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Home My WebLink About190-073MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-12 KUPARUK RIV UNIT 3G-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 3G-12 50-103-20131-00-00 190-073-0 W SPT 5686 1900730 3000 2618 2618 2618 2618 241 420 425 422 REQVAR P Adam Earl 8/6/2025 MIT-IA tested as per AIO 2C.090 to MAIP 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3G-12 Inspection Date: Tubing OA Packer Depth 560 3310 3150 3110IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250808084657 BBL Pumped:2.4 BBL Returned:2.2 Monday, September 22, 2025 Page 1 of 1            CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3G-12 (PTD 190-073) Update and plan forward 8/8/23 Date:Tuesday, August 8, 2023 8:42:25 AM Attachments:AnnComm Surveillance TIO for 3G-12.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Tuesday, August 8, 2023 8:12 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3G-12 (PTD 190-073) Update and plan forward 8/8/23 Chris, KRU 3G-12 (PTD 190-073) Subsequent the last correspondence on 7/10/23 the IA pressure was bled down, and the monitor period was extended 30 days, but over the following weeks the IA repressurized. The plan is to WAG the well to water injection after which the well will be placed on a 30-day monitor to verify mechanical integrity while on water injection. Assuming this goes well the intent is to apply for an AA to allow water injection only subsequent the water injection monitor period. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 3G-12 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3G-12 2023-07-02 10.0 100 90.0 OA 3G-12 2023-07-11 1739.0 500 -1239.0 IA 3G-12 2023-07-30 1995.0 1450 -545.0 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,419.0 3G-12 1/2/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull catcher & plug, set DMY 3G-12 5/8/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By Note: DV @ 6173; FISHING NECK IS APPARENTLY COMPROMISED. 4/24/2023 fergusp NOTE: View Schematic w/ Alaska Schematic9.0 8/30/2010 ninam NOTE: UPPOER 1500' PRODUCTION CASING REPLACED, SCREWED INTO EXISTING CSG 3/1/1991 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,040.6 3,040.2 36.00 J-55 BTC PRODUCTION 1991 7 6.28 33.1 1,529.8 1,529.8 26.00 J-55 AB MOD-BTC PRODUCTION 1990 7 6.28 1,529.8 6,735.3 6,066.8 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.4 Set Depth … 6,260.8 Set Depth … 5,712.2 String Ma… 3 1/2 Tubing Description TUBING 3.5"x2.875" @ 6222' Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.4 31.4 0.03 HANGER 8.000 WKM GEN IV HANGER 3.500 1,812.9 1,812.9 0.52 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (Locked out flapper only 4/29/2006) 2.812 2,648.0 2,647.7 1.37 GAS LIFT 5.620 MERLA TMPD 2.875 4,585.3 4,500.1 35.91 GAS LIFT 5.620 MERLA TMPD 2.875 6,173.4 5,647.3 42.05 GAS LIFT 5.750 CAMCO MMG-2 2.920 6,221.7 5,683.2 42.12 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 6,222.2 5,683.6 42.12 SEAL ASSY 3.500 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.387 6,225.0 5,685.6 42.13 PACKER 5.687 BAKER D PERMANENT PACKER 3.250 6,228.6 5,688.3 42.15 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 6,248.6 5,703.1 42.23 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 6,260.1 5,711.6 42.28 SOS 3.750 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,152.0 2,151.9 1.41 CSG PATCH 7" Csg Patch to Repair Collapsed Csg, Drift ID 5.851" 3/4/1991 5.976 6,431.0 5,837.9 42.27 FISH 5' Dyna Strip Strip Left in Hole from Perf Job on 8/8/91 8/8/1991 6,444.0 5,847.5 42.21 FISH 2 - 1 1/2" DV Left in Rathole 9/3/1991 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,648.0 2,647.7 1.37 1 GAS LIFT DMY BK 1 0.0 3/4/1991 0.000 4,585.3 4,500.1 35.91 2 GAS LIFT DMY BK 1 0.0 5/4/2023 0.000 6,173.4 5,647.3 42.05 3 GAS LIFT DMY RK 1 1/2 0.0 9/3/1991 F/N Stripp ed? 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,344.0 6,354.0 5,773.6 5,781.0 C-4, UNIT B, 3G -12 8/8/1991 8.0 IPERF 90 deg pH; 2 1/8"Dyna Strip 6,390.0 6,420.0 5,807.6 5,829.7 A-4, A-3, 3G-12 8/6/1991 8.0 IPERF 90 deg ph; 2 1/8"Dyna Strip 6,430.0 6,460.0 5,837.1 5,859.4 A-2, 3G-12 3/2/1991 4.0 IPERF 180 deg. ph, 4.5" Csg Gun 3G-12, 5/9/2023 7:24:35 AM Vertical schematic (actual) PRODUCTION 1990; 1,529.8- 6,735.3 IPERF; 6,430.0-6,460.0 FISH; 6,444.0 FISH; 6,431.0 IPERF; 6,390.0-6,420.0 IPERF; 6,344.0-6,354.0 PACKER; 6,225.0 GAS LIFT; 6,173.4 GAS LIFT; 4,585.3 SURFACE; 35.0-3,040.6 GAS LIFT; 2,648.0 CSG PATCH; 2,152.0 SAFETY VLV; 1,812.9 PRODUCTION 1991; 33.1- 1,529.8 CONDUCTOR; 36.0-115.0 KUP INJ KB-Grd (ft) 36.21 RR Date 6/21/1990 Other Elev… 3G-12 ... TD Act Btm (ftKB) 6,749.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032013100 Wellbore Status INJ Max Angle & MD Incl (°) 47.08 MD (ftKB) 5,100.00 WELLNAME WELLBORE3G-12 Annotation Last WO: End Date 3/1/1991 H2S (ppm) DateComment SSSV: Locked Out Flapper MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, September 20, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-12 KUPARUK RIV UNIT 3G-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/20/2023 3G-12 50-103-20131-00-00 190-073-0 G SPT 5686 1900730 1500 3620 3621 3623 3624 200 240 240 240 4YRTST P Adam Earl 8/1/2023 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3G-12 Inspection Date: Tubing OA Packer Depth 1500 3090 2860 2840IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230802193850 BBL Pumped:3.1 BBL Returned:3 Wednesday, September 20, 2023 Page 1 of 1          CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3G-12 (PTD 190-073) Update and plan forward Date:Monday, July 10, 2023 3:30:31 PM Attachments:image001.png AnnComm Surveillance TIO for 3G-12.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, July 10, 2023 2:27 PM To: Byrne, Jan <Jan.Byrne@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3G-12 (PTD 190-073) Update and plan forward Chris- KRU 3G-12 (PTD #190-073) has completed the 60 day monitor period to investigate the suspected IA pressure build up. During the monitor period on gas injection, the IA showed an upward trend. However, the injection temperature has an upward trend as well which maybe the cause of the continued IA pressure increase. CPAI intends to bleed the IA and extend the monitor period by 30 days to continue to investigate the potential of an unexplainable IA pressure increase. Depending on the results of the 30 day extension, the proper notifications for continued injection or repair will be submitted at that time. Attached is a current 90 day TIO trend and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Byrne, Jan Sent: Thursday, May 11, 2023 9:37 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3G-12 (PTD 190-073) Update and plan forward Chris, KRU 3G-12 (PTD 190-073) was reported 3/10/23 for suspect IA pressure build up. Subsequent the report DHD degassed the IA and passed a diagnostic MITIA. The well was shut in 3/30/23 due to continued IA pressure build up. Subsequent shut in the well was secured and the well bore was circ’d out with new fluids to eliminate gas saturated fluids. The plan is to BOI for a 60 day monitor period to determine if the IA pressure build up has been resolved with the circ out. A 90 day TIO trend, wellbore schematic, and 10-426 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) 265-6471 Cell phone: (808) 345-6886 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,419.0 3G-12 1/2/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull catcher & plug, set DMY 3G-12 5/8/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By Note: DV @ 6173; FISHING NECK IS APPARENTLY COMPROMISED. 4/24/2023 fergusp NOTE: View Schematic w/ Alaska Schematic9.0 8/30/2010 ninam NOTE: UPPOER 1500' PRODUCTION CASING REPLACED, SCREWED INTO EXISTING CSG 3/1/1991 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,040.6 3,040.2 36.00 J-55 BTC PRODUCTION 1991 7 6.28 33.1 1,529.8 1,529.8 26.00 J-55 AB MOD-BTC PRODUCTION 1990 7 6.28 1,529.8 6,735.3 6,066.8 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.4 Set Depth … 6,260.8 Set Depth … 5,712.2 String Ma… 3 1/2 Tubing Description TUBING 3.5"x2.875" @ 6222' Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.4 31.4 0.03 HANGER 8.000 WKM GEN IV HANGER 3.500 1,812.9 1,812.9 0.52 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (Locked out flapper only 4/29/2006) 2.812 2,648.0 2,647.7 1.37 GAS LIFT 5.620 MERLA TMPD 2.875 4,585.3 4,500.1 35.91 GAS LIFT 5.620 MERLA TMPD 2.875 6,173.4 5,647.3 42.05 GAS LIFT 5.750 CAMCO MMG-2 2.920 6,221.7 5,683.2 42.12 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 6,222.2 5,683.6 42.12 SEAL ASSY 3.500 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.387 6,225.0 5,685.6 42.13 PACKER 5.687 BAKER D PERMANENT PACKER 3.250 6,228.6 5,688.3 42.15 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 6,248.6 5,703.1 42.23 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 6,260.1 5,711.6 42.28 SOS 3.750 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,152.0 2,151.9 1.41 CSG PATCH 7" Csg Patch to Repair Collapsed Csg, Drift ID 5.851" 3/4/1991 5.976 6,431.0 5,837.9 42.27 FISH 5' Dyna Strip Strip Left in Hole from Perf Job on 8/8/91 8/8/1991 6,444.0 5,847.5 42.21 FISH 2 - 1 1/2" DV Left in Rathole 9/3/1991 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,648.0 2,647.7 1.37 1 GAS LIFT DMY BK 1 0.0 3/4/1991 0.000 4,585.3 4,500.1 35.91 2 GAS LIFT DMY BK 1 0.0 5/4/2023 0.000 6,173.4 5,647.3 42.05 3 GAS LIFT DMY RK 1 1/2 0.0 9/3/1991 F/N Stripp ed? 