441 36.9 6,781.6 4,219.5 6.50 L-80 EUE 0/4 UPPER ' Completion Details I Nominal ID Tap(ftKB) Top(NO)(ftKB) Top Incl(°) Item Des Com (in) 36.9 36.9 0.01 HANGER FMC TUBING HANGER 2.992 GAS LIFT;3,032.1 II 41.4' 41.4 0.02 XO Reducing 3-1/2"x 2 7/8 9.3#,L-80,EUE Brd Mod Crossover sub 2.441 I 6,746.8 4,201.7 59.29 LOCATOR BAKER LOCATOR SUB 2.450 6,747.8 4,2022 59.29 SEAL ASSY BAKER 80-32 SEAL ASSEMBLY 2.400 6,754.8 4,205.8 59.26 PBR BAKER 80-32 POLISH BORE RECEPTACLE 3.250 GAS LIFT;5,461.4 6,778.3 4217.8 59.12 XO Enlarging 2-7/8'EUE box x 3-1/2"EUE pin crossover 2.420 6,779.9. 4,218.6 59.11 ANCHOR BAKER KBH-22 ANCHOR SEAL ASSEMBLY 3.010 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...WI(Ib/ft) Grade Top Connection TUBING-WO 2015- 27/8 2.441 6,780.5 9,878.0 6,067.5 6.50 L-80 EUE Mod LOWER Completion Details Nominal ID SURFACE;41.3-6,520.0 v Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 6,780.5 4,219.0 59.11 PACKER BAKER FA PACKER 3.650 6,784.8 4,221.1 59.08 XO Reducing 3-1/2"NU 10rd X 2-7/8"L-80 EUE 8rd Mod TBG XO joint 2.500 GAS LIFT;6,691.7 C • 9,863.8 6,055.3 31.29 XO Enlarging 2-7/8"x 3-1/2"EUE 8rd Crossover Sub 2.430 II 9,865.3 6,056.7 31.28 LOCATOR BAKER LOCATOR SUB 2.430 ` 9,866.2 6,057.4 31.27 SEAL ASSY BAKER GBH-22 BONDED 80-40 SEAL ASSEMBLY 2.990 LOCATOR;6,746.8 SEAL ASSY;8,747.8 _ Tubing Description String Ma...ID(in) Top(kKB) Set Depth(ft..Set Depth(ND)(...Wt(IVO Grade Top Connection TUBING-WO 2007 31/2 2.992 9,871.6 9,990.6 6,164.2 9.30 L-80 EUE8rdABMOD PER;6,754.8 Completion Details XO Enlargng;6,7]8.3 - Nominal ID (9 Top(ftKB) Top(TVD)(MB) Top Mel(°) Item Des Com (in) ANCHOR;6,779.9 €Eli 9,871.6 6,062.0 31.23 PBR PBR 3.000 PACKER;6,780.5 Il t/ 9,885.2 6,073.6 31.14 PACKER BAKER SABL-3 PACKER w/KBH-22 ANCHOR SEAL 2.780 I 9,936.0 6,117.2 30.86 NIPPLE OTIS 2.313"XN NIPPLE(2.205"No-Go) 2205 9,984.9 6,1592 30.44 OVERSHOT 3.5"POORBOY OVERSHOT-SWALLOWS 3.1'OF 3.5" 3.625 TUBING STUB(3.10'over stub) -.... Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/k) Grade Top Connection TUBING-ORIGINAL 31/2 2.992 9,987.7 10,428.8 6,544.9 9.30 L-80 EUE8rd 0 1997 LOCATOR;9,865.3 Completion Details Nominal ID SEAL ASSY;9,866.2 Top(ftKB) Top(ND)(kKB) Top Incl 7) Item Des Com (in) PBR;6,671.6 10,419.1 6,536.3 28.68 NIPPLE CAMCO'D'NIPPLE NO GO 2.250 10,426.8' 6,543.1 28.68 LOCATOR BAKER LOCATOR 3.000 PACKER;9,885.2 10,427.8• 6,544.0 28.68 SEAL ASSY BAKER GBH-22 LOCATING SEAL ASSEMBLY w/17' 2.992 - SEALS I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 'YX, , �I jQti.i NIPPLE;9,936.0 /" Top(TVD) Top Incl its Top(ftKB) (ftKB) (°) Des Com Run Dale ID(In) 1 CSG PATCH SURFACE CASING PATCH:Install.375"SC patch 9/15/2008 that straddles SC collar.Total patch length from a bottom of mandrel hanger to lower most wedding band is 10'3";ID 7.625" OVERSHOT;9,984.9 -I ' I Perforations&Slots Li , Shot Dens Top(ND) Btm(TVD) (ehotsk Top(ftKB) Bbn(kKB) (ftKB) (ftKB) Zone Date t) Type Com 10,534.0 10,554.0 6,637.2 6,654.7 A-3,3K-32 8/19/1997 4.0 RPERF 2 1/8"EnerJet,180 deg. -.`'. phase 10,534.0 10,554.0 6,637.2 6,654.7 A-3,3K-32 5/28/1997 4.0 (PERF 2 1/8"Big Hole EJ,180 I GAS LIFT,10,406.9 I deg.phase 10,572.0 10,592.0 6,670.5 6,688.0 A-2,3K-32 4/21/2006 6.0 APERF 2 1/8"EnerJet,45 deg. phase NIPPLE;10,419.1 1Mandrel Inserts 4 Bt - ali LOCATOR;10,426.8 on Top(TVD) Valve Latch Port Size TRO Run I___ N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,032.1 2,433.6 CAMCO KBMM 4 3/4 GAS LIFT DMY BK-5 1.000 0.0 7/29/2015 I 2 5,461.4 3,569.3 CAMCO KBMM 4 3/4 GAS LIFT DMY BK-5 1.000 0.0 7/29/2015 - 3 6,691.7 4,173.5 CAMCO KBMM 4 3/4 GAS LIFT SOV BKS 1.000 2,500.0 7/29/2015 SOV SHEA RED RPERF;10534.0-10,554.01 . 4 10,406.9 6,525.6 CAMCO KBMM 1 GAS LIFT DMY 0.000 0.0 5/17/1997 Notes:General&Safety End Date Annotation APERF;10,572.0-10,592.0 7/26/2008 NOTE:VIEW SCHEMATIC w/9.0 PRODUCTION 5.5.4.5•/10419';38.8-10,923.0 Time Log & Summary ConocoPhillips Wellview Web Reporting Report Well Name: 3K-32 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 6/27/2015 10:00:00 PM Rig Release: 7/5/2015 4:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/26/2015 24 hr Summary Remove berming from around the rig. Pull pit module away from rig and move module from 30 pad to 3K pad. Bridle up and lower cattle shoot. Lower derrick. Move sub base from 30 pad towards 3K pad. Shuffle rig mats. 06:00 08:30 2.50 0 0 MIRU MOVE RURD P Remove berming from around the rig. Jack up pits, pull matting boards from underneath. Pull pits away from sub base. 08:30 13:00 4.50 0 0 MIRU MOVE RURD P Prep rig floor for bridling up. Lower cattle shoot. Disconnect top drive. Bridle up and lower derrick. Jack up sub base, remove matting boards and herculite. Transport pit module from 30 pad _and stage at the entrance of 3K pad. 13:00 17:00 4.00 0 0 MIRU MOVE MOB P Move sub base from 30 pad to 3K pad. 0.5 miles from 3K access road rear driller side tire fell through road. 17:00 18:30 1.50 0 0 MIRU MOVE MOB T Lower sub base. Dig out from around the tires; place dunnage under tires. Back rig up onto rig _mats. 18:30 00:00 5.50 0 0 MIRU MOVE MOB P Shuffle mats-double mat behind rig. Back rig over double mats and shuffle the double mats into single mats x2 to get rig past thin road base. Continue moving rig towards 3K pad. X6/27/2015 Continue to move rig to 3K pad, shuffling mats as needed. Rig on location at 05:30. Hang tree in cellar. Spot sub base over well. Attempt to spot pit module, unable to sit pits down due to well houses. Pull sub base off well. Move well houses. Spot sub base over 3K-32. Raise Derrick and spot pit module. Bridle up, and berm around rig. Pre-RWO meeting. Hook up circulation hoses in cellar *Rig Accepted at 22:00 00:00 05:30 5.50 0 MIRU MOVE MOB P Continue moving rig to 3K pad, shuffling mats. Sub base on location at 05:30. 05:30 06:30 1.00 MIRU MOVE RURD P Hang tree in cellar,stage adapter flange in cellar. 06:30 08:30 2.00 MIRU MOVE MOB P Spot sub base over 3K-32. 08:30 09:30 1.00 MIRU MOVE RURD P Lay herculaite for pit module. Simops inspect derrick for raising. 09:30 10:30 1.00 MIRU MOVE MOB T Attempt to spot pit module. Well houses two wells down obstructing pits, unable to sit pits down Page 1 of 9 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 MIRU MOVE MOB T Jack up sub base and move off well to allow access for crane to move well houses. 12:00 14:00 2.00 MIRU MOVE RURD T Remove two wellhouses obstructing pit module. Simops: prep to raise derrick. Clean and clear pipeshed 14:00 15:00 1.00 MIRU MOVE MOB T Spot sub base over 3K-32. Set rig mats. Set sub base. 15:00 16:00 1.00 MIRU MOVE RURD P Raise derrick. Install pins. Rig up electric to top drive junction box. 16:00 17:00 1.00 MIRU MOVE MOB P PJSM with Peak. Spot pit module. Set mats. Set pits down and release Peak. 17:00 19:30 2.50 MIRU MOVE RURD P Install handrails and stairs. Berm around cellarbox and pits. Hook up interconnect to pit module 19:30 22:00 2.50 MIRU MOVE RURD P Bridle down blocks, Bridle up to TD. Hang rig tongs. Rig up floor. Sim ops:Take on fluid in the pits, spot auxiliary equipment. 22:00 22:30 0.50 MIRU WELCTL SFTY P Rig accepted at 22:00. Pre-RWO meeting-Davey's crew. 22:30 00:00 1.50 MIRU WELCTL RURD P Take on second load of brine in the pits. Rig up circulating hoses in cellar. 36/28/2015 Continue to rig up circulating hoses in cellar. Lubricate out BPV. Initial pressure: tubing=550 psi; IA=400 psi. Bleed off gas cap, both bleed to 0. Circulate 300 bbls of 8.4 ppg seawater at 4 bpm 900 PSI. Monitor well, static. Set BPV and test. N/D tree, N/U BOPE. Test BOPE's 250/3000 psi,with 3-1/2"test joint. State's right to witness waived by Bob Noble. Accumulator test: starting pressure 3000 psi, final pressure 1650 psi. First 200 psi recharge 38 seconds. Final recharge 154 seconds. 6 N2 bottles at 2075 psi average. Pull BPV. Rig up and attempt to pull seals from PBR. Work up to max pull of 200K(35K block weight). Continue to work pipe while waiting on digital slickline. 00:00 00:45 0.75 MIRU WELCTL RURD P Continue to rig up cellar to pull BPV, and circulation hoses to kill well. 00:45 02:15 1.50 MIRU WELCTL MPSP P PJSM. Pick up lubricator, and make up to tree. PT lubricator. Lubricate out BPV. L/D BPV. Tubing pressure-550 psi IA Pressure-400 psi OA Pressure-0 psi 02:15 04:45 2.50 MIRU WELCTL KLWL P PJSM blow air through hardline to ensure clear. PT hardline to 3500 psi-good. Bleed off gas cap on IA and tubing, no pressure build up. Establish circulation and stage pumps up to 4 bpm 740 psi final circulating pressure 900 psi. Pump _a total of 300 bbls. 04:45 05:15 0.50 MIRU WELCTL OWFF P Monitor well,static. 05:15 06:00 0.75 MIRU WHDBO MPSP P Set BPV and test to 1000 psi for 10 minutes-good. Page 2 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:30 0.50 MIRU WHDBO RURD P Rig down circulating equipment. 06:30 07:00 0.50 MIRU WHDBO SFTY P Pre-RWO meeting with Jason's Crew 07:00 09:30 2.50 MIRU WHDBO NUND P PJSM. Nipple down tree and adapter flange. Clean well head, install blanking sub. 09:30 12:00 2.50 MIRU WHDBO NUND P Nipple up BOP's. Install mousehole. Measure and record RKB's. 12:00 14:00 2.00 MIRU WHDBO RURD P Rig up testing equipment. Pick up test joint and make up safety valves. Fill stack and purge choke. 14:00 18:00 4.00 MIRU WHDBO BOPE P Test BOPE's 250/3000 psi,with 3-1/2"test joint. State's right to witness waived by Bob Noble. Accumulator test:starting pressure 3000 psi, final pressure 1650 psi. First 200 psi recharge 38 seconds. Final recharge 154 seconds. 6 N2 bottles at 2075 psi average. 18:00 19:00 1.00 MIRU WHDBO OTHR P Rig down testing equipment. 19:00 20:00 1.00 COMPZ RPCOM MPSP P Pull blanking plug and'H' BPV. 20:00 21:00 1.00 COMPZ RPCOM PULL P Make up landing joint to hanger. Back out lock down screws. 21:00 00:00 3.00 COMPZ RPCOM PULL T Attempt to pull seal free. Hanger free at 135K. Work pipe up to max pull 200K(35K block weight). Unable to pull seals from PBR. Call E-Line supervisor. E-Line unavailabe until further notice. Digital slickline avaialbe in the morning; ETA 07:00 Establish circulation, stage up to 5 bpm 900 psi while working pipe up to max pull. Still unable to pull seals free 06/29/2015 Continue to work pipe while waiting on Digital Slickline. Circulate seawater with 0.6%Safe-Lube to reduce friction. Work pipe up to 215K without pulling seals free. Rig up digital slickline. Make up string shot and RIH on slickline. Fire string shot at 9850'. POOH. Make up chemical cutter and RIH on Digital Slickline to 9,850'. Cut 3-1/2"tubing. Rig down Digital Slickline. Pull hanger to the floor. PUW 110K. Circulate annular volume. POOH with 3-1/2"decompletion to 8,500'. 00:00 04:15 4.25 0 0 COMPZ RPCOM WAIT T Continue to work pipe while waiting on Digital Slickline. Order out Safe-Lube and add 0.6%to active pit system. 04:15 05:15 1.00 0 0 COMPZ RPCOM CIRC T Circulate hole volume with 0.6% Safe-Lube in seawater while working pipe up to 200K. Observe increase in stretch as lubricant comes around. Unable to pull seals free. 05:15 06:15 1.00 0 0 COMPZ RPCOM WAIT T Continue to work pipe up to max pull of 215K. Page 3 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:15 07:00 0.75 0 0 COMPZ RPCOM RURD T Land tubing and back out landing joint. Pick up(3)8rd EUE pup joints and make up to hanger. Pull 40K over and set in slips to space out for Digital Slickline. 07:00 07:30 0.50 0 0 COMPZ RPCOM SVRG P Service rig. Grease and inspect drawworks. 07:30 09:00 1.50 0 0 COMPZ RPCOM WAIT T Continue to wait for digital slickline. Continue to work pipe with no success. 09:00 10:00 1.00 0 0 COMPZ RPCOM SLKL P Spot in Digital Slickline 10:00 12:00 2.00 0 0 COMPZ RPCOM SLKL P PJSM rig up digital slickline. Hang sheave in derrick. 12:00 12:30 0.50 0 0 COMPZ RPCOM SLKL P PJSM. Make up string shot in cellar via mousehole. Stab lubricator rig up cement line. 12:30 16:00 3.50 0 0 COMPZ RPCOM SLKL P RIH with string shot on digital slickline. Coorelate and fire string shot at 9850'. POOH with slickline. 16:00 19:30 3.50 0 0 COMPZ RPCOM SLKL P M/U chemical cutter. RIH and cut tubing at 9,850'. POOH and rig down slickline. 19:30 20:30 1.00 9,850 9,820 COMPZ RPCOM PULL P Pull hanger to the floor. Tubing broke over at 155K. PUW 110K. 20:30 22:00 1.50 9,820 9,820 COMPZ RPCOM CIRC P Circulate annular volume x2 while finishing rigging down slickline; and rig up WTF casing equipment. 22:00 00:00 2.00 9,820 8,500 COMPZ RPCOM PULL P POOH with 3-1/2"IBTm tubing from 9820'to 8,500'. PUW 105K, SOW 75K 06/30/2015 Continue to POOH with decompletion. Significat pitting from 6,845'; holes at 7768', 7798', 7845', 8199'. Lay down cut joint. Install wear bushing. Pick up BHA#1 Spear assembly. RIH picking up PH-6 from the shed to 4,148". 00:00 01:00 1.00 9,500 8,162 COMPZ RPCOM PULL P Conitnue to POOH from 8500'(PUW 85K)to 8,162'. 01:00 03:00 2.00 8,162 8,162 COMPZ RPCOM RGRP T Fix hydrualic hose on skate. 03:00 03:30 0.50 8,162 8,162 COMPZ RPCOM SVRG P Inspect and service top drive and skate. 03:30 13:00 9.50 8,162 0 COMPZ RPCOM PULL P Continue to POOH with 3-1/2"de completion from 8,162'to surface. Significant pitting observed from joint 218 from (6,904-6936')on pin and box ends. Significant pitting on the body beginning on joint 237 from (7495-7526) Holes found at 7836; 7,867'; 7,915'; 8,240'. Cut joint length 16.41'. Pictures can be found in the S: S:\ANC\Longterm\Drilling&Wells Ops\G K A\3K Pad\3K-32 Work Over 2015\Nabors 9 ES Rig Files\Pictures 13:00 14:30 1.50 0 0 COMPZ RPCOM OTHR P Clean and clear rig floor. Unload pipe shed of decompletion. Load Baker fishing tools. Page 4 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 15:15 0.75 0 0 COMPZ RPCOM RURD P Install wear bushing. 15:15 18:00 2.75 0 0 COMPZ RPCOM BHAH P PJSM. M/U BHA#1 spear assembly as per Baker. 18:00 20:30 2.50 0 2,080 COMPZ RPCOM PULD P RIH with BHA#1, pick up PH-6 pipe from the shed. Knock scale out of pipe. RIH to 2,080' 20:30 21:00 0.50 2,080 2,080 COMPZ RPCOM CIRC T Reverse circulate 1 drill pipe volume to clear pipe of any potential scale and prevent plugging BHA. 21:00 23:00 2.00 2,080 3,960 COMPZ RPCOM PULD P Continue to RIH with BHA#1, pick up PH-6 pipe from the shed. Knock scale out of pipe to 3960'. 23:00 23:30 0.50 3,960 3,960 COMPZ RPCOM CIRC T Reverse circulate 1 drill pipe volume to clear pipe of any potential scale and prevent plugging BHA. 1.5 bpm 480 psi 23:30 00:00 0.50 3,960 4,148 COMPZ RPCOM PULD P Continue to RIH with BHA#1, pick up PH-6 pipe from the shed. Knock scale out of pipe to 4148' 07/01/2015 Continue to RIH with BHA#1, spear assembly, picking up PH-6 to 9,831', PUW138K, SOW 82K. Engage tubing stump at 9,831'. Pick up to 190K and seals came free. Circulate hole clean. POOH and lay down seal assembly. Rig up and RIH with BHA#2 casing scraper/test packer to 2,400'. 00:00 02:30 2.50 4,148 5,837 COMPZ RPCOM PULD P Continue to RIH with BHA#1, picking up PH-6 drill pipe from the shed from 4,148'to 5837' 02:30 03:15 0.75 5,837 5,837 COMPZ RPCOM CIRC T Reverse circulate 1 drill pipe volume to clear pipe of any potential scale and prevent plugging BHA. 1.5 bpm 563 psi 03:15 08:00 4.75 5,837 9,800 COMPZ RPCOM PULD P Continue to RIH with BHA#1, picking up PH-6 drill pipe from the shed from 5837'to 9800-ft 08:00 09:00 1.00 9,800 9,800 COMPZ RPCOM CIRC T Reverse circulate 100 bbls at 2.5 bpm @ 1670 psi 09:00 09:45 0.75 9,800 9,824 COMPZ RPCOM FISH P Continue to Pick up and RIH w/BHA #1 from 9,800-ft 138k Up wt, 82k Dn wt to TOF @ 9,850-ft ELM(9,843-ft RKB Corrected)and engage @ 9,848-ft. Set 15k down on fish and pull up to 155k, allow jars to bleed and bring pump on line at 1 bpm @ 450 psi. Continue to pull on seals from PBR and seen seals move 190k. increase PR to 2.0 bpm @ 1200 psi w/seals setting 2-ft above PBR. 09:45 12:00 2.25 9,824 9,824 COMPZ RPCOM CIRC P Pump 40 bbl hi visc sweep to clean well bore. @ 2.4 bpm @ 1500 psi. Monitor well for 10 minutes. 12:00 17:30 5.50 9,824 231 COMPZ RPCOM TRIP P POOH with BHA#1 standing back in derrick.. PUW 135K, SOW 80K.to 231'. 17:30 19:00 1.50 231 0 COMPZ RPCOM BHAH P PJSM. Lay down BHA. Break out Seal assembly and lay down. Page5of9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:00 1.00 0 0 COMPZ WELLPF RURD P Change out elevators. Clean and clear rig floor. Send out Baker fishing tools. Pick up Casing scraper tool. 20:00 20:30 0.50 0 0 COMPZ WELLPF SVRG P Inspect and service top drive and drawworks. 20:30 22:30 2.00 0 1,983 COMPZ WELLPF TRIP P PJSM Pick up mule shoe. Trip in the hole with mule shoe to 1,983'. 22:30 23:30 1.00 1,983 2,009 COMPZ WELLPF BHAH P Make up crossovers,casing scraper _and test packer. 23:30 00:00 0.50 2,009 2,400 COMPZ WELLPF TRIP P Continue to trip in the hole with stands to 2,400'. PUW 58K, SOW 55K. 07/02/2015 Continue to RIH with test packer to 8,850'(test packer COE 6,850'). Set test packer and test 5-1/2"casing to surface to 3000 psi for 30 minutes-no pressure loss. Continue to trip in the hole to 9,867'. Circulate 1.5 times annular volume at 5 bpm. Slip and cut drilling line. Trip out of the hole laying down drill pipe. 00:00 00:45 0.75 2,400 2,855 COMPZ WELLPF TRIP P Contine to RIH from derrick from 2,400'to 2,855'PUW 58K, SOW 50K. 00:45 01:15 0.50 2,855 2,855 COMPZ WELLPF DHEQ P Shallow test test packer. Set packer and test to 1500 psi for 5 minutes- good. 01:15 05:00 3.75 2,855 8,850 COMPZ WELLPF TRIP P Continue to trip in hole from 2855'to 8,850'. 05:00 06:30 1.50 8,850 8,850 COMPZ WELLPF PRTS P Set test packer at 6,850'ORKB and test 5-1/2"casing to 3000 psi for 30 minutes from 6,850'to surface. Good test no pressure loss. 06:30 08:15 1.75 8,850 9,867 COMPZ WELLPF TRIP P Continue to trip in the hole to 9,867' and no go mule shoe in PBR. PUW 132K, SOW 80K 08:15 10:00 1.75 9,867 9,867 COMPZ WELLPF CIRC P Circulate 1.5 times hole voulme at 5 bpm 1868 psi. Monitor well for 10 minutes. 10:00 11:30 1.50 9,867 9,867 COMPZ WELLPF SLPC P Slip and cut 84'of drilling line. 11:30 12:00 0.50 9,867 9,867 COMPZ WELLPF SVRG P Inspect and service top drive. 12:00 22:00 10.00 9,867 1,983 COMPZ WELLPF PULD P POOH laying down drill pipe from 9867'to 1983' 22:00 23:00 1.00 1,983 1,983 COMPZ WELLPF BHAH P Lay down casing scraper, boot basket and test packer. 2 cups of _ __ sand recovered in boot basket. 23:00 00:00 1.00 1,983 0 COMPZ WELLPF PULD P Continue to POOH laying down drill pipe to surface. 07/03/2015 Set test plug. Change out UPR's to 2-7/8 x 5 VBR's. Test Annular, UPR and LPR with 2-7/8"test joint 250/3500 psi. Upper pipe rams did not hold;with new elements and top seal. Change out elements and top seal and attempt to test again, rams did not hold. Perform break in cycle and retest 250/3500 psi-good. Rig down testing equipment. Rig up and RIH with 2-7/8"completion to 6309'. 00:00 00:30 0.50 0 0 COMPZ RPCOM RURD P Change out pipe handling equipment to 2-7/8". 00:30 01:00 0.50 0 0 COMPZ RPCOM SFTY P Safety stand up with Davey's crew. Review incident with wicker in hand getting infected. AAR on laying down PH-6 drill pipe. Page 6 of 9 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 01:00 01:30 0.50 0 0 COMPZ RPCOM BOPE P Suck out stack. Pull wear bushing. Set test plug. 01:30 03:15 1.75 0 0 COMPZ RPCOM BOPE P PJSM. Change out UPR to 2-7/8"x 5"VBR's. Rig up to test BOPE. 03:15 04:00 0.75 0 0 COMPZ RPCOM'BOPE P PJSM. Fill BOPE stack and rig up to test BOPE's. 04:00 05:30 1.50 0 0 COMPZ RPCOM BOPE P Test BOPE rams on 2-7/8"test joint 250/3500 psi. Annular-pass LPR-pass UPR fail. Unable to get 2-7/8"x 5" VBR to hold pressure. Packers _ elements in ram are new. 05:30 09:00 3.50 0 0 COMPZ RPCOM EQRP T Lay down test joint. Drain BOPE and remove top rams. Inspect top rams. Appear to be in good condition. Change out top seal and packer element. Install pipe rams. 09:00 09:15 0.25 0 0 COMPZ RPCOM BOPE T Pick up test joint and fill stack. 09:15 10:00 0.75 0 0 COMPZ RPCOM BOPE T Attempt to test UPR on 2-7/8"test joint, rams still not holding pressure 10:00 12:30 2.50 0 0 COMPZ RPCOM BOPE T PJSM. Drain stack. Open UPR doors and inspect. Inspect top seal, element,wear plates. Appear to be in good condition. Close UPR doors. 12:30 14:30 2.00 0 0 COMPZ RPCOM BOPE T Attempt to test UPR with 2-7/8"test joint. Function rams, increase manifold pressure to max and function rams several times. Lower manifold pressure to 1500 psi and _ test UPR's 250/3500 psi-good. 14:30 15:00 0.50 0 0 COMPZ RPCOM BOPE P Lay down test joint. Pull test plug. Fill stack. 15:00 15:30 0.50 0 0 COMPZ RPCOM RURD P Rig up to RIH with 2-7/8"completion 15:30 19:45 4.25 0 3,080 COMPZ RPCOM PUTB P RIH with 2-7/8"completion as per detail to 3,080' 19:45 20:30 0.75 3,080 3,113 COMPZ RPCOM PUTB P Pick up Baker SABL packer, PBR with KBH Anchor seal assembly. 20:30 00:00 3.50 3,113 6,309 COMPZ RPCOM PUTB P Continue to pick up 2-7/8"tubing as per detail to 6,309'. PUW 62K, SOW 52K. 07/04/2015 Continue to RIH with 2-7/8"completion as per detail to 9838'. Rig up circulating equipment. Locate PBR with 1 bpm, observe pressure increase at 9,862'. Observe No-Go at 9,874'. Pick up and spot corrosion inhibited brine between SABL packers. Space out 3'and set SABL packer with 4500 psi. Shear out PBR. Spot corrosion inhibted seawater from PBR to surface on IA. Space out and land tubing. PT tubing to 3000 psi for 15 minutes-good. PT IA to 2500 psi for 30 minutes-good. Shear out SOV. Monitor well, static. Set BPV and test from below-good. N/D BOPE, N/U tree. Pull BPV and set TWC and test tree/adapter flange 250/5000 psi-good. 00:00 04:00 4.00 6,309 9,838 COMPZ RPCOM PUTB P Continue to pick up tubing and run 2-7/8"completion as per detail to _9838. PUW 83K, SOW 60K. 04:00 05:00 1.00 9,838 9,838 COMPZ RPCOM RURD P Rig up circulating head Page 7 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:45 0.75 9,838 9,874 COMPZ RPCOM HOSO P Slack off pumping 1 bpm to locate PBR. Observe pressure increase at 9,862'. Shut down pumps slack off and no-go at 9,874'. 05:45 07:30 1.75 9,874 9,858 COMPZ RPCOM CRIH P Pick up to 9,858'and spot corrosion inhibted brine between SABL packers. Pump 50 bbls corrosion inhibited seawater with 0.55 gal/bbl Conqor 303A, 0.25 ppb Sodium Metabisulfite and 0.05 gal/bbl Busan. Followed by 63 bbls of clean seawater(57 tubing tail plus 6 line volume.) 07:30 08:30 1.00 9,858 9,871 COMPZ RPCOM PACK P Drop ball and rod. Slack off to 3' from no-go. Pressure up to 4500 psi to set packer as per Baker 08:30 09:00 0.50 9,871 9,871 COMPZ RPCOM PRTS P Pressure test the SABL packer with 2500 psi down the IA-good. 09:00 10:15 1.25 9,871 6,759 COMPZ RPCOM THGR P With 2500 psi on tubing pick up and shear out PBR. Space out 7'. Make up tubing hanger and landing joint. 10:15 11:30 1.25 6,759 6,775 COMPZ RPCOM CRIH P Spot corrosion inhibited brine to fill the IA; Pump 105 bbls corrosion inhibited seawater with 0.55 gal/bbl Conqor 303A, 0.25 ppb Sodium Metabisulfite and 0.05 gal/bbl Busan. Followed by 40 bbls of clean seawater 11:30 12:30 1.00 0 0 COMPZ RPCOM THGR P Drain BOPE, land hanger, RILDS. 