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,344.0 6,354.0 5,773.6 5,781.0 C-4, UNIT B, 3G -12 8/8/1991 8.0 IPERF 90 deg pH; 2 1/8"Dyna Strip 6,390.0 6,420.0 5,807.6 5,829.7 A-4, A-3, 3G-12 8/6/1991 8.0 IPERF 90 deg ph; 2 1/8"Dyna Strip 6,430.0 6,460.0 5,837.1 5,859.4 A-2, 3G-12 3/2/1991 4.0 IPERF 180 deg. ph, 4.5" Csg Gun 3G-12, 5/9/2023 7:24:35 AM Vertical schematic (actual) PRODUCTION 1990; 1,529.8- 6,735.3 IPERF; 6,430.0-6,460.0 FISH; 6,444.0 FISH; 6,431.0 IPERF; 6,390.0-6,420.0 IPERF; 6,344.0-6,354.0 PACKER; 6,225.0 GAS LIFT; 6,173.4 GAS LIFT; 4,585.3 SURFACE; 35.0-3,040.6 GAS LIFT; 2,648.0 CSG PATCH; 2,152.0 SAFETY VLV; 1,812.9 PRODUCTION 1991; 33.1- 1,529.8 CONDUCTOR; 36.0-115.0 KUP INJ KB-Grd (ft) 36.21 RR Date 6/21/1990 Other Elev… 3G-12 ... TD Act Btm (ftKB) 6,749.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032013100 Wellbore Status INJ Max Angle & MD Incl (°) 47.08 MD (ftKB) 5,100.00 WELLNAME WELLBORE3G-12 Annotation Last WO: End Date 3/1/1991 H2S (ppm) DateComment SSSV: Locked Out Flapper CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3G-12 (PTD 190-073) Report of suspect IA pressure increase Date:Thursday, May 11, 2023 10:47:19 AM Attachments:AnnComm Surveillance TIO for 3G-12.pdf Correct PTD is 1900730, not 1990730. Thanks Chris From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, March 10, 2023 7:44 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3G-12 (PTD 199-073) Report of suspect IA pressure increase Chris, KRU 3G-12 (PTD 199-073) is exhibiting suspect IA pressure increase. The plan is for DHD to perform initial diagnostics including an MITIA, pack off tests, and adjusting the IA pressure for a 30 day monitor period. Any required paperwork for continued injection or corrective action will be submitted once initial diagnostics and monitor period have been completed. 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) 265-6471 Cell phone: (808) 345-6886 3G-12 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.921 Top (ftKB) 35.0 Set Depth (ftKB) 3,040.6 Set Depth (TVD) … 3,040.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION 1991 OD (in) 7 ID (in) 6.276 Top (ftKB) 33.1 Set Depth (ftKB) 1,529.8 Set Depth (TVD) … 1,529.8 Wt/Len (l… 26.00 Grade J-55 Top Thread AB MOD- BTC Casing Description PRODUCTION 1990 OD (in) 7 ID (in) 6.276 Top (ftKB) 1,529.8 Set Depth (ftKB) 6,735.3 Set Depth (TVD) … 6,066.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING 3.5"x2.875" @ 6222' String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 31.4 Set Depth (ft… 6,260.8 Set Depth (TVD) (… 5,712.2 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.4 31.4 0.03 HANGER WKM GEN IV HANGER 3.500 1,812.9 1,812.9 0.52 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE (Locked out flapper only 4/29/2006) 2.812 6,221.7 5,683.2 42.12 XO Reducing CROSSOVER 3.5 x 2.875 2.875 6,222.2 5,683.6 42.12 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.387 6,225.0 5,685.6 42.13 PACKER BAKER D PERMANENT PACKER 3.250 6,228.6 5,688.3 42.15 SBE BAKER SEAL BORE EXTENSION 3.250 6,248.6 5,703.1 42.23 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,260.1 5,711.6 42.28 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 2,152.0 2,151.9 1.41 CSG PATCH 7" Csg Patch to Repair Collapsed Csg, Drift ID 5.851" 3/4/1991 5.976 6,431.0 5,837.9 42.27 FISH 5' Dyna Strip Strip Left in Hole from Perf Job on 8/8/91 8/8/1991 6,444.0 5,847.5 42.21 FISH 2 - 1 1/2" DV Left in Rathole 9/3/1991 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 6,344.0 6,354.0 5,773.6 5,781.0 C-4, UNIT B, 3G-12 8/8/1991 8.0 IPERF 90 deg pH; 2 1/8"Dyna Strip 6,390.0 6,420.0 5,807.6 5,829.7 A-4, A-3, 3G- 12 8/6/1991 8.0 IPERF 90 deg ph; 2 1/8"Dyna Strip 6,430.0 6,460.0 5,837.1 5,859.4 A-2, 3G-12 3/2/1991 4.0 IPERF 180 deg. ph, 4.5" Csg Gun Mandrel Inserts St ati on N o/ Top (ftKB) Top (TVD) (ftKB) Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,648.0 2,647.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/4/1991 2 4,585.3 4,500.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/4/1991 3 6,173.4 5,647.3 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/3/1991 Notes: General & Safety End Date Annotation 3/1/1991 NOTE: UPPOER 1500' PRODUCTION CASING REPLACED, SCREWED INTO EXISTING CSG 8/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: Locked Out Flapper3G-12, 1/25/2017 11:23:03 AM Vertical schematic (actual) PRODUCTION 1990; 1,529.8- 6,735.3 IPERF; 6,430.0-6,460.0 FISH; 6,444.0 FISH; 6,431.0 IPERF; 6,390.0-6,420.0 IPERF; 6,344.0-6,354.0 SOS; 6,260.1 NIPPLE; 6,248.6 SBE; 6,228.6 PACKER; 6,225.0 SEAL ASSY; 6,222.2 GAS LIFT; 6,173.4 GAS LIFT; 4,585.3 SURFACE; 35.0-3,040.6 GAS LIFT; 2,648.0 CSG PATCH; 2,152.0 SAFETY VLV; 1,812.9 PRODUCTION 1991; 33.1- 1,529.8 CONDUCTOR; 36.0-115.0 HANGER; 31.4 Annotation Last Tag: SLM Depth (ftKB) 6,419.0 End Date 1/2/2016 Annotation Rev Reason: PULL CA-2 PLUG W/GUAGE Last Mod By pproven End Date 1/25/2017 KUP INJ KB-Grd (ft) 36.21 Rig Release Date 6/21/1990 Annotation Last WO: End Date 3/1/1991 3G-12 H2S (ppm) Date ... TD Act Btm (ftKB) 6,749.0 Well Attributes Wellbore API/UWI 501032013100 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 47.08 MD (ftKB) 5,100.00 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3G-12 (PTD 190-073) Update and plan forward Date:Thursday, May 11, 2023 10:03:36 AM Attachments:AnnComm Surveillance TIO for 3G-12.pdf MIT KRU 3G-12 diagnostic MITIA 03-22-23.xlsx From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, May 11, 2023 9:37 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3G-12 (PTD 190-073) Update and plan forward Chris, KRU 3G-12 (PTD 190-073) was reported 3/10/23 for suspect IA pressure build up. Subsequent the report DHD degassed the IA and passed a diagnostic MITIA. The well was shut in 3/30/23 due to continued IA pressure build up. Subsequent shut in the well was secured and the well bore was circ’d out with new fluids to eliminate gas saturated fluids. The plan is to BOI for a 60 day monitor period to determine if the IA pressure build up has been resolved with the circ out. A 90 day TIO trend, wellbore schematic, and 10-426 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) 265-6471 Cell phone: (808) 345-6886 3G-12 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3G-12 2023-03-12 2300 1000 -1300 IA 3G-12 2023-03-13 382 310 -72 IA 3G-12 2023-03-14 390 200 -190 IA 3G-12 2023-03-21 762 300 -462 IA 3G-12 2023-03-22 250 500 250 IA 3G-12 2023-03-31 2390 1750 -640 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,419.0 3G-12 1/2/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull catcher & plug, set DMY 3G-12 5/8/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By Note: DV @ 6173; FISHING NECK IS APPARENTLY COMPROMISED. 4/24/2023 fergusp NOTE: View Schematic w/ Alaska Schematic9.0 8/30/2010 ninam NOTE: UPPOER 1500' PRODUCTION CASING REPLACED, SCREWED INTO EXISTING CSG 3/1/1991 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,040.6 3,040.2 36.00 J-55 BTC PRODUCTION 1991 7 6.28 33.1 1,529.8 1,529.8 26.00 J-55 AB MOD-BTC PRODUCTION 1990 7 6.28 1,529.8 6,735.3 6,066.8 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.4 Set Depth … 6,260.8 Set Depth … 5,712.2 String Ma… 3 1/2 Tubing Description TUBING 3.5"x2.875" @ 6222' Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.4 31.4 0.03 HANGER 8.000 WKM GEN IV HANGER 3.500 1,812.9 1,812.9 0.52 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (Locked out flapper only 4/29/2006) 2.812 2,648.0 2,647.7 1.37 GAS LIFT 5.620 MERLA TMPD 2.875 4,585.3 4,500.1 35.91 GAS LIFT 5.620 MERLA TMPD 2.875 6,173.4 5,647.3 42.05 GAS LIFT 5.750 CAMCO MMG-2 2.920 6,221.7 5,683.2 42.12 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 6,222.2 5,683.6 42.12 SEAL ASSY 3.500 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.387 6,225.0 5,685.6 42.13 PACKER 5.687 BAKER D PERMANENT PACKER 3.250 6,228.6 5,688.3 42.15 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 6,248.6 5,703.1 42.23 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 6,260.1 5,711.6 42.28 SOS 3.750 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,152.0 2,151.9 1.41 CSG PATCH 7" Csg Patch to Repair Collapsed Csg, Drift ID 5.851" 3/4/1991 5.976 6,431.0 5,837.9 42.27 FISH 5' Dyna Strip Strip Left in Hole from Perf Job on 8/8/91 8/8/1991 6,444.0 5,847.5 42.21 FISH 2 - 1 1/2" DV Left in Rathole 9/3/1991 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,648.0 2,647.7 1.37 1 GAS LIFT DMY BK 1 0.0 3/4/1991 0.000 4,585.3 4,500.1 35.91 2 GAS LIFT DMY BK 1 0.0 5/4/2023 0.000 6,173.4 5,647.3 42.05 3 GAS LIFT DMY RK 1 1/2 0.0 9/3/1991 F/N Stripp ed? 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,344.0 6,354.0 5,773.6 5,781.0 C-4, UNIT B, 3G -12 8/8/1991 8.0 IPERF 90 deg pH; 2 1/8"Dyna Strip 6,390.0 6,420.0 5,807.6 5,829.7 A-4, A-3, 3G-12 8/6/1991 8.0 IPERF 90 deg ph; 2 1/8"Dyna Strip 6,430.0 6,460.0 5,837.1 5,859.4 A-2, 3G-12 3/2/1991 4.0 IPERF 180 deg. ph, 4.5" Csg Gun 3G-12, 5/9/2023 7:24:35 AM Vertical schematic (actual) PRODUCTION 1990; 1,529.8- 6,735.3 IPERF; 6,430.0-6,460.0 FISH; 6,444.0 FISH; 6,431.0 IPERF; 6,390.0-6,420.0 IPERF; 6,344.0-6,354.0 PACKER; 6,225.0 GAS LIFT; 6,173.4 GAS LIFT; 4,585.3 SURFACE; 35.0-3,040.6 GAS LIFT; 2,648.0 CSG PATCH; 2,152.0 SAFETY VLV; 1,812.9 PRODUCTION 1991; 33.1- 1,529.8 CONDUCTOR; 36.0-115.0 KUP INJ KB-Grd (ft) 36.21 RR Date 6/21/1990 Other Elev… 3G-12 ... TD Act Btm (ftKB) 6,749.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032013100 Wellbore Status INJ Max Angle & MD Incl (°) 47.08 MD (ftKB) 5,100.00 WELLNAME WELLBORE3G-12 Annotation Last WO: End Date 3/1/1991 H2S (ppm) DateComment SSSV: Locked Out Flapper Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1900730 Type Inj N Tubing 3757 3758 3758 3755 Type Test P Packer TVD 5686 BBL Pump 2.3 IA 750 3300 3200 3175 Interval O Test psi 3000 BBL Return OA 17 17 17 17 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3G Pad Miller 03/22/23 Notes:Diagnostic MITIA Notes: 3G-12 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 3G-12 diagnostic MITIA 03-22-23 (002) Well Name KUPARUK RIV UNIT 3G-12 IInsp Num: mitAGE190805110452 Rel Insp Num: API Well Number 50-103.20131-00-00 Inspector Name: Adam Earl Permit Number: 190-073-0 Inspection Date: 8/3/2019 Packer yep 3G -a TTypelnj w --]TVD _� PTD 1900730 Type Testl spT Test ps - o.a "'BBL Returned: BBL Pumped: Interval 4YRTST P/F Notes: MIT/IA Depth 5686 Tubing 1500 IA 07 OA P' Pretest Initial 15 Min 30 Min 45 Min 60 Min 1730 1730 3730 3730 —� — 1390 3010 1960 1940 - 600 650 650 650 Page I of I Tuesday, August 6, 2019 State of Alaska MEMORANDUM Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 6, 2019 TO: Jim Rper >�-7� CJI Cl IQ ( SUBJECT: Mechanical Integrity Tests P.I. Supervisor ConmoPhillips Alaska, Inc. 3G-12 FROM: Adam Earl KIIPARUK RIV UNIT 3G-12 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Suprv, NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-12 IInsp Num: mitAGE190805110452 Rel Insp Num: API Well Number 50-103.20131-00-00 Inspector Name: Adam Earl Permit Number: 190-073-0 Inspection Date: 8/3/2019 Packer yep 3G -a TTypelnj w --]TVD _� PTD 1900730 Type Testl spT Test ps - o.a "'BBL Returned: BBL Pumped: Interval 4YRTST P/F Notes: MIT/IA Depth 5686 Tubing 1500 IA 07 OA P' Pretest Initial 15 Min 30 Min 45 Min 60 Min 1730 1730 3730 3730 —� — 1390 3010 1960 1940 - 600 650 650 650 Page I of I Tuesday, August 6, 2019 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,August 21,2015 TO: Jim Regg 1 /i3115 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-12 FROM: John Crisp KUPARUK RIV UNIT 3G-12 Petroleum Inspector Src: Inspector Reviewed By:p�, P.I.Suprv3D NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-12 API Well Number 50-103-20131-00-00 Inspector Name: John Crisp Permit Number: 190-073-0 Inspection Date: 8/15/2015 Insp Num: mitJCr150821100836 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-12 ,Type ln j I G 1TVD -7 5686 ^ Tubing 3853 . 3849 3847 3850 ' 1900730 PTD LTyp e Test'SPT Test psi' 1500 — — j - IA 290 2000 ^ 1870 - 1840 - Intervali4YRTST JP /F P OA 80 100 100 100 Notes: 4.2 bbls pumped for test. - SCANNED ', ,;r Friday,August 21,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission (■-? 1 11 (,I DATE: Wednesday, September 07, 2011 TO: Jim Regg P.I. Supervisor << SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G -12 FROM: Jeff Jones KUPARUK RIV UNIT 3G -12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 1 - NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3G -12 API Well Number: 50 -103- 20131 -00 -00 Inspector Name: Jeff Jones , Insp Num: mitJJ110906081534 Permit Number: 190 -073 -0 Inspection Date: 8/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3G -12 ' Type Inj. W 5686 IA 1200 T 3240 ' 1 3060 I 3020 P.T.D 1900730 ' TypeTest SPT Test psi 1500 OA 360 560 560 560 Interval 4YRTST P/F P _ Tubing 2673 2674 2667 1 2685 Notes: 3 BBLS diesel pumped. 1 well inspected; no exceptions noted. Wednesday, September 07, 2011 Page 1 of 1 1 ~ COI'10C ~ ~ ~ oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: '~~ '.; i?~ ;~" „ f, !-~ ? ~ ' i'' ~ R~~EIVED AUG 2 4 2d09 Alask~ Qi1 ~ Gas Cons. Commis~ion Anchor4pa a- a~~ ~~ ~ ~ r ~ ~ Enclosed please find a spreadsheet with a list of wells from the Kupaxuk field (KRL~. 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 July 30~` 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~~ MJ Lov land ConocoPhillips Well Integrity Projects Supervisor • ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11109 ar~ ~u ~v n_ ~n o„a Well Name API # PTD # Initial top o cement Vol, of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date bbis al 3G-12 501032Q1310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-106 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1879290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 187004U 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # i ~ t, ~~~.,~:, ,.~ . %` ~ 0 ~ 20G9 q' ¢¢~~~~yy,yyyy ~~^^ NO. 5261 ~E1t4~P~C Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken ., .w ; ,~~~~ ; ~ t ~ A ; ~- ; ~ ^ ~ ~ ~ ~ 333 West 7th Ave, Suite 100 ~~~+'~ ~ --~' ~ 4 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 06/03/09 2U-15 AZCM-00012 GLS 03/28/09 1 1 3G-12 B04C-00047 INJECTION PROFILE -- `} / // 05/10/09 1 1 1C-172A B04C-00049 GLS 05/11/09 1 1 3G-11 804C-00050 PRODUCTION PROFILE 05/12/09 1 1 2A-06 6148-00048 DDL 05/15/09 1 1 2A-16 B14B-00047 LDL 05/15/09 1 1 3G-16 B14B-00049 INJECTION PROFILE p _ 05/16/09 1 1 3G-18 B14B-00050 PRODUCTION PROFILE 05/17/09 1 1 2D-05 AYS4-00072 INJECTION PROFILE 05/21/09 1 1 1 E-15 B14B-00058 LDL 05/24/09 1 1 3H-33 B04C-00006 CH EDIT (PEX,SONIC SCANNER,CHFR) 02/09/09 4 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r 1 LJ f MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~s~;:r~isor Ren £/?iJ107 DATE: Wednesday, August 22, 2007 SUBJECT: Mechanical Integrity Tests eONOeOPIDLLIPS ALASKA INe 30-12 KUPARUK RIV UNIT 30-12 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ."fBf!- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3G-12 API Well Number: 50-103-20131-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070820171504 Permit Number: 190-073-0 Inspection Date: 8/20/2007 Rei Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 30-12 Type Inj. 0 TVD 5686 IA 1200 2460 2420 2420 P.T. l'JUU/:5U TypeTest :)YI Test psi 1500 OA 280 320 320 320 Interval 4YRTST ./PIF P ./ Tubing 3590 3590 3590 3590 Notes: Pretest pressures observed for 30+ minutes and found stable. / SCANNED Sf P 1 0 2007 Wednesday, August 22, 2007 Page 1 of 1 RECEiVED ¡ ! i iN 9 '1 'ìllne; v·.......J -J tJ LU0U Schlumbel'gel' . , ,,-"'} r-< ",,... .. e,"'¡mIT1issiÇn _:..;.~ ~ . . ~ ',.J. '''; ~J: I_.(.r~. \...'-,.11111' · . ~':i~""" ~ ~rdi-cæ.ge Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth ~ /O/,{ \c>,P SCANNED JUN 2 3 2006 0~~ Well Job # Log Description Date 1 F-06 11249918 PRODUCTION PROFILE W/DEFT 06/13/06 1 F-20 11320984 PRODUCTION PROFILE WIDEFT 06/12/06 1A-15 11249917 INJECTION PROFILE 06/12/06 2T -40 11249919 SCMT 06/14/06 2M-20 11235372 PRODUCTION PROFILE 06/18/06 3G-12 11320978 INJECTION PROFILE 06/01/06 1Y-27 11235341 PRODUCTION PROFILE W/DEFT 02/26/06 3M-21 11213734 INJECTION PROFILE 04/04/06 2Z-12A 11216199 MEMORY PRODUCTION PROFILE 06/04/06 1 A-22 11213761 PRODUCTION PROFILE WIDEFT 06/15/06 06/22/06 NO. 3858 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color -..,./ CD 1 1 1 1 1 1 1 1 1 1 It::> Please sign and return one copy of this transmittal t~~ above address or fax to (907) 561-8317. Thank you. J 83'-0) &03-0 I qo ..(). nQ'-O ~ 01-1-01 ~~~ .. 02/16/04 Scblumberger NO.3113 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Log Description Date BL Color CD Job# c' 1Y-13 10709699 INJECTION PROFILE (REDO) 01/27/04 1 v lö 3N-18L2 10696831 PRODUCTION PROFILE 01130/04 1 U;~ 1 L-19 10696833 LEAK DETECTION LOG 02/01/04 1 ~r.2 3G-12 10709686 INJECTION PROFILE 12/31/03 1 ...... 2P-419 10703972 USIT/CBL 02/06/04 1 1 \,~,~ .. SIGN~~~"'''~~:6\ ~ ~.~ ç¡ [). ~~~ í RECEIVED FEB DATE: Please sign an~ return ()ne copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank,Y~askaOiI&GasCons.CommiIion ~tA~~E~:,,) MAH 1 5 2004, AncMrage '" . RECEIVE:.r:\. FEB 1 7 2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PORT OF SUNDRY WELL OPERATIONS - -. }~~ '~!1~~~~6rme~: .~. '.Äb~~~on' ',,0. . , " :' .,$'~SP7~~"",D. ','''' pperation Shutdow". [j :':,":,",'P:enorateD ',', ' . ,,~~~~c~ " D ArÌnular[)isp. tJ , '. ' ",.' :Ao.r!'QfS~~""" . ,.', ' , ".. ',' " '",~an~e,~p,~~:~;:~ ,.' .".g,';';~:~!i'.g.", ".~;;~~~~~;:~:',g'."::,:>~~Äume.