12:30 14:00 1.50 0 COMPZ RPCOM PRTS P Pressure test tubing to 3000 psi for 15 minutes. Bleed down to 1500 psi. Pressure test IA to 2500 for 30 minutes-good. Bleed pressure. Pressure up IA and shear out SOV at 2300 psi. 14:00 14:30 0.50 COMPZ RPCOM OWFF P Monitor well for 30 minutes-static. 14:30 15:00 0.50 COMPZ RPCOM RURD P Clean and clear rig floor. Rig down Weatherford casing tools 15:00 15:30 0.50 COMPZ WHDBO MPSP P Set BPV and test to 1000 psi from below-good. 15:30 18:30 3.00 COMPZ WHDBO NUND P Blow down choke manifold, mud manifold, HCR's. Drain stack. Nipple down BOPE's 18:30 21:00 2.50 COMPZ WHDBO NUND P Clean up tubing spool and hanger. Nipple up tubing adapter and tree. DSO M. Davis witnessed 21:00 21:30 0.50 COMPZ WHDBO MPSP P Pull BPV. Set TWC. 21:30 22:30 1.00 COMPZ WHDBO PRTS P Test adapter voids 250/5000 psi- good. Test tree 250/5000 psi-good. 22:30 23:00 0.50 COMPZ WHDBO MPSP P Drain tree. Pull TWC. SimOps: Empty and clean pits 23:00 00:00 1.00 COMPZ WHDBO RURD P Rig up manifold and hoses to freeze protect well with Little Red Services. 07/05/2015 Freeze protect well with 49 bbls of diesel, allow to U-tube. Set BPV. RDMO Page 8 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 COMPZ WHDBO RURD P Continue rigging up to freeze protect well. Rig up Little Red Services. Simops: Disconnect interconnect to pits. 01:00 03:00 2.00 COMPZ WHDBO FRZP P PJSM. PT lines. Freeze protect well with 49 bbls of diesel, pumped down the IA. Allow well to U-tube. SimOps: Continue to rig down and prep for rig move. 03:00 03:30 0.50 COMPZ WHDBO MPSP P PJSM. Set BPV 03:30 04:00 0.50 DEMOB MOVE RURD P Secure cellar. Dress tree. Continue to rig down. Released Nabors 9ES at 04:00 on 7-6-15 Page 9 of 9 ConocoPhillips Time Log & Summary WelIview Web Reporting Report Well Name: 3K-32 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 7/22/2015 4:00:00 PM Rig Release: 7/30/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/21/2015 2a hr Summary Jack sub base up. Pull herculite and mats from underneath. Prep rig floor to Derrick up. Raise Derrick. Hook sow to pit module and spot in. 12:00 17:00 5.00 MIRU MOVE RURD P Jack up sub base. Pull herculite and rig mats from underneath sub base. Lay out rig mats. Off load PH-6 from truck. 17:00 18:00 1.00 MIRU MOVE OTHR P Post maintenance derrick inspection. 18:00 21:00 3.00 MIRU MOVE RURD P Prep rig floor to raise derrick. Raise and pin derrick. Clean and clear rig floor and prep for RWO. Move auxiliary equipment to spot in pit module. 21:00 22:00 1.00 MIRU MOVE MOB P Move sub base over to allow pit module by. 22:00 00:00 2.00 MIRU MOVE MOB P Hook sow to pit module, move around sub base and line up. 07/22/2015 Spot sub base over well,spot pit module. Berm up around rig. Bridle down lines, bridle up blocks. Take on seawater. Rig up circulating hoses. Lubricate out BPV. Bleed off pressure and circulate out corrosion inhibited seawater and freeze protect with clean sewater. Set BPV. 00:00 00:30 0.50 MIRU MOVE RURD P Lay rig mats around cellar 00:30 02:45 2.25 MIRU MOVE MOB P Spot in sub base over 3K-32. Lay out herculite and center sub base over well. 02:45 03:45 1.00 MIRU MOVE RURD P Set rig mats and herculite for pit • _ module. 03:45 06:00 2.25 MIRU MOVE MOB P Spot in pit module. 06:00 12:00 6.00 MIRU MOVE RURD P Berm up around pit module, cellar and cuttings box. Hook up interconnect. Install dog bones on top drive. Inspect high pressure mud line at interconnect. 12:00 16:00 4.00 MIRU MOVE RURD P Bridle down lines, bridle up blocks. Prep pipe shed for loading 3=1/2" PH-6. Take on seawater to pis. Rig accepted at 16:00 16:00 19:00 3.00 MIRU WELCTL RURD P Rig up circulating lines to tree. Blow air through kill tank to ensure clear. 19:00 21:00 2.00 MIRU WELCTL MPSP P Pick up lubricator and test. Lubricate out'H' BPV. Tubing pressure 250, IA=250 psi. Page 1 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:45 1.75 MIRU WELCTL KLWL P PJSM. Bleed off tubing and IA pressure. No pressure build up. Circulate seawater staging pumps up to 4 bpm 810 psi. Circulate until returns are clean,215 bbls. 22:45 23:15 0.50 MIRU WELCTL OWFF P Monitor well,static. 23:15 23:30 0.25 MIRU WHDBO MPSP P Set'H' BPV 23:30 00:00 0.50 MIRU WHDBO SFTY P Pre-RWO meeting with both crews X7/23/2015 Rig down circulating manifold. N/D tree and adapter. Install blanking plug. N/U BOPE. Rig up and test BOPE's with 2-7/8"and 3-1/2"test joints. Test witnessed by AOGCC rep John Crisp.Accumulator test: Starting pressure 3900 psi,final 1600 psi. First 200 psi recharge 34 seconds,full recharge 165 second. 6 N2 bottles with 2025 psi average. Rig down testing equipment. Pick up 10 stands of 4"drill pipe and create'L' shape in derrick to assist standing back 2-7/8"drill pipe. 00:00 00:30 0.50 MIRU WHDBO RURD P Rig down circulating manifold 00:30 02:30 2.00 MIRU WHDBO NUND P Nipple down tree and adapter, hang tree in cellar. Install blanking plug. 02:30 07:00 4.50 MIRU WHDBO NUND P Nipple up BOPE with 2-7/8"x 5" VBR's in UPR and LPR. Install riser. 07:00 09:00 2.00 MIRU WHDBO RURD P Rig up to test BOPE's. Grease choke manifolds. Fill stack and purge air out of systems. 09:00 18:00 9.00 MIRU WHDBO BOPE P Test BOPE with 2-7/8"and 3-1/2" test joints. Initial test on components 250/5000 psi; subsequent and annular 250/3000 psi. Test witnessed by AOGCC rep John Crisp. 1.Annular with 3-1/2"TJ; kill demco; 4" HT40 TIW; chokes 1, 2, 3, 16- pass 2. UPR with 3-1/2"TJ; HCR kill; chokes 4, 5, 6-pass 3. Manual Kill; chokes 7, 8,9-pass 4. Choke 10, 11 -pass 5. Choke 12, 13, 14-pass 6. Choke 15-pass 7. TIW; HCR choke-pass 8. Manual choke-pass 9. LPR with 3-1/2"TJ-pass 10. Blind rams-pass 11. Annular with 2-7/8"TJ, Dart - pass 12. UPR with 2-7/8"TJ-pass 13. LPR with 2-7/8"TJ -pass 14. Outer test spool;TD IBOP - pass 15. Inner test spool; Manual TD- pass Accumulator test: Starting pressure 3900 psi, final 1600 psi. First 200 psi recharge 34 seconds,full recharge 165 second. 6 N2 bottles with 2025 psi average. Page 2 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 MIRU WHDBO RURD P Rig down testing equipment. Blow down choke manifold,top drive, kill line. Suck out stack. 19:00 21:15 2.25 COMPZ RPCOM RURD P Prep rig floor to pick up drill pipe to create'L'to assist in standing back 2-7/8"tubing. Pick up and rig up pipe handling equipment; bails, elevators, rig tongs. Pick up and install mouse hole. Rig up Weatherford Casing equipment. 21:15 00:00 2.75 COMPZ RPCOM PULD P Install mouse hole. Pick up and stand back 10 stands 4"drill pipe in 'L'shape tie up to assist holding up 2 7/8"tubing. Lay down mouse hole. 07/24/2015 Pull blanking plug and'H' BPV. Make up landing joint with TIW valve on top. Back out lock down screws. Pull hanger to the floor; PUW 65K. Circulate annular volume at 5 bpm 925 psi. Pull out of the hole with 2-7/8" decompletion. Standing tubing back in the derrick, laying down all GLM's. Replacing seal rings and inspecting all threads. Install wear bushing. Make up BHA#1 PBR retrieval tool. Single in the hole with PH-6 drill pipe from pipe shed to 5600'. 00:00 01:15 1.25 0 0 COMPZ RPCOM MPSP P PJSM. Pick up blanking plug removal tool Pull blanking plug. Dry rod 3"'H' BPV 01:15 03:30 2.25 6,774 6,746 COMPZ RPCOM PULL P Pick up landing joint, install TIW valve. Screw into hanger. BOLDS. Pull hanger to the floor; PUW 65K no drag observed. Break out and lay down hanger. 03:30 04:00 0.50 6,746 6,746 COMPZ RPCOM CIRC P Circulate annular volume, 5 bpm 925 psi. Monitor well for 10 minutes. 04:00 12:00 8.00 6,746 0 COMPZ RPCOM PULL P POOH standing back 2-7/8" decompletion, changing out seal rings. Lay down GLM's and pup joint. Inspect 2-7/8"threads on the way out. Lay down seal assembly; seals are in good condition. 12:00 13:30 1.50 0 0 COMPZ RPCOM RURD P Rig down 2-7/8"pipe handling equipment. Change out dies for power tongs. Prep pipe shed, load BHA 1 components 13:30 14:00 0.50 0 0 COMPZ RPCOM RURD P Install wear bushing, RILDS 14:00 16:00 2.00 0 286 COMPZ RPCOM BHAH P PJSM Pick up and make up BHA#1 PBR retrieve)tool, bumper sub, Bowen Jars and Drill collars 16:00 00:00 8.00 286 5,600 COMPZ RPCOM PULD P Single in the hole with PH-6 drill pipe picking up pipe from pipe shed from 286'to 5600'. X7/25/2015 Continue to RIH with PBR retireval tool to 6,757'. Engage PBR, pick up 5K over nuetral weight and rotate to release K-Anchor. Monitor well,static. POOH with BHA#1. Lay down BHA and fish; PBR and K-Anchor. Pick up BHA#2 Packer Milling assembly and RIH to 6,777';tag packer. Mill SABL packer; pumping high viscosity sweeps to clean hole. Mill 1.5'and observe packer drop—1.5'. Mill additional 1'. Circulate hole clean. Page 3 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:45 1.75 5,600 6,757 COMPZ RPCOM PULD P Continue to RIH with BHA#1 picking up PH-6 drill pipe fromt he shed to 6,561'. Establish parameters PUW 95K, SOW 72K, ROTW 80K;2150 ft-lbs free torque at 10 rpms. Continue RIH with BHA#1 to 6,757. 01:45 02:15 0.50 6,757 6,757 COMPZ RPCOM FISH P Tag PBR at 6,757'. Slack off 10K WOB; pick up 10K over. Slack off 15K to verify. Pick up and bleed jars with 15K over. Pick up to 5K over nuetral weight and rotate 22 turns; working torque down. Pick up, pipe free. Monitor well 10 minutes 02:15 06:00 3.75 6,757 286 COMPZ RPCOM TRIP P Pull out of the hole standing back PH-6 in derrick to 286'. Monitor the hole for 10 minutes at BHA. 06:00 08:30 2.50 286 0 COMPZ RPCOM BHAH P Lay down BHA#1 and fish; PBR and !Anchor assembly. 08:30 11:15 2.75 0 389 COMPZ RPCOM PULD P Pick up and make up BHA#2 Packer Milling assembly. Pick up (12)2-7/8"drill collars 11:15 17:00 5.75 389 6,767 COMPZ RPCOM TRIP P RIH with BHA#2 from derrick from 389'to 6,767'. Establish parameters; PUW 92K, SOW 72K, RTW 77K; 17:00 21:15 4.25 6,767 6,780 COMPZ RPCOM MILL P Establish circulation and wash down to 6,777 and tag packer. Mill SABL packer;WOB 0-5K, 60-80 rpms, 2000 ft-lbs to 3500 ft-lbs circulating 2-4 bpm 700-900 psi. Pumping 15 bbl high viscosity sweeps; 3 ppb Duovis and Supersweep to assist in cleaning hole. Mill—1.5'on packer and observe packer drop 1.5'. Continue milling additional 1'for total of 2.5'. 21:15 23:30 2.25 6,780 6,780 COMPZ RPCOM CIRC P Pump high viscosity sweep and two hole volumes at 3 bpm 960 psi to clean hole. Monitor well for 15 minutes. Blow down top drive. 23:30 00:00 0.50 6,780 6,780 COMPZ RPCOM SVRG P 'Service top drive. 37/26/2015 POOH with BHA#2; packer mill. Lay down BHA, recovered 15 pounds metal shavings from boot baskets. Pull wear ring. Wash out BOP stack. Install Wear ring. Pick up BHA#3 Itco spear assembly. Trip in the hole to 6,780'. Engage fish and jar free. Pull out of hole with BHA#3. Lay down BHA and drill collars. Break out Spear. 00:00 03:15 3.25 6,780 389 COMPZ RPCOM TRIP P POOH with BHA#2 packer milling assembly from 6780; PUW 95K, SOW 70K;to 389'. 03:15 05:00 1.75 389 0 COMPZ RPCOM BHAH P Lay Down BHA#2; Lay down drill collars. Break out and clean out boot baskets; 15 lbs of metal collected from boot basket. 05:00 05:30 0.50 0 0 COMPZ RPCOM RURD P Pull wear bushing. 05:30 06:30 1.00 0 0 COMPZ RPCOM WWWH P Make up joint to bull nose. Flush out stack. Blow down lines. Page 4 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:00 0.50 0 0 COMPZ RPCOM RURD P Install wear bushing 07:00 08:00 1.00 0 0 COMPZ RPCOM PULD P Pick up three addition)stands of 4" HT40 drill pipe. Stand back in derrick to extend'L'to support 2-7/8" tubing. 08:00 09:30 1.50 0 392 COMPZ RPCOM BHAH P Pick up and make up BHA#3; Spear to fish out remaining completion. Pick up drill collars. 09:30 14:30 5.00 392 6,770 COMPZ RPCOM TRIP P RIH with BHA#3 to 6,770'. 14:30 15:00 0.50 6,770 6,756 COMPZ RPCOM FISH P Establish parameters. PUW 93K SOW 70K. Wash down at 2 bpm 1130 psi. Observe spear engage fish with pressure increase at 6,780'(N9 RKB). Stack 10K down. Pick up to 47K over,fire jars. Fish free. Pick up to 6756' 15:00 16:30 1.50 6,756 6,756 COMPZ RPCOM CIRC P Ciruclate annular volume at 2 bpm 2140 psi. Monitor well for 15 minutes, stateic. 16:30 21:15 4.75 6,756 392 COMPZ RPCOM TRIP P POOH with fish from 6756'(BHA depth)to 392'. 21:15 00:00 2.75 392 3,083 COMPZ RPCOM BHAH P Lay down BHA and drill collars. Break spear out of fish. 37/27/2015 POOH with 2-7/8"decompletion standing back in Derrick. Lay down jewelry and seal assembly. Make up cleanout assembly. Run in hole with BHA#4 to 9,800'. Wash down to top of junk catcher and circulate hole clean. Monitor well, static. Pull out of the hole with BHA#4 to 75'. 00:00 04:00 4.00 3,083 0 COMPZ RPCOM PULL P Pull out of the hole with 2-7/8" decompletions standing back in derrick. Lay down'X'nipple. Lay down 80-40 seal assembly. 04:00 04:45 0.75 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. Pick up and change out pipe handling equipment. 04:45 06:00 1.25 0 75 COMPZ WELLPF BHAH P Make up BHA#4, clean out assembly. 06:00 09:00 3.00 75 6,547 COMPZ WELLPF TRIP P Trip in the hole with stands from 75' to 6,547' 09:00 14:00 5.00 6,547 9,800 COMPZ WELLPF PULD P Continue running in the hole with BHA#4 picking up drill pipe from shed from 65,47'to 9,800'. PUW 133K, SOW 90K 14:00 15:00 1.00 9,800 9,898 COMPZ WELLPF WASH P Wash down at 5 bpm 1,130 psi and tag catcher at 9,898'with 5K down. 15:00 17:00 2.00 9,898 9,898 COMPZ WELLPF CIRC P Circulate high viscosity sweep 4 bpm 1350 psi. Monitor well for 15 minutes, static. 17:00 20:00 3.00 9,898 7,200 COMPZ WELLPF PULD P Pull out of the hole laying down PH-6 drill pipe from 9,898'to 7200'. 20:00 21:00 1.00 7,200 5,000 COMPZ WELLPF TRIP P Pull out of the hole with BHA#4 from 7,200'to 5,000'standing back in derrick. 21:00 22:00 1.00 5,000 5,000 COMPZ WELLPF SVRG P Service rig, adjust link tilt mounts, grease draw works. 22:00 00:00 2.00 5,000 75 COMPZ WELLPF TRIP P 'POOH with BHA#4 from 5,000'to 75'standing back in derrick. Page 5 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/28/2015 24 hr Summary Lay down BHA#4 clean out assembly. Rig up dutch riser. Rig up slickline. Run in hole with slickline and retrieve 2.77"junk catcher. Make up 2.25"junk catcher and set on top of'XXN' plug. Rig down slickline. Rig up and RIH with stands 2-7/8"completion to 3,114'as per detail. Continue to RIH with completion string on drill pipe.to 9847'. Rig up circulating head pin and wash down at 1 bpm. Observe seals engage PBR with pressure increase at 9867'(ORKB). Slack off and no go at 9879'(ORKB) 00:00 01:00 1.00 75 0 COMPZ WELLPF BHAH P Lay down BHA#4 as per Baker. 01:00 01:45 0.75 0 0 COMPZ WELLPF RURD P Clean and clear rig floor. Off load BHA components. 01:45 02:30 0.75 0 0 COMPZ WELLPF RURD P Rig up dutch riser. 02:30 04:30 2.00 0 0 COMPZ WELLPF SLKL P Spot in Halliburton slickline truck. Load slickline tools on rig floor. Make up Junk catcher retrieval tool. 04:30 06:15 1.75 0 0 COMPZ WELLPF SLKL P RIH with junk catcher retrieval tool on slickline. Retrieve junk catcher and POOH with slickline. 06:15 07:30 1.25 0 0 COMPZ WELLPF SLKL P Make up 2-7/8"Junk catcher. Max OD 2.25", overall length 93". RIH and set Junk catcher on top of'XXN' plug. POOH with slickline. 07:30 08:30 1.00 0 0 COMPZ WELLPF SLKL P Rig down E-Line. Drain BOP Stack, Rig down dutch riser. Clean and clear rig floor. 08:30 09:00 0.50 0 0 COMPZ RPCOM RURD P PJSM rig up to RIH with 2-7/8" completion. 09:00 14:30 5.50 0 3,093 COMPZ RPCOM RCST P Run in hole with 2-7/8"completion as per detail, running stands of tubing from Derrick. Drift tubing on the way in the hole.to 3,124'. 14:30 16:00 1.50 3,093 3,114 COMPZ RPCOM PULD P PJSM. Pick up and make up FA-1 packer. Make up B-2 setting tool. 16:00 22:00 6.00 3,114 9,847 COMPZ RPCOM RCST P RIH with 2-7/8"on drill pipe from Derrick to 9,847' 22:00 23:00 1.00 9,847 9,847 COMPZ RPCOM RURD P Rig up to circulate. Make up head pin with TIW valve and XO. Change out elevators. 23:00 00:00 1.00 9,847 9,859 COMPZ RPCOM RCST P Establish circulation at 1 bpm 110 psi. wash down and observe seals engage PBR at 9,867'(ORKB)with a pressure increase. Shut down pumps and slack off. Observe No-Go at 9879'(ORKB); verify with 10K down. Pick up to 9859' 07/29/2015 Spot 55 bbls of corrosion inhibited brine between SABL and FA1 Packers. Space out 1'off No-Go. Drop ball and set FA1 packer as per Baker. Test packer to 2500 psi for five minutes-good. Release running tool with 10 right hand turns. Shear out ball catcher. POOH laying down drill pipe. Rig up and RIH with 2-7/8" completion as per detail. Latch up anchor assembly. Shear out PBR. No-Go and space out 7.03'. Make up hanger and landing joint. Circulate corrosion inhibited fluid. 00:00 01:30 1.50 9,859 9,859 COMPZ RPCOM CRIH P PJSM rig up and spot corrosion inhibited brine between SABL and FA packers. Pump 55 bbls of corrosion inhibited brine followed by 68 bbls clean seawater at 3 bpm 715 psi. 01:30 02:00 0.50 9,859 9,859 COMPZ RPCOM RURD P Rig down circulating equipment. Page 6 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 04:00 2.00 9,859 9,870 COMPZ RPCOM PACK P Slack off and observe No-Go at 9879' (ORKB). Space out 1'. Set FA Packer as per Backer: Drop ball and allow to fall on seat. Pressure up to 2000 psi, pull 35K over,slack off to nuetral and bleed pressure, slack off 40K repeat procedure. Test packer to 2500 psi for five minutes; good. Set in nuetral weight and rotate to the right 10 turns to release B-2 running tool. Pick up to 6' Pressure up to 3000 psi and shear ball seat. 04:00 04:30 0.50 9,870 9,870 COMPZ RPCOM RURD P Blow down lines. Rig up to POOH to lay down drill pipe 04:30 05:00 0.50 9,870 9,870 COMPZ RPCOM SVRG P Service top drive and drawworks. 05:00 13:00 8.00 9,870 0 COMPZ RPCOM PULD P Pull out of hole with B-2 setting tool laying down drill pipe. 13:00 13:30 0.50 0 0 COMPZ RPCOM RURD P Rig up to RIH with upper completion, change out pipe handling equipment. 13:30 14:00 0.50 0 0 COMPZ RPCOM RURD P Pull wear bushing. 14:00 21:00 7.00 0 6,781 COMPZ RPCOM PUTB P PJSM RIH with 2-7/8"completion as per detail with stands from the derrick. Latch anchor at 6781'with 20K WOB. Pick up 20K over and confirm on depth. Shear out PBR: with 1800 psi on tubing pick up 30K over and observe PBR shear. 21:00 22:30 1.50 6,781 6,750 COMPZ RPCOM HOSO P Pull seals out of PBR and observe pressure increase at 6754'as seals engage. No-Go at 6775'. Calculate space out 7.03'space out. Lay down three joints. Pick up 10.22' pup joint. Make up full joint above pup joint. Make up hanger and landing joint. 22:30 00:00 1.50 6,750 6,750 COMPZ RPCOM CRIH P Circulate 145 bbls of corrosion inhibited fluid around at 3 bpm 470 psi. 07/30/2015 Continue circulating corrosion inhibited fluid. Land hanger, RILDS. Test tubing and IA. Shear out GLM. Set BPV and test from below. N/D BOPE, N/U tree and test. Freeze protect well. RDMO 00:00 00:30 0.50 6,750 COMPZ RPCOM CRIH P Continue to circulate 145 bbls of corrosion inhibited brine at 3 bpm 473 psi. 00:30 01:00 0.50 COMPZ RPCOM THGR P Land hanger. RILDS 01:00 02:15 1.25 COMPZ RPCOM PRTS P Test tubing to 3000 psi for 15 minutes-good. While holding 1500 psi on tubing test IA to 2500 psi for 30 minutes-good. Bleed off pressure. Pressure up IA and shear out GLM at 2450 psi. 02:15 02:45 0.50 COMPZ RPCOM OWFF P Monitor well, static. 02:45 03:15 0.50 COMPZ RPCOM RURD P 'Rig down landing joint and circulating ,equipment. Page 7of8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 04:00 0.75 COMPZ WHDBO MPSP P Set BPV and test to 1000 psi for 10 minutes-good. 04:00 05:30 1.50 COMPZ WHDBO OTHR P Lay down 13 stands of HT40 drill pipe used to make'12 in derrick, pull _mouse hole. 05:30 07:00 ! 1.50 COMPZ WHDBO NUND P ND BOPE and Rack back on stump. 07:00 08:00 1.00 COMPZ WHDBO NUND P NU tree 08:00 08:30 0.50 COMPZ WHDBO MPSP P Pull BPV and Install TWC 08:30 09:00 0.50 COMPZ WHDBO PRTS P Test TBG hanger voids at 250/5,000 psi for 5 minutes along with Pressure testing tree. 09:00 09:30 0.50 COMPZ WHDBO MPSP P Dry rod out Tree test plug 09:30 10:30 1.00 COMPZ WHDBO FRZP P RU Little Red Services and PT pump line. Pump 50 diesel down the IA taking returns to kill tank. RD LRS and RU to allow well to utube. Utube well for 45 minutes. Bleed off pressure from???to zero. 10:30 11:00 0.50 COMPZ WHDBO MPSP P Dry rod in BPV. 11:00 12:00 1.00 DEMOB MOVE RURD P Dress tree and prepare to RD Nabors 9ES. Release Nabors 9ES at12:00 hrs on 7-30-15 Remove all berming, RD kill line to to kill tank and disconnect modules. Lay derrick over, install Jeep under pit module, pull pits away from sub. Page 8 of 8 Loepp, Victoria T (DOA) From: Nesvold, Janelle R <Janelle.R.Nesvold@conocophillips.com> Sent: Wednesday, July 29, 2015 6:58 AM To: Loepp, Victoria T (DOA) Subject: RE: 3K-32 workover sundry#315-352(PTD 197-076) Follow Up Flag: Follow up Flag Status: Flagged Victoria, We should be done this evening. It was a quick fix that required an extension on the original plan but the well will be completed as per the original planned design. Thanks, Janelle SCANNED AUG 2 4 2015 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, July 28, 2015 2:34 PM To: Nesvold, Janelle R Subject: [EXTERNAL]RE: 3K-32 workover sundry #315-352(PTD 197-076) How much of the scope of work have you completed?Will you be returning within 30 days?A change of approved program may be appropriate if your procedure has changed. Let me know- From: Nesvold, Janelle R [mailto:Janelle.R.Nesvold©conocophillips.com] Sent: Wednesday, July 22, 2015 8:08 AM To: Loepp, Victoria T(DOA) Subject: 3K-32 workover sundry #315-352(PTD 197-076) Victoria — The 3K-32 workover was recently completed on Nabors 9ES. After the rig was released we discovered the workover was unable to be put back on production because we could not pull a plug in the tailpipe due to a downhole restriction. We are going back to this well and continue workover operations in accordance to the plan we initially outlined in sundry#315-352. Please let me know if you have any questions. Thank you, Janelle Nesvold Workover Engineer 263-4641 pili /9 - 6 ,ts Loepp, Victoria T (DOA) From: Nesvold,Janelle R <Janelle.R.Nesvold@conocophillips.com> Sent: Wednesday,July 22, 2015 8:08 AM To: Loepp,Victoria T(DOA) Subject: 3K-32 workover sundry#315-352(PTD 197-076) Follow Up Flag: Follow up Flag Status: Flagged Victoria — The 3K-32 workover was recently completed on Nabors 9ES. After the rig was released we discovered the workover was unable to be put back on production because we could not pull a plug in the tailpipe due to a downhole restriction. We are going back to this well and continue workover operations in accordance to the plan we initially outlined in sundry#315-352. Please let me know if you have any questions. Thank you, Janelle Nesvold Workover Engineer 263-4641 3Gp 1E ' 1 7-1//1;11-4" s� THE STATE Alaska Oil and Gas ofALASI�:A Conservation Commission _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALASICP Fax: 907 276 7542 www.aogcc alaska.gov p JUL 0F7 %V.; Janelle Nesvold SCAt4�E Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3K-32 Sundry Number: 315-352 Dear Ms. Nesvold: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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. / rr4Commissioner DATED this /bday of June, 2015 Encl. STATE OF ALASKA • F >KA OIL AND GAS CONSERVATION COM, ;ION . g,C"e\44 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1,Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing 17Operations Shutdown r Suspend r Perforate r Other Stimulate r //'�"Alter Casing Change Approved Program "-" Rug for Redrill r Fbrforate New Pool r Repair Well/Re-enter Susp Well E Other. -1fia c � f 'tic C t � Ij 2.Operator Name: 4.Current Well Class: 5 Permit to Drill Number: ConocoPhillips Alaska, Inc . Exploratory r- Development r. 197-076 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22763-00 ' 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception'? Yes r O 17 / KRU 3K-32. 