~~i~~;~~:~:;~~" .g": "',.' bnmr',[?J' 2. Operator Name: :' 4,:"Cu,iÏ'eï;r\JVøH'Stat~$::, ' ., ", ',. '5. Permit to Drill Number: ConocoPhillips Alaska, Inc." Ó~vêlop~~~~,' :"0:,' E~'6ratorYD " 190-073/ 3. Address: : St~tig~phic" D' 'S~rvíce '0 6. API Number: P. O. Box 100360 50-103-20131-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 89' 3G-12 wJ¡§ -6-0 /P 1(;, 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 6749' feet true vertical 6077' feet measured 6650 feet true vertical 6002 feet Length Size MD 115' 16" 1151 2951' 9-5/8" 30401 66461 7" 67351 Plugs (measured) Junk (measured) TVD Burst Collapse 115' 3040' 6067' Measured depth: 6344-6354; 6390-6420; 6430-6460 true vertical depth: 5774-5781; 5808-5830; 5837-5859 Tubing (size, grade, and measured depth) 2-7/8", L-80, 6261' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'ECl' (PKR BETWEEN PROD & SUR CSG); (SEE HANDOVER FORM 3/4/91); BAKER 'D' MODEL PERM. pkr= 151 SSSV= SSSV SSSV= 1813' ,'1 '2. Stimu,lation dr C::13~ent squee;!:e sUmmary: ' , Intervals treated (measlir~d) , . . .. .. . . . . .. . TreaÙn~nt des,cr,iptjpns iheluding' v91~nies us~~ t:ind final pre$sure: '",13,. ' 'Hep'reseritative -Däily Averag,e -P~odyctk)n'p( Injectio~ Data ", , ' "'Oil-Bbl ',' , '". Gas-Md' ,,', , , ' -:Wa:te¡-~Bbl, " , ' , ' , , Pri~r tCPJlel! opération, , , ' ' ,. '2~Ù: :' , , : S.~bsequeöt :tq ,()perati,pn ' , , ,,', ','215$ , , ,'. ". ,,', ',14. AttØchments' , ' , , ' ., , ' ,15. Wë\l G.las$ ~fter proposøØ,work: " , , Cdpjes of Logs élnd,S\.I!Yeys run ~ " Exploratory, ,0, b~vélopin~nt ,0 ,',Service ,0, . . . . .. . .. . . . . . . . . .. . , D~ily' Report of. weli operations -::-X ': 16. W eU:' status 'after ,proþos~d wbrk:' ' , "', "',, ' "OilÇJ , "Gas,D ", WAG0' GiNjD',' 'y¡JII'.jj D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number M f'.1/1I " - ~ "".._~....t. ,Contact N/A ,. Casin' Pr'essüre , ' ' 1,,fPQ, "110Q Tubin Pressure'" ",~$5,1 , 3625', : WD,SPLD Signature Title Phone I~ I ;: . 'I. ,"'",', , '3G-12. DESCRIPTION OF WORK COMPLETED SUMMARY . I' ,,' ,;,' Date Event Summary 02107/04 [g2fiiiTI.ê'f1Ce.d"WAG:E,()R Jn~oh:: , . " " "I " " , . -.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk/KRU/3G DATE: 08/04/03 OPERATOR REP: Arend/Brake - APC AOGCC REP' Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well l3G-10 I Typelnj T.V.D. I 5789 ]TubingI 20001 2000] 20001 2000]lnterval P.T.D.11900840I TypeTest Test psiI 1500 I Casing I 1350l 2460] 24201 24201 P/F Notes: 2 Yr MIT required by internal Waiver Well13G.12 I Type Inj P.T.D. I1900730 TypeTest Notes: T.V.D. I I Tubingl 23501 23501 23501 Interval TestpsiI 1500 I Casing I 12501 235O1 23001 22801 P/F [4. P.T.D. I1901160 Type Test Test psiI 1500 I Casing I 11401 24001 23801 23801 P/F Notes: P.T.D. I1901210 Type Test TestpsiI 1500 I Casing I 12401 24501 24251 24251 P/F Notes: A header pressure anonomile occurred right before the start of the test , Well13G-16 I Type Inj P.T.D. I1901040 Type Test Notes: T.V.D. I 5764 I Tubingl 31001 31001 31001 31001Interval Test psiI 1500 I Casing I 13001 24001 24001 24001 P/F Well 13G-24 P.T.D. 11901340 Notes: Type Test Test psiI 1500 I Casing I 12001 21001 21001 21001 P/F Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 3G 08-04-03.xls 8/5/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' FROM: Randy Ruedrich Commissioner Jim Regg "~{c~ P.I. Supervisor DATE: August 4, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3G Pad KRU Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Welll 3G-10 P.T.D.I 190-084 Notes: P.T.D.I 190-073 Notes: WellI 3G-13 P.T.D.I 190-116 Notes: WellI 3G-15 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. ~.~'~i.I~ I~-~.~- I~ITubing I2000I~ooo I~ooo I~ooo I'"'er~'l" TypetestI P ITestpsil 1447 I CasingI 1350I 2460I 2420I 2420I P/F I P ~'.i.I ~I~.v.D. I~ I Tubing I~o I~o I~o I~~o I'~rv~'l" Type testI P I Testpsil 1422 I Casingl 1250I 2350I 2300 I 2280 I P/F I P ~.~'~.1 ~ I~.~.D. I~ I~"~". I~° I~° I ~o I~o I,~,~rv~,l , Type testI P I Testpsil 1445 I CasingI 1140I 2400I 2380I 2380I P/F '1 P I Type,nj.I G I T.V.D. 15727 I Tubing 14000 14000 14000 14000 I,nterva, I 4 I Type testI P I Testpsil 1432 I Casingl 1240I 2450I 2425I 2425I P/FI P P.T.D.I 190-104 ITypetestl P ITestpsil 1441 I Casingl 1300 I 2400 I 2400 I 2400I P/FI P Notes: WellI 3G-24 I Typelnj. I S I T.V.D. 15716 I Tubing 12350 12350 I 2350 I 2350I,nterva, I4 P.T.D.I 190-134 ITypetestl P ITestpsil 1429 I Casingl 1200I 2100I 2100I 2100I P/F I P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R-- Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3G Pad in the Kuparuk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Number of Failures: 0 Attachments: Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. ~CANN~b AUG ~ ! 2003 2003-0804_M IT_KR U_3 G-24_cs .xls 8/15/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C.,CMM~ REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown.__ Pull tubing ..----- Alter casing Stimulate Plugging Perforate ~ Repair well ,, O t h e r ;~ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 2538' FNL, 95' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1770' FSL, 1362' FWL, Sec. 24, T12N, R8E, UM At effective depth 1640' FSL, 1493' FWL, Sec. 24, T12N, R8E, UM At total depth 1582' FSL 1553' FWL Sec. 24 IM 12, Present well condition summary Total Depth: measured 6 7 4 9' feet true vertical 6079' feet Plugs (measured) 6. Datum elevaton (DF or KB) 9O' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-12 9. Permit number/approval number 90-73/91-220 10. APl number 5_o-103-20131 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 6650' feet true vertical 6002' feet Junk (measured) Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3040' 9 5/8" Cemented 225 Sx AS I 700 Sx AS III & Measured depth 115' 3040' True vertical depth 115' 2950' Intermediate Production Liner Perforation depth: 6737' 7" measured 6344'-6354', true vertical 5774'-5780', Tubing (size, grade, and measured depth) 400 Sx Class G 350 Sx Class G & 210 Sx Class G Tail 6390'-6420', 6430'-6460' 5808'-5830', 5837'-5859' 6737' 6068' 13. Stimulation or cement squeeze summary Converted from Producing Well to Water Injection Well Intervals treated (measured) 3 1/2" 9.3#, EUE, ABMOD, IPC, Bottom @ 6222, & 2-7/8" L-80, 6.5#, IPC, w/tail @ 6261' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA ~ 1813'~ Packer: Baker Model 'D' @ 6225' Treatment description incl~ing volumes used and final pr~sure ~]~S~ 14. Rooresentative Daily Averace Producaon or In~ection Da~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 21 0 0 2 5 2 5 1 4 0 0 1 5 8 Subse¢ 0 - - 0 - 10034 975 2620 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector _X Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title SUBMIT IN DUPLICATE Re: ql--'/ o Well Name i.o~ 'lypc Run Date Kuparuk Kuparuk Kupamk Kuparuk Kupan~k Kupal'uk Kuparuk Kuparuk Kuparuk Kupamk Kuparuk Kuparuk Kuparuk K u.pal uk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk River Unit IA.Il River Unit 11.....10 ltivcr Unit 11..--14 River Unil IL-..17 Rive, 'U,fit 11;.22 River Unit lit 04 [fiver Unit 1Y--10 iiiver i~nil iV-ii River Unit 1Y-.12 River Unit 1Y...15 River tJnit 2B-08 River Unit 2C.O2 Rive, Unit 2(2-04 River Unit 2C 05 l-fiver Unil 2(74)6 i~iver llnit 2V-10 .River Unit 2V--13 River Unit 3G.- 12 River (init 3H.-O2 River Unit 3(3--20 Water i:iow l'.og (Ti')T-.P) Injection Profile Injection Profile Injection Prohle Injection Profile Injection P~'ofile Injection Profile Injection Profile lnjtx:tion Profile Injection Profile Injection Profile Injection .Profile Injection Profile Injectiou Profile Smw-ey Injection Profile Sumey Injection Profile Production i.og Production Log Injection Profile Injection Profile Survey Inicx:tion Profile 07.IAN 1991 10-.1...91 03 NOVEMBER1991 4 NOV EM BI£R 1991 tl N()VE.MI'IISR 1991 11 ,O6.-I 991 6/30/91 12-13.--.1991 l 1-19.-91 11..17--1991 12...2-91 12...27-.1991 26 .DEC 1991 10--27.-1991 11125/91 11...16.-1991 8--.llJlqK..-1991 31 -.JULY.- 1991 11 NOV 1991 101119191 11..-29--1991 Dated: Copy sent to ;;ender: Ve.$ ,// No ~~ RECEIVED MAR 2 6 1992 Alaska 011 & Gas Cons. Commission Anchorage STATE OF ALASKA Al, .(A OIL AND GAS CONSERVATION CO,¥,,,/IISSION ..... WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classirmation of Service Well OIL ~ GAS r~ SUSPENDED [~ ABANDONED F-] SERVICE r~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc i' 7.~;;; ;? ~.- 90-73 3 Address ~ ...... ,,, :.~'~-,r~ 8 APl Number P.O. Box 100360, Anchorage. AK 99510-0360 ? ~]/~'.2 , ~' 50-103-20131 At Top Producing Interval~~ ~~ 10 Well Number FSL, 1362' FWL, SEC 24, T12N, R8E, UM i ;~/~..~ ~_ 1770' At Total Depth i '~~ 1";1'" Field and Pool 1582' FSL, 1553' FWL, SEC 24, T12N~ R8E~ UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Deaignatien and Sm, iai No. KUPARUK RIVER OIL POOL RKB 89', PAD 53' GL ADL 25547~ ALK 2661 12 Date Spudded6/15/90. 13 Date T.D. Reached6/19/90. 14 DIte Comp., Sump. or Aband.3/04/91. I15 watm' Depth' if °ffsh°reNA feet MSL {16 No. of Completions1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Sun~ey 20 Depth where SSSV set 21 Thickness of permafrost 6749' MD, 6079' TVD 6650' MD, 6002' TVD YES~X~ NO D 1813' feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR/CN/S FD/DGR/CET/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo3'rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24- 220 SX ASI 9-5/8" 36# J-55 SURF 3040' 12-1/4' 700 SX AS II1~ 400 SX CLASS G 7" 26# J-55 SURF 6737' 8-1/2' 350 SX CLASS G~ 210 SX CLASS G TAIL 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2' 6261' 6225' 6430%6460' W/4-1/2" CSG GUN @ 4SPF MD 5837'-5859' TVD · 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PROOUCTION TEST Date First Production IMethed of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BIN. GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BIN. OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~. 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dip~ artd presence of oil, gas or water. Submit core chips. Form 10-407 Submit Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKE, FOP'~ ' ~X:3N TESTS ,, = -- Include interval tested, pressure data, all fluids recoverd and gravity, ., MEAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase. _ KUPARUK C TOP 6344' 5774' NA (UPARUK C Bo'FrOM 6352' 5779' <UPARUK A TOP 6376' 5797' <UPARUK A BO'i-rOM 6541' 5920' , ,,, 3-1~ LIsT oF ATTACHMENTS GYRO ..... , , ,, ' "' 3-2. '1 hereby Certify that'the foregoing is true and correct Jo'the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas Injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 6107191 3G-12 Frac KRU "A" sand perfs from 6430'-6460' 4SPF in 10 stages as follows: Stage 1. Pmp 135 bbls YF240 SX Gelled H20~ 25 bpm 5830-4020 psi Stage 2 Prnp ISIP: 65 bbls YF240 SX Gelled H20 Non XL GW@ 25 bpm 4020-3185 psi 1423 FracGrad: .68 Perf Fric: 0 Stage 3* Pmp 250 bbls YF240 XL Gel H20 @ 25 bpm 3200-3400psi Stage 4 Prop 69bbls YF240 XL Gel H20 w/2ppg 16/20 Carbolite @ 25 bpm 3400- 3200 psi Stage 5 Stage 6 Stage 7 Pmp 68 bbls YF240 XL Gel H20 w/4ppg 16/20 Carbolite @ 25 bpm 3200-3135 psi Prnp 71 bbls YF240 XL Gel H20 w/6ppg 16/20 Carbolite @ 25 bpm 3135- 3190 psi Pmp 80 bbis YF240 XL Gel H20 w/7ppg 16/20 Carbolite @ 25 bpm 3090-3120 psi Stage 8** Prop 76 bbls YF240 XL Gel H20 w/10ppg 16/20 Carbolite @ 25 bpm 3120-3410 psi Stage 9 Prnp 23 bbls YF240 XL Gel H20 w/12ppg 12/18 Carbolite @ 25 bpm 3410-3960 psi Stage 10 Prop 12 bbls YF240 XL Gel H20 Flush @ 25 bpm 3960-3970 psi Pmp 12 bbls YF240 Non-XL Flush~ 25 bpm 3960-3970 psi Pmp 34 bbls Slick Diesel Flush @ 25 bpm 3960-3970 psi *Shut down 58 bbls into pad to work on comptuer/pod communication. **Misprogrammed sand ramp: skipped 8 ppg stage: made up sand volume on 10 ppg stage. Average Pressure: 3300 psi Fluid to recover: 1361 bbls H20 & 34 Diesel Sand in zone: 94,089# 16/20 Carbolite & 9,022# 12/18 Carbolit( Sand in casing: 9788 12/18 Date ARCO ALASKA INC. ---~ DAILY OPERATIONS WELL: 3G-12 PAGE: 1 BOROUGH: NORTH SLOPE FIELD: KUPARUK RIVER FIELD UNIT: KUPARUK RIVER UNIT LEASE: ADL 25547 ALK 2661 API: 50-103-20131 PERMIT APPROVAL: 90-73 AFE: AK4982 WI: 55.252072 ACCEPT: 02/20/91 SPUD: RELEASE: 03/04/91 OPERATION: COMPLETION RIG: NORDIC 02/20/91 (8) TD: 0 PB: 6650 SUPV:GB/LA 02/21/91 (9) TD: 0 PB: 6650 SUPV:GB/LA 02/22/91 (10) TD: 0 PB: 6650 SUPV:GB/LA LAY DOWN 1-1/4" CIRC LINE 7"@ 6735' MW:10.9 NaC1 MOVE RIG FROM 3G-06 TO 3G-12, ND TREE AND NU BOP'S, PU LANDING JOINT AND BOLDS, PU TUBING HNGR DAILY:S116,282 CUM:$784,546 ETD:S784,546 EFC:$1,200,000 WAITING ON SPOOL TO Nil BOP 7"@ 6735' MW:10.9 NaC1 SERVICE RIG, LD TBG HNGR, CIRC WARM DIESEL, PULL 1-1/4" TBG, TUBING DRAGGING EVERY MIDDLE JOINT, SET TEST PLUG AND TEST BOPE, PULL TEST PLUG AND SET WEAR BUSHING, MU TRI-STATE FTA #1, RIH ON 3-1/2" DP, TAG SOLID AT 443', POH, MARKS ON GUIDE SHOE 180 DEG APART, MU 1 JT 3-1/2" TUBING AND RIH ON 3-1/2" DP, TAG SOLID AT 443', POH, BOTTOM OF 3-1/2" TBG PINCHED IN TO 2-1/2", CONFIFMS COLLAPSED 7" CSG, RACK AND TALLY 59 JTS ' OF 1-1/4" HYDRIL TBG, RIH AND CIRC OUT DIESEL WITH 10.9 PPG BRINE AT 443', POH, ND BOP STACK, ND TUBING HEAD, PULL PACKOFF, INSTALL KEEPER PIN IN SLIPS, NU ADAPTER FLANGE AND SET BOP, NOT ENOUGH EXTENSION IN RISER TO MATE UP WITH FLOW LINE, ORDER 11" SPOOL FROM WAREHOUSE DAILY:S37,737 CUM:$822,283 ETD:S822,283 EFC:$1,200,000 PULL CUT 7" CSG 7"@ 6735' MW:10.9 NaC1 SERVICE RIG, NU 11" 3KSI SPOOL & 11" 5KSI BOPE & TEST, MU TRI-STATE CSG CUTTER W/KNIFE TRAVEL TO 7.5" OD, RIH, PU & SERVICE KELLY, TAG COLLAPSED CSG @ 443', CIRC DIESEL OUT OF 7" CSG, PU & CUT 7" CSG @ 437', BLOW DOWN & STAND BACK KELLY POH W/CUTTER, RIH W/7" SPEAR, SPEAR CSG & PU TO 90K#, WORK CSG, WON'T PULL FREE, RELEASE & LD SPEAR, RIH W/OE-DP TO 441', CIRC WARM BRINE-90DEG IN 80 DEG OUT, POH, PU SPEAR & PO, SPEAR CSG & BREAK CIRC TO CIRC THRU CUT, NO CIRC, WORKED CSG, NO MOVEMENT, CSG NOT CUT, RELEASE & LD SPEAR, MU TRI-STATE CUTTER, REMOVED STOP SO KNIVES TRAVEL TO 8" OD, RIH, RECUT CSG @ 437', BLOW DOWN & STAND BACK KELLY, POH W/CUTTER, PU SPEAR, RIH & SPEAR 7" CSG & PULL 18' ABOVE FLOOR, CSG SLIPS SLID DOWN JOINT TO FIRST COLLAR BUT WON'T PULL THRU 11" SPOOL, SET CSG ON ROTARY SLIPS, RU SLINGS TO BOP STACK & UNBOLT, CUT OFF 13' OF 7" ABOVE FLOOR, SET SAFETY CLAMP ON 7" & LATCH SLIP TYPE ELEVATORS, RAISE BOP STACK & 7" CSG & REMOVE 7" CSG FROM BOWL, SET 7" ON ROTARY SLIPS & SET STACK DOWN & REBOLT, MU CIRC HEAD & CIRC MUD OUT OF 7" X 9-5/8" ANN, POH & LD 7" CSG, RECOVERED TOP JT & 8 FULL JOINTS + 20.5' CUTOFF PIECE, UNLOAD 7" FROM SHED DAILY:S34,554 CUM:$856,837 ETD:S856,837 EFC:$1,200,000 ARCO ALASKA INC. DAILY OPERATIONS WELL: 3G- 12 OPERATION: COMPLETION RIG: NORDIC 02/23/91 (11) TD: 0 PB: 6650 SUPV:GB/LA RIH W/ 7" SPEAR 7"@ 6735' MW:10.9 NaCl UNLOAD 7" CSG FROM PIPE SHED, MU 7" SPEAR AND RIH AND SPEAR 7" CSG AT 438', BACKOFF 7" CSG, POH W/ 25' CUT OFF JT, MU FTA #8 (ROLLING DOG OVERSHOT) AND RIH AND WASH DOWN TO 528', LATCH 1-1/4" HYDRIL TUBING FISH AT 541' AND POH W/ FISH, RIH WITH FTA #9, TAG BP AT 2192', CIRC, CONTINUED TO CIRC UNTIL 55 DEG RETURNS, POH, MU 7" SPEAR AND RIH DAILY:S56,916 CUM:$913,753 ETD:S913,753 EFC:$1,200,000 02/24/91 (12) TD: 0 PB: 6650 SUPV:GB/LA PREP TO FIRE BACKOFF AT 1211' 7"@ 6735' MW:10.9 NaC1 SERVICE RIG, SPEAR 7" AT 817' AND BACKOFF 2 JTS, RIH AND SPEAR CASING AT 904' AND BACKOFF 1 JT, RIH AND SPEAR CASING AT 948' AND BACKOFF 2 JTS, RIH AND SPEAR CASING AT 1035' AND BACKOFF 1 JT, RU HLS AND SPRS FREEPOINT TOOLS, RIH TO 1700', SPEAR CASING AT 1079', 7" STUCK AT 1681' - VERY LITTLE MOVEMENT AT 1440' AND 1289', MOSTLY FREE AT 1189', POH WITH DP AND E-LINE, SPEAR CSG AT 1079' AND MU BACKOFF SHOT ON E-LINE, RIH AND SPOT SHOT 3 JTS BELOW SPEAR, PREP TO BACKOFF 7" DAILY:S28,147 CUM:$941,900 ETD:S941,900 EFC:$1,200,000 02/25/91 (13) TD: 0 PB: 6650 SUPV:GB/LA POH 7"@ 6735' MW:10.9 NaCl PUT LH TORQUE IN DP, FIRE SHOT AT 1211' AND BACKOFF 7" 10 TURNS, POH W E-LINE, RECOVERD 1 JT OF 7" CSG, RIH W/ OPEN ENDED DP AND TAG BP, CIRC AND WARM HOLE, BRINE IS 110 DEG OUT, RIH AND SITH SPEAR AND BACKOFF CSG, RECOVERED 1 JT OF CSG, RIH AND SPEAR 7" AND BACKOFF AT 1215', RIH AND SPEAR 7" AT 1215', BACKOFF 1 JT OF CSG, RIH AND SPEAR 7" AT 1254' BACKOFF AND PREP TO POH DAILY:S41,817 CUM:$983,717 ETD:S983,717 EFC:$1,200,000 02/26/91 (14) TD: 0 PB: 6650 SUPV:GB/LA 02/27/91 (15) TD: 0 PB: 6650 SUPV:GB/LA POH W/ FTA #12 7"@ 6735' MW:10.7 NaC1 SERVICE RIG, TEST BOP, POH W/ FTA #12 (RECOVERED 1 JT OF CSG), TOP OF 7" AT 1298', RIH WITH SPEAR TO 7" AND BACKOFF CSG, RECOVERD ONE JT DOWN TO 1342', RIH W/ SPEAR TO 7" AND BACKOFF CSG, RECOVERD ONE JT DOWN TO 1386', RIH W/ SPEAR TO 7" CSG AND BREAK CIRC, RECOVERED ON JT DOWN TO 1430', CIRCULATING BROUGHT UP MUD/SAND/CMT IN RETURNS, RIH W/ SPEAR AND BACKOFF CSG, RECOVERD ONE JT CSG DOWN TO 1475', RIH W/ SPEAR AND BACKOFF CSG, APPEAR TO BACKOFFED TOOL JT, POH, FOUND SPEAR ASSEMBLY BACKED PFF AT BOTTOM OF BUMPER SUB, RIH AND RECOVER, POH, RIH AND AND CHECK TORQUE ON ALL CONNECTIONS, RIH TO 7" CSG AND SPEAR, RECOVER ONE JOINT, TIGHT JOINT (BROKE AT 11,000 FT-LBS) DAILY:S28,147 CUM:$1,011,864 ETD:S1,011,864 EFC:$1,200,00 RUNNING 7" 7"@ 6735' MW:10.7 NaCl SERVICE RIG, FINISH POH W/ 7" CSG JOINT, TOP OF 7" AT 1521', RIH AND ATTEMPT TO BACKOFF 7" AGIAN, NO GO AT 11,000 FT-LBS, POH, RIH AND WASH DOWN TO TOP OF 7" AT 1521', REVERSE CIRC HOLE CLEAN, POH, RU FLOOR TO RUN 7", RUN 7" CSG WITH TRI-STATE SKIRTED SCREW IN ASSEMBLY ON BOTTOM OF BAKER ECL PAKCER ON BTM JOINT DAILY:S66,367 CUM:$1,078,231 ETD:S1,078,231 EFC:$1,200,000 RECEIVED Gas Cons, ~chorage PAGE: 2 WELL: 3G- 12 OPERATION: COMPLETION RIG: NORDIC 02/28/91 (16) TD: 0 PB: 6650 SUPV:GB/LA REVERSE ClRC AT ClBP 7"@ 6735' MW:10.6 NaCl/Br SERVICE RIG, FINSIH RUNNING 7" CSG, REVERSE CIRC DIESEL FOLLOWED BY ARCTIC PACK DISPLACING BRINE, SCREW INTO 7", TEST 7" TO 1000 PSI FOR 15 MIN, PRESS UP TO SET ECL PACKER, TEST 7" TO 2500 PSI FOR 30 MIN, TEST 7"X9-5/8" ANNULUS TO 1500 PSI, ND AND RAISE BOP, CENTER CASING AND SET SLIPS, CUT OFF 7" CSG, ND ADAPTER AND NU WKM GEN IV TUBING HEAD, TEST, NU