9.Property Designation(Lease Number): _g3-619 ��rT bib. C\ 10.Field/Pool(s). ADL 25519/ �S �9 Y)(o�l Zl I Kuparuk River Field/Kuparuk River Oil Pool 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10944 • 6997 , 9936' none Casing Length Size MD TVD Burst Collapse _ CONDUCTOR 80 16 121' 121' SURFACE 6479 7.625 6520' 4086' RECEIVED PRODUCTION 10884 5.5 10923' 6978' JUN '0 M Hit .AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade. Tubing MD(ft): 10534'-10554', 10572-10592 6637'-6655',6671'-6688' 3.5 L-80 9881 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-ISOLATION PACKER MD=9872 TVD=6164 - PACKER-BAKER SABL-3 PACKER W/KBH-22 ANCHOR SEAL MD=9885 TVD=6074 NIPPLE-CAMCO DS NIPPLE MD=504 TVD=504 . 12.Attachments: Description Surrmary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r •- Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/30/2015 OILf�- WINJ r WDSPL r Suspended r 16 Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Janelle Nesvold @ 263-4641 Email. Janelle.R.Nesvold@conocophillips.com Printed Name Janelle Title. Wells Engineer Signature I Phone:263-4641 Date (0/57/,j Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 31 6 - - 5 2 Plug Integrity r BOP Test /Mechanical Integrity Test r Location Clearance r Other: BOP 1-c5f fo aovop5 ; (/►IASP IS 2 7-6 7- psi ff Kir) u/ctl---- prrVekii-Cr 74--r5 t to ZSoo ps . Spacing Exception Required? Yes ❑ No Z Subsequent Form Required: it l 4O APPROVED BY (�/I� VTL 6`15//5 Approved by: <01—......- COMMISSIONER THE COMMISSION Date: c Aphool p c t !sir d tor 12 months tro a date of approval. �� Submit Form and .., Gni1n_enz ao,,k<od cnnic '7 17 i&,? �.siG ConocoPhillips RECEIVED Alaska P.O. BOX 100360 JUN 0 8 20F F ANCHORAGE,ALASKA 99510-0360 June 5,2015 AOGCC Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Producer 3K-32(PTD# 197-076). 3K-32 was originally drilled and completed on 5/17/1997 as an"A" sand gas-lifted producer in Kuparuk. In July of 2006,a tubing leak was detected at 8,845'MD.In 2007 the well was worked over to repair the leak and a packer was stacked.A surface casing leak identified in 2001 was repaired in 2008 with a 10' welded patch. In August of 2014 3K-32 failed a TIFL. Subsequent diagnostic work found leaks in the tubing at 6,391'MD and 7,938'MD. Production casing leaks were also found at 7 922'MD and 91823'MD after running a spectraflow log. The proposed workover is to pull the existing upper 3-1/2"tubing and install a new 2-7/8"tubing completion with a stacked packer. If you have any questions or require any further information,please contact me at 263-4641. Sincerely, // Reltrk6( Janelle Nesvold Wells Engineer CPAI Drilling and Wells 3K-32 Rig Workover • P&R 3-1/2"Tubing, Install 2-7/8"tubing w/stacked packer (PTD#: 197-076) Current Status: This well is currently shut in waiting to be worked over to fix leaks in the tubing and production casing. Scope of Work: Pull the existing upper 3-1/2"tubing and install a new 2-7/8"tubing with a stacked packer completion. General Well info: Well Type: Producer MPSP: 2,767 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 3,690 psi/6,645' TVD(10.6 ppg EMW)measured on 08/23/2011. Wellhead type/pressure rating: FMC Gen IV,7-1/16"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT TxIA failed- 10/06/2014 MIT-OA passed- 10/06/2014 Earliest Estimated Start Date: June 30,2015 Production Engineer: Scott Pessetto Workover Engineer: Janelle Nesvold(263-4641/Janelle.R.Nesvold@ConocoPhillips.com) Pre-Rig Work Slickline: 1. Inspect pad and work area for hazards. Complete the PJSM. 2. RU Slickline. RIH and pull GLV from GLM#1 at 3,443'RKB. Replace with DV. 3. RD Slickline. DHD: 1. PT POs and FT LDS. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure MIRU,Kill Well,BOP Test 1. MIRU. 2. Pull BPV. Reverse circulate with 11.1 ppg brine.Obtain SITP&SICP, if still seeing pressure at surface, calculate new KWF,weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV,ND tree,NU BOPE&test to 250/3,000 psi. 4. Pull BPV,screw in landing joint,BOLDS's,unland tubing hanger. Meat of the Workover(Tripping Pipe) 5. POOH laying down 3 '72"tubing. a. If tubing will not pull free,RU E-line:Fire a string shot and cut the tubing in the middle of the first full joint below the previous cut. b. If tubing was cut,RIH w/overshot&grapple and pull seal assembly from PBR. 6. RIH with cleanout assembly down to right above the top set of perforations. Reverse circulate until fluid returns are clean. RIH w/2-7/8" Stacked Packer Completion 7. MU the 2-7/8"completion and RIH. Swap well over to corrosion inhibited brine and engage seals into PBR until fully located. 8. Drop ball and rod.Pressure up on tubing to 4,500 psi to set the SABL-3 packer.PT the IA to 2,500 psi to ensure that packer is set. 1 3K-32 Rig Workover • P&R 3-1/2"Tubing,Install 2-7/8"tubing w/stacked packer (PTD#: 197-076) 9. PT the tubing to 3,000 psi,bleed tubing to 1,500 psi,PT the IA to 2,500 psi/30 mins,and record.Bleed the IA to zero,then tubing. Ramp up the IA pressure quickly to shear the SOV. 10. Pull the landing joint, install BOV. Pressure test the BPV to 1,000 psi from below. 11. ND BOPE. 12. NU tree,pull BPV. 13. Set BPV. 14. RDMO. Post-Rig Work 1. Pull ISA' BPV. 2. RU Slickline: a. Pull ball&rod. b. Pull SOV and run DV. c. Pull RHC plug body. 3. Reset well house(s)and flowlines of adjacent wells. 4. Handoff to operations. 2 . Kuparuk Producer 3K-32 RWO Proposed Well Schematic - I I 6/5/2015 Janelle Nesvold ''$ z 16"62.5 ppf H-40 welded conductor to 121'MD t 7-5/8"29.7 ppf L-80 AMB-BTC surface casing 2-7/8"6.5 ppf L-80 EUE 8rd _______---- production tubing I OLMH Depth-e NQ Death-11 MD Valve Two 1 2,500 3,174 Dummy I f 2 3,600 5,501 Dummy Max.inclination 65°@ 2750'MD 3 4 30 6,935 Dummy 4 4 75 7,822 SOV Max.DLS 6°/100'@ 2050'MD (annulus to tubing ,------------Baker PBR / f r Baker SABL-3 Packer@+/-7850'MD Production casing is leaking @ 7,922'MD xt_ iv-- 2.313""X"nipple Production casing is leaking @ 9,823'MD -- Baker Seal Assembly @ 9,870' .- Baker SABL-3 Packer @+/-9885'MD "XN"nipple @ 9,936'MD Overshot @ 9,985'MD SiF-Camco"D"nipple @ 10,419'MD C C � C C C C C 5-1/2"15.5 ppf L-80 LTC-Mod production casing from 37'-10,419'MD(ID:6.276") �, KUP PROD 3K-32 ConocoPhillips " Well Attributes Viltni Max Angle&MD TD Alaska,Ina ,ro Wellbore API/UWI Field Name Wellbore Status Inc!C) MD(kKB) Act Btm(ftKB) cere'ofhi/Iips 500292276300 KUPARUK RIVER UNIT PROD 64.95 2,750.00 10,944.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3K-32,3/10/20151:41:38 PM SSSV:NIPPLE 130 12/24/2012 Last WO: 2/1/2007 41.02 5/29/1997 Vented schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - - --- - Last Tag:SLM 10,645.0 9/8/2014 Rev Reason:GLV C/O hipshkf 3/10/2015 HANGER;34.6 int,10- -Casing Sffings .. ...., Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H-40 WELDED �.� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 41.3 6,520.0 4,086.1 29.70 L-80 ABM-BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,�PRODUCTION 51/2 4.950 38.8 10,923.0 6,978.4 15.50 L-80 LTC MOD 5.5x4.5"@10419' CONDUCTOR.410-1210 , Tubing:Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth IND)(...Wt(Ib/f1) Grade Top Connection 1111 TUBING WO 3 1/2 2.992 34.6 9,881.4 6.070.4 9.20 L-80 IBT Mod NIPPLE;503.7 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(3 Item Des Com (in) 34.6 34.6 0.01 HANGER FMC Hanger w/2.62'double pin pup 3.500 503.7 503.7 0.95 NIPPLE CAMCO DS NIPPLE 2.875 ',. 9,869.5 6,060.2 31.25 LOCATOR BAKER LOCATOR 2.992 9,869.9 6,060.6 31.25 SEAL ASSY BAKER SEAL ASSEMBLY approx.11.50'long 3.000 I Tubing Description String Me...ID(In) Top(ftKB) Set Depth(ft..Set Depth IND)(...Wt(lb/ft) Grade Top Connection GOT HIT,3,443.4 ISOLATION PACKER 3 1/2 2.992 9,871.6 9,990.6 6,164.2 9.30 L-80 EUE8rdABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(3 Item Des Com (ie) 9,871.6 6,062.0 31.23 PBR PBR 3.000 9,8852 6,073.6 31.14 PACKER BAKER SABL-3 PACKER w/KBH-22 ANCHOR SEAL 2.780 GAS LIFT.6.390.9 - 9,936.0 6,1172 30.86 NIPPLE OTIS 2.313"XN NIPPLE(2205"No-Go) 2205 9,984.9 6,159.2 30.44 OVERSHOT 3.5"POORBOY OVERSHOT-SWALLOWS 3.1'OF 3.5" 3.625 TUBING STUB(3.10'over stub) Tubing Description String Ma...ID(in) Top(ftKB) Sat Depth(ft..Set Depth)TVD)(...Wt(lb/ft) Grade Top Connection TUBING Original 3 1/2 2.992 9,987.7 10,428.8 6,544.9 9.30 L-80 EUE8rd SURFACE;41,36.520.0--, G Completion Details Nominal ID I Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) • 10,419.1 6,536.3 28.68 NIPPLE CAMCO'D'NIPPLE NO GO 2.250 GAS LIFT;8.342.5 I 10,426.8 6,543.1 28.68 LOCATOR BAKER LOCATOR 3.000 10,427.8 6,544.0 28.68 SEAL ASSY BAKER GBH-22 LOCATING SEAL ASSEMBLY w/17' 2.992 SEALS GAS LIFT,9.392.8 III: Other In Hole'.(Wireline retrievable plugs,valves,pumps,fish,etc.) I Top(ND) Top Inc( Top(ftKB) (kKB) (°) Des Com Run Date ID lin) 9,926.0 6,108.6 30.91 CATCHER NO GO CATCHER 9/8/2014 0-02 LIFT,9.818.1 '4 9,936.0 6,1172 30.86 PLUG XXN PLUG 9/8/2014 CSG PATCH SURFACE CASING PATCH:Install.375"SC patch 9/15/2008 that straddles SC collar.Total patch length from bottom of mandrel hanger to lower most wedding I band is 10'3";ID 7.625" LOCATOR;9,869.5 l , SEAL ASSY;9,869.91 Perforations&Slots PBR;9,871.6 ? _I I Shot Dens Top(ND) Btm(ND) (shots/f PACKER;9.8852 Top(ftKB) Btm(ftKB) (ftKB) (BBB) Zone Date t) Type Com .... 10,534.0 10,554.0 6,637.2 6,654.7 A-3,3K-32 8/19/1997 4.0 RPERF 21/8"EnerJet,180 deg. phase CATCHER;9,926.0 \I))))) 10,534.0 10,554.0 6,637.2 6,654.7 A-3,3K-32 5/28/1997 4.0 (PERF 2 1/8"Big Hole EJ,180 deg.phase NIPPLE;9,936.0 %� 10,572.0 10,592.0 6,670.5 6,688.0 A-2,3K-32 4/21/2006 6.0 APERF 2 1/8"EnerJet,45 deg. PLUG;9,936.0 l!ltl 'i phase Mandrel Inserts St on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Seri Type Type (in) (psi) Run Date Com OVERSHOT;9,984.9 I ' 1 3,443.4 2,626.3 Camco KBG-2- 1'GAS LIFT 'DMY BTM 0.000 0.0 3/9/2015 7:00 I 9 2 6,391.0 4,020.9 Camco KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 9/10/2014 EXT 9 PKG a 6:00 3 8,342.5 5,022.5 Camco KBG-2- 1 Gas Lift DMY BTM 0.000 0.0 9/9/2014 10:30 1 9 II 4 9,392.8 5,670.5 Camco KBG-2- 1-Gas Lift DMY BTM 0.000 0.0 4/29/2007 '5:00 GAS LIFT;10,406.9 9 5 9,818.1 6,016.4 Camco KBG-2- 1 Gas Lift OPEN BTM 0.000 0.0 9/11/2014 2:00 NIPPLE;10.418.1 !:. INotes:General&Safety End Date Annotation LOCATOR;10,426.8 -, 7/26/2008 NOTE:VIEW SCHEMATIC w/9.0 RPERF;10,534.0-10,554.0, IPERF;10,534.0-10,554.0 APERF;10,572.0-10592.0 PRODUCTION uk_ 5.5x4.5"e10419;38.8-10,923.0 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN D Color items - Pages: GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: Other - pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [] 1:3 .Logs of vadous kinds Other COMMENTS: Scanned by: Beverly Mildred,Daretha(~n Lov~ll TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: • _, ._, ConocoPh i I I i ps Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~~ r 1 -1~ 3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped starting March 13, 2008 and the corrosion inhibitor/sealant was pumped starting November 10, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~'~~ Jo%~~ ~~, M.J. oveland ConocoPhillips Well Integrity Projects Supervisor ~ • ConocoPhillips Alaska Inc, Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/12/08 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 36-10 185-114 >25' 6.00 6'6" 10/30/2008 7.65 11/12/2008 3K-32 197-076 11' 1.80 12" 10/3/2008 2.00 11/12/2008 3R-11 D 192-016 6" 1.00 11/10/2008 3R-12RD 192-014 16' 1.90 18" 10/6/2008 4.25 11/10/2008 3R-14 192-045 20" 4.50 11/10/2008 3R-17 192-005 20" 4.25 11/12/2008 3R-18 192-017 14' 2.10 20" 10/6/2008 4.25 11/12/2008 3R-20 192-022 9'4" 1.50 16" 9/11/2008 2.80 11/12/2008 3R-21 192-043 SF 1.70 11/12/2008 3R-22 192-039 14" 1.70 11 /12/2008 3R-26 195-187 13' 1" 2.25 11" 3/13/2008 2.25 11/10/2008 I "{ • ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 21, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~~ ~~rf~ ~ °~ 2DG8 ~.,. Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 3K-32 (PTD 197-076). The report records the completion of the surface casing excavation, inspection, and repair of Kuparuk well 3K-32. Please call MJ Loveland/Perry Klein at 659-7043 if you have any questions. Sincerely, MJ Loveland Well Integrity Project Supervisor ,...~~s. • ~ r r; ~ ~ ~IJ~'7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION /-' °"°~, REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other /^ Patch SC - Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ 'Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ~OnOCOPhIIIIpS Alaska, InC. Development ~ Exploratory ^ 197-076 / 3. Address: Strati ra hic Service g p ^ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22763-00 7. KB E,Jevation ft): 9. Well Name and Number: RKB ~l/ ~ y. y~(• °`~ 3K-32 8. Property Designation: 10. Field/Pool(s): ADL 25628, ALK 2561 Kuparuk River Field /Kuparuk Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 10944' feet true vertical 6997' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 6520' 7-5/8" 6520' 4086' PROD. CASING 10440' 5-1/2" 10440' 6555' PROD. Liner 483' 4-1/2" 10923' 6978' Perforation depth: Measured depth: 10534-10554'; 10572-10592 true vertical depth: 66637-6655; 6670-6688' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10429' MD. Packers &SSSV (type & measured depth) Packer: SABL east' SSSV= NIP SSSV= 524' 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 Casin Pressure Tubin Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: OilO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: 306-406 contact Pery Klein/ MJ Lovela d Printed Name MJ Lo la Title WI Project Supervisor Signature /~iG~/~ Phone 659-7043 Date 9/21/08 F~~ ~ ' ~" ¢ t~t ~ . €~ ~~. ~E~ ~ 2000 ~ 4• ~ •~s Form 10 404 Revised 04/2004 ~ ~, ~ ~ ~ l Submit Original Only ~~1~ • 3K-32 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summa 7/6/2008 SET 2.875" CS-A2 PLUG @ 504' RKB, BLEED TUBING TO 0 PSI. JOB COMPLETE. 7/11/2008 Excavated for surface casing repair,set shoring box and stairs,installed insulation blankets. 8/3/2008 Purge nitrogen while cutting 1" conductor additonal 3'-1"for total of 11'-1" conductor removed down from landing ring. Marked 12" "A" and "B" bands total length is 10'-9" . T/I/O = SI/0/0. 9/15/2008 SC patch weld -Complete. Purge nitrogen down annulus while welding Patch as per M.E. specs. Weld 13 3/4" .500" upper wedding band in no-go style including tie in seal weld to mandrel hanger. Bottom portion of upper wedding band is also welded to SC collar. 4" lower 500 wall wedding band. Install .375" SC patch that straddles SC collar. Total patch length from bottom of mandrel hanger to lower most wedding band is 10' 3". T/I/O = 0/0/0. 9/16/2008 MITOA -PASSED, {Post SC patch weld). Pre MIT T/I/O = SI/0/0 Pressured OA to 1800 psi with .5 bbl diesel. Initial MIT T/I/O = SI/0/1800, started MITOA, 15 min. - T/I/O = SI/0/1700, 30 min - T/I/O = SI/0/1690, 45 min - T/I/O = SI/0/1690, 60 min - T/I/O = SI/0/1690 ,Total loss of 110 psi. Bled OA. T/I/O = SI/0/0. Photo taken of the SC repair. Then wrapped SC with Denso wrap. Ready to install conductor. • ~ • • . 1. Operations Performed: Abandon D Repair Well 0. Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing 0. Perforate New Pool D Waiver D Time Extension D Change Approved Program D Opera!. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 197-0761 . 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22763-00 . 7. KB Elevation (ft): 9. Well Name and Number: Rig RKB 41', Pad 34' 3K-32 . 8. Property Designation: 10. Field/Pool(s): ADL 25628:ALK 2561 Kuparuk River Field 1 Kuparuk Oil Pool . 11. Present Well Condition Summary: Total Depth measured 10944' . feet true vertical 6997' . feet Plugs (measured) Effective Depth measured 9878' feet Junk (measured) true vertical 6046' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 6479' 7-5/8" 6520' 4086' PROD. CASING 10399' 5-112" 1 0440' 6555' PROD. CASING 483' 4-1/2" 1 0923' 6978' Perforation depth: Measured depth: 10534'-10554',10572'-10592' true vertical depth: 6637'-6655',6670'-6688' $~1,;\NNE.Ð MAR o 6 2007 Tubing (size, grade, and measured depth) 3-1/2"& 2-7/8", L-80, 10421' & 10429' MD. Packers & SSSV (type & measured depth) SABL-3 pkr @ 9885' Cameo DS nipple @ 524' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Brett Packer @ 265-6845 Printed Name ~t Packer ~ Title Wells Group Engineer ¿r 2(~O~ Signature ~7 Phone Date PreDared bv Sharon AI/sun-Drake 263-4612 RECEIVED . STATE OF ALASKA. MAR 0 1 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION. . . REPORT OF SUNDRY WELL OPERA TION~aska Oil & Gas Clns. CommtSSlln Form 10-404 Revised 04/20040 RIG I r~ A L RBDMS 8ft MAR 0 6 Z007 h ~ ¡ tJ. Submit Original Only ~~7 fiQ J ·2.'°7 ~ ConocoPhillips We/Mew Web Reporting Time Log Summary 01/08/2007 07:00 00:00 17.00 MIRU MOVE MOB P Rig Released from 2M-29 @ 0700, 1/8/07. RDMO. Rig departed 2M Pad @ 0730. Move rig to 3K Pad, derrick up, 21.2 mile rig move. Will start movin cam to 3K after ri nears 3K. 01/09/200700:00 03:30 3.50 MIRU MOVE PSIT P Move rig to 3K. Place tree to cellar. Move over well 3K-32. Accept Nordic rig #3 this date 1/9/2007, 0330 hrs. 03:30 06:00 2.50 COMPZ MOVE RURD P RU circ hoses to tree 1 wellhead. Close in cellar. 06:00 09:00 3.00 COMPZ RPCOfl. RURD P PJSM, Open SSV, RU lubricator, pull BPV. 09:00 12:00 3.00 COMPZ WELCì OTHR P Test kill lines to tbg 1 wellhead 3500 si. while brin in test t 1 tubulars. 12:00 18:00 6.00 RPCOfl. WOEQ NP WO berm construction, arrival kill tank 1 hardline connections to same due to weather 1 permitting. Continue rig work. 18:00 20:00 2.00 COMPZ RPCOfl. SFEQ NP RU to start circulating well with Sea Water 8.5 ppg. Stand pipe on rig is frozzen heat line to free u . 20:00 22:00 2.00 COMPZ WELCì CIRC P Circulate well with Sea water @ 3 bpm 2250 - 1800 psi tubing and 1750 - 1600 psi lA, Close choke and Inject 15 bbls of Sea Water to perfs. 254 bbls pumped some diesel in returns out of Sea water order more and monitor well Head ressure. 22:00 00:00 2.00 P Monitor well pressure to determine kill wt fluid. 1310 psi initial pressure tubin 01/10/200700:00 01:30 1.50 P Call out additional Sea Water we still have diesel on IA. Monitor well for stabilized ressure. 01:30 02:30 1.00 P Circulate additional 82 bbls down tubing returns out IA inject 15 more bbls shut in well and monitor ressure. 02:30 03:00 0.50 P Well head pressure of 1275 psi with 8.6 ppg SW to Mid perf @ 6662' TVD 2980 psi GR. = 4255 psi BHP add 125 si tri mar in. = 12.63 Brine 03:00 04:30 1.50 COMPZ WELCì COND P Mix Brine in pits in preparation to kill well 12.7 Circulate KWF down tubing out IA to outside tanks. 12.7 ppg Brine 3 bpm. Shut in, bullhead 15 bbls to perfs, open to surface, cont circ brine to surface until clean. 07:30 08:00 0.50 P Open ann I tbg, monitor well. Well static. 08:00 08:30 0.50 P RD hoses, set BPV. Prep for ND tree. 08:30 10:30 2.00 P PJSM, ND prod tree, inspect hgr threads I eneral condition. OK 10:30 16:00 5.50 P PJSM, NU BOPE, all related equip. 16:00 21:00 5.00 P PJSM, test BOPE, all components 250/3000, annular 250 12500 si. 21:00 22:00 1.00 P BOP test completed, Pull Blanking plug and BPV (well stable). Back out lockdown screws 22:00 23:00 1.00 P Attempt to pull completion free of PBR. Max ull116K not comin free 23:00 00:00 1.00 P Waiting on Eline crew to have 6 HRs off. Continue to exercise pipe attem tin to ull free. well stable 01/11/2007 00:00 04:00 4.00 P Waiting on Eline crew to RU and chemical cut. Continue to exercise pipe attempting to pull free. (well stable 04:00 07:00 3.00 CPBO P Pulled 147K up wt compensating for the wt of 3300' of 3 1/2" tubing to the first jt of 27/8". No success. Seal ass will not ull from PBR. 07:00 08:00 1.00 ELNE P PJSM, RU Schlum wireline for string shot. 08:00 14:30 6.50 ELNE P RIH string shot on wireline. Difficult RIH due to high angle and 12.8 brine. Hold 40M over string wt, shoot string shot. No loss in string wt. Re-cip pipe. Can not pull seal assy. from PBR. POH wireline, LD sent strin shot. 14:30 23:00 8.50 COMPZ FISH ELNE P PJSM, RU wireline for chem cut to 9912' MD log into place and fire chem cut, leaving 10' 2 7/8 stub above fish. POOH with eline. 23:00 00:00 1.00 COMPZ FISH ELNE P OOH with Chem cutter, slips on cutter kept hanging up on mandrel and then 3.5" collars. Had to pump down the tubing to make slips release. Severing head cut in half and left in the hole along with piston bull plug and centralizer. 24" long with an OD of 2.12" should be setting on top of fish. RU to start ullin com letion 01/12/200700:00 02:00 2.00 9,912 9,600 COMPZ FISH PULL P Pull completion after chem cutting @ 9912' MD. Laying down old tubing and GLM. tlt!a2.aa I'~.oo Ilia .!It!J! 1:111 ~ laœ~,th~7~~te -¡- losing 1 BPM while pumping 3 BPM slow rate to 2 BPM min. losses 05:00 18:00 13.00 9,600 4,300 COMPZr FISH PULL P Continue pulling completion. Laying down old tubing and GLM. Filling well every 20 jts with 2 bbls. Slow going. Pull slow due to swabbing. 18:00 01:00 7.00 4,300 COMPZr FISH PULD P Pulling slowly while cut back brine to 12.5 ppg 200 bbls additonal brine on location from MI plant. Inspect 12.6 ft cut jt 2 7/8. Clean cut, tbg wall section good condition. No fish (lower end chem cutter) found in tbg. 01:00 08:00 7.00 COMPZr FISH OTHR P PJSM, load fishing BHA I remainder PH6 workstring to pipe shed. Strap, record dimensions of same. 08:00 09:00 1.00 COMPZr RPCOI\ OTHR P Install wear ring. 09:00 10:00 1.00 COMPZ~ FISH PULD P PJSM, MU fish assy #1, flow check, RIH same. COMPZ~ FISH TRIP P Follow BHA with PH6 work string. Slow going, string flow back due to tiaht clearance PH6 X 5 1/2 CSQ. 01/13/2007 00:00 01:00 1.00 COMPZ~ FISH PULL P POOH with completion (well stable) 01:00 08:00 7.00 COMPZ~ FISH RURD P Load and Strap fishing BHA and PH-6 work strinQ. 