BOP AND TEST, RIH W/ 6-1/8" BIT AND CIRC OUT DIESEL AND ARCTIC PACK DISPLACING W/ BRINE, RIH TO CIBP AND WEIGHT UP BRINE TO 10.9 PPG DAILY:S83,548 CUM:$1,161,779 ETD:S1,161,779 EFC:$1,200,00 PAGE: 3 03/01/91 (17) TD: 0 PB: 6650 SUPV:GB/LA 03/02/91 (18) TD: 0 PB: 6650 SUPV:DB/LA 03/03/91 (19) TD: 0 PB: 6650 SUPV:DB/LA WO HOWCO CSG PATCH TO CURE 7"@ 6735' MW:10.9 NaC1/Br FIN REV CIRC, WEIGHT UP BRINE TO 10.9 PPG, 2.5 BPM 400 PSI, CIBP @ 2192', POH W/BHA #3, LD BIT & SCRAPPER, MU 20' HOWCO CSG PATCH ON HYDRAULIC SETTING TOOL, COAT FIBERGLASS SLEEVE ON OUTSIDE OF 1/8" THICK STEEL PATCH W/EPOXY RESIN, RIH W/PATCH & TOOL ON 3-1/2" DP, SPOT PATCH ON DEPTH, PU & SO = 30K#, PRESS UP TO 3000 PSI, SAW SETTING TOOL STROKE FIRST 5' @ 1300 PSI, HOLD 3000 PSI FOR 5 MIN, PU ON DP & PULL CONE & COLLET THRU PATCH IRONING OUT LAST 15' OF PATCH, FREE TRAVEL FIRST 5' AS PISTON ROD PULLED OPEN, PULLED 20K# TO 22K# OVER LAST 15' EXPANDING PATCH INTO 7" CSG, PULLED FREE AS CONE & COLLET CAME OUT OF TOP OF PATCH, PATCH SET @ 13:30 2/28/91, PATCH RESTRICTS DRIFT/ID OF 7" BY 0.300", ID=5.976, DRIFT-5.851, CIBP@ 2200'WL=2192'NORDIC, PERFS@ 2160'-2165' WL=2152'-2157'NORDIC, 20' HOWCO PATCH @ 2152.5'-2172.5'WL=2144.5'-2164.5'NORD, POH LD HOMCO SETTING TOOLS, WAIT 24 HRS FOR EPOXY TO CURE, RACK, TALLY, DRIFT, & INSTALL SEAL RINGS IN 3-1/2" TBG & JEWELRY, SERVICE RIG DAILY:S44,289 CUM:$1,206,068 ETD:S1,206,068 EFC:$1,200,000 PERFORATING 7"@ 6735' MW:10.8 NaCl/Br WO EPOXY TO CURE ON HOMCO CSG PATCH, RIG MAINT & CLEANING, RIH W/BHA #4, EASE MILL THRU PATCH-NO OBSTRUCTIONS, TAG CIBP @ 2192', TEST 7" CSG & PATCH TO 3000 PSI FOR 30 MIN, LOST 100 PSI-OK, MILL OUT CIBP @ 2192', BLOW DOWN & STAND BACK KELLY, RIH & TAG BOTTOM @ 6608', BREAK CIRC & SET 20K# DOWN, SOLID BOTTOM @ 6608' NORDIC, 6618' DOYON 14 RKB, TEST 7" CSG TO 3000 PSI FOR 15 MIN, LOST 50 PSI-OK, REV CIRC & FILTER BRINE, POH LD MILL, PULL WEAR BUSHING, ND FLOW NIPPLE, RU HLS, MU GUN #1 USING BOW SPRING FOR ORIENTATION & PREP TO RIH. DAILY:S31,861 CUM:$1,237,929 ETD:S1,237,929 EFC:$1,200,000 RIH W/ CAT STANDING VALVE 7"@ 6735' MW:10.9 NaCl/Br RIH TO PERF, PERF F/6460'-6430' W/4-1/2" CSG GUNS @ 4 SPF 180 DEG ORIENT W/ BELLY SPRING DECENTRALIZER & HLS NAY TOOLS ALTERNATING 36 GM DP & 30 GM BP SHOTS THREE RUNS (ONE RUN MISFIRE), USED BELLY SPRING TO FIT THRU PATCH-ROLLER SYSTEM TO TIGHT, RIH W/5.8" GR & JB TO 6400', SLIGHT TAG AT TOP OF 7" CSG PATCH, LIGHT PULL IN SAME AREA POH, RD HLS, RU FLOW NIPPLE, LD KELLY & RAT HOLE, RU TO RUN TBG, MU 2-7/8" TAILPIPE & TIW 3-1/2" PBR/2-7/8"X7" HM-1 RET PKR, REPIN PKR FOR 1626 PSI SETTING PRES & PBR FOR 32,800 # SHEAR PULL, RIH W/COMP ASSY, MU HGR & DROP BALL, TESTED CL TO 5000PSI WHEN MU TO SSSV & HGR, LAND HGR, RILDS, RU CIRC LINES, PRESS UP TO SET PKR, SOMETHING SHEARED .(PBR OR SHEAR OUT SUB) @ 1000PSI FOR 5 SEC & CAN CIRC STRING, RU HLS & RIH W/2.250" CAT STANDING VALVE, RAN 2.250" SV TO 6380', BOTTOM OF 2-7/8" TAIL HAD BEEN @ 6266', 2.281" NOGO ON SV WOULD NOT PASS 2.250" D-NIPPLE IF IT WERE THERE, APPARENTLY SHEARED PBR, PREP TO POH W/TBG. DAILY:S47,624 CUM:$1,285,553 ETD:S1,285,553 EFC:$1,200,000, WELL: 3G- 12 OPERATION: COMPLETION RIG: NORDIC 03/04/91 (20) TD: 0 PB: 6650 SUPV:DB/LA RIH W/3-1/2" COMP ASSY 7"@ 6735' MW:10.8 NaCl/Br CONT RIH W/2.25" CAT STANDING VALVE (2.281" NOGO ON SV) ON SLICKLINE TO 6380' SLM, D NIPPLE HAD BEEN @ 6380', POH, SAW BUMP RE-ENTERING SEAL ASSY, APPEARS PBR SHEARED & SHOT PKR DWN HOLE, RD OTIS, NU FLOW NIPPLE, BOLDS, LD HGR, POH W/3-1/2" COMP ASSY, STAND BACK TBG, LD JEWELRY, RAN & RECOVERED 35 SS BANDS ON CL, CHANGE SEAL RINGS & DRIFT TBG WHILE POH, LD TIW PBR STINGER, RU SPINNER, INSTALL WEAR BUSHING, MU FTA #13, RIH, SPEAR INTO TIW PBR BARREL TO 6574' TOF @ 6568', TAIL SETTING ON BOTTOM @ 6608' NORDIC RKB, PU ON FISH. SLIGHT TUG OFF BOTTOM, FISH FREE, POH W/FTA #13, RECOVERED ALL OF FISH, RD FLOW NIPPLE, PULL WEAR BUSHING, RU HLS, MU BAKER MODEL 'D' PKR W/10' SEAL BORE EXTENSION ON WL & RIH, TIE-IN EWR LOG 6/19/90 & PET 7/6/90, SET PKR @ 6225' WLM, BOTTOM OF TAIL @ 6261', WLM, POH, RD HLS, RU TO RUN TBG MU BAKER SEAL ASSY, RIH W/3-1/2 COMP ASSY DAILY:S45,204 CUM:$1,330,757 ETD:S1,330,757 EFC:$1,200,00 PAGE: 4 03/05/91 (21) TD: 0 PB: 6650 SUPV:DB/LA RIG RELEASED 7"@ 6735' MW:10.8 NaCl/Br SERVICE RIG, FINISH RUNNING 3-1/2" COMP ASSY, TEST TUBING TO 2500 PSI, TEST SSV, SET BPV AND ND BOPE, NU WKM GEN IV TREE, PULL BPV, TEST TREE, TEST ANNULUS TO 2500 PSI, DISPLACE 450' OF WELL WITH DIESEL, RELEASE RIG DAILY:S140,946 CUM:$1,471,703 ETD:S1,471,703 EFC:$1,200,000 SIGNATURE: DATE: I. DA$1$ OF lOCATION ANO ~L~VA?ION 18 D.$, MONUMRNTAT/ON P~R LOUN$~UNF ~ R. ffLRVA~"ION9 SROWN ARR B. RM.$.L. VIClNIFY M& I"= ~ 'MI. 0 L a r. LO ?0~ ~R' 4?,gRR" ' 1~0~00'$9.655" /50000,~0.£65. 1~0~00'40,990' 160~0'4~. 460" 160~00'~$. I~/ " I~0~0'~$. 9/$" I ~0~00~ 4 ?, ~ ~ " NO. 1' I S $,980, 6e0.54 490, R34. · 0 $,900, $~0.00 RI $,~00, $00.$$ R~ 6,900, $00.6~ F,N.L. g$30 '"' · ,°636'"' ?0' ."$36'*'"' I45' 4?.£ ~$. ! 47. I 46.9 ~$. I 46.8 ~$.0 46,~ $~.9 48.5 $3. 0 46,4 ~.9 SURVE¥OR~ C~NTIFI I HEREBY CERTIFY THAT ! AM ~ffOISrffRffO ~NO LIC~NSffO ~ ~RACrlC~ ~NO SUAVffrlN; IN rH~ $VAT~ O~ ALASKA AND ~AT rNl$ PLAT N~PRff$~N~ ( ~ r~r ALL 01~N$1~$ AND O~H~R ~r&lLS ARE ~R~T aS OF ~lL R~, 1990. ARCO ALASKA,/NC. OW~. NO. ' NSDK. 3~00. CRA. 03 OR/L/. $17'£ CONDUCTORS AS Or, Il/. ?' LOCATION C#.by.'E,~.M. / o~ / O~.'~-t$.~O10w~. No..'N$~ ~ ~O?dO Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77224 713/461-3146 Fax: 713/461-0920 August 13.1990 Mr. Steve Edwards ARCO.Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 3G-12 (24-12-8) North Slope Borough, Alaska Dear Mr. Edwards: Enclosed please find one (1) original and nine (9) copies the survey addendum to KRU 3G-12 (24-12-8). Please let me know if I can provide further assistance. A 1 Kudr 1 e Representative Enclosures of AnChot~ag~ ,- - Gyrodata Services, Inc. Houston, TX / Lafayette, LA / New Orleans, LA/Ventura, CA / Aberdeen, U.K. / Calgary, Alberta Anchorage, AK / Kuantan, Malaysia / Buenos Aires, Argentina / Bergen, Norway GREAT LAND DIRECTIONAL DRILLING, Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-12 (24-12-8) Section at: S,50.73,E Surveyor..: BOBBY BIRSS S MEAS INCLN C DEPTH ANGLE 7 100 0.11 7 200 0.13 7 300 0.20 7 400 0.27 7 500 0.23 VERTICAL-DEPTHS BKB SUB-SEA INC. SECTION DISTNCE 100.0 11.0 -0.1 200.0 111.0 -0.1 300.0 211.0 -0.2 400.0 311.0 -0.3 500.0 411.0 -0.6 7 600 0.26 600.0 511.0 7 700 0.25 700.0 611.0 7 800 0.20 800.0 711.0 7~ 900 0.38 900.0 811.0 7 1000 0.46 1000.0 911.0 7 1100 0.28 1100.0 1011.0 7 1200 0.33 1200.0 1111.0 7 1300 0.33 1300.0 1211.0 7 1400 0.37 1400.0 1311.0 7 1500 0.39 1500.0 1411.0 7 1600 0.38 1600.0 1511.0 7 1700 0.23 1700.0 1611.0 7 1800 0.50 1800.0 1711.0 7 1900 0.63 1900.0 1811.0 7 2000 0.76 2000.0 1911.0 7 2100 1.24 2099.9 2010.9 for Gyrodata Services, RECORD OF SURVEY Inc. Computation...: Survey Date...: RKB Elevation.: API Number .... : Job Number .... : os/ o?9o RADIUS OF CURVATURE 07/06/90 89.00 ft 50-103-20131 AK0790G234 ~Survey Codes: 7/GYRO -0.8 -1.1 -1.4 -1.4 -1.1 -0.6 -0.1 0.4 1.0 1.7 2.3 2.6 2.4 1.7 0.8 -0.1 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD S 39.73 W 0.0 N S 54.24 W 0.1 S S 58.72 W 0.3 S S 64.35 W 0.5 S S 78.39 W 0.6 S S 78.69 W 0.7 S S 80.71 W 0.8 S S 67.67 W 0.9 S S 20.48 W 1.2 S S 7.88 W 1.9 S S 26.87 E 2.6 S S 35.92 E 3.0 S S 33.15 E 3.5 S S 36.83 E 4.0 S S 40.06 E 4.5 S S 30.47 E 5.1 S S 31.49 W 5.6 S S 89.42 W 5.9 S S 88.85 W 5.9 S S 75.86 W 6.1 S S 66.43 W 6.6 S 0.1 W 0.2 W 0.5W 0.8 W 1.2 W 1.7 W 2.1 W 2.5 W 2.8 W 3.0 W 2.9 W 2.6 W 2.3 W 1.9 W 1.5 W 1.1 W 1.1 W 1.7 W 2.7 W 3.9 W 5.5W CLOSURE DL DISTNCE BEARING /100 0.1 N 70.14 W 0.11 0.3 S 62.13 W 0.02 0.5 S 59.11 W 0.07 0.9 S 60.16 W 0.07 1.4 S 63.68 W 0.04 1.8 S 67.18 W 0.03 2.2 S 69.66 W 0.01 2.6 S 70.34 W 0.05 3.1 S 66.27 W 0.18 3.6 S 56.96 W 0.08 3.9 S 48.29 W 0.18 4.0 S 40.76 W 0.05 4.2 S 33.10 W 0.00 4.4 S 25.77 W 0.04 4.8 S 18.58 W 0.02 5.2 S 12.59 W 0.01 5.7 S 11.52 W 0.15 6.1 S 15.84 W 0.27 6.5 S 24.25 W 0.13 7.2 S 32.48 W 0.13 8.6 S 39.75 W 0.48 (KRU3G12) KRU 3G-1 2 S MEAS C DEPTH 7 2200 7 2300 7 2400 7 2500 7 2600 INCLN ANGLE VERTICAL-DEPTHS BKB SUB-SEA 1.56 2199.9 2110.9 1.74 2299.9 2210.9 1.52 2399.8 2310.8 1.42 2499.8 2410.8 1.37 2599.8 2510.8 SECTION DISTNCE -1.3 -2.8 -4.2 -5.5 -6.9 7 2700 1.37 2699.7 2610.7 -8.4 7 2800 1.18 2799.7 2710.7 -9.8 7 2900 1.06 2899.7 2810.7 -10.9 7 3000 1.15 2999.7 2910.7 -12.0 7 3100 1.28 3099.7 3010.7 -13.1 7 3200 1.00 3199.6 3110.6 -14.1 7 3300 1.70 3299.6 3210.6 -13.0 7 3400 4.63 3399.4 3310.4 -7.6 7 3500 7.17 3498.9 3409.9 2.5 7 3600 9.81 3597.8 3508.8 17.0 7 3700 12.01 3696.0 3607.0 7 3800 14.51 3793.3 3704.3 7 3900 17,02 3889.5 3800.5 7 4000 19.57 3984.5 3895.5 7 4100 22.20 4077.9 3988.9 RECORD OF SURVEY 35.7 58.4 85.2 116.2 151,6 7 4200 25.16 4169.5 4080.5 191.7 7 4300 28.17 4258.8 4169.8 236.5 7 4400 31.24 4345.7 4256.7 286.1 7 4500 33.66 4430.1 4341.1 339.7 7 4600 36.30 4512.0 4423.0 397.0 DIRECTION BEARING S 69.97 W S 71.38 W S 68.60 W S 72.81 W S 75.27 W RELATIVE-COORDINATES FROM-WELL-HEAD Page 2 CLOSURE DISTNCE 7.5 S 7,8 W 10.8 8.5 S 10.5 W 13.5 9.4 S 13.2 W 16.2 10.3 S 15,6 W 18.7 11,0 S 17.9 W 21.0 77.99 W 11.5 S 20.2 W 23,3 76.58 W 12.0 S 22.4 W 25.4 74.16 W 12.5 S 24.3 W 27.3 72.08 W 13.1 S 26.2 W 29.2 71.06 W 13.7 S 28.2 W 31.3 S 64.69 W 14.5 S 30.0 W 33.3 S 48.52 E 16.5 S 30.3 W 34.5 S 64.01 E 19.5 S 25.7 W 32.3 S 62.08 E 24.2 S 16.5 W 29.3 S 60.42 E 31.3 S 3.6 W 31.5 S 59.26 E S 59.23 E S 60.12 E S 58,89 E S 56.51 E 40.8 S 12.8 E 42.7 52.5 S 32.5 E 61.7 66.2 S 55.9 E 86.7 82.1 S 83.0 E 116.8 101.2 S 113.1 E 151.8 S 52.01 E 124.6 S 145.7 E 191.7 S 50.51 E 152.7 S 180.7 E 236.6 S 50.08 E 184.4 S 218.8 E 286.1 S 49.14 E 219.1 S 259.7 E 339.8 S 47.74 E 257.2 S 302.6 E 397.1 7 4700 39.21 4591.0 4502.0 458.1 S 46.86 E 298.7 S 347.5 E 458.3 o /lo'/9o DL BEARING /100 S 45.93 W 0.32 S 51.06 W 0.18 S 54.32 W 0.2~ S 56.54 W 0.10 S 58.54 W 0.05 S 60.37 W 0.00 S 61,83 W 0,19 S 62.78 W 0.12 S 63.46 W 0.09 S 64.01 W 0.13 S 64.24 W 0.28 S 61.49 W 0.71 S 52.81 W 2.93 S 34.40 W 2.54 S 6.58 W 2.64 S 17.37 E 2.20 S 31.73 E 2.5C S 40.18 E 2.51 S 45.28 E 2.55 S 48.18 E 2.65 S 49.45 E 3.07 S 49.79 E 3.03 S 49,88 E 3.07 S 49.84 E 2.44 S 49.64 E 2.69 S 49.32 E 2.93 'Survey Codes: 7/GYR0 KRU 3G-12 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 4800 42.44 7 4900 44.07 7 5000 45.28 7 5100 47.08 7 5200 46.86 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 4666.7 4577.7 523.4 4739.5 4650.5 591.9 4810.6 4721.6 662.2 4879.9 4790.9 734.4 4948.1 4859.1 807.5 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD 49.14 E 342.4 S 396.1 E 50.27 E 386.7 S 448.4 E 51.48 E 431.1 S 502.9 E 50.94 E 476.3 S 559.2 E 51.46 E 522.1 S 616.1 E 7 5300 46.16 5016.9 4927.9 880.0 7 5400 45.56 5086.6 4997.6 951.7 7 5500 44.76 5157.1 5068.1 1022.5 7 5600 44.31 5228.4 5139.4 1092.4 7 5700 43.91 5300.2 5211.2 1161.8 52.33 E 566.9 S 673.2 E 53.46 E 610.2 S 730.4 E 54.63 E 6.51.8 S 787.8 E 55.31 E 692.1 S 845.3 E 55.87 E 731.4 S 902.7 E 7 5800 43.41 5372.5 5283.5 1230.5 7 5900 43.07 5445.4 5356.4 1298.6 7 6000 42.46 5518.8 5429.8 1366.1 7 6100 42.10 5592.8 5503.8 1432.8 7 6200 42.03 5667.0 5578.0 1499.3 S 56.46 E 769.8 S 960.0 E S 57.11 E 807.4 S 1017.4 E S 57.73 E 843.9 S 1074.6 E S 58.10 E 879.7 S 1131.6 E S 57.93 E 915.1 S 1188.4 E 7 6300 42.44 5741.0 5652.0 1566.3 7 6400 42.40 5814.9 5725.9 1633.7 7 6500 41.97 5889.0 5800.0 1700.8 7 6600 40.68 5964.1 5875.1 1766.4 X 6749 40.68 6077.1 5988.1 1862.6 S 52.58 E S 48.02 E S 47.41 E S 42.55 E S 42.55 E 953.4 S 1243.6 E 996.5 S 1295.5 E 1041.7 S 1345.2 E 1088.4 S 1391.8 E 1159.9 S 1457.5 E ASurvey Codes: 7/GYRO X/EXTRAPOLATED Page 3 08/10/90 CLOSURE DISTNCE BEARING 523.6 S 49.16 E 592.1 S 49.22 E 662.4 S 49.40 E 734.5 S 49.57 E 807.6 S 49.72 E 880.1 S 49.90 E 951.8 S 50.13 E 1022.5 S 50.40 E 1092..4 S 50.69 E 1161.8 S 50.98 E 1230.6 S 51.27 E 1298.8 S 51.56 E 1366.3 S 51.86 E 1233.3 S 52.14 E 1499.9 S 52.40 E 1567.0 S 52.52 E 1634.4 S 52.43 E 1701.4 S 52.25 E 1766.9 S 51.98 E 1862.7 S 51.49 E DL /lOO 3.39 1.72 1.3¢ 1.82 0.35 0.83 0.83 0.99 0.56 0.48 0.57 0.46 0.67 0.40 0.10 2.47 2.0~ 0.51 2.43 0.00 KRU 3G-12 Page 4 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 08/10/90 SUBSEA NEAS INCLN DEPTH DEPTH ANGLE TVD BKB 0 89 0.10 89 100 189 0.13 189 200 289 0.19 289 300 389 0.26 389 400 489 0.23 489 500 589 0.26 589 600 689 0.25 689 700 789 0.21 789 800 889 0.36 889 900 989 0.45 989 1000 1089 0.30 1089 1100 1189 0.32 1189 1200 1289 0.33 1289 1300 1389 0.37 1389 1400 1489 0.39 1489 1500 1589 0.38 1589 1600 1689 0.25 1689 1700 1789 0.47 1789 1800 1889 0.62 1889 1900 1989 0.75 1989 2000 2089 1.19 2089 2100 2189 1.53 2189 2200 2289 1.72 2289 2300 2389 1.54 2389 2400 2489 1.43 2489 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 0 0 S 39.73 W 0.06 S 0.05 W 0 0 S 52.64 W 0.10 S 0.20 W 0 0 S 58.23 W 0.26 S 0.43 W 0 0 S 63.73 W 0.45 S 0.78 W 0 0 S 76.85 W 0.60 S 1.19 W 0 0 S 78.66 W 0.69 S 1.61 W 0 0 S 80.49 W 0.77 S 2.04 W 0 0 S 69.10 W 0.87 S 2.43 W 0 0 S 25.67 W 1.17 S 2.78 W 0 0 S 9.26 W 1.86 S 2.98 W 0 0 S 23.05 E 2.52 S 2.91 W 0 0 S 34.93 E 2.97 S 2.64 W 0 0 S 33.45 E 3.45 S 2.32 W 0 0 S 36.43 E 3.94 S 1.97 W 0 0 S 39.71 E 4.46 S 1.57 W 0 0 S 31.52 E 5.00 S 1.17 W 0 0 S 24.69 W 5.54 S 1.11 W 0 0 S 83.06 W 5.86 S 1.58 W 0 0 S 88.91 W 5.89 S 2.53 W 0 0 S 77.28 W 6.02 S 3.71 W 0 0 S 67.46 W 6.5'3 S 5.29 W 0 0 S 69.58 W 7.42 S 7.50 W 0 0 S 71.23 W 8.37 S 10.18 W 0 0 S 68.90 W 9.34 S 12.89 W 0 0 S 72.36 W 10.22 S 15.32 W 2500 2589 1.38 2589 0 0 S 75.00 W 10.90 S 17.67 W KRU 3G-1 2 Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 5 08/10/90 SUBSEA DEPTH 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 ~EAS DEPTH 2689 2789 2889 2989 3089 3189 3289 3390 3490 3591 3693 3796 3899 4005 4112 4222 4334 4451 4572 4697 4830 4969 5113 5260 5403 INCLN TVD MD-TVD VERT DIRECTION ANGLE BKB DIFF CRRT BEARING 1.37 2689 0 0 S 77.70 W 1.20 2789 0 0 S 76.73 W 1.07 2889 0 0 S 74.42 W 1.14 2989 0 0 S 72.30 W 1.27 3089 0 0 S 71.17 W 1.03 3189 0 0 S 65.37 W 1.63 3289 0 0 S 36.50 E 4.32 3389 1 0 S 62.39 E 6.92 3489 1 0 S 62.27 E 9.57 3589 2 1 S 60.57 E 11.85 3689 4 2 S 59.34 E 14.40 3789 7 3 S 59.23 E 17.01 3889 10 4 S 60.11 E 19.70 3989 16 5 S 58.78 E 22.56 4089 23 7 S 55.97 E 25.81 4189 33 10 S 51.69 E 29.23 4289 45 13 S 50.36 E 32.47 4389 62 17 S 49.60 E 35.55 4489 83 21 S 48.14 E 39.13 4589 108 26 S 46.88 E 42.93 4689 141 33 S 49.48 E 44.91 4789 180 39 S 51.11 E 47.05 4889 224 44 S 51.01 E 46.44 4989 271 46 S 51.98 E 45.53 5089 314 44 S 53.50 E RELATIVE COORDINATES FROM WELL HEAD 11.46 S 20.00 W 11.96 S 22.20 W 12.45 S 24.12 W 13.00 S 25.95 W 13.66 S 27.94 W 14.40 S 29.84 W 16.22 S 30.44 W 19.11 S 26.42 W 23.60 S 17.63 W 30.53 S 4.92 W 40.02 S 11.48 E 51.93 S 31.51 E 66.14 S 55.77 E 82.98 S 84.34 E 103.73 S 116.89 E 130.39 S 152.99 E 163.24 S 193.41 E 201.74 S 239.37 E 246.02 S 290.18 E 297.55 S 346.33 E 355.83 S 411.71 E 417.52 S 485.98 E 482.48 S 566.77 E 548.94 S 650.12 E 611.64 S 732.43 E 5100 5545 44.56 5189 356 41 S 54.94 E 669.98 S 813.60 E KRU 3G-12 Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL O8/lO/9O SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5200 5684 43.97 5289 5300 5823 43.33 5389 5400 5960 42.71 5489 5500 6095 42.12 5589 5600 6230 42.15 5689 5700 6365 42.41 5789 5800 6500 41.97 5889 5900 6633 40.68 5989 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 395 40 S 55.78 E 725.34 S 893.79 E 434 38 S 56.61 E 778.42 S 973.03 E 471 37 S 57.48 E 829.26 S 1051.46 E 506 35 S 58.08 E 877.85 S 1128.68 E 541 35 S 56.34 E 925.92 S 1205.08 E 576 35 S 49.62 E 980.96 S 1277.71 E 611 35 S 47.41 E 1041.72 S 1345.19 E 644 33 S 42.55 E 1104.18 S 1406.33 E KRU 3G-12 Page 7 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 08/10/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING DL/ 100 1000 0.46 1000 911 2000 0.76 2000 1911 3000 1.15 3000 2911 4000 19.57 3984 3895 5000 45.28 4811 4722 -1 S 7.88 W 1 S 75.86 W -12 S 72.08 W 116 S 58.89 E 662 S 51.48 E 2 S 3 W 6 S 4 W 13 S 26 W 82 S 83 E 431 S 503 E 4 S 56.96 W 0.1 7 S 32.48 W 0.1 29 S 63.46 W 0.1 117 S' 45.28 E 2.6 662 S 49.40 E 1.4 6000 42.46 5519 5430 1366 S 57.73 E 844 S 1075 E 1366 S 51.86 E 0.7 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. O8/lO/9O Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-12 Section at: S,50.73,E Surveyor..: BOBBY BIRSS Computation...: RADIUS OF CURVATURE Survey Date...: 07/06/90 RKB Elevation.: 89.00 ft API Number .... : 50-103-20131 Job Number .... : AK0790G234 INTERPOLATED MARKERS REPORT Surface Location' 2538 SNL 95 EWL S24 T12N R8E MARKER IDENTIFICATION MEAS INCLN VERT-DEPTHS SECT DIRECTION REL~COORDINATES DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD KB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A 0 0.00 0 -89 0 N 0.00 E 3040 1.20 3040 2951 -12 S 71.67 W 6344 42.42 5774 5685 1596 S 50.57 E 6352 42.42 5779 5690 1601 S 50.21 E 6376 42.41 5797 5708 1618 S 49.11 E ON 0E 13 S 27 W 972 S 1267 E 975 S 1271 E 986 S 1283 E BASE KUPARUK A 7" CASING TD 6541 41.44 5920 5831 1728 S 45.42 E 1061 S 1365 E 6737 40.68 6068 5979 1855 S 42.55 E 1154 S 1452 E 6749 40.68 6077 5988 1863 S 42.55 E 1160 S 1458 E Grs~t L sn6 9ire£tJ~nsl Dr/ll/ng. <KB>O 350 700 i050 1400 1750 2i00 2450 2800 3150 3500 3850 4200 4550 490O 5250 5600 5950 6300 350 VERTICAL SECTION VIEW ARCO ALASKA, INC. KRU 3G-12 Section at: S 50.73 E ........ TVD Scale.: ! inch = 700 feet Dep Scale.: i inch = 700 feet .......... Drawn ..... · 08/09/90 ~arker Identification MD TVD SECTN A) KB 0 0 0 t -- 8) TD 6749 6077 i863 · .... , , , INCLN 0.00 .88 0 350 700 i050 i400 i750 2i00 2450 2800 3i50 3500 Section Depart:ure ~arker Identification ~0 N/S A) KB 0 0 N 0 E 8) TO 8749 ~tBO S t45B E PLAN VIEW ARCO ALASKA. INC. KRU 3G-12 CLOSURE ..... : 1863 ft S 51.49 E DECLINATION.: 0.00 E SCALE · 1 inch = 300 feet ORANN '08/09/90 t50 0 t50 300 450 6OO 750 9OO t050 t200 t350 t500 1650 1800 t950 t50 0 t50 <- NEST · EAST -> 300 450 600 750 900 t050 t200 1350 1500 t850 PEIIMiT # COMPLETION DATE che'cl~ off or"ii~t ~ta cored intervals AOGCC GEOLOGICAL MATERIALS iNVENTORY LIST 3 i, ~ iR ~ co. CONTACT /f j~ d as it is received.