08:00 08:30 0.50 COMPZ~ FISH RURD P Set wear Ring 08:30 09:00 0.50 COMPZr FISH SFTY P PJSM on pisking up and RIH with 3.5" PH-6 FishinQ string. 09:00 11:00 2.00 0 215 COMPZ~ FISH PULD P Pick up Fishing BHA. 2 7/8 overshot Grapple, Bumper Sub, Oil Jars, 6 3 1/8 Drill Collars, Accelerator Jar, and Pump out sub, RIH 11:00 22:30 11.50 215 9,912 COMPZI FISH PULD P Pick up PH-6 RIH to 9912' MD 310 jts. Slow RIH pipe displacinQ vis. brine 22:30 23:00 0.50 9,912 9,912 COMPZI FISH FISH P Engage fish @ 9912' while pumping 2 bpm pressure 1101-1430 psi. Had to rotate onto stub, suspect eline fish setting on top of stub now inside overshot. 6400 ftllbs Torque. 137K up wt. 40K down wt. 23:00 00:00 1.00 9,912 9,912 COMPZr FISH JAR P Jar on fish with 58K over, strat pull to 116k over. Pumping on tubing we can pressure up on tubing to 2000 psi with a med leak off 2000 down to 1100 psi in 30 seconds. could be fill on top of fish. Pressure up and bleed off trying to surge PBR lose. 01/14/2007 00:00 07:00 7.00 9,912 9,912 COMPZr FISH JAR P Continue Jarring on fish with 58K over, strat pull to 116k over. appears to be about 5' of movement. No further I progress. 07:00 08:00 1.00 9,912 COMPZr FISH OTHR P Attempt release overshot. Excessive toraue, cannot rotate strinQ. Order pipe lube, wait on arrival, mix lube while 'ar on fish. 15:30 16:00 0.50 CIRC P Pump 115 bbls 6% Lube, 12.3 ppg, to annulus. 4 b m at 1800 si. 16:00 17:00 1.00 JAR P Resume attempt jar seal assy free. Note immediate 35K decrease in up wt, 4000 ft Ib reduction in torque. Capability to release overshot at this time. Attempt circ dn tbg. No go, tbg lu ed. 17:00 17:30 0.50 COMPZ FISH OTHR P Release overshot. No difficulty due to lube. 17:30 19:30 2.00 9,912 9,912 COMPZ FISH CIRC P Circ I cond fluids, monitor shaker for ·unk. 19:30 00:00 4.50 9,912 6,772 COMPZ FISH PULL P POOH with fishing BHA, slow going, ti ht clearance I swabbin 01/15/200700:00 05:00 5.00 6,772 0 COMPZ FISH PULL P POOH with fishing BHA 05:00 06:30 1.50 0 COMPZ RIGMN SVRG P Out of hole with Grapple, Marks on bottom possibly made by Eline fish. Sli Drill line and ins ect brakes 06:30 08:00 1.50 COMPZ FISH PULD P PJSM, MU washpipe BHA assy, RIH same. Slow oin ,ti ht clearance. 08:00 14:00 6.00 COMPZ FISH TRIP P Flow check, follow BHA with 3 1/2 drill string to 9930 ft. Up 140, Dn 80, Rot 90, 3 bpm I 1500 si. 14:00 22:00 8.00 COMPZ FISH WASH P Commence wash I mill over 2718 tbg stub. Reduce to 2 bpm I 780 psi. Note returns at shaker: sludge, sand, rubber, crude bi-products. Approx 20 al initial, slowin to 1 al er hr. 22:00 00:00 2.00 9,836 9,836 COMPZ FISH CIRC P After attempting to mill and making no progress. We re figured the tool depth and determined we are 68' above the cut off and 95' above GLM (tight spot at 9836)'. Also after bring circulation rate to 3 bpm to clean hole, we circulated up Calcium Carbonate to shakers plugging the screens. Had to shut down circulation, and call for a super sucker to clean up solids. Wash over shoe is 4 3/4" OD sent to Baker to turn down OD to 4 11/16" same as Gra Ie we used on revious run. 01/16/200700:00 02:30 2.50 9,836 9,836 COMPZ FISH CIRC P Circulate 3 BPM 1280 psi, move pipe 113K up wt. Possibility of casing dama e 9836' MD 02:30 08:00 5.50 9,836 COMPZ FISH TRIP P POOH with PH6 to change wash over shoe. 08:00 09:00 1.00 FISH PULD P Flow check, handle BHA, LD washover shoe. Inspect for damage. Cutting area new, no wear, no signs of 'unk down hole. 09:00 10:00 1.00 COMPZ FISH OTHR P Clear floor, prepare for new BHA. 01/16/2007 10:00 11 :00 1.00 COMPZr FISH PULD P MU BHA with new shoe turned dn to 4 11/16". Flow check. RIH same. 11:00 17:00 6.00 COMPZr FISH TRIP P Follow BHA with 3 1/2 work string 9902 ft. No filiI gain I losses. 17:00 17:30 0.50 COMPZr FISH WASH P MU TD, tag at 9920 ft. Wash over 2 7/8 stub. No fill. Cont wash to mandrel at 9928 ft. No fill. 17:30 00:00 6.50 COMPZr FISH MILL P Commence mill over mandrel 9928' to 9929.5' 01/17/2007 00:00 09:00 9.00 COMPZr FISH MILL P Mill over 2-7/8" GLM from 9929.5' to 9931 ft. No further progress, torquing I I packing off. 09:00 09:30 0.50 COMPZI FISH CIRC P Circ I cond fluids I wellbore. No gain I loss. 09:30 15:00 5.50 COMPZr FISH TRIP P PJSM, flow check, POH for washover shoe. 15:00 16:00 1.00 COMPZr FISH PULD P Retrieve upper section GLM with Strip Gun inside. Secure fish, clear floor all personnel. Barricade area. Notify Schlum. 16:00 18:00 2.00 COMPZ~ FISH WOP P Wait on Schlumberger arrival for removal perf guns. 18:00 20:00 2.00 COMPZ~ FISH PULD P SLB arrival, PJSM, all personnel, remove guns from shoe. Recovered- 10' of strip guns and entire firing head from chemical cutter. Also recovered top 2.25' of 2-7/8" GLM. 20:00 21:00 1.00 COMPZr WELCì OWFF T Well is not static. Get approval from Chuck Scheve with AOGCC to delay BOP test until tomorrow. MU BHA to RIH. 21:00 23:00 2.00 COMPZr WELCì TRIP T RIH wI wash pipe and shoe. Gained 4 bbls in pits above pipe displacement with 25 stands in hole. 23:00 00:00 1.00 COMPZr WELCì TRIP T Continue to RIH to 4015'. Gained 2 bbls in pits above pipe displacement with 45 stands in hole. 01/18/2007 00:00 02:30 2.50 COMPZr WELCì TRIP T RIH with washover shoe BHA and workstring to 9900'. 02:30 03:00 0.50 COMPZ~ WELCì OWFF T Monitor hole. Well appears static. Hole has 12.4# mud. 03:00 04:00 1.00 COMPZ~ WELCì CIRC T Circulate 12.5# mud down tubing taking returns up IA; Getting some gas breaking out at surface with bottoms up pumped. 04:00 05:00 1.00 COMPZ WELCl CIRC T Continue pumping 12.5# mud. No more gas, but get heavy slug of 13.4# mud, followed by light mud wts of 12.3#. 05:00 09:30 4.50 COMPZI WELCì CIRC T Wt up mud in pits to 12.5#. 09:30 20:00 10.50 COMPZI FISH MILL P Commence washover I mill GLM 9929 to 9931' 20:00 21:00 1.00 COMPZI FISH CIRC P Not making any progress with mill. Decide to POOH with milling BHA. Circulate bottoms up at 4 bpm. 01/18/200721:00 00:00 3.00 COMPZr FISH TRIP P Hold PJSM. POOH with milling BHA. 01/19/2007 00:00 03:00 3.00 COMPZr FISH TRIP P POOH with PH-6 workstrin9 and milling BHA. Did not recover any portion of the 2-7/8" GLM. Washover shoe has 2 large pieces of metal missing from sides of shoe. 03:00 05:00 2.00 COMPZr WELCì OTHR P Clean floor and prep to run Baker Lockset Packer. 05:00 08:00 3.00 COMPZr WELCì OTHR T MU Baker Lockset Packer, for tbg hd packoff repair. Attempt RIH PKR. Will not pass tbg hd. Drain BOP stack, discover junk in lower section tbg hd. LD PKR. 08:00 13:00 5.00 COMPZr FISH WOEQ T Call for fishing tools, WO same. 13:00 14:00 1.00 COMPZr FISH FISH T Take arrival fishing tools, MU spear, attempt retrieve junk in tbg hd. No succeess, junk falls down hole. 14:00 18:30 4.50 COMPZr WELCì BOPE P Decision made to test BOPE due to AOGCC request. Prep floor, set test plug, test BOPE I all related equip (250 I 3000), (250 I 2500 annular), remove test plug, install wear ring. Witness test waived, Mr Chuck Scheve AOGCC 18:30 19:30 1.00 COMPZr FISH OTHR P PJSM, MU mill BHA. 4-5/8" Junk Mill, bit sub, double pin sub, boot basket, boot basket, bit sub, x-over sub, bumper sub, oil jar, x-over sub, 6 drill collars. 19:30 00:00 4.50 COMPZr FISH TRIP P RIH with flat bottom junk mill. 01/20/2007 00:00 02:00 2.00 9,929 COMPZr FISH TRIP P RIH with mill and tag 2-7/8" GLM at 9928.5' 02:00 03:00 1.00 9,929 9,929 COMPZr FISH CIRC P Circulate bottoms up. 03:00 09:30 6.50 9,929 9,932 COMPZI FISH MILL P Mill on 2-7/8" GLM with 4-5/8" flat bottom junk mill from 9928.5' to 9931.5. No further progress. 09:30 10:00 0.50 COMPZr FISH CIRC P Circ for TOH. No gain I loss. Approx .5 cu. ft. metal shavings at shaker. wellbore clean. 10:00 16:30 6.50 9,932 0 COMPZr FISH TRIP P PJSM, flow check, POH for BHA change. 16:30 18:00 1.50 COMPZr FISH PULD P Handle BHA #6, MU BHA #7 (Washover I washpipe assy). 18:00 19:00 1.00 COMPZr FISH OTHR P Cut drill line. 19:00 00:00 5.00 0 6,000 COMPZr FISH TRIP P RIH with washover shoe BHA. 4-11/16" shoe, 2 joints washpipe, drive sub, double pin, 2 boot baskets, bit sub, x-over sub, bumper sub, oil jar, x-over sub, 6 drill collars. 01/21/2007 00:00 03:00 3.00 6,000 9,930 COMPZr FISH TRIP P RIH and tag top of 2-7/8" GLM at 9930' 01/21/200703:00 04:00 1.00 9,930 9,930 COMPZ~ FISH CIRC P Circulate bottoms up. 04:00 14:30 10.50 9,930 9,969 COMPZ~ FISH MILL P Mill I washover GLM #2, 9930' to 9956'. Cont wash I mill over 2-7/8 jt to 9969 ft. Mill junk in 2-7/8 X 5-1/2 ann. Shoe dull. 14:30 22:00 7.50 9,969 0 COMPZr FISH TRIP P PJSM, flow check, POH for washover shoe. Washover shoe split down sides, but recovered all of shoe. Did not recover any part of GLM or 2-7/8" tubing. 22:00 23:00 1.00 0 0 COMPZr FISH PULD P MU new 4-11/16" washover shoe/washpipe BHA. 23:00 00:00 1.00 0 2,200 COMPZr FISH TRIP P RIH with washover shoe/washpipe BHA 01/22/2007 00:00 05:30 5.50 2,200 9,920 COMPZr FISH TRIP P RIH with washover shoelwashpipe BHA. 05:30 13:30 8.00 9,920 9,980 COMPZr FISH MILL P Wash 30 ft to top of fish 9920 ft, cont. wash over to 3-1/2 XO collar at 9978 ft. Commence mill collar and wash I mill 4 ft beyond collar to 9980 ft. No further progress. Torquing and hydraulic lock. 13:30 14:00 0.50 9,980 9,980 COMPZr FISH TRIP P Prepare floor for TOH. 14:00 20:00 6.00 9,980 0 COMPZr FISH TRIP P PJSM, flow check, POH for overshot. 20:00 21:30 1.50 0 0 COMPZr FISH PULD P Washover shoe on surface. Did not recover any part of GLM or 2-7/8" tubing. Lay down washover BHA and MU Overshot BHA. 21:30 00:00 2.50 0 3,420 COMPZr FISH TRIP P PJSM, flow check, RIH with overshot/grapple. 01/23/2007 00:00 06:00 6.00 3,420 9,928 COMPZr FISH TRIP P RIH with overshot w/4-11/16" overshot and 3-1/2" spiral qrapple. 06:00 07:00 1.00 9,928 9,928 COMPZr FISH CIRC P Circulate bottoms up @ 4bpm, 1980 I psi. 07:00 08:00 1.00 9,931 9,936 COMPZr FISH FISH P Circulate at 7 spm, 125K up wt, 85K down wt. Tag top of fish at 9931' md and engage to 9936' md. Pull 25K over to 150K, then wt broke back to 125K. Run back in hole and set down 10k, pull up hole wI clean Qick up. 08:00 13:00 5.00 9,936 0 COMPZr FISH TRIP P Monitor well for flow; POOH. 13:00 15:00 2.00 0 0 COMPZ~ FISH PULD P At surface with overshot/grapple. Did not recover fish. 3-1/2" spiral grapple was worn "flat" and appeared fish slipped throuqh. 15:00 20:00 5.00 0 9,928 COMPZr FISH TRIP P MU 4-11/16" overshot wI 3-3/8" spiral Qrapple and RIH 20:00 21:00 1.00 9,928 9,928 COMPZr FISH CIRC P Circulate bottoms up at 4 bpm, 2110 'psi. Getting 12.5# returns. Circulate at 10 spm, 745 psi, 125K up, 93K down. Tag top of fish at 9931' and engage down to 9936', setting down 20K. Overpull of 45K to 170K before wt breaking back. RBIH and set 20K down, clean ick u . 21:30 00:00 2.50 9,936 7,745 COMPZ FISH TRIP P Monitor hole for flow. POOH 01/24/2007 00:00 04:00 4.00 7,745 0 COMPZ FISH TRIP P POOH with 4-1/16" overshot and 3-3/8" s iral ra Ie. 04:00 05:00 1.00 0 0 COMPZ FISH PULD P Lay down fishing BHA. Did not recover fish. Missing 3-3/8" spiral grapple. Appears grapple was "shucked' when moving uphole from 2-7/8" tubing to larger 3-1/2" OD of GLM. 05:00 09:00 4.00 0 0 COMPZ WOOR P Clean floor and discuss plan forward with town. 09:00 11 :00 2.00 0 0 COMPZ PULD P MU milling BHA #11. 4-11/16" shoe, 2 joints washpipe, drive sub, double pin, 2 boot baskets, bit sub, x-over, bumper sub, oil jars, x-over sub, 6 drill collars. 11 :00 14:00 3.00 0 4,588 COMPZ TRIP P RIH with milling BHA to 4588' and monitor hole for 15 min. cont to RIH 14:00 17:00 3.00 4,588 9,460 COMPZ TRIP P Cont to RIH to 9460'. Monitor well. 17:00 19:30 2.50 9,460 9,929 COMPZ CIRC P Circulate bottoms up at 9929. Pump at 84 spm, 2350 psi. 125K up, 80K down 19:30 00:00 4.50 9,968 9,969 COMPZ FISH MILL P Wash over fish at 9930' and work down to 2-7/8" x 3-1/2" collar at 9968' and begin milling. Mill from 9968' to 9969' 01/25/2007 00:00 02:00 2.00 9,969 9,970 COMPZ FISH MILL P Milling on 2-7/8" x 3-1/2" collar with 4-11/16' washover shoe wI 3-1/2" ID. Mill from 9969' to 9969.5'. 02:00 03:00 1.00 9,967 9,967 COMPZ FISH CIRC P After milling with washover shoe for 6 hrs, decide to POOH and inspect mill. Pum Bottoms U . 03:00 04:00 1.00 9,967 9,934 COMPZ FISH JAR P Attempt to POOH but stuck on fish at 9934'. Pull60K over to 200K and set jars off 4 times, straight pull to 250K after each jar. Pull 70K over to 21 OK and set jars off 4 times, straight pull to 250K after each jar. Pull 85K over to 225K and set jars off 3 times. Straight pull to 240K and release from fish. Jar total of 11 times, with max straight ull of 11 OK over to 250K. 04:00 09:00 5.00 9,934 0 COMPZ FISH TRIP P POOH with washover shoelwashpipe BHA #11. LD boot baskets and jars. Pull 2 jts of washover pipe and shoe to floor. No fish in washover i e. 10:30 11:30 1.00 280 280 COMPZ RIGMN SVRG 11:30 13:00 1.50 280 280 COMPZ RIGMN SVRG 13:00 19:00 6.00 280 9,925 COMPZ FISH TRIP P 19:00 20:00 1.00 9,925 9,925 COMPZ CIRC P 20:00 00:00 4.00 9,969 9,970 FISH MILL P 01/26/2007 00:00 06:00 6.00 9,970 9,970 COMPZ FISH MILL 06:00 06:30 0.50 9,970 9,970 FISH CIRC 06:30 07:30 1.00 9,970 9,900 FISH OTHR 07:30 14:30 7.00 9,900 0 COMPZ FISH TRIP LD shoe. Shoe had minor wear, with a small piece of cutting structure between water courses broken out, in good shape otherwise. MU redressed shoe. Inspect wash over pipe. Clean out boot baskets. Recovered a slab of metal hung in top of lower junk basket and about a cup of debris from same. Debris was more of same plus several pieces of grapple lost in hole, and a couple sma1fpieces of possible perf gun metal. Very little junk from upper boot basket. Metal slabs appear to be pieces of washover shoe from earlier runs. MU boot baskets and jars. RIH 2 stands DC - washover BHA #12. P PJSM. Slip & cut drilling line. P Service top drive. Inspect top drive and derrick after jarring on fish, recautiona . Service crown. RIH with fishing BHA #12 - Washover Shoe and 2 jOints of Washover Pipe, etc. Circulate bottoms up at 9925' at 4 b m, 2430 si WI pump off, 140K up, 85K down. Locate top of fish at 9930', wash down to 9969' and start milling with washover shoe. Mill from 9969' to 9969.5'. P Mill from 9969.5 to 9970'. Unable to get any deeper. Have been milling with current washover shoe for 10 hrs. Decide to POOH. P Circulate bottoms up, 4 BPM, 2500 si. P Blow down top drive. PU & pulled tight at 9934'. Bleed jars open and straight pull staging up to 105K# overpull. Shoe pulled free on 2nd or 3rd pull, saw a small amount of drag for a few feet after pulling free, then normal PU weight of 140K#. Monitor well. P POOH. LD fishing BHA #12. Shoe in good condition, some wear on inside, very little wear on face, light scars inside where shoe caught with junk at top of fish (GLM). LD & clean out boot baskets, 3 pieces of old shoe debris and 1 piece of old grapple in bottom junk basket. LD washover pipe, looked in same condition as run in hole. LD bum er sub and ·ars. Clear & clean floor. Pull wear bushing. PU washing tool and wash out BOP stack to remove any metal debris. Set test lu . 16:30 21:00 4.50 0 0 P Test BOPE. Rams 250/3000, Annular Preventer 250/3000. Witnessing of weekly test waived by Lou Grimaldi, AOGCC Field Ins ector. 21:00 21:30 0.50 0 0 NP While pulling test plug, found metal debris on top of plug in BOPE. Call out for magnet to check for more metal. 21:30 00:00 2.50 0 0 WOEQ NP Wait on new washover mill to arrive on location. 01/27/2007 00:00 02:00 2.00 0 WOEQ NP Wait on magnet and new washover shoe to arrive on location. Service top drive while waitin . 02:00 03:00 1.00 FISH P Run magnet through BOP stack onto top of tubing head. Did not recover an metal. 03:00 04:00 1.00 0 275 PULD P MU BHA #13. 4-11/16" OD x 3-518" ID sawtooth washover shoe, 2 joints washpipe, drive sub, double pin sub, 2 boot baskets, bit sub, x-over sub, bumper sub, oil jar, x-over sub, 6 drill collars. 04:00 09:00 5.00 275 9,925 FISH TRIP P RIH with milling BHA to 9925'. 09:00 10:00 1.00 9,925 9,925 FISH CIRC P MU top drive & break circulation. CBU, 4 BPM, 2150 si. 10:00 10:30 0.50 9,925 9,969 FISH WASH P Tag TOF @ 9930'. Wash & ream down, tag bottom at 9969', l' fill~unk. 140K# PU, 85K# SO, 95K# Rot WI, 60 RPM, 2 BPM, 1300 si. 10:30 18:00 7.50 9,969 9,970 COMPZ FISH MILL P MiIIlwashover from 9969' to 9970'. 65 RPM to 80 RPM, 10K# WOB, 2 BPM, 1350 si. 18:00 20:00 2.00 9,970 9,985 COMPZ FISH MILL P Continue to mill at 9970'. Mill through 2-7/8" x 3-1/2" collar and continue to washover 3-1/2" tubin to 9985'. 20:00 21:00 1.00 9,985 9,995 COMPZ FISH CIRC P Pump bottoms up at 9985' at 4 bpm. Make connection and washover to 9995', reaching max depth with washover i e. 21:00 22:00 1.00 9,993 9,993 FISH CIRC P Pump 35 bbl high visc pill and circulate to surface from 9993'. 22:00 00:00 2.00 9,993 9,100 FISH TRIP P POOH wI washover shoelwash pipe BHA. Did not have any overpull at 9934' compared to previous trips out of the hole. Cont. to POOH. 01/28/2007 00:00 04:00 4.00 9,100 0 COMPZ FISH TRIP P POOH with wash over shoelwashpipe BHA 01/28/200704:00 05:00 1.00 COMPZI FISH PULD P Lay down milling BHA. Recoverfish from 2-7/8" x 3-1/2" x-over and above. Fish includes 2-718" GLM (0.95'), 2-7/8" pup (5.55'), joint 2-7/8" tubing (32.17'). Total length offish = 38.67'. Appears strip gun is inside 2-7/8" tubing. Will send to SLB. 05:00 07:30 2.50 COMPZ~ FISH WOEQ P Call Engineer and discuss next plan forward. Decide to have slickline drift through 3-1/2" tubing stub. Call out for SL 07:30 09:00 1.50 COMPZr RPCOfl. SLKL P PJSM. RU SL 09:00 15:30 6.50 COMPZ~ RPCOfl. SLKL P RIH with 1.98" drift to 10,180' SLM. Did not have any trouble getting through 3-1/2" tubing stub at 9969'. RD SL. 15:30 18:00 2.50 COMPZI RPCOfl. PULD P MU Baker Lockset BHA. RIH to +1- 750' and set plug. POOH 18:00 18:30 0.50 COMPZI RPCOfl. OTHR NP Attempt to pressure test plug. Gland nut on tubing head blew out while pressuring up. Release of 30 gallons into cellar area. 18:30 23:30 5.00 COMPZI RPCOfl. OTHR NP Call FMC to inspect gland nut. Appears gland nut was not fully threaded into tubing hanger. Replace with new gland nut and lock-down screw. Clean up cellar area. 23:30 00:00 0.50 COMPZI RPCOfl. OTHR P Pressure test Baker Lockset plug to 2500 psi. Good test. 01/29/2007 00:00 02:30 2.50 COMPZr RPCOfl. NUND P ND BOPE 02:30 07:00 4.50 COMPZr RPCOfl. OTHR P Replace casing pack-offs and tubing head. Substitute FMC Gen IV tubing head for FMC retro-fit Gen V. Test I pack-off to 3000 psi. 07:00 10:30 3.50 COMPZI RPCOfl. NUND P NU BOPE 10:30 11 :30 1.00 COMPzr WELCì BOPE P Set test plug. Test BOPE 250/3000 psi. 11:30 13:00 1.50 COMPZ~ RPCOfl. PULD P Pull test plug. RD test equipment. Set wear ring. 13:00 16:00 3.00 COMPZ~ RPCOfl. PULD P RIH and retrieve Baker Lockset plug. POOH and lay down BHA. 16:00 19:00 3.00 COMPZ~ RPCOfl. PULD P MU overshot, XN nipple, & SABL-3 packer assembly. 19:00 00:00 5.00 0 7,940 COMPZI RPCOfl. TRIP P RIH wI overshot, XN nipple & SABL-3 packer assembly on PH-6 workstring. 01/30/2007 00:00 02:00 2.00 7,940 9,974 COMPZ~ RPCOfl. TRIP P RIH 3-1/2" overshot, XN nipple, and packer assembly on PH-6 workstring. 02:00 02:30 0.50 9,974 9,974 COMPZI RPCOfl. OTHR P Locate top of 3.5" tubing stub at 9970.2' md. See tattle tail screws shear at 8.5' down on jt 315 (9971.9' md). Bottom out overshot 12' on jt 315 (9975.4). Space out l' leaving bottom of overshot mule shoe at 9974.4'. 135K up, 80K down. 03:30 04: 15 0.75 9,974 9,974 04:15 04:30 0.25 9,974 9,974 04:30 07:00 2.50 9,974 9,974 07:00 11 :30 4.50 9,974 9,974 11:30 13:00 1.50 9,974 9,974 13:00 13:30 0.50 9,974 9,800 13:30 16:00 2.50 9,800 9,800 COMPZ RPCm. CIRC 16:00 16:30 0.50 9,800 9,800 RPCOfl. TRIP P 16:30 00:00 7.50 9,800 1,630 RPCm. TRIP P 01/31/2007 00:00 02:00 2.00 1,630 0 RPCOfl. TRIP P 02:00 02:30 0.50 0 COMPZ RPCOfl. RURD P 02:30 03:30 1.00 COMPZ RPCm. PULD P Drop ball and rod. Pump down workstring at 5 spm and 520 psi. Ball and rod did not seat. P Move workstring up-down attempting to get ball and rod to move downhole. Locate 3.5" tubing stub, space out and begin pumping at 5 spm, 540 psi. Ball and rod still not seatin . P Increase pump rate to 1.5 bpm and 1270 psi. Still no luck seating ball and rod. T Shut down pump and call for Slickline to assist in pushing ball and rod to RHC plug body. Clear floor & prepare to RU slickline. T RU HES slickline. RIH with 2.23" gauge ring and tool string to 9901' SLM & chase drop bar to RHC seat in XN Ni Ie. POH. Ri aside slickline. P Stage pump up 1 BPM, 2 BPM, 3BPM. Dart seated, Pressure up to 4500 psi and set Baker SABL-3 Packer, held pressure 20 minutes to assure packer fully set. Saw PBR pins shear at about 3800 psi. Bleed off work string pressure. Test annulus to 2000 psi for 10 minutes to verify packer set, OK. Bottom of Poor Boy Overshot @ 9974.4' MD; Top of Baker SABL3 Packer at 9869'; Top of PBR 9855.42' MD - Nordic 3 RKB. P Break out top drive. Pull seals out of PBR and LD 3 joints of PH-6. MU top drive. P Circulate once around, 3 BPM, 1400 psi to recondition fluid, 12.5 ppg in & out. RU to LD work string while circulatin . Break out and blow down top drive and lines. POOH LD 3-1/2" PH-6 work string. Continue POOH and laying down PH6 workstring. LD locatorlseal assembly with Jt #1 of 3-1/2" IBr Mod Tubin . Pull Wear Ring. Clear pipe shed. Bring in jewelry. RD PH6 handling tools. Hold PJSM, start pick up and running in hole wI seal assembly, and production string. RU Eckel tongs and tubing handling tools. Strap 'ewel . 12:00 00:00 12.00 8,055 8,055 COMPZ RPCOfl. PULD 02/01/2007 00:00 02:00 2.00 8,055 8,055 COMPZ RPCOfl. WOW 02:00 04:00 2.00 8,055 9,850 COMPZ RPCOfl. PULD 04:00 06:30 2.50 9,850 9,850 COMPZ RPCOfl. PULD 06:30 07:30 1.00 9,850 9,850 RPCOI\ CIRC 07:30 08:30 1.00 9,850 9,862 RPCOfl. PULD 08:30 10:30 2.00 9,862 0 RPCOfI. DHEQ 10:30 11:00 0.50 0 COMPZ 11:00 15:30 4.50 COMPZ 15:30 16:30 1.00 PU Jt #1 with locator seal assembly. PU & MU 3-1/2" x 1" Camco KBG-2-9 GLM Assy wI annular Shear Valve. Run completion, PU 3-1/2", 9.2#, L-80, IBT Mod Tubing and Jewelry. Phase 3 Weather conditions declared at about 11 :40 hours. Suspend RIH, install head pin on top of Jt #255, seal assy at about 8055' MD. (Top of PBR 9855' MD, Nordic RKB . NP Operations suspended, stand by monitoring well, non-essential work suspended due to Phase 3 weather conditions. NP Operations suspended, stand by monitoring well, non-essential work suspended due to Phase 3 weather conditions. P Check for pressure, pull and LD head-pin. Continue PU and running of 3-1/2", 9.2#, L-80, IBT Mod Tubing to com lete well. P Finish PU of 3-1/2" tubing. Tag top of PBR at 9850' MD, Nordic RKB. Locate No-Go at 9861.81' MD. PU and strap for space out. Install space out pups a full joint below hanger. MU new FMC hanger with XO to IBT (hanger has 3-1/2" EUE 8R landing thread and u ). P Circulate bottoms up, 3 BPM, 1300 si. P Land hanger. RILDS. RU lines to test. P Test tubing to 2500 psi, 15 minutes, OK. Bleed down tubing and hold 1500 psi, pressure up IA to 2500 psi, hold for 30 minutes, lost 70 psi, OK. Bleed off tubing and shear open SOV in bottom GLM. Bleed off out tubing side. Pump in each side to verify SOV 0 en. P Set TWC. P PJSM. ND BOPE. NU new 11" 5 Ksi x 3-1/8" 5 Ksi FMC Tubing Head Adapter. Test packoffs & flange to 5000 psi. NU 3-1/8" 5 Ksi tree. Test tree to 5000 si, 15 minutes, OK. P Pull TWC with lubricator. 19:30 20:00 0.50 COMPZ RPCOfl. RURD PJSM. RU Little Red Hot Oil unit and lines. Test lines. Reverse circulate 80 bbls Diesel (50 F) into lA, taking 12.5 ppg returns from tubing thru open choke to pits, 1.4 BPM, initiallA pressure at shut down 1600 psi.. Connect IA and Tubing and let diesel U-tube until equalized for freeze protection, approx. 3900' MD, 2835' TVD. SITP = SlAP = 525 psi. Start cleanin its. P Set BPV with lubricator. 20:00 23:00 3.00 COMPZ RPCOfl. RURD 23:00 00:00 1.00 COMPZ RPCOfl. RURD P Finish cleaning pits. RD and blow down lines. Secure well and dress tree. Clean out and dig out snow blown in around rig. RD for move. (Note: Sent 500 Bbls of 12.5 ppg viscosified NaCl/NaBr brine to MI Mud Plant for storage and breaking for recove . P PJSM. Finish digging out snow around rig. Jack up rig and start to back off well. Rig Released at 2400 hours, 2/1/07. . . SARAH PALIN, GOVERNOR A1tASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 C¡: (;I (.,} \) Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K-32 Sundry Number: 306-406 tq7;D7 (¡; Dear Ms. Loveland: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisjJaay of December, 2006 Encl. . ~/ ConocoPhillips Alaska . P,O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED DEC 2 6 December 25, 2006 Alaska Oil (',¡ Ancl\(¡¡ ag2 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc, we1l3K-32 (197-076). The request is for approval to excavate, inspect and repair the surface casing for external corrosion. Please call Jerry Dethlefs or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. Sincerely, MJ Loveland Problem Well Supervisor Attachments IJrs- '¿¡¿to/, -.¡ ?'"~ ~\.?-[ DEC 2 6 2006 STATE OF ALASKA ~, ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & \:)(is Commission APPLICATION FOR SUNDRY APPROVAL Anchorage 20 MC 25.280 . RECE\V\::.U 1. Type of Request: Abandon D Suspend D Operational Shutdown D Perforate D Waiver D Other D Alter casing D Repair well D- Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development, D Exploratory D 197-076 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22763-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes D No D 3K-32 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25628: ALK 2561 RKBO' Kuparuk River Field / Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10944' 6997' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SUR. CASING 6520' 7-518" 6520' 4086 PROD. CASING 1 0440' 5-1/2" 1 0440' 6555 ~ PROD. CASING 483' 4-1/2" 1 0923' 6978 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10534-10554'; 10572-10592 66637-6655; 6670-6688' 3-1/2" L-80 10429' Packers and SSSV Type: Packers and SSSV M~, ',' ~~ no packer SSSV= NIP SSSV= 524' 13. Attachments: Description Summary of Proposal D 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development D Service D 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: March 1, 2006 Oil D Gas D Plugged D Abandoned D 17. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Jerry Dethlelfs Printed Name MJ LoveX _L .' Title: Well Integrity Project Supervisor ;/;7// Signature / Phone 659-7043 Date 12/25/06 ",,/ /' Commission Use Only Sundry Number: 4I'J I~ Conditions of approval: Notify Commission so that a representative may witness '?rJ1 () .- v Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: Co---~&~\?<i'X.b\-~\-CHr~Q\~Ù~\ ~'-( ~ ~\~~S ~~'§ ( ~ ~~i 0'. Subsequent Form Required: ~Ol-\... "" { -, .,( <> ..t;l",,,,,",,,,-,,,- ~ "" '" "Q. ~,,___<§ (",,,,,,,.- RBDIAS SrI (Jj rr) ~OMMISSIONER APPROVED BY Approved by: THE COMMISSION Date: 1~~¡.?-tJ6 Form 1 0-403 Revised 06/200h P I ~ f\ MI - .",AP 1'&· &1,.0," Submit in Duplicate . . ConocoPhilIips Alaska, Inc. Kuparuk Wen 3K-32 (PTD 197-076) SUNDRY NOTICE 10-403 APPROVAL REQUEST December 25, 2006 This application for Sundry approval for Kuparuk well 3K-32 is for the repair of a surface casing' leak. The well is an oil producer, completed in May 1997. On April 30, 2006 fluids were observed at the conductor top during a diagnostic MITOA and the suspected surface casing leak was reported to AOGCC. Subsequent testing indicated a near surface leak in the surface casing. With approval, repair of the surface casing will require the following general steps: 1. Post rig workover scheduled for Mid January, Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT -OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and waterproof sealant. 10. Backfill gravel around the wellhead; 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. RECEIVED 07/25/06 Schlumbel'gel' AUG 0 8 2006 4: 20 SCANNED f\UG NO. 3895 ~ka Oil & Gas CGns. Comm~rJ ~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: J07--Ó?b Field: Kuparuk Well Log Description Date BL Color CD Job # 3K-32 11213780 SBHP SURVEY 07/19/06 1 2K-28 11235380 INJECTION PROFILE 07/22/06 1 2K·24 11213781 INJECTION PROFILE 07/20/06 1 2U-15 11213782 PROD PROFILE W/DEFT 07/21/06 1 1Q-16 11213873 PROD PROFILE W/DEFT 07/22/06 1 1G-13 11213784 PROD PROFILE WIDEFT 07/23/06 1 1 J-1 01 PB1 40012836 MD & TVD VISION RESISTIVITY 12/17/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . ConocciPhillips . Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 12, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3K-32 (APD # 197-076) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operation on the Kuparuk well 3K-32. / If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, Pi. Nf'0 M. Mooney Wells Group Team Leader CPAI Drilling and Wells ,.;' MM/skad " . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS' ..... 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0, Exploratory D 197-0761 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22763-00 ' 7. KB Elevation (ft): 9. Well Name and Number: Rig RKB 41', Pad 34' 3K-32 . 8. Property Designation: 10. Field/Pool(s): ADL 25628, ALK 2561 Kuparuk River Field 1 Kuparuk Oil Pool - 11. Present Well Condition Summary: Total Depth measured 10944' , feet true vertical 6997' feet Plugs (measured) Effective Depth measured 9878' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 6479' 7-5/8" 6520' 4086' PROD. CASING 1 0399' 5-1/2" 1 0440' 6555' PROD. CASING 483' 4-1/2" 10923' 6978' Perforation depth: Measured depth: 10534'-10554',10572'-10592' true vertical depth: 6637'-6655', 6670'-6688' RBDMS 8Ft. MAY 3 0 2006 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10429' MD. Packers & SSSV (type & measured depth) no packer Cameo 'OS' nipple @ 524' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasilliLPressure Tubinn Pressure Prior to well operation 314 . 1292 768 -- 208 Subsequent to operation 266 . 1194 964 -- 189 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0' Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader Signature 14, ,1/, Phone Date 5/z z,¡Gç. PreDared b ''''haron AII<uM-Drake 263-4612 ~ Form 10-404 Revised 04/2004 ORIGINAL Á5('$(j ~~ {·Z3 0<- ~ø:/; . 3K-32 Well Events Summary . Da~ Summary 04/19/06 ATTEMPT TO PERFORATE A-2 SANDS 10572'-10592'. GUN DID NOT FIRE. POOH. DETERMINE JOB CAN NOT BE CONTINUED DUE TO DAMAGED PRIMA CORD ON GUN. CAUSE OF MISRUN DETERMINED TO BE FLOODED ROLLERS. ***JOB CANCELLED*** 04/21/06 PERFORATE INTERVAL 10572'-10592'. (2-1/8" SPIRAL ENERJET, HMX, 6SPF, 45 ./ DEG) POOH, GUN STUCK IN GLM #5 (9949' RKB). PUMP 100 BBLS DIESEL DOWN TUBING AND UNABLE TO PUMP FREE. GUN STRING LEFT IN HOLE. (FISH LENGTH= 41.2') 04/23/06 RECOVER E-LlNE TOOL STRING & 26" OF E-LlNE STRIP PERF GUN.@ 9862' WLM. IN PROGRESS 04/24/06 TAGGED TOP OF FISH @ 9878 I WLM. BRING WELL BACK ON PRODUCTION. JOB ,/ COMPLETE. .,.. ConocoPhillips Alala, Inc. . KRU 3<-32 3K-32 API: 500292276300 Well TVDe: PROD Anale (ã) TS: 29 dea (ã) 10373 SSSV Tvae: NIPPLE Oria ComDletion: 5/29/1997 Anale (ã) TO: 29 dea (ã) 1 0944 NIP (524-525, Annular Fluid: last W/O: Rev Reason: TAG FISH Reference loa: Ref loa Date: last UDdate: 4/29/2006 OD3.500) last T aa: 9878' WlM TO: 10944 ftKB last Taa Date: 4/18/2004 Max Hole ' 2750 Casino Strino Description Size Top Bottom TVD Wt Grade Thread Gas Lift CONDUCTOR 16.000 0 121 121 62.50 H-40 MandrelNalve SUR. CASING 7.625 0 6520 4086 29.70 l-80 1 PROD. CASING 5.500 0 10440 6555 15.50 l-80 (3426-3427, PRnn rAC:It\lr.: 4.500 10440 10923 6978 12.70 l-80 Tubino Strino - I UtslNü Size Top Bottom TVD Wt Grade Thread 3.500 0 3388 2601 9.30 l-80 EUE 8RD MOD 2.875 3388 3470 2639 6.50 l-80 EUE 8RD 3.500 3470 6342 3997 9.30 l-80 EUE 8RD MOD Gas Lift 2.875 6342 6424 4037 6.50 l-80 EUE 8RD MandrelNalve 3.500 6424 8302 5002 9.30 l-80 EUE 8RD MOD 2 2.875 8302 8384 5043 6.50 l-80 EUE 8RD (6380-6381, 3.500 8384 9359 5645 9.30 l-80 EUE 8RD MOD I 2.875 9359 9440 5707 6.50 l-80 EUE 8RD 3.500 9440 9912 6097 9.30 l-80 EUE 8RD MOD 2.875 9912 9993 6166 6.50 l-80 EUE 8RD 3.500 9993 10369 6492 9.30 l-80 EUE 8RD MOD 2.875 10369 10421 6538 6.50 l-80 EUE 8RD Gas Lift 3.500 10421 10429 6545 9.30 l-80 EUE 8RD MOD MandrelNalve Perforations Summary 3 Interval TVD Zone Status Ft SPF Date TYDe Comment (8341-8342, 1 0534 - 1 0554 6637 - 6655 A-3 20 8 8/19/1997 21/8" 180 deg. phasing Ener Jet 10572 - 10592 6670 - 6688 A-2 20 6 4/21/2006 21/8" 45 deg. phasing Ener Jet Gas Lift St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Gas Lift Run Cmnt MandrelNalve 1 3426 2618 Cameo KBMM GlV 1.0 BK 0.125 1265 9/4/1997 4 (9396-9397, 2 6380 4016 Cameo KBMM GlV 1.0 BK 0.156 1309 9/4/1997 3 8341 5022 Cameo KBMM GlV 1.0 BK 0.188 1343 9/4/1997 '--- 4 9396 5673 Cameo KBMM OV 1.0 BK 0.250 0 9/7/1997 5 9949 6128 Cameo KBMM DMY 1.0 BK 0.000 0 8/23/1997 6 10407 6526 Cameo KBMM DMY 1.0 BK 0.000 0 1 0/25/1998 - a nil in At~_\. FISH Depth TVD Type Description ID (9878-9879, 524 524 NIP Cameo 'OS' 2.813 OD:2.125) 10419 6536 NIP Cameo '0' NiDDle NO GO 2.250 10427 6543 lOCATOR Baker 'GBH-22' w/17' seals 3.000 Gas Lift 10429 6545 SBE Baker 3.000 IndrellDummy ~i",h. ¡: I~I-I Valve 5 Depth I Description I Comment (9949-9950, ODA.507) 9878 IFISH 118' OAl 2.125" 00 SPIRAL ENERJET STRIP GUNS (left in hole 4-21-06) l Gas Lift .ndrellDummy Valve 6 10407-10408, ODA.507} NIP 10419-10420, 00:2.750) II Perf - - 10534-1 0554) - I-- Perf - f-- 1 0534-1 0554} - I-- - I-- Perf == ~ 10572-10592) - I-- - I-- - I-- - f-- - I-- ... ... ./ 3K-32 (PTD 197-076) . . Subject: 3K-32 (PTD 197-076) From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Thu, 04 May 2006 08:28:39 -0800 To: tom _)n.aundel'@aâtnÌn.state.ak.us,.jim3egg@admin.state.ak.us CC: NSK Problem Well Supv <n16I7@conocophillips.com> Tom, I just realized I was a day off in my head, please note the revised dates. Sorry for any confusion. Perry 3K-32, gas lift producer, failed a TIFL 05/03/2006 while investigating the previously reported surface casing leak. The well was freeze protected and shut in last night. We plan to have slickline trouble shoot the tubing leak in the next day or two. 05/03/2006 T 11/0 = 1250130010 If you have any questions let me know. f' t) Iif \!' I) J Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907 -943-1244 «3K-32.pdf» Content-Description: 3K-32.pdf 3K-32.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 12/27/20069:33 AM 3K-32 (PTD 197-076) report ofSC leak . . Tom & Jim, A surface casing leak to the conductor was identified in gas lifted producer 3K-32 (PTD 197-076) on 4/30106 when a diagnostic MITOA breached to surface up the conductor. No fluids were spilled to the cellar as the MITOA was done in a controlled environment with a spill dike in the cellar and a vac truck monitoring the conductor top. The diagnostic MITOA was scheduled to monitor the well for an old leak previously noted in 2003. This well had an OA cmt shoe pumped under sundry approval 303-203 in 8/2003 due a suspected leak near the conductor top. At that time, the leak was suspected to be a braidenhead thread leak between the surface casing mandrel hanger and the casing head. An MITOA passed with no leaks to the surface in 8/2003 after the OA shoe was pumped. It is suspected that the cmt shoe temporarily sealed the surface casing leak, the cement has since broken down and the leak is active again. Diagnostics are planned to determine the leak depth to evaluate repair options. A 10-403 will be submitted as needed. Attached is a schematic and 90 day T/I/O plot for your reference. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 iii' «3K-32.pdf» «3K-32 90 day TIO plot 5-1-06.gif» Content-Description: 3K-32.pdf 3K-32.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: 3K-32 90 day no plot 5-1 3K-32 90 day TIO plot 5-1-06.gif Content-Type: image/gif Content-Encoding: base64 1 of 1 12/27/20069:33 AM e ConocóP'hillips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 April 13, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3K-32 (APD # 197-076) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 3K-32. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, µ,Þf~ M" Mooney Wells Group Team Leader CPAI Drilling and Wells , .~;;"ì¡C:'''' r ...;.~ :...~ '.~V··' ¡- ¡". \;::>vn.,,·, ,'; ;.", M M/skad , . ..... &oJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION e e APR I 8 2006 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Cammission Am.:horage 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate 0 Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 197-0761 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, AnchoraQe, Alaska 99510 50-029-22763-00 7. KB Elevation (ft): 9. Well Name and Number: Rig RKB 41', Pad 34' 3K-32 8. Property Designation: 10. Field/Pool(s): ADL 25628, ALK 2561 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 1 0944' feet true vertical 6997' feet Plugs (measured) Effective Depth measured 10551 ' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 6479' 7-5/8" 6520' 4086' PROD. CASING 10399' 5-1/2" 1 0440' 6555' PROD. CASING 483' 4-1/2" 10923' 6978' Perforation depth: Measured depth: 10534'-10554' true vertical depth: 6637'-6655' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10429' MD. RBDMS 8Ft APR 1 8 2006 Packers & SSSV (type & measured depth) no packer Cameo 'DS' nipple @ 524' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 10534'-10554' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation 315 1253 827 -- 194 Subsequent to operation 314 1292 768 -- 208 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name ;¡MOd~ Title Wells Group Team Leader ..1/ f 7/bÇ; Signature Phone Date Preoared bv Sharon AI/sun-Drake 263-4612 , ..~ Form 10-404 Revised 04/2004 Submit Original Only DATE 04/01/0605:00 PM e e 3K-32 Well Events Summary R¡::r1=n If::f) Summary Established injection rate of 3 BPM @ 870 psi with 60 bbls of seawater. Pumped 28.5 bbls of 12% HCI acid down tubing, followed by 62 bbls of sea water to place at top of perfs. Handed well over to production for flow-back. ConocOPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 30, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Sundry Notices for ConocoPhillips Alaska, Inc., wells 3F-17 (PTD 1961130), 3K-32 (PTD 1970760), and 2T-39 (PTD 2011830). The Sundry Notices regard cement shoes that were pumped on the surface casing. ,, Please call Nina Woods, or me at 907-659-7224 if you have any questions. Sincerely, . ~ Problem Well Supervisor ConocoPhillips Alaska, Inc. Attachments SCANNED:> SEF 1,5 2003 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon J--J Suspend J--J Operation Shutdown J--'l Perforate J--1 Variance J--J Annular Disp. J--'J Alter Casing j---J Repair Well J--'J Plug Perforations J--J Stimulate J--J Time Extension J'-'J Other [] Change Approved Program J--J Pull Tubing J--J Perforate New Pool J--'J Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: 5, Permit to Drill Number:. ConocoPhillips Alaska, Inc. Development _ ~ Exploratory E~ 197-076 / 3. Address: Stratigraphic [~ Service [ 6. APl Number: P. O. Box 100360 50-029-22763-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 0' 3K-32 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 10944' feet true vertical 6997' feet Plugs (measured) Effective Depth measured 10857 feet Junk (measured) true vertical 6920 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 6520' 7-5/8" 6520' 4086' PROD. CASING 10440' 5-1/2" 10440' 6555' PROD. CASING 483' 4-1/2" 10923' 6978' Perforation depth: Measured depth: 10534-10554' I::'" ,:,, i~ true vertical depth: 6637-6655' ~;'ii ~:~ ~r~© ~'~ ,:~,;'r' Tubing (size, grade, and measured depth) 3-1/2", L-80, 10429' MD. ??"',,' i. ~' 'i,,.i' ,', Packers & SSSV (type & measured depth) no packer SSSV= NIPPLE SSSV= 524' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13, RepresentatiVe Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water:Bbl Casin,q Pressure Tubin,q Pressure Prior to well operation 550 250 550 1250 150 Subsequent to operation 550 250 550 1250 150 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run M Exploratory J-'l Development J~] Service J--'J , ,, Daily Report of Well Operations MX 16. Well Status after proposed work: Oil[-~ Gas r'--~ WAG[]--] GINJ[--~ WIN0 [--] WDSPL['-~ ,, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: I 3O3-2O3 Contact Nina Woods/MO Loveland Printed Name MJ Loveland Title Problem Well Supervisor Signature ~¢,~,JJ~___.,..,,...~,~ Phone ,, . . 659-7224_ . Date ~//~/~.~ Form 10-404 Revised 2/2003 · ORI61NAL SUBMIT IN DUPLICATE 3K-32 ~sc.,~o. o~ wo.~ co~.~ SUMMARY Date Event Summary 8/20/20031Pumped 25 bbls of 15.8 ppg cement w/90 bbls diesel freeze protect down OA (7-5/8" la..nnulus). Cement Top @ 5463' MD RKB, 787' cement column. 8/25/2003[MITOA - passed at 1800 psi, Initial T/I/O = 1150/400/500 Pressure up OA with diesel to 1800 lpsi, start MITOA T/I/O= 1150/400/1800, 15 minute reading T/I/O= 1150/400/1760, 30 minute lreading T/I/O= 1150/400/1750 I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 2O AAC 25.280 1. Type of Request: Abandon [~] Alter casing Change approved program [] Suspend E] Operation Shutdown Repair well E~ Plug Perforations Pull Tubing E~ Perforate New Pool Perforate E~ Vadance E~] Stimulate E~] Time Extension [~ Re-enter Suspended Well E~ Annular Disp. r'-] Other [] 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development_ ~] Exploratory ['~ Stratigraphic ~ Service [~ 5. Permit to Drill ,Numar: v 197-076 6. APl Number: 50-029-22763-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 0' 3K-32 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10944' 6997' 10857 6920 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SU R. CASING 6520' 7-5/8" 6520' 4086 PROD. CASING 10440' 5-1/2" 10440' 6555 PROD. CASING 483' 4-1/2" 10923' 6978 Perforation Depth MD It): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 0534-10554' 6637-6655' 3-1/2" L-80 10429' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIPPLE SSSV= 524' 12. Attachments: Description Summary of Proposal [~] 13. Well Class after proposed work: Detailed Operations Program BI BOP Sketch BI Exploratory BI Development ~-~ Service E~ 14. Estimated Date for Commencing Operations: August 1,2003 16. Verbal Approval: Date: 15. Well Status after proposed work: Oil ~-~ Gas ~ Plugged E~ Abandoned WAG r~ GINJ ~ WINJ [-~ WDSPL [] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jerry Dethlefs Signature c"~.~.<: ~__~ ~__--~ / Commission Use Only Contact: Jerry Dethlefs @ 659-7043 Title: Problem Well Supervisor Phone 659-7043 Date I Location Clearance Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~] BOP Test E~ Mechanical Integrity Test JUL .:~ S ubsequent Fo~Require~ .............................. ~"~ '::,~ ~' ~ ~ BY ORDER OF Approved by: ~h~~~,r,'~/' ;'~~;M M:SS ION E R THE COMMISSION , Date: SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. Kuparuk Well 3K-32 (PTD 1970760) SUNDRY NOTICE 10-403 REQUEST 7/20/03 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Kupamk producing well 3K-32. 3K-32 was drilled in May 1997 and has been in production since that time. A surface casing cement shoe was not pumped at the time of original completion. Since 2002 Operations personnel have reported signs of diesel wetness around the casing head and conductor. Bleeding the OA down will stop the minor leak. However, the OA will slowly re-pressure from the formation below the surface casing shoe and the leak is again evident. The leak path appears to be from the buttress thread connection between the surface casing and casing head. The proposed plan includes pumping a cement shoe and performing an MIT-OA to test surface casing integrity. If the buttress thread connection is verified as the leak path, a seal welding operation will be performed to repair the leak. NSK Problem Well Supervisor 07/20/03 ARCO Alaska, Inc. A (524-525, 0D:3.500) Gas MandreWalve 1 (3426-3427, 0D:4.507) Gas Lift -- Mandrel/Valve 2 (6380-6381, 0D:4.507) Gas Lift Mandrel/Valve 3 (8341-8342, OD:4.507) Gas Lift Mandrel/Valve 4 (9396-9397, 0D:4,507) NO GO (10419-10420, 0D:2.750) Per[ (1O534-1O554) Per[ (10534-10554) KRU 3K-32 3K-32 APl: PBTD: 5O029227630O SSSV Type: Camco 'DS' Nipple Annular Fluid: Last Tag 10539 Rev Reason: Tag fill, run gauge by mO Well Type: Orig Completion: Last W/O: Last Tag Date: Last Update: PROD 5/29/97 10/25/98 10/26/98 10944 ffKB TD: 10944 ftKB Max Hole 65 deg @ 2750 Angle: 29deg... 10373 Angle (~ TS: 29deg@ 10944 Angle @ TD: Casing String - CONDUCTOR Size Top 16.000 0 121 Casing String - SURFACE Size Top I 7.625 0 6520 Bottom I TVD VVt GradeI Thread I 121 62.50 H-40 Bottom TVD Wt Grade Thread 4086 29.70 L-80 Casing String - PRODUCTION Size Top I Bottom TVD 5.500 0 I 10440 6555 4.500 10440 10923 6978 Tubing,String - TUBING Size 3.500 Top 0 Bottom 3388 TVD 2601 2.875 3388 3470 2639 3.500 3470 6342 3997 2.875 6342 6424 4037 3.500 6424 8302 5002 2.875 8302 8384 5043 3.500 8384 9359 5645 2.875 9359 9440 5707 3.500 9440 9912 6097 2.875 9912 9993 6166 3.500 9993 10369 6492 2.875 10369 10421 6538 10429 3.500 10421 6545 VVt GradeI Thread 15.50 L-80 12.70 L-80 VVt I Grade'' 9.30 I L-80 6.50 I L-80 9.30 L-80 6.50 [ L-80 9.30 ] L-80 6.5o I L-80 9.30 / L-80 6.50 I L-80 9.30 I L-80 6.50 I L-a0 9.30 I L-80 6.50 L-80 9.30 L-80 Thread EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD Perforations Interval TVD I Zone F¥='e~--[~PFI Date I Type Comment 10534- 6637-6655 A-3 | 2O/ 4 5/28/97 2 1/8" Big Hole EJ 180deg. phasing 10554 / 10534- 6637-6655 A-3 | 2O/ 4 8/19/97 2 1/8" EnerJet 180deg. phasing 10554 / / GaS Lift M~n:d:~ls/ValVes : :: : :: :: :::: Stn MD 'TVD Man Mfr Man Type I VIvMfr VIvType VIvOD Latch Port TRO Date Run I 3426 2618 Camco KBMM I GLV 1,0 BK 10'125 1265 914197 2I 6380 40161 Camco I KBMM GLV 1.0 BK 10.156 1309 9/4/97 3 8341 5022 Camco KBMM GLV 1.0 BK 0.188 1343 9/4/97 4 .... ~,i396 .... 5073 (~i(io ' -I~L3MM ......... O'--~/ ..... 1.0 .... BK '" 0.25'~' t7'-'(,.)'/'-(,-:17 5_. 9949 ('i12_8_.. Camco KBt....II'_.! ....... DMY .... : 1..(_).. .B_:.K .0_000 ...... 0 . J.~23..'97 6 10,~(i'~' 6526 ...... Camc~'."-i.' KB,~,!k_~ ......... DMY ..... 1..0__ . R_K . .0._000 ......... 0. 1_0_.25,"9~...~ Other (plugs~ equip., otc.) - JEWELRY Depth I TVD'I Typ~ ........... I ............. D~"~(~riPti~'~ ........ '1'D 5241 5241 NIPPLE I Camco'DS' 2.813 104191 65361 NO GO I Camco 'D' Nipple 2,250 10427 6543 LOCATOR Baker'GBH-22' w/17' seals 3.000 10429 6545 SBE Baker 3.000 Re: 3F-17 and 30-04 Subject: Re: 3F-17 and 30-04 Date: Mon, 21 Jul 2003 16:41:04 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: I will attempt to answer your questions in order. Also, you will be getting a couple more Sundrys for OA cement lobs, so the following statement applies to them as well. 3F-17: I have not yet completed the procedures for the actual cement pumping yet. But based on experience (some bad) we plan for a minimum of 500' cement column in the OA. We then mix and pump 100-120% excess to account for the amount that goes past the shoe. If the reservoir does not take any cement we may end up with a 1000' column. From experience we found it will probably take quite a lot. If we do not get a pressure bump we will shut down pumping with the calculated 500' column. The displacement fluid is 5 bbls water spacer to clean lines followed by diesel. There will not be any "Arctic Pack" pumped. The cement blend is recommended by Dowell for this purpose. An MITOA will be done a couple days after the job to test for integrity. 30-04: In preparation for attempting a SealTite repair on this well a couple months ago, we drilled and tapped a 3/4" hole in the conductor. The vendors needed a leak rate through the surface casing into the conductor to plan their sealant repair. When the hole was drilled it was obvious there was cement in the conductor, since the hole drilled straight into cement. However, we were able to establish a leak path from the surface casing out our hole in the conductor. Just by luck the hole we drilled in the conductor is fairly close to where we identified the leak with the boroscope. As we pumped diesel to get the leak rate, chunks of cement came out with the diesel and the leak rate increased up to 10 gpm, which is the maximum rate our pump would put out. That high of leak rate is not suitable for a SealTite repair, so we did not follow,up on that option. We expect there is a distinct possibility of hydrocarbon contaminated cement in the conductor. Since the void area should mostly be cement, we expect very little accumulated fluid. The Welding Foreman wants holes drilled top and bottom prior to cutting the window to verify that condition. I am unclear about your statement about cutting the window--the procedure starts with the major steps only. All the safeout steps and nitrogen purging are to be done prior to and in conjunction with cutting the window AND the casing repair. There will be nitrogen purging on the conductor, OA and IA during all the hotwork. After looking at the boroscope picture again, I suspect there is a split in either the surface casing mandrel or the pup joint immediately below it. Cutting the conductor window should make that clear. We can keep you posted as to what we find--I think it will take at least a few days or more after cutting the window before we attempt the repair. There are lots of approvals internally that will need to be obtained. I will be leaving the slope Tuesday and Nina will be here for another week. Please let us know if you want more information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska Tom Maunder <tom_maunder@admin.state.ak.us> I of 2 7/22/2003 7:30 AM Re: 3F-17 and 30-04 07/21/2003 12:17 PM To: Jerry C Dethlefs/PPCO@Phillips, NSK Problem Well Supv/PPCO@Phillips cc: Michael B Mooney/PPCO@Phillips Subject: 3F-17 and 30-04 Jerry, MJ or Nina, I was looking at the sundries for these wells and had a few questions. 3F-17--What cement volume is proposed?? Will the displacement fluid be diesel?? 30-04--In the Job Procedure, step 2, it is noted that N2 should leak through the surface casing hole and provide purge for cutting the conductor window. With all the other gas checks planned, it seems strange that there are no similar plans for the conductor x OA. --Is the fluid level in the conductor x OA below the split?? --What fluid is present in the conductor x OA?? --Where is the cement level in the conductor x OA?? --Prior to cutting will the atmosphere in the conductor x OA be checked?? --Is it planned to attempt to keep water in the conductor x OA while the cutting is performed to allow steam to develop and prevent formation of an explosive mixture?? Thanks for you attention to these questions. Tom Maunder, PE AOGCC (See attached file: tom_maunder.vcf) Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 7/22/2003 7:30 AM Re: 3K-32 OA Cement Sh~e ! . . Tom The information that I received says that there is very little gas in the OA. When the OA is bled they get very little to no gas. You can not see down the OOA to observe any gas and there is no seal on the conductor flange to trap any gas that may get into the OOA. On a different topic, did you get a chance to review the last water flow log for 2L-317A? Thanks, Pete Tom Maunder <tom maunder@admin.state.ak.us> --~~-- 27 12/02/01 10:51 AM To: NSK Problem Well Supv/PPCO@Phillips cc: AOGCC North Slope Office .state.ak.us> ect: Re: 3K-32 OA Cement Shoe Pete, Where do you think the gas is coming from?? Have you shot a fluid level in the OA to see how it moves? Is there any gas seen in the OOA? I will be heading to slope tomorrow. I will try to talk with you from there. Tom NSK Problem Well Supv wrote: Tom I am looking for approval to pump a OA cement shoe into 3K-32. 3K-32 is a gaslift assisted producer that is having a OA x OOA communication problem. The OA is pressuring up to 350 psi which is causing the OOA (surface x conductor) to fill up with fluid. When the OA is bled down to 0 psi, it pressures back up to 350 psi by the next day. The well is currently on line with about 1200 psi of lift gas pressure on the IA. Since the OA pressure has not been recorded above 350 psi, I am comfortable saying that there is no IA x OA comunication. Drilling reports show that lof2 12/27/20069:33 AM Re: 3K-32 OA Cement Shoe . . OA shoe is open and that the OA has not been Artie Packed. We did an injection test on 11/30/01 and were able to inject 1 bpm at 1750 psi. I would like to pump a cement shoe into the OA. This is a similar problem and procedure that was performed on 3G-26 earlier this year. On 3G-26 we tried to leave 500 ft inside the OA but it looked like the formation drank most of the cement. It failed the susequent MIT-OA. It did plug up the formation enough that the OA did not build up pressure and leak into the OOA as it did prior to the cement job.I have attached the procedure for pumping the cement shoe on 3K-32. I increased the desired cement height to 1000 ft inside the OA to compensate for the formation taking the slurry as it did with 3G-26. (See attached file: 3K-32.pdf) (See attached file: 3K-32 OA Cement Shoe 12-01-01.doc) Peter Nezaticky Phillips Alaska Inc (907) 659-7224 ------------------------------------------------------------------------ Name: 3K-32. pdf 3K-32.pdf Type: Acrobat (application/pdf) Encoding: base64 Name: 3K-32 OA Cement Shoe 12-01-01.doc 3K-32 OA Cement Shoe 12-01-01.doc (application/msword) Type: WINWORD File Encoding: base64 (See attached file: tom_maunder.vcf) Content- Type: application/octet-stream tom maunder.vcf Content-Encoding: base64 20f2 12/27/20069:33 AM . . 3K-32 Outer Annulus Cement Shoe AFC# K85329 / CC: 230DS26KL OBJECTIVE: Cement outer annulus casing shoe with Arctic grade cement (Dowell "Tail" system). The cementing procedure is designed for a cement column of 1000' -2000' md. The well has OA x surface communication; OA pressures up due to the absence of a cement shoe and annular fluids leak to the OOA via a small leak. According to the drilling records, this well has not been Arctic packed. An OA injectivity test was performed at 1 bpm @ 1700 psi with diesel. PROCEDURE: 1. Before the cement treatment SI the well and freeze-protect the flowline and tubing. 2. Contact State Field Inspector to witness cement operation. 3. Bleed the IA pressure off to < 150 psi (bleed to flowline). Bleed the OA pressure off to 0 psi. 4. RU cement pumper. Pump 100 bbls (800 F) fresh water to prime pumps and establish injection down OA. Pump 33 bbls Dowell "Tail" system 15.8 PPG cement. (5-112" x 7-5/8" annulus = 0.0165 bbls/ft; 33 bbls = 2000'). This volume is 100% excess for minimum 1000' cement column (assuming some loss out the shoe); setup time is 4-5 hours. Note: 5-1/2" 15.5# L-80 collapse pressure = 4990 psi, 7-5/8" 29.7# L-80 yield pressure = 6,890 psi. 5. Immediately displace the cement with 5 bbls water and up to 86 bbls diesel (91 bbls total displacement). 91 bbls (total fluids) is full displacement, 1000' cement column 74 bbls (total fluids) will put lead cement to shoe 2000' cement column If pressure bump of 500 psi or more is observed (over inj ection pressure) with cement to shoe (74 bbls flush), shut-down pumping. If a pressure bump is not observed with 91 bbls flush away, stop pumping and allow cement to squeeze off shoe. Note: Do not pump more than 91 bbls total displacement behind cement. 6. Shut-down pumps leaving 500 psi on OA if it will support the pressure. 7. Clean up pump and equipment. Rig down. Surface wash water goes to Pad 3 (Class I non- haz, non-exempt). 8. Waiting on cement for 48 hrs, perform MITOA to 2000 psi, with IA below 500 psi. Observe surface casinghead for leaking during MITOA. 9. IfMITOA passes, bring well back on production with AL. IfMITOA fails, perform injectivity test to evaluate for secondary cement job. 10. File State Sundry 10-404 after the cement job is complete with a description of the job performed. MEMORANDUM. TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, ~3,t~O'~ Commissioner Tom Maunder, ~_~~ P. I. Supervisor FROM: John Crisp, SUBJECT- Petroleum Inspector DATE: May 18, 2001 Safety Valve Tests Kuparuk River Unit 3K Pad May 18,2001: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. 'SUMMARY: i witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested. 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL SVS KRU 3K 5-18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Ernie Barndt AOGCC Rep:., ~ohr~,. Crisp. Submitted By: Date: Field/Unit/Pad: Kuparuk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 i i ! i Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GllqJ, Number Number PSI PSI Trip Code Code Code Passed GAS orCYCLE 3K-01 1861010 65 70 50 P P "' OIL 3K-03 1861030 65 70 '55 P P OIL ~-06 1861240 65 70 .... 50 P' P OIL 3K-09A 1861740, 65 60 54 P P OIL 3K-10 ' 1861630 65 " 70 52 ' P P " OIL 3K-11 1861640' 65, 70 50 P P OIL 3K-14 1861370 65! 60 58 P P OIL ,, 3K-16 1861390 65 70 70 P P OIL , , 3K-17 1861520 65 60 35 P P OIL ! 3K-23 1970970 65 70 58 P P OIL ~K-24 'i982490 65 70 50 P P " OIL 3K-27 1970460 65 " 70! "52! P 4 OIL ;'19~0760 65 70 55: P P OIL 3K-35 1971090 65 701 50 P P OIL _~ , Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.57% F190 var Remarks: RJF 1/16/01 Page 1 ofl SVS KRU 3K 5-18-01jc AOGCC Geological Materials Inventory TD /c7' q'..r'3 C PERMIT 97-071 ARCO Log Data Sent Received Box NGP/DGR/CNP/SLD,77h ~89~6 ~.?:{!) .... ::J:~:~-! i.: b~ ;?~ 12/10/1997 12/10/1997 D NGP/DGR/CNP/SLDi'4,~ '\ ~ 1~0512 1490~5-. ] ~,-,, ~yD ~ ~ /. ? :/o~ i:2c 12/10/1997 12/10/1997 D NGP/DGR/EWR4-MD 'Lea ..10512-14905 12/10/1997 12/10/1997 D NGP/DGR/EWR4-TVD ,~ 8901-10256t,/~ 12/10/1997 12/10/1997 D e~.~ MWD SRVY ~"'~- SPERRY 10479.19-14905. 1/21/1998 2/2/1998 8171 ~j~SCHLUM AND-LWD (ASCII) 11/10/1997 11/21/1997 ADN-MD t~¢'_ BL(LWD) 13744-14905 11/10/1997 11/21/1997 ADN-TVD tL-~ BL(LWD) 9200-10200 11/10/1997 11/21/1997 GR/CCL-PERF ~ 14450-14768 / [/~:~/~ ~ 12/17/1997 12/19/1997 JWL-GR/CCL y 10~50-14823 ///Zg/~t~ 11/2/1909 12/3/1997 PERF-GR/CCL ~ 10650-14823 /;;~/~ ~ 11/2/1909 12/3/1997 STAT PRES SRVY ~ 11630-11790 ////~ 5-~1/~ ~ 11/2/1909 12/3/1997 · USIT ~ BL (C) 2000-3000 /O ~ 10/14/1997 10/16/1997 · USIT-GPIT-GR /.MS-~ 2000-3000 12/8/1997 12/18/1997 ~-407 Completion Date / 2/~ /:;/ Daily well ops c~f/,(? (/;? ~-... ~,~ ~.,: ...... / ,": .~ ,. , Are dry ditch samples required? yes Was the well cored? yes .......... ~ho Are tests required? yes ........ Well is in compliance Comments Initial fa o And received? '~--.--yes ........... no-.. Analysis _description received? Received? ~.yes ...... ' ...... no~ yes .......~:.... no Wednesday, October 13, 1999 Page I of 1 PERMIT 97-076 97-076 97-076 97-076 97-076 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS .......................................... MWD SRVY ~R"0.-10944. CBL ~10400-10700 DGR/EWR4-TVD ~076-6960 DGR/EWR4-MD ~' 6532-10944 8073 ~'-~PERRY MPT/GR/EWR4/ROP Page: 1 Date: 05/24/99 RUN RECVD FINAL 07/25/97 FINAL 08/20/97 FINAL 08/20/97 5,6 08/20/97 10-407 ~OMPLET~ON DA?~. '3 /2~;/-.,~ // DA~LY WELL OPS R ~?1 ?1~'7 TO .~?1~1 Are dry ditch samples required? yes ~~d received? Was the well cored? yes ~.~alysis & description received? Are well tests required? yes n~eceived? ~~ Well is in compliance ~ Initial CO~ENTS yes~._~ no T D BOX .... MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: FROM: DATE: May 24,1998 Blair Wondzell, (~'J~' ,,,~ FILE NO: P. I. Supervisor _. _~~ ~~(~- Petroleum Inspector .DOC Annular Injection Kuparuk River Unit 3K-32 PTD 97-076 May 24,1998: I traveled to the Parker 245 rig on 3K pad to witness the pumping of solids down the annulus of 3K-32. The pump had a minimum rate of.5 bbls per minute due to rod oiler problems at lower rates. The test was rate driven due to the small pressure span between 0.5-4.0 bbls per min. Rate Pressure mud weight 0.5 bpm 675 10.9 1.0 725 10.9 1.5 800 10.9 2.0 825 10.9 2.5 875 10.9 3.0 975 10.9 3.5 1075 10.9 4.0 1125 10.9 Volume pumped 190 bbls during the test. SUMMARY: I witnessed the annular injectiOn pressures on Parkers ball mill. Attachments: cc; NON-CONFIDENTIAL STATE OF ALASKA AIJ-,,;dKA OIL AND GAS CONSERVATION COMMIS;SION REPORT OF SUNDRY WELL OPERATIONS' 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 1097' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1146' FNL, 1505' FWL, Sec. 6, T12N, R9E, UM At effective depth 1197' FNL, 1729' FWL, Sec. 6, T12N, R9E, UM At total depth 1 12. 6. Datum elevation (DF or KB) RKB 41 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-32 9. Permit number/approval number 97-76 10. APl number 50-029-22763-00 11. Field/Pool Kuparuk River Field/Oil Pool 206' FNL, 1772' FWL, Sec. 6, T12N, R9E, UM Present well condition summary Total Depth: measured true vertical 1 0994 feet 6997 feet Plugs (measured) None feet Effective depth: measured 1 0857 feet true vertical 6920 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 6479' 10884' Size Cemented Measured depth True vertical depth 1 6" 125 Sx AS I 1 21 ' 7-5/8" 458 Sx AS III & 6520' 540 Sx Class G w/65 Sx AS I Top Job 5.5"x4.5" 200 Sx Class G 1 0 9 2 3' measured 10534'-10554' true vertical 6637'- 6655' 121' 4063' 6842' Tubing (size, grade, and measured depth) O.~tl .~..~/~iA 3.5", 9.3#/ft., L-80 @ 10429' Packers and SSSV (type and measured depth) Pkr: Baker GBH-22 Locater @ 10427'; SSSV: None, Camco nipple @ 524' 13. Stimulation or cement squeeze summary Perforate 'A' Sands on 5/28/97. Intervals treated (measured) 10534'-10554' Treatment description including volumes used and final pressure ;;.i~','r4!'-:u Perforate using 2-1/8" EJ w/ BH Charges, 4 spf, oriented 90° CCW f/ highside, fp = 750 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1000 178 Subsequent to operation I 4 2 4 67 48 1000 208 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~.~~ Title Wells Superintendent Form 1~p'5~'04/ I~e¢' (~1.5"~8'~ ' / Date //,~ .~/'¢'-"/'7 SUBMIt~ iN DUPLI'CA'i'E STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development XL Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1097' FSL, 316' FWL, Sec. 35, T13N, At top of productive interval 1146' FNL, 1505' FWL, Sec. 6, T12N, At effective depth 1197' FNL, 1729' FWL, Sec. 6, T12N, At total depth 1206' FNL, 1772' FWL, Sec. 6, T12N, R9E, UM R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 1 0994 feet true vertical 6997 feet 6. Datum elevation (DF or KB) RKB 41 7. Unit or Property' name Kuparuk River Unit 8. Well number 3K-32 9. Permit number/approval number 97-76 10. APl number 50-029-22763-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None Effective depth: measured 1 0 8 5 7 fe et true vertical 6920 feet Junk (measured) None 13. 14. Casing Length Structural Conductor 8 0' Surface 6 4 7 9' Intermediate Production 10884' Liner Perforation depth: Size Cemented Measured depth True vertical depth 1 6" 125 Sx AS I 121 ' 7-5/8" 458 Sx AS III & 6520' 540 Sx Class G w/65 Sx AS I Top Job 5.5"x4.5" 200 Sx Class G 1 0 9 2 3' measured 1 0534'-1 0554' true vertical 6637'- 6655' None, Camco nipple @ 524' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 10429' Packers and SSSV (type and measured depth) Pkr: Baker GBH-22 Locator @ 10427'; SSSV: Stimulation or cement squeeze summary Perforate 'A' Sands on 8/19/97. Intervals treated (measured) 10534'-10554' Treatment description including volumes used and final pressure Perforate using 2-1/8" EJ w/ BH Charges, 4 spf, 90° phasing, fp = 250 psi. 121' 4063' 6842' ORISINA! . ,. Representative Daily Avera_ae Production or Injection Data ., .,,,,.~..'" Oil-abl Gas-Mcf Water-Bbl Casing Press u r.e,..~ ,.b_~..?:",~u'6i,'~."'F~'r'e~s u re 568 221 4 970 157 Prior to well operation Subsequent to operation 2 3 7 0 1101 74 1000 232 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations Z 16. Status of well classification as: Oil X Gas Suspended Service 7. I her,?...V.,~ertify that the foregoing is true and correct to the best of my knowledge. Signed %. ~ Title Wells Superintendent Form 10.-,~'-~4~ R~v ,/06~'-r'~/~~ - - SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT ~ K1(3K-32(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-32 PERFORATE, PERF SUPPORT 081697201 3.9 DATE DAILY WORK UNIT NUMBER 08/19/97 REPERF A SAND W/2 1/8" ENERJETS 4 SPF 180 DEG, 20 FOOT ZONE 8337 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes O No (~) Yes O No SWS-MAJCHER SCHUROSKY ^,, oosT ^oo cosT ESTIMATE 998679 230DS36KL $8,620 $10,075 Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer/~nn I Final~uter Ann 250 PSI 250 PSI 1050 PSI 1200 PS111650 PSI . 650 PSI DAILY SUMMARY REPERF A SAND 10534-10554 W/2 1/8" ENERJETS, 4 SPF, 180 DEG. TIME LOG ENTRY 09:30 MIRU SWS #8337 W/MAJCHER-LEVY-HUSEMAN 10:45 TGSM, PICK UP GUNS - 2 1/8" ENERJET X 20', -90 DEG PHASED,MPDF, CCL, 1 11/16" WT BAR X 6', 35' TOTAL LENGTH, PTEST TO 3500# 11:45 RIH W/ABOVE GUNS AND SET DOWN AT 3380 SEVERAL ATTEMPTS MADE. DECIDE TO WING WELL IN. HAD TO WING IN ALL THE WAY TO GET PAST 3380. TIE-IN, SHOOT AND POOH. 14:00 AT SURFACE, LAY DOWN 1ST GUN AND ARM 2ND GUN, SAME AS 1ST GUN, BUT +90 DEG PHASE. PTEST TO 3500#. 14:45 RIH W/2ND GUN, TIE IN, SHOOT 16:15 POOH W/2ND GUN, LAY DOWN, AND RD 17:30 RDF, MO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $160.00 HALLIBURTON $0.00 $635.00 LITTLE RED $0.00 $660.00 SCHLUMBERGER $8,620.00 $8,620.00 TOTAL FIELD ESTIMATE $8,620.00 $1 0,075.00 STATE OF ALASKA AL/-v:SKA OIL AND GAS CONSERVATION COMMI,5~51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1097' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1146' FNL, 1505' FWL, Sec. 6, T12N, R9E, UM At effective depth 1197' FNL, 1729' FWL, Sec. 6, T12N, R9E, UM At total depth 1206' FNL, 1772' FWL, Sec. 6, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 1 0994 feet 6997 feet 6. Datum elevation (DF or KB) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-32 9. Permit number/approval number 97-76 10. APl number 50-029-22763-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 1 0857 feet true vertical 6920 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 6479' 10884' Size Cemented Measured depth True vertical depth 1 6" 125 Sx AS I 121 ' 7-5/8" 458 Sx AS III & 6520' 540 Sx Class G w/65 Sx AS I Top Job 5.5"x4.5" 200 Sx Class G 1 09 2 3' measured 10534'-10554' true vertical 6637'- 6655' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 10429' Packers and SSSV (type and measured depth) Pkr: Baker GBH-22 Locater @ 10427'; SSSV: None, Camco nipple @ 524' 121' 4063' 6842' RIGINAL 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 5/30/97. Intervals treated (measured) 10534'-10554' Treatment description including volumes used and final pressure Pumped 35 Mlbs of 20/40 & 12/18 ceramic proppant into formation, fp = 8000 '~$ii~',~ ~,, 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure ' T't~bi'ng :Pressure Prior to well operation 0 0 0 995 178 Subsequent to operation 1 4 2 4 67 48 1025 2O8 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby, certify that the foregoing is true and correct to the best of my knowledge. Si~lned ,,f~ Title Wells Superintendent Form 'J,0"-40-4~ Re~/'06/~'5/8~ ~ - / SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~' K1(3 K-32(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-32 FRAC, FRAC SUPPORT 0523970515.1 DATE DAILY WORK UNIT NUMBER 05/30/97 "A" SAND FRAC DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O NoI (~) Yes O No DS-YOAKUM CHANEY ,,-- FIELD AFC~ CC4f DALLY COST ACCUM COST Sig~e~l ESTIMATE 998679 230DS36KL $69,524 $69,947 .~ ~!,,.~/' ~"--- ....,.-~-',~- Initial Tb.cl PressFinal Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann J Final Outer~fn 750 PSI 2000 PSI 385 PSI 500 PSI] 500 PSII ,/450 PSI DAILY SUMMARY "A" SAND FRAC COMPLETED, SCREENED OUT TO SURFACE. INJECTED 35000 LBS IN THE FORMATION W/4.8# PPA OF #12/18 THE PERF'S. MAXIMUM PRESSURE 9250 PSI & F.G./.80) TIME 06:00 07:45 08:20 09:10 10:10 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRK, AND LRS HOT OIL TRK. HELD SAFETY MEETING ( 15 ON LOCATION ). PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER. P'I'D HIGH PRESSURE LINES AND EQUIP TO 10500 PSI. PUMP BREAKDOWN W/40# DELAYED XL GW @ 30 TO 20 BPM. VOLUME PUMPED 283 BBLS. USED 2086 LBS OF ~20/40 FOR SCOURING. MAXIMUM PRESSURE 9250 PSI AND ENDING PRESSURE 4850 PSI. S/D AND OBTAINED ISIP OF 2389 PSI W/F.G. @ (.80). STOOD-BY AND MONITORED WHTP. PULSED TO DETERMINE CLOSURE. PUMP DATAFRAC W/40# DELAYED XL GW @ 5 TO 20 BPM. VOLUME PUMPED 203 BBLS. MAXIMUM PRESSURE 6100 PSI AND ENDING PRESSURE 4700 PSi. S/D AND OBTAINED ISIP OF 2540 PSI W/F.G. @ (.83). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/40# DELAYED XL GW @ 5 TO 20 BPM. SCREENED OUT BACK TO SURFACE. PUMPED 53711 LBS OF PROP. INJECTED 35000 LBS IN THE FORMATION ( 8500 LBS OF #20/40 & 45211 LBS OF 12/18 ) W! 4.8# PPA OF #12/18 @ THE PERF'S. LEFT 18711 LBS OF PROP IN THE WELLBORE. VOLUME PUMPED 796 BBLS. MAXIMUM AND ENDING PRESSURE 8000 PSI. 11:30 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL TRK. 12:15 13:15 REMOVED TREESAVER (50% OF CUPS LOST). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $5,800.00 $5,800.00 DIESEL $400.00 $400.00 DOWELL $61,784.00 $61,784.00 HALLIBURTON $0.00 $423.00 LI'I-rLE RED $1,540.00 $1,540.00 TOTAL FIELD ESTIMATE $69,524.00 $69,947.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT __ WELL SERVICE REPORT K1(3K-32(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-32 PERFORATE, PERF SUPPORT 0522971801.7 DATE DAILY WORK UNIT NUMBER 05/28/97 PERFORATE, PERF SUPPORT 8337 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes k~ NoI ® Yes O No SWS-WALSH KRALICK FIELD AFC~ CC# DAILY COST ACCUM COST Signed ESTIMATE A K8797 230DS36KG $ 9,534 $24,645 Initial Tb.q Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 750 PSI 0 PSI 0 PSII 0 PSII 0 PSI DALLY SUMMARY PERFORATED 10534~54' 4 SPF WITH BIG HOLE CHARGES 4 SHOT PER FOOT. TIME LOG ENTRY 07:00 MI-TGSM-RU 08:00 PT 2500 PSI. RIH WITH WT/CCL/MAG/20' GUN. 2.125" OD, 32' 09:10 TIED IN & SHOT 10534-54'2 SPF 90 DEG CW FROM HIGH SIDE. USED 2 1/8" BIG HOLE ENERJET CHARGES. 17 GRAM, 10" PEN, .57" EH. WELL HEAD PRESSURE 750 PSI. 10:20 OOH. ALL CHARGES FIRED. 10:40 RIH W/WT/CCL/MAG/20' GUN. 2.125" OD, 32'. 11:35 SHOT 10534-54' 2 SPF, 90 DEG CCW FROM HIGH SIDE. 12:20 OOH. 13:00 RDMO. WELL TURNED OVER TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $200.00 $400.00 SCHLUMBERGER $9,334.00 $24,246.00 TOTAL FIELD ESTIMATE $9,534.00 $24,646.00 STATE OF ALASKA AI~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1097' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1146' FNL, 1505' FWL, Sec. 6, T12N, R9E, UM At effective depth 1197' FNL, 1729' FWL, Sec. 6, T12N, R9E, UM At total depth 1206' FNL, 1772' FWL, Sec. 6, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 41 feet 7. unit or Property name Kuparuk River Unit 8. Well number 3K-32 9. Permit number/approval number 97-76 10. APl number 50-029-22763-00 11. Field/Pool Kuparuk River Field/Oil Pool 1 0994 feet 6997 feet Plugs (measured) None Effective depth: measured 1 0857 feet true vertical 6920 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 6479' 10884' 1 6" 125 Sx AS I I 21 ' 7-5/8" 458 Sx AS III & 6520' 540 Sx Class G w/65 Sx AS I Top Job 5.5"x4.5" 200 Sx Class G 1 092 3' measured 10534'-10554' true vertical 6637'- 6655' 121' 4063' 6842' , Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 10429' Packers and SSSV (type and measured depth) Pkr: Baker GBH-22 Locator @ 10427'; SSSV: None, Camco nipple @ 524' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 8/31/97. Intervals treated (measured) 10534'-10554' Treatment description including volumes used and final pressure Pumped 261 Mlbs of 20/40 & 12/18 ceramic proppant into formation, fp = 7300 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 2 1 9 589 10 1000 249 Subsequent to operation 2 3 7 0 1 1 01 74 1000 232 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Si~lned ~.~.,~.~, ~~.,~ Title Wells Superintendent Form 10~(~4 (Re"v .~6"/~'5/88,~- / SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT '~ K1 (3K-32(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-32 FRAC, FRAC SUPPORT 081 6972013.9 DATE DAILY WORK UNIT NUMBER 08/31/97 "A" SAND REFRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes C'~ No (~ Yes O No DS-GALLEGOS CHANEY FIELD AFC,# CO# DAILY COST ACCUM COST Signed~/ ESTIMATE 998679 230DS36KL $1 48,042 $172,81 0 Initial Tbq Press Final Tbcl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Fina!/Outer Ann 650 PSI 1 500 PSI 250 PSI 500 PSII 700 PSII" 600 PSI DAILY SUMMARY I"A" SAND REFRAC COMPLETED INTO FLUSH. INJECTED 261206 LBS OF PROP IN THE FORMATION W/13~ PPA OF #12/18 @ THE I PERF'S. FREEZE PROTECTED TBG DOWN TO 3800' W/33 BBLS OF DIESEL. MAXIMUM PRESSURE 8400 PSI & F.G. @ (.78/ I TIME 07:30 10:00 10:45 11:20 12:30 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRUCK, AND LRS HOT OIL TRUCK. HELD SAFETY MEETING (15 ON LOCATION) PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 10000 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 27 BPM TO 15 BPM. VOLUME PUMPED 325 BBLS. USED 2135 LBS OF #20/40 PROP. MAXIMUM PRESSURE 8400 PSI AND ENDING PRESSURE 3750 PSI. S/D AND OBTAINED ISlP OF 2201 PSI W/F.G. @ (.78). STOOD-BY AND MONITORED WHTP. PULSED FOR CLOSURE. DETERMINED CLOSURE TIME +-14 MINS @ 1900 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 203 BBLS. MAXIMUM PRESSURE 7300 PSI AND ENDING PRESSURE 4150 PSI. S/D AND OBTAINED ISlP OF 2457 PSI W/F.G. @ (.81). STOOD-BY AND MONITORED WHTP FOR CLOSURE. DETERMINED CLOSURE TIME +-14.5 MINS @ 2150 PSI. PUMP FRAC W/50# DELAYED XL GW @ 5 BPM TO 15 BPM. COMPLETED INTO FLUSH, SCREENED OUT IN THE LAST 7 BBLS OF FLUSH VOLUME. VOLUME PUMPED 1780 BBLS. PUMPED 265024 LBS OF PROP (17869 LBS OF #20/40 & 247155 LBS OF #12/18). INJECTED 261206 LBS OF PROP IN THE FORMATION W/13# PPA OF #12/18 @ THE PERF'S. LEFT 3818 LBS OF PROP IN THE WELLBORE AND EST FILL TO BE @ 10350'. FREEZE PROTECTED TBG DOWN TO 3800' W/33 BBLS OF DIESEL. 14:45 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL TRUCK. 15:45 17:00 REMOVED TREESAVER (LEFT 5% OF CUPS IN THE WELL). CONTINUED R/D R/D COMPLETED AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 -- $1,280.00 APC $6,900.00 $7,400.00 DIESEL $400.00 $400.00 DOWELL $138,653.00 $138,653.00 HALLI BU RTO N $0.00 $7,478.00 LITTLE RED $2,090.00 $8,980.00 SCHLUMBERGER $0.00 $8,620.00 TOTAL FIELD ESTIMATE $148,043.00 $172,811.00 CI I::! I I--I-- I I~J I~ S G I:1~./I C ~: S WELL LOG ~SMrFTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs August 20, 1997 3K-32, AK-MM-T0126 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Ym'~ Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, gG, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22763-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 _ A Dresser Industries, Inc. Company I-II:III_LING WELL LOG TRANSMITTAL To: State of Alaska August 20, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - 3K-32, AK-MM-70126 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ywn Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3K-32: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22763-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22763-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia '~' 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company _ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 6, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-32 (Permit No. 97-76) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3~3~ i G i N AL If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad STATE OF ALASKA ~ ' ALASK, , OIL AND GAS CONSERVATION C_ MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-76 3. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-22763 4. Classification of Service Well 5. 12. 17. 22. Location of well at surface 9. Unit or Lease Name 1097' FSL, 316' FWL, Sec. 35, T13N, RDE, UM ~ ...... :;"_ ':!;~ .... : i ~ Kuparuk River Unit At top of productive interval ; ~);',i ~ ¢ I.' ~ ! 10. Well Number 1146' FNL, 1505' FWL, Sec. 6, T12N, R10E UM i -..,~--~-'~--¢-//~¢,,Z'~ ~ J _~ j 3K-32 Attotal depth ; ~'~?'~' ~ ~ 11. Field and Pool 1206' FNL, 1772' FWL, Sec. 6, T12N, R10E_~ DM___ :~-2:~-:~~--"-~-~- ~ Kuparuk River Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. Rig RKB 41', Pad 34' j ADL 25628, ALK 2561 Date Spudded j13. Date T.D. Reached 114. Date Comp., Susp., or Aband.j15. Water depth, if offshore J 16. No. of Completions 5/16/97 5/29/97 N/A MSLJ One i .... j ............... j.. , Total Depth (MD+TVD)j18. Plug Back Depth (MD+TVD)J19. Directional Surveyj20. Depth where SSSV set~21. Thickness of Permafrosl 109446997FT] 10857 6920 F~ I~Yes I-INo j N/A MDJ 1650' (Approx.) Type Electric or Other Logs Run GR/Res, GR/CCL/SLTJ 23. CASING S~ZE 16" i 7.625" 4.5" WT. PER FT. GRADE 151.5# X-65 29.7# L-80 ..... ~1--5~ ....... 12.7# L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH j HOLE. j ToP BO-FrOM j S!ZE j CEMENTING RECORD Surf. 121' ! 30'~' J125sx AS I Surf. 6520', J 9.875" 1458 sx AS III LW, 540 sx 'G', 65 sx AS I i-~-4'1 § -j- -~ ~;;--- 200- ~-X Cla~-s G Surf. _ ..... :_ j ............ 10419' 10923; I 6.75.. Jtapered String AMOUNT PULLED I 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) MD TVD 10534'-10554' 6637'-6655' 4 spf MD TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 1 O429' 26. ACID FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1 0534'-1 0554' Pumped 53711# of prop. Injected 35000# in formation (8500# of #20/40 & 45211# of 12/18) w/4.8# ppa of #12/18 @ the perfs. Left 18711# of prop in the wellbore. 27. PRODUCTION TEST iDate First Production JMethod of Operation (Flowing, gas lift, etc.) i Gas Lift 6/8/97 Date of TestlHours Tested 7/15/97 i 7.2 I PRODUCTION FOR TEST PERIOD · Flow TubingjCasing PressureCALCULATED · OIL-BBL WATER-DEL Press. 249{ 1145 24-HOUR RATE 121 9 10 28. CORE DATA OIL- BBL J GAS-McF 403 I 390 -- J 589 WATER-BBL j CHOKE SIZE j GAS-OIL RATIO 3 JOIL GRAVITY-APJ (CORR) .l ............... .0._ .............. i ...................... .................... I 0 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Anchorage 29. Geologic Mark' Formation Tests _ Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 10373' 6496' Total pump volumes for this event: Bottom Kuparuk C 10416' 6534' Category 1. 21800 Top Kuparuk A 10517' 6622' Category 2. 100 Bottom Kuparuk A 10659' 6747' Category 3. 0 Total: 21900 Total To Date: 21900 Annulus left open - freeze protected with diesel. 3'1. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ............... ,--~¢__ -,-.._4_..~ ;~ ~.--.~__7____-- ....... Title t~,'~l/(~c,,_~v,.-~--~,,'~ Date ~ Pre'Cpared ~y Name/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 6/20/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3K-32 RIG:PARKER 245 WELL ID: AK8797 TYPE: AFC: AK8797 AFC EST/UL:$ 1270M/ 1520M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:05/07/97 START COMP: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22763-00 05/07/97 (D1) TD: 623' (623) SUPV: DEB DAILY: $ 05/08/97 (D2) TD: 3605' (2982) SUPV: DEB DAILY: $ 05/09/97 <D3) TD: 5327' (1722) SUPV: DEB DAILY: $ 05/10/97 (D4) TD: 6530' (1203) SUPV: DEB DAILY: $ 05/11/97 (D5) TD: 6530' ( 0) SUPV: DEB DAILY: $ 05/12/97 (D6) TD: 8982' (2452) SUPV: DEB DAILY: $ 05/13/97 (DT) TD:10090' (1108) SUPV: DCL DAILY:$ MW: 9.0 VISC: 74 PV/YP: 10/24 APIWL: 13.4 DRILLING @ +/- 1600' Move rig from 3K-22 to 3K-32. Accept rig @ 1200 hrs. 5/7/97. NU diverter system. Function test diverter. OK. Spud @ 1630 hrs. Drill to 623'. 50,573 CUM:$ 50,573 ETD:$ 100,868 EFC:$ 1,219,705 MW: 9.3 VISC: 62 PV/YP: 19/21 APIWL: 8.8 DRILLING @ +/-4800' Drill from 623' to 3574'. Pump lo vis/hi vis sweep and circulate. RIH to 3574', tight spot @ 2796' Drill to 3605' 85,146 CUM:$ 135,719 ETD:$ 302,055 EFC:$ 1,103,664 MW: 9.6 VISC: 61 PV/YP: 16/18 APIWL: 8.4 DRILLING @ 6065' Drill from 3605' to 5327'. MWD failed. RIH and test MWD, OK. 80,723 CUM:$ 216,442 ETD:$ 418,234 EFC:$ 1,068,208 MW: 9.5 VISC: 53 PV/YP: 18/17 APIWL: 7.6 CIRC THRU 7-5/8" STAGE COLLAR Drill from 5327' to 6530'. Pump lo vis/hi vis sweeps and circulate around. Hold pre-job safety meeting. Run 7-5/8" casing. 76,106 CUM:$ 292,548 ETD:$ 507,391 EFC:$ 1,055,157 MW: 9.2 VISC: 45 PV/YP: 16/14 APIWL: 15.6 FORMATION LEAK-OFF TEST CIP on 7-5/8" surface pipe. Got good 10.5+ ppg cement returns to surface. Shoe @ 6520'. 9-7/8" TD @ 6530'. 154,529 CUM:$ 447,077 ETD:$ 507,391 EFC:$ 1,209,686 MW: 9.0 VISC: 42 PV/YP: 12/12 APIWL: 9.2 DRILLING @ 9500' Drill out LC, cement, FC cement and shoe from 6386' to 6520'. Clean out rathole to 6530' and drill 20' of new hole to 6550' Perform formation leak-off test. Leaked off at 14.9 ppg EMW. Drill from 6550' to 8982'. 122,677 CUM:$ 569,754 ETD:$ 917,846 EFC:$ 921,908 MW: 10.4 VISC: 51 PV/YP: 22/20 APIWL: 4.8 MIX LCM Drilling from 8982' to 9906'. Well flowing on connection. CBU. Well is breathing. Mix 8 ppb fine barafiber. Monitor well. Static. Drilling from 9906' to 10090'. Perform OH LOT, 12.0 ppg EMW. 94,916 CUM:$ 664,670 ETD:$ 1,103,320 EFC:$ 831,350 Date: 6/20/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/14/97 (D8) TD:10103' ( 13) SUPV:DCL DAILY:$ MW: 11.2 VISC: 58 PV/YP: 32/26 APIWL: 4.4 CIRC Increase mud weight to 11.2 ppg. Hole started taking fluid. Pump 5 ppb barafiber. Drilling from 10090' to 10103' Started losing 50% returns. Pump pill. 94,175 CUM:$ 758,845 ETD:$ 1,105,496 EFC:$ 923,349 05/15/97 (D9) TD:10835' ( 732} SUPV: DCL DAILY:$ MW: 11.2 VISC: 55 PV/YP: 28/22 APIWL: 4.6 WIPERTRIP Circ and condition mud. Add 10 ppb fine/med baraseal. Drilling from 10103' to 10835'. Flow check and CBU. No gas. 81,506 CUM:$ 840,351 ETD:$ 0 EFC:$ 2,110,351 05/16/97 (D10) TD:10944' ( 109} SUPV: DCL DAILY:$ MW: 11.2 rISC: 55 PV/YP: 29/19 APIWL: 4.5 CIRC AT SHOE Drilling from 10835 to 10944'. CBU. No gas. Pump pill. Held prejob safety meeting. RIH w/4.5" x 5.5" casing. 71,751 CUM:$ 912,102 ETD:$ 0 EFC:$ 2,182,102 05/17/97 (Dll} TD:10944' ( 0) SUPV:DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIH W/3.5" COMPLETION RIH w/casing w/ no returns. Unable to work pipe below 10923' Pump cement. Set pack off and test to 3000 psi. NU BOPE. 193,761 CUM:$ 1,105,863 ETD:$ 0 EFC:$ 2,375,863 05/18/97 (D12) TD:10944' ( 0) SUPV:DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Pump water and diesel to freeze protect. Held prejob safety meeting. RIH w/3.5" x 2-7/8" completion. Test casing. Freeze protect. ND BOPE. 145,982 CUM:$ 1,251,845 ETD:$ 0 EFC:$ 2,521,845 05/19/97 (D13) TD:10944' ( 0) SUPV:DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: RIG RELEASED Release rig at 02:30 hrs. 5/19/97. 6,912 CUM:$ 1,258,757 ETD:$ 0/ 0 APIWL: 0.0 0 EFC:$ 2,528,757 End of WellSummary for Well:AK8797 I~ur?II~UI~ ltl ¥ ~lt UI~II · WELL SERVICE REPORT JOB SCOPE JOB NUMBER PERFORATE, PERF SUPPORT 0522971801.7 DA1LYWORK UNIT NUMBER :3~-3~. PERFORATE, PERF SUPPORT 8337 OPERATION OO~ ] SU~FUL ] KEY PF_P, SON SUPERVISOR YES YES SWS-WALSH KRALICK [ [ ] Ann I Final Outer Ann Initial Tbg Press Final Tbg Press [ Initial Inner Ann Final Inner Ann Initial Outer 0 PSI 750 PSI} 0 PSI 0 PSI 0 PSI 0 PSI SUMMARY tTED 10534-54' 4 SPF WITH BIG HOLE CHARGES 4 SHOTPER FOOT. LOG ENTRY MI-TGSM-RU PT 2500 PSI. RLI-I WITH WT/CCL/MAG/2ff GUN. 2.125" OD, 32' TIED IN & SHOT 10534-54' 2 SPF 90 DEG CW FROM HIGH SIDE. USED 2 1/8" BIG HOLE ENERJET CHARGES. 17 GRAM, 10" PEN, .57" EH. WELL HEAD PRESSURE 750 PSI. RIH W/WT/CCL/MAG/20e GUN. 2.125" OD, 32'. SHOT 10534-54' 2 SPF, 90 DEG CCSV FROM HIGH SIDE. RDMO. WEI 1. TURNED OVER TO PRODUCTION. ARCO ALASKA, INC. KRU / 3K-32 500292276300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -75.30 121.00 121.00 45.70 359.00 359.00 283.70 447.00 447.00 371.70 540.00 539.96 464.66 633.00 632.78 557.48 724.00 723.37 648.07 827.82 826.35 751.05 919.20 916.35 841.05 1012.61 1007.21 931.91 f-SUN DRILLING SERVICES ANCHORAGE ALASKA COURS INCLN DG MN 0 0 0 0 0 15 0 30 2 15 4 45 6 7 8 15 11 36 15 15 1109.93 1100.55 1025.25 17 33 1193.95 1180.06 1104.76 20 6 1287.55 1267.36 1192.06 22 7 1380.56 1352.79 1277.49 24 27 1473.82 1437.41 1362.11 25 14 1565.67 1519.73 1444.43 1655.69 1598.31 1523.01 1746.16 1675.04 1599.74 1838.82 1751.03 1675.73 1932.63 1824.35 1749.05 DATE OF SURVEY: 050497 MWD SURVEY JOB NUMBER: AK-MM-70126 KELLY BUSHING ELEV. = OPERATOR: ARCO ALASKA INC 27 23 30 58 32 58 36 48 40 21 PAGE 1 2024.64 1892.38 1817.08 44 15 2117.40 1956.30 1881.00 48 35 2210.08 2015.69 1940.39 51 41 2304.01 2072.88 1997.58 53 17 2398.51 2127.94 2052.64 55 25 75.30 FT. 2491.59 2178.42 2103.12 58 2581.99 2223.74 2148.44 60 2765.77 2307.13 2231.82 65 3042.54 2429.70 2354.40 62 3321.64 2555.37 2480.07 64 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N .00 E .00 .00N .00E N .00 E .00 .00N .00E S 2.00 W .11 .52S .02W S 38.00 E .40 1.01S .21E S 65.00 E 1.96 2.10S 2.12E 52 56 4 20 7 S 84.00 E 2.93 3.28S 7.60E S 85.00 E 1.51 4.10S 16.18E S 81.78 E 2.09 5.64S 29.07E S 87.13 E 3.81 7.04S 44.74E S 75.21 E 4.88 10.65S 66.02E S 72.18 E 2.53 18.41S 92.37E S 73.43 E 3.07 26.41S 118.29E S 71.18 E 2.33 36.69S 150.40E S 68.44 E 2.76 49.41S 184.89E S 67.19 E 1.01 64.22S 221.18E 3505.79 2639.04 2563.74 61 48 3778.89 2764.82 2689.52 63 20 4052.13 2890.22 2814.92 62 1 4333.78 3018.46 2943.16 63 47 4607.82 3142.56 3067.26 62 20 S 67.39 E 2.34 79.93S 258.73E S 68.55 E 4.04 96.37S 299.43E S 69.12 E 2.22 113.66S 344.10E S 71.61 E 4.42 131.41S 394.02E S 71.59 E 3.78 149.88S 449.52E S 70.80 E 4.28 169.85S 508.14E S 71.29 E 4.69 191.67S 571.69E S 72.19 E 3.42 213.95S 639.25E S 71.07 E 1.95 237.43S 709.95E S 69.88 E 2.48 263.10S 782.31E S 70.90 E 3.83 289.33S 855.96E S 71.74 E 2.42 314.37S 930.04E S 71.47 E 2.26 366.04S 1085.40E S 70.82 E 1.01 446.21S 1320.21E S 71.93 E .73 525.77S 1556.32E S 72.11 E 1.26 576.39S 1712.32E S 72.99 E .63 649.07S 1943.54E S 73.66 E .53 718.73S 2176.07E S 74.36 E .67 787.78S 2417.09E S 74.54 E .54 853.27S 2652.45E VERT. SECT. .00 .00 .13 .50 2.64 8.23 16.67 29.45 44.85 66.26 93.73 120.85 154.56 191.27 230.29 270.80 314.51 362.28 415.21 473.69 535.58 602.73 673 .85 748.32 825.02 903.12 981.29 1144.96 1392.94 1641.99 1805.96 2048.33 2291.07 2541.75 2785.98 ORIGINAL Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KRU / 3K-32 500292276300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 050497 MWD SURVEY JOB NUMBER: AK-MM-70126 KELLY BUSHING ELEV. = 75.30 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4886.97 3277.06 3201.76 60 2 5257.83 3458.74 3383.44 61 17 5531.41 3587.87 3512.57 62 22 5809.00 3721.84 3646.54 59 53 6086.67 3858.71 3783.41 61 2 S 75.14 E .85 917.24S 2888.49E 3030.41 S 75.52 E .35 999.11S 3201.23E 3353.44 S 73.57 E .74 1063.39S 3433.65E 3594.50 S 73.75 E .90 1131.77S 3666.87E 3837.53 S 76.04 E .83 1194.68S 3900.06E 4078.93 6271.56 3947.42 3872.12 61 37 6459.39 4039.64 3964.34 59 33 6696.44 4160.07 4084.77 59 22 6976.26 4303.65 4228.35 58 53 7251.80 4446.30 4371.00 58 45 S 73.30 E 1.34 1237.57S 4056.46E 4241.04 S 73.69 E 1.11 1284.05S 4213.32E 4404.64 S 73.05 E .25 1342.48S 4408.95E 4608.81 S 71.56 E .49 1415.47S 4637.75E 4848.94 S 72.43 E .27 1488.33S 4861.93E 5084.63 7529.67 4590.27 4514.97 58 50 7808.87 4735.92 4660.62 58 16 8082.19 4875.04 4799.74 60 31 8358.00 5011.42 4936.12 60 12 8544.08 5104.18 5028.88 59 59 S 72.20 E .08 1560.53S 5088.37E 5322.28 S 71.19 E .37 1635.33S 5314.50E 5560.39 S 70.65 E .84 1712.23S 5536.77E 5795.43 S 69.38 E .42 1794.15S 5762.06E 6034.81 S 69.30 E .12 1851.07S 5912.99E 6195.78 8636.91 5152.12 5076.82 57 48 8728.45 5202.37 5127.07 55 35 8822.05 5256.61 5181.31 53 33 8916.74 5314.30 5239.00 51 21 9008.99 5373.30 5298.00 49 5 S 69.00 E 2.36 1879.35S 5987.26E 6275.07 S 69.30 E 2.44 1906.58S 6058.75E 6351.38 S 69.46 E 2.17 1933.44S 6130.12E 6427.49 S 70.06 E 2.38 1959.41S 6200.55E 6502.43 S 71.61 E 2.77 1982.70S 6267.50E 6573.26 9099.89 5434.22 5358.92 46 43 9191.62 5498.36 5423.06 44 31 9282.64 5564.34 5489.04 42 31 9375.10 5633.65 5558.35 40 20 9468.88 5706.33 5631.03 38 1 S 72.44 E 2.70 2003.52S 6331.65E 6640.69 S 74.05 E 2.70 2022.43S 6394.41E 6706.24 S 74.74 E 2.27 2039.30S 6454.77E 6768.89 S 74.47 E 2.37 2055.53S 6513.75E 6830.04 S 75.29 E 2.53 2071.00S 6570.93E 6889.24 9561.29 5780.32 5705.02 35 35 9654.26 5856.11 5780.81 35 10 9745.42 5931.14 5855.84 34 2 9832.04 6003.81 5928.51 31 51 9933.09 6090.10 6014.80 30 51 S 76.99 E 2.84 2084.28S 6624.67E 6944.52 S 77.25 E .49 2096.28S 6677.15E 6998.22 S 77.98 E 1.31 2107.39S 6727.72E 7049.83 S 77.33 E 2.56 2117.45S 6773.74E 7096.79 S 78.06 E 1.07 2128.66S 6825.11E 7149.20 10020.33 6165.09 6089.79 30 35 S 78.26 E .32 10944.00 6960.22 6884.92 30 35 S 78.26 E .00 2137.81S 6868.73E 7193.59 2233.45S 7328.94E 7661.70 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7661.70 FEET AT SOUTH 73 DEG. 3 MIN. EAST AT MD = 10944 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 106.94 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 10,944.00' MD S~ '-SI/N DRILLING SERVICES ANCHOR3kGE ALASKA PAGE ARCO ALASKA, INC. KRU / 3K-32 500292276300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6 / 10 / 97 DATE OF SURVEY: 050497 JOB NUMBER: AK-MM-70126 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -75.30 .00 N .00 E 1000.00 995.03 919.73 9.85 S 62.86 E 2000.00 1874.58 1799.28 164.28 S 492.04 E 3000.00 2410.09 2334.79 433.84 S 1284.54 E 4000.00 2865.76 2790.46 705.77 S 2131.90 E .00 4.97 4.97 125.42 120.45 589.91 464.49 1134.24 544.33 5000.00 3333.51 3258.21 942.35 S 2983.14 E 6000.00 3816.75 3741.45 1176.39 S 3826.47 E 7000.00 4315.91 4240.61 1421.90 S 4657.03 E 8000.00 4834.59 4759.29 1688.52 S 5469.27 E 9000.00 5367.41 5292.11 1980.56 S 6261.06 E 1666.49 532.25 2183.25 516.76 2684.09 500.84 3165.41 481.32 3632.59 467.18 10000.00 6147.59 6072.29 2135.70 S 6858.60 E 10944.00 6960.22 6884.92 2233.45 S 7328.94 E 3852.41 219.82 3983.78 131.38 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 19, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-32 Dear Mr. Commissioner: Enclosed please find a LOT plot, cementing detail and the casing detail sheets for ~Kupa_ruk_Well 3K-32. These forms are to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development MAY 20 1997 DKP/skad cc: Blair Wondzell CASING AND LEAK-OFF FRACTURE TESTS Well Name' Supervisor: KRU 3K-32 Date: 5/12/97 Don E. Breeden 7 5/8, 29.7#, L-80, ABM-BTC Casing Size and Description: Casing Setting Depth: Mud Weight: 8.4 6520' TMD 4071' TVD ppg EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD EMW = 1375 psi / (0.052 x 4071 ft) + 8.8 ppg EMW= 14.9ppg (10 Minute Shut-in after Leak-Off) 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 I LEAK-OFF TEST 0 2 4 6 8 10 12 14 16 18 20 22 ~ _~- .,,,2'6~.~ ~28~ 30 STROKES .... .z, .~ ~,~ AnchOmga CASING / TUBING / LINER DETAIL 7-5/8" Surface Casina WELL: 3K-32 KRU -- ARCO Alaska, Inc. DATE: 5/11/97 Subsidiary of Atlantic Richfield Company I OF I PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB to Landing Ring 41.08 Fluted Mandrel Casing Hanger 1.42 41.08 43 Jts 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A Casing 1 825.79 42.50 Joint 'B' 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A - Baker Locked 43.1 9 1 868.29 Halliburton ES Cementer 2.50 1 911.48 Joint 'A' 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A - Baker Locked 43.40 1 913.98 104 Jts 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A Casing 4428.63 1 957.38 Landing Collar 2.24 6386.01 1 Jt 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A Casing 42.1 5 6388.25 Float Collar 2.20 6430.40 2 Jts 7-5/8", 29.7#, L-80, ABM-BTC, Range 3, Class A Casing 85.70 6432.60 Float Shoe 1.50 651 8.30 Bottom of Shoe ==>> 651 9.80 I TD = 6530' MD (10' Rathole)! 37 Centralizers: Install a Bow Spring Centralizer on each of the first 35 joints, Install a Bow Spring Centralizer on each of Joints 'A' & 'B'. Remarks: String Weights with Blocks: 240K# Up, 130K# Dn, 80K# Blocks. Ran 152 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections (National = BOL 2000). Made up connections to the base of the triangle stamp. Parker Rig #245 Drilling Supervisor: Don E. Breeden ARCO Alaska, Inc. Cementing Details Well¢: 3K-32 Casing Size 7-5/8" Centralizers Mud Spacer Lead Cement Tail Cement Displacement Hole Diameter 9-7/8" Field: Kuparuk River Unit Hole Angle I Shoe Depth 62°I 6520' MD Date: 5/11/97 LC Depth 6386' MD % washout State type used, intervals covered and spacing Used 37 Bow Spring Centralizers: Installed one on each of the first 35 joints & one on the two joints next to the Halliburton ES Cementer. (GEMOCO) Weight JPV(prior cond) 9.7/9.4+ ppg 1 8 Gels before Gels after 1 4/46 3/8 Type Water Type I Mix wtr temp AS III LWI +70°F PV(after cond)IYP(prior cond) 13 I 23 Total Volume Circulated 800 Bbls Volume 50 Bbls No. of sacks 2OO & 258 Weight 10.5 ppg YP(after cond) 10 Weight 8.33 ppg Yield 4.42 cfs Additives: 3.5% D44 + 0.6% D46 + 30% D53 + 1.5% D79 + 50% D124 + 1.5% S1 ClassG&ASI +70°F 540 & 65 15.8 & 15.7 1.15 & 0.93 Additives: Class G + 0.266% D29 + 0.2% D46 + 0.3% D65 + 1% S1 Stage 2: AS I Rate(before tail at shoe) 7.2 BPM Reciprocation length 10'- 15' Theoretical Displacement 293 Bbls & 88 Bbls CJP O730, 5/11 Calculated top of cement 1911' & 6170' Rate(tail around shoe) 7.2 BPM Reciprocation speed +30 FPM Actual Displacement 295 Bbls & 88 Bbls Bumped plug ]Floats held YesJ Yes Str. Wt. Up 1 60 KC Str. Wt. Down 50K¢ Str. Wt. in mud 105K¢ Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Stage 1' 10 Bbls water, test lines 3500 psi, 50 Bbls water, Mix & pump 157 Bbls Lead, drop "bottom" bypass plug, mix & pump 100 Bbls Class 'G' tail, drop "top" shut-off plug, pump 10 Bbls of tail on top of plug, pump 20 Bbls wash up water, rig pump 265 Bbls mud & bumped plug to 1300 psi, floats held, 1st Stage CIP @ 0530. Stage 2: Pressure up to 3200 psi to open ES Cementer @ 1911', circulate annulus clean, circ- ulated out lead cement & contaminated mud, est. cement was +1000' from surface, circulated 250 Bbls. Pump 20 Bbls water ahead, mix & pump 10.5 ppg lead cement until getting good 10.5- ppg cement returns, pumped 203 Bbls lead, switch to tail & pump 10 Bbls AS 1, drop "top" I closing plug, pump 20 Bbls wash up water, rig pump 68 Bbls mud, bump plug to 800 psi, pressure up & close ES Cementer @ 1350 psi, pressure up & hold 2000 psi, ok, check floats, floats held, 2nd Stage CIP @ 0730, 5/11/97. Full returns throughout. Recip. until Lead around shoe. Cement Company I Rig Contractor ]Signature Dowell Parker Rig ¢245 Don E. Breeden 7/22/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11171 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk '! C-06 ~t ' ©~-~ [.}~_~ WATER INJECTION PROFILE 970422 1 1 1H-1 c~ 3' c~©C~. PRODUCTION LOG W/DEFT 970423 I 1 2 F- 19 ~:~ (~, ~ 0 I CEMENT MAPPING TOOL 97 0501 .1 1 2 F- 19 ,,~ CEMENT MAPPING TOOL 97 0501 I I ~. 2Z-01 ~. O'~ ~ TDT WATER FLOW LOG 970331 I I 2Z-13 ~, IOL~ WATER FLOW LOG 970419 I 1 ..3 B- 13 '3 S ' (_b ~ ~ PRODUCTION PROFILE 97041 0 I 1 3H-07 .~:~. ~"~ L.K \ (~ INJECTION PROFILE 970424 I 1 3K-22 ~-'( · L~Lo (.~ (,,L~ ¢_ CEMENT MAPPING TOOL 970509 I 1 3 K- 27 ~ ~, C~ ~ (.p .~ CEMENT MAPPING mooL 97 0508 I 1 3K-32 ~'-] ' (~-7 ~''& CEMENTBOND LOG 970527 I 1 · Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Rk. CE. iVEL JUL 2 5 997 ri !:! I I_1_ I I~ G S ~:: I:t ~./I C ~::: S June 10, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 3K-32 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 3K-32 Tie in point 0.00', to interpolated depth at 10,944.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 25, 1997 Michael Zanghi Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3K-32 ARCO Alaska, Inc. Permit No: 97-76 Sur. Loc.: 1097'FSL, 316'FWL, Sec. 35, T13N, R9E, UM Btmhole Loc: 1102'FNL, 1726'FWL, Sec. 6, T12N, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. This approval includes annular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) - cementing records, FIT data, and any CQLs are to be submitted to the Commission prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Jol~ton Chairman BY ORDER OF THE COMMISSION dlf/enclosures CC: Department of ~ ish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA AL,-,,.,,(A OIL AND GAS CONSERVATION COMMIS,.....)N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill E] lb Type of Well Exploratory r-~ Stratigraphic Test [] Development Oil X Re-Entry r"J Deepen ~ Service E] Development Gas r-J Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Rig RKB 41', Pad 34' feet Kuparuk River Field 31 Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 25628, ALK 2561 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 1097' FSL, 316' FWL, Sec. 35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1071' FNL, 1623' FWL, Sec. 6, T12N, R10E, UM 3K-32 #U-630610 At total depth 9. Approximate spud date Amount 1102' FNL, 1726' FWL, Sec. 6, T12N, R10E, UM 4/28/97 $200,000 t2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3K-1 2 10793' MD 1071 @ Target feet 12'@ 20' feet 2437 6857' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 60.9° Maxirnumsurface 241 2 ' psig At total depth (TV•) 3600" psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~t Wei~iht Grade Couplin~l Length MD TVD MD TVD (include stac,;le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875" 7.625" 29.7# L-80 LTC 6409' 41' 41' 6450' 4074' 970 Sx Arcticset III & HF-ERW 520 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 10259 41' 41' 10300' 6397' 120 Sx ClassG HF-ERW 6.75" 4.5" 12.8# L-80 EUESrdM 493' 10300' 6397' 10793' 6857' Top 500' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Surface ~,= Intermediate Production ~;p~ Liner I 7 ]9~t~' Perforation depth: tr%eeaOvUre~IdicalORIGINAL Anch0raqe 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r~ Refraction analysis D Seabed report E~ 20 AAC 25.050 requirements X 21. I hereby certify t. t the foreg ing is true and correct to the best of my knowledge Signed ~,~i Title Drill Site Bevel°p- Supv. Date~/'~('~ 7 v k,, ( / ~ Commission Use Only / Permit Numbej' _ vj ~ number .... I Approval date !, · _ J See cover letter for Conditions of approval Samples required F~ Yes ,~ No Mud log r(~quiredl' F~ Yes ~ No Hydrogen sulfidemeasures [] Yes E~ No Directional surveyrequired [] Yes E~ No Required working pressure for BORE [] 2M [] 3M [] 5M ~ 1OM D 15M Other: Original Signed By Oavid W. Johnston byorder of Approved by Commissioner the commission Date~--/a Form 10-401 Rev. 7-24-89 ' t ~te · . . . , . . . . 10. 11. 12. 13. 14. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3K-32 Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (6,450')according to directional plan. ~¢(-- ¢oo' ~~ pC'/tCu3 Run and cement 7-5/8" casing, using stage collar placed at(the base of permafrost, and light weight lead cement. /, Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test, maximum pressure allowed 16.0 ppg EMW. Drill 6-3/4" hole to total depth (10,793') according to directional plan· Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 4-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 5-1/2" x 4-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU tubinghead & master valve and upper tree assembly. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3K-32 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes- Weight up to TD 10.9 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2412 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3K-32 is 3K-12. As designed, the minimum distance between the two wells would be 12' @ 20'. Drilling Area Risks: Risks in the 3K-32 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.9 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 3K-32 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3K-32 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3K-32 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3K surface casing shoes will be set _+200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4042 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft)Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC~M 4990 ..4, 2 4 2 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). ARCO ALASKA, Inc. Pad 3K 32 slot ~r52 [uparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes I NTEQ Your ref : 32 Version #2 Our ref : prop1790 License : Date printed : 4-Mar-97 Date created : 26-Aug-96 Last revised : 4-Mar-9? Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on nTO 25 48.667,w149 45 49.2 Stol location is n70 25 59.456,w149 45 39.928 SLot Grid coordinates are N 6008090.717, E 529307.582 Slot local coordinates are 1097.00 N 316.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wel[path PGMS <O-9843'>,,18,Pad 5K PGMS <O-9584'>,,17,Pad 3K PGMS <O-9038'>,,16,Pad 3K Pr.~lS <O-9275'>,,15,Pad 5K PGMS <O-8960'>,,14,Pad ~K PGMS <O-8580'>,,l],Pad 3K PC~lS <O-7770'>,,12,Pad 3K PGMS <O-7853'>,,11,Pad 3K PGMS <O-7'500'>,,lO,Pad 3K PMSS <5275 - 7443'>,,9,Pad 3K PGMS <O-7580'>,,9A,Pad 3K PGMS <O-8500'>,,8,Pad 3K PGMS <O-8500'>,,7, Pad 3K PGMS <O-8100'>,,60Pad 3K PC.~MS <O-8140'>,,5,Pad 3K Pr.~s <O-8980'>,,4,Pad 3K PGMS <O-8900'>,,3,Pad 3K PGMS <O-9960'>,,2,Pad 3K 3K-~SIE Version #1,,IE,Pad 3K 3K-Z2D Version ffS,,22D,Pad 3K L Version #1,,L,Pad 3K E Version #2,,E,Pad 3K ID Version#1,,ID,Pad 3K H Version #2,,H,Pad 3K 3K-F Version #1,,F,Pad 3K CLosest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging fro~ M.D. 10-0ct-96 1~8.0 20.0 20.0 10-0ct-96 112.0 20.0 20.0 10-0ct-96 88.0 20.0 20.0 10-0ct-96 63.0 20.0 20.0 10-0ct-96 37.0 20.0 625.0 10-0ct-96 13.0 20.0 600.0 10-0ct-96 12.0 20.0 20.0 10-0ct-96 37.7 220.0 220.0 10-0ct-96 59.0 600.0 600.0 10-0ct-96 137.0 20.0 20.0 10-0ct-96 137.0 20.0 20.0 10-0ct-96 162.0 20.0 400.0 10-0ct-96 187.0 20.0 20.0 10-0ct-96 212.0 20.0 360.0 10-0ct-96 234.9 550.0 550.0 10-0ct-96 262.0 20.0 20.0 10-0ct-96 287.0 20.0 20.0 10-0ct-96 312.0 20.0 20.0 25-Feb-97 75.0 280.0 280.0 25-Feb-97 275.0 500.0 500.0 26-Feb-9? 175.0 500.0 500.0 26-Feb-97 250.0 300.0 300.0 26-Aug-96 25.0 500.0 500.0 8-0ct-96 200.0 300.0 300.0 11-00t-96 50.0 300.0 300.0 ARCO ALASKA, Inc. Structure : Pad 5K Well : 52 Field : Kuparuk River Unit Location : North Slope, Alaska 500 1000 1500 ~ 2000 ~-~ 2500 -I,- ~ 3000 3500 > 4000 I-- 4500. I 5000 5500 6000 65O0 7OOO East (feet) -> 500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I / 1097' FSL, 316' FWL I F.~KOP J SEC. 35, T13N, R9E I B/ PERMAFROST '~""'~'~ ~ - I TARGET LOCATION: I ~ I 1071' FNL, '1625' FWL I ~ TVD=6561 ~'--...~/ W SAK SNDS TMD=10478 ~ DEP=7438 SOUTH=2168 B/. W SAK SAN~IsING POINT EAST=7115 RKB ELEVATION: 75' ~ DROP TD KOP TVD=500 TMD=500 DEP=O TARGET - A3 INT (EOD)~i...) 3.00 9.00 15.00 DLS: 5.00 deg per 100 ft 106.94 Deg Az 21.oo (743g' TO T~RGET ~o2' [~c, ~726' m, 27.00 SEC. 6, T~2N, R~OE 35.00 39.00 B/ PERMAFROST TVD=1640 TMD=1722 DEP=378 ¢5.00 51.00 57.00 EOC TVD=2169 TMD=2531 DEP=g82 500 500 1000 1500 20O0 25OO T/ UGNU SNDS TVD=2679 TMD=3580 DEP=1898 MAXIMUM ANGLE 60.92 DEG T/ W SAK SNDS TVD=3403 TMD=5069 DEP=3200 8/ W SAK SNDSTVD=3874 TMD=6038 DEP=4047 7 5/8" CASING PT TVD=4074 TMD=6450 DEP=4407 BEGIN ANGLE DROP TVD=5037 TMD=8432 DEP=6139 CAMPANIAN T SNDS TVD=5845 TMD=9663 DEP=7055 B/ HRZ TVD=6098 TMD=9966 DEP=7221 ~ l[2." & ,~Lq'Z.." ~> .---~.t-. K-1 MARKER TVD=6188 TMD=10069 DEP=7272 T/~P D UNIT TVD=6520 TMD=10216 DEP=7558 [I'~D- ~:~'"tl' 'TMD: IoSoo' - r T/ C UNIT TVD=6419 TMD=10325 DEP=7382 ~'""------~ T/_B UNIT TVD=6458 TMD=10367 DEP=7399 T/A UNIT 1'VD=6547 TMD=10465 DEP=7455 TARGET A3 INT (EOD) TVD-6561 TMD-10478 DEP-7438 B/ KUP TVD=6669 TMD:10595 DEP=7478 tARGET ANGLE ec,x 4q~'rD T'v'r=om~? TMD=I07g3 DEP=?540 20 DEG i i i i i i i i i i i i i i i ii i ii [ i i i i i i i I i i i 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 Vertical Section (feet) -> DLS: 2.00 deg per 100 ft 60.00 56.00 52.00 48.00 44.00 40.00 56,00 32.00 28.00 24.00 Azimuth 106.94 with reference 0.00 N, 0.00 E from slot #52 creoteO ~y finch For: D PETRASH ] nqte plotted : 4-MQr-g7 I I Plot Reference is 32 Version ~12. I Caordlnotea ore [ri feet reference alot ~52, I ARCO ALASKA, Inc. Structure : Pad 5K Well : 32 Field : Kuparuk River Unit Location : North Slope, Alaska 14O 120 100 A 40 '+- 20 0 O Z 20 40 6o 100 120 20 0 20 40 I t I I I I I I I I I I I I I t I I I I I t i t I I I I i I I I I I I I I I I I I I I /2~00 .............. ?_ ....................... 7 ..................................................................................................... o~ 2900 ...... ~ 1900 3100 ~ ....... ..~100 500 -...... ~ ......... --... 900 Eosf (feet) -> 60 80 1 O0 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 1700 3300 500 500 ... 1100 70(3 .,... '""--........ '"x 700 " .... --.... 5OO 900 1300 i i i I i I i I i I i 280 . 300 320 340 360 380 · 1900 ......................... ' ........-._...~ 270~ I I I I I I I I I I I I I I I I 40 60 80 100 120 140 160 180 200 220 240 260 Eosf (feet) -> 400 40 20 0 20 140 12O lOO 8o 6o 40 A I Z 20 0 °? 20 ~ 4O 6O lOO 120 Creoted by finch For: D PETRASH Date plotted: 4-Mar-g7 Plot Reference is 52 Version Coordinot ..... ~n f,,t ret ....... lot ~52. ARCO ALASKA, Inc. Structure : Pad 5K Well: 52 Field : Kuparuk River Unit Location : North Slope, Alaska Easf (feel) 500 400 500600 700 800900 1000 11 O0 1200 1.300 1400 1500 1600 1700 1800 1900 2000 21 O0 2200 2500 2400 [ I I I I I I I I I I I I I I [ I I I I I I I I I I I I I I I I I I I I I I I t I I I L~ .......1900 2100 ............... ;% ........... .. -.-_'_'_'_ 2300 /' o~ --'" ................. 2500 lOO d,O. ~....- - ............................ _ o ............................................... 2700 ~ .................................. 9oo 1 oo ~'::::::-.....2700 .... &::::: .... 2900 < .... ;::::-~.,.. 31 O0 200 1900 °~OC)'':~':~:''~'''''~ 5500 ,,,(3° """'"'" .... '-. 2100 3700 -'~'~-, '~- 1700 '"'-- ~-~-.~.~.. Q3 ..... ---.... 3900 "-" 400 .............. '.::::...27oo ~3o'6"-::::::: ..... c- '~':i'-.t-----.. 455(3'--::: ...... '~" ~ Z / UU · '3 ......... - .................. 4706' ......;;; ....... 0 ~00 2700 .......... -'~%-~- ...... ~o~?~ .... :::~: ........ ,~ I ........... '-%'~6:: .... C:;.:.::: ...... 2500 2500 "-- 5300 '---. "~"---- .... V ~oo ..... - ..... -...~:: ......... 1700 2900 ....... 5500 ....... ' ....... - ....... ~,o~ ..... 2700 ........... ....... ~oo .......... 59~ ......... ' ............ ........... .2700 6~6~D' ......... '"z~ 3 oo ' 800 1900 .... 900 1 ooo 21oo 2300 21 O0 33OO 3500 1100 % i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 300 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 1500 1600 1700 1800 1900 2000 21 O0 2200 2300 2400 Easf (feel) -> 200 100 lOO 2O0 3OO t/) o r --I- 4OO 500 .~_ I 6o0 V 7OO 800 900 1000 1100 7 , 6 I3 1. 16" - 2000 PSI STARTING HEAD 2_ 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST. 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4..RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3.1/2" TO ,5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. KUPARUK RIVER UN,,' 20" DIVERTER SCHEMATIC 6 I4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE ~. OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"-2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 WELL PERMIT CHECKLISToo. Y ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. Lease number appropriate ................ Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force .......... Y Permit can be issued without conservation order .... Y Permit can be issued without administrative approval. . . Can permit be approved before 15-day wait ........ ENGINEERING APPR ~ 14. 15. 16. 17. 18. 19. 20. 21. 22 23 24 25 26 27 28 29. Conductor string provided ............... .Y~ Surface casing protects all known USDWs ........ CMT vol adequate to circulate on conductor & surf csg. · CMT vol adequate to tie-in long string to surf csg . . ' Y CMT will cover all known productive horizons ...... (~ N Casing designs adequate for C, T, B & permafrost .... ~ ~ N Adequate tankage or reserve pit ............ If a re-drill, has a 10-403 for abndnmnt been approved-~--N Adequatewellboreseparationproposed ......... ~N~.i~'~ If diverter required, is it adequate .......... ~ N Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate ..................... ~ N '~,,~ , BOPE press rating adequate; test to .. '~~.-, .p~i N -/ Choke manifold complies w/API RP-53 (May 84) N Work will occur without operation shutdown ...... N Is presence of H2S gas probable ............ N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/N__/,,~ / /) 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... //. Y N 34. Contact name/phone for weekly progress reports . ./. . Y N [exploratory only] REMARKS GEOLOG~Y~ ' ENGINEERING: COMMISSION JDH ~ mcm Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed Aug 13 14:38:11 1997 Reel Header Service name ............. LISTPE Date ..................... 97/08/13 Origin ................... STS Reel Name ................ I/NKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/08/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UlVKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NLTMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 5 AK-MM-70126 S.BURKHARDT D.BREEDEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: M CROF LM[D 3K-32 500292276300 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 13-AUG-97 MWD RUN 6 AK-MM-70126 P. SMITH D. LUTRICK 35 13N 09E 1097 316 .00 75.30 34.30 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7.625 6520.0 6.750 10944.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 4 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 5 AND 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE REMARK ON THE SCHLUMBERGER CBT LOG RAN ON 27 MAY, 1997. THE CBT DATA WAS TIED INTO SPERRY-SUN'S EWR-4 DATA DATED 16 MAY, 1997. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10944'MD, 6960'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Da~e of Generation ....... 97/08/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE AIUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMIW_ARY PBU TOOL CODE GR RPD RPM RPS RPX FET R0P .5000 START DEPTH 6479 5 6515 5 6515 5 6515 5 6515 5 6530 5 6532 0 STOP DEPTH 10904 5 10911 5 10911 5 10911 5 10911 5 10911 5 10943 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 5 6532.0 10090.0 6 10090.0 10944.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MK~ AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Narae DEPT ROP GR RPX RPS RPM RPD FET Min 6479.5 15 5048 25 3418 0 8213 0 8335 0 8347 0 8861 0 0972 Max Mean Nsam 10943.5 8711.5 8929 647.574 227.79 8824 517.596 102.085 8851 2000 3.47826 8793 2000 3.62642 8793 2000 3.81352 8792 2000 5.46377 8793 40.6069 0.891238 8763 First Reading 6479.5 6532 6479.5 6515.5 6515.5 6515.5 6515.5 6530.5 Last Reading 10943 5 10943 5 10904 5 10911 5 10911 5 10911 5 10911 5 10911 5 First Reading For Entire File .......... 6479.5 Last Reading For Entire File ........... 10943.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE S~RY VENDOR TOOL CODE START DEPTH GR 6479.5 RPD 6515.5 RPM 6515.5 RPS 6515.5 RPX 6515.5 FET 653 0.5 ROP 6532.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2.17f SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MA_XIMUM ANGLE: STOP DEPTH 10051 5 10058 5 10058 5 10058 5 10058 5 10058 10090 TOOL STRING (TOP TO BOTTOM) XrENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA 14-MAY-97 ISC 4.88/4.96 CIM 5.46/SP4 5.03/DEPII MEMORY 10090.0 6532.0 10090.0 30.6 60.5 TOOL NUMBER P0715SP4 P0715SP4 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHI~IM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep C~de Offset DEPT FT 4 1 68 GR MWD 5 AAPI 4 1 68 RPX MWD 5 OHMM 4 1 68 RPS MWD 5 OHMM 4 1 68 RPM MWD 5 OHMM 4 1 68 RPD MWD 5 OHMM 4 1 68 ROP MWD 5 FT/H 4 1 68 FET MWD 5 HOUR 4 1 68 6.750 6.8 LSND 201.90 44.0 9.0 450 6.2 0 4 8 12 16 20 24 28 3 .000 2.130 3 .900 3.200 .0 Channel 1 2 3 4 5 6 7 8 44.5 Name DEPT GR RPX RPS RPM RPD ROP Min 6479.5 40 0577 0 8213 0 8335 0 8347 0 8861 15 5048 Max Mean Nsam 10090 8284.75 7222 517.596 103.025 7145 2000 3.36527 7087 2000 3.60335 7087 2000 3.86603 7087 2000 5.91169 7087 647.574 245.188 7117 First Reading 6479 5 6479 5 6515 5 6515 5 6515 5 6515 5 6532 Last Reading 10090 10051.5 10058.5 10058.5 10058.5 10058.5 10090 FET 0.0972 20.465 0.55397 7057 6530.5 10058.5 First Reading For Entire File .......... 6479.5 Last Reading For Entire File ........... 10090 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/13 Maximum Physical Record..65535 File Type ~ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUM14ARY VENDOR TOOL CODE START DEPTH GR 10048.0 FET 10053.5 RPS 10053.5 RPX 10053.5 RPD 10054.0 RPM 10054.0 ROP 10086.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.17f DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG STOP DEPTH 10904 5 10911 5 10911 5 10911 5 10911 5 10911 5 10943 5 16 -MAY- 97 ISC 4.88/4.96 CIM 5.46/SP4 5.03/DEPII MEMORY 10944.0 10090.0 10944.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMPiA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMIC) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type ..... ~ ............ 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record .............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 30.6 30.6 TOOL NUMBER P0715SP4 P0715SP4 6.750 6.8 LSND 215.40 55.0 8.8 5OO 4.6 2.400 1.290 2.100 3.200 58.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 i 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 RPX MWD 6 OHNIM 4 1 68 8 3 RPS MWD 6 0 HlV~4 4 1 68 12 4 RPM MWD 6 OHlV~4 4 1 68 16 5 RPD MWD 6 OHFiM 4 1 68 20 6 ROP MWD 6 FT/H 4 1 68 24 7 FET MWD 6 HOUR 4 1 68 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 10048 25.3418 1 0856 1 0583 1 0719 1 0924 17 4658 0 1563 Max Mean Nsam 10943.5 10495.8 1792 183.986 98.263 1714 95.408 3.93591 1717 63.0437 3.71131 1717 61.8474 3.58398 1716 53.5632 3.59296 1716 598.228 156.697 1715 40.6069 2.53154 1717 First Reading 10048 10048 10053.5 10053.5 10054 10054 10086.5 10053.5 Last Reading 10943 5 10904 5 10911 5 10911 5 10911 5 10911 5 10943 5 10911 5 First Reading For Entire File .......... 10048 Last Reading For Entire File ........... 10943.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