~list received date for 407. if i ii i drillin~i history' j x/j core ana. l,~sis i iii i I surve,v! t! 'well tests dry ditch intervals not rF]uired list as Nil ,0 ! core descriptiorJ~P., .... di!itai data i' ~.,,,:' ,~, -rvr:~, , ~_:_ i RUN l,q,~ ?~R~ALo' ~ SCALE ... NO. [to thc nearest footJ .. [inchl100'] , , 11] 12) "iii ........ i4) ........ ~si ...... ~ ,I I , ~ OIL AND GAS CONSERVATION COMMIS~,ON REPORT OF SUNDRY WELL OPERATIONS Stimulate __ Plugging Perforate _ Repair well Other ~; 6. Datum elevation (DF or KB) 1. Operation Performed: Operation Shutdown Pull tubing Alter casing 5. Type of Well: Development Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 4. Location of well at surface 90' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-12 9. Permit number/approval number 90-73/91-220 10. APl number 50-103-20131 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) 2538' FNL, 95' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1770' FSL, 1362' FWL, Sec. 24, T12N, R8E, UM At effective depth 1640' FSL, 1493' FWL, Sec. 24, T12N, R8E, UM At total depth 1582' FSL~ 1553' FWL~ Sec. 24r T12Nr R8E~ UM 12. Present well condition summary Total Depth: measured 6749' feet true vertical 6079' feet Effective depth: measured 6650' feet Junk (measured) true vertical 6002' feet Casing Length Size Structural Conductor 1 1 5' I 6" Surface 3 04 0' 9 5/8" Intermediate Production 6 73 7' 7" Liner Perforation depth: measured 6344'-6354', true vertical 5774'-5780', Cemented Measured depth True vertical depth 225 Sx AS I 1 15' 1 15' 700 Sx AS III & 3040' 2950' 400 Sx Class G 350 Sx Class G & 6737' 6068' 210 Sx Class G Tail 6390'-6420', 6430'-6460' 5808'-5830', 5837'-5859' Tubing (size, grade, and measured depth) 3 1/2" 9.3#, EUE, ABMOD, IPC, Bottom @ 6222, & 2-7/8" L-80, 6.5#, IPC, w/tail @ 6261' Packers and SSSV (type and measured depth) · SSSV: Camco TRDP-1A-SSA @1813', Packer: Baker Model 'D'@ 6225' 13. Stimulation or cement squeeze summary Converted from Producing Well to Water Injection Well. -~"- Intervals treated (measured) Treatment description, including volumes used and final pressure 'Anc, h~ra~ 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2100 2525 1 400 158 Prior to well operation Subsequent to operation - 0 - - 0 - 1 0 0 3 4 9 7 5 15. Attachments ! 16. Status of well classification as: Copies of Logs and Surveys run -- I Water Injector ~( Daily Report of Well Operations X Oil_ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 2620 Service Date Si~ned Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE WELL ARCO Alaska, Inc' , Subsidiary of Atlantic Richfield ComDany '~NTRACTOR REMARKS WELL SERVICE REPORT tPBDT I FIELD. DISTRICT. STATE i DATE OPER.~TION AT REPORT ' CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ~ Teml3, ~ Chill Factor ~'i Visibility 'Wind Vel, . Si Report OF, OF: miles, knota I y/~/~.' ! ! ARCO Alaska, Inc. Subsidiary of Atlantic RichfielO Company WELL SERVICE REPORT WELL iPBDT i ~~o FIELD-DISTRICT-STATE iDA7 DATE ~-. ~. ~ - // .__ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. ' Chill Factor ' Visibility 'Wind Vel. Signed Report °F °F miles knots STATE OF ALASKA ALASKA OIL AND GAS ~SERVATION COMMIS~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Pull tubing 2. Name of Operator Operation Shutdown Stimulate m Plugging Perforate X Alter casing Repair well Ct he r 6. Datum elevation (DF or KB) Plugs (measured) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 95' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1770' FSL, 1362' FWL, Sec. 24, T12N, R8E, UM At effective depth 1640' FSL, 1493' FWL, Sec. 24, T12N, R8E, UM At total depth 1582' FSL, 1553' FWL, Sec. 24, T12N~ R8E, UM 12. Present well condition summary Total Depth: measured 6749' feet true vertical 6079' feet Junk (measured) Effective depth: measured 6 650' feet true vertical 6002' feet Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3040' 9 5/8" Intermediate Production 6 73 7' 7" Liner Perforation depth: measured 6344'-6354', true vertical 5774'-5780', 90' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-12 9. Permit number/approval number 90-73/N^ 10. APl number so-103-201 31 11. Field/Pool Kuparuk River Oil Pool 5. Type of Well: Development Exploratory Stratigraphic Service Cemented Measured depth True vertical depth 225 Sx AS I 1 15' 1 15' 700 Sx AS III & 3040' 2950' 400 Sx Class G 350 Sx Class G & 6737' 6068' 210 Sx Class G Tail Tubing (size, grade, and measured depth) 6390'-6420', 6430'-6460' 5808'-5830', 5837'-5859' 3 1/2" 9.3#, EUE, ABMOD, IPC, Bottom @ 6222, & 2-7/8" L-80, 6.5#, IPC, w/tail @ 6261' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA @ 1813', Packer: Baker Model 'D' @ 6225' ~ r' ~ ~ ~ ~,, ! ~ ~.~ 13. Stimulation or cement squeeze summary ~,~ !_, Added perforations in the upper intervals of the Kuparuk Formation. Intervals treated (measured) ~h:-~;'-i 6390'-6420' & 6430'-6460' '~'" Treatment description including volumes used and final pressure ~uns w~th a density of 8 SPFphased at 90°. Al,~;,~a, Perforated both zones using strip ' ' ' .... I,~ 0ii ;~ 14. Hepresentative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2109 2601 0 400 158 158 Prior to well operation Subsequent to operation 21 0 0 2 5 2 5 1 4 0 0 15. Attachments 15. Status of well classification as: Copies of Logs and Surveys run~ Water Injector Daily Report of Well Operations X Oil Z Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Signed Date Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT /FIELD - DISTRICT - ~:~~j I DA~, jDATE,~~~ REMARKS ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. i Chill Factor !Visibilityl Wind Vel. Report °F °Fi miles i I ,I Signed knots j ARCO Alaska, Inc, ~'~, Subsidiary of Atlantic Richfield Company '"ONTRACTOR REMARKS WELL SERVICE REPORT /FI ELD - DIST,~.C,/~- yTE OPERATION AT REPORT TIME IDAYS I DATE 133.o F"-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. Chill Factor I Visibility Report °F °F miles IWind Vel. ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL ~NTRACTOR 'REMARKS ;PBDT FIELD-DISTRICT-STATE OPERATION AT REPORT TIME DAYS DATE __ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weatl~er Temp. Chill Factor Visibility Wind Vel. Report °F °F miles ,, STATE OF ALASKA - ' ~ OIL AND GAS CONSERVATION COMMIS,~ION ,~? APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ susPend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other .~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ RKB ~0 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 2538' FNL, 95' FWL, Sec. 24, T12N, R8E, UM 3G-12 At top of productive interval 9. Permit number 1770' FSL, 1362' FWL, Sec. 24, T12N, R8E, UM 90-7;3 At effective depth 10. APl number ~1640' FSL, 1493' FWL, Sec.24, T12N, R8E, UM so-103-20131 At total depth 11, Field/Pool Kuparuk River Field 1582' FSL~ 1553' FWL~ Sec. 24~ T12N~ R8E~ UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 6 74 9' feet Plugs (measured) true vertical 6 079' feet None Effective depth: measured 6650' feet Junk (measured) true vertical 6 0 0 2' feet Nolle Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 1 5' 1 6" 220 Sx AS I 1 1 5' 1 1 5' Surface 3040' 9 5/8" 700 Sx AS III & 3040' 2950' Intermediate 400 Sx Class G Production 6737' 7" 350 Sx Class G & 6737' ' 6068' Liner 210 SX Class G Tail ' ,. ~,' Perforation depth: measured 6430'-6460' . ~ true vertical ' ' "~:' Tubing (size, grade, and measured depth) 3-1/2" J-55 , 9.3#, AB Mod., IPC, Bottom @ 7873' & 2-7/8" L-80, 6.5#, IPC, @~';~!)~?!,: ~. ;'' Packers and SSSV (type and measured depth) Baker Model 'D' Pkr., @ 6225'~ Camco TRDP-1A-SSA SSSV @ 1813' 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch _ Convert well from oil producer to water injector. 14. Estimated date for commencing operation 15. Status of well classification as: AUGUST 1991 Oil ~ Gas ~ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17' I heLT~~ ~t the f°~g~ is true and correct t° the best °f my kn°wledge' ~ Signed · ~ Title ~..,~¢t'J~ ~~~ Date 7 -'~ 2- ~{ FOR COMMISSION USEII3NLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity_ BOP Test_ Location clearance__ I ~/-~30 Mechanical Integrity Test .~ Subsequent form require lO-~'g? Approved b}, order of the Commission Commissioner Date-"] Z~¢) '~::~1 Form 10-403 Rev 09/12/90 SUE ~/IIT IN,TRIPLICATE Water Injection Conversion Procedure Well 3G-1 2 Procedure: I . . . . SI well to perform surface equipment modifications. Install catalytic heater, rotate check valve and choke, install 1.5" meter runs, and calibrate instrumentation. MIRU slick line unit. RIH and tag fill. Conduct MIT. Note: The state should be notified a few days prior to performing the MIT so they can witness the test. After well has been shut in for at least 72 hours, contact Operations Engineering (x7525) to record wellhead pressure and shoot tubing fluid level. This information will be used for waterflood surveillance. Begin injection, eventually working up to a flow rate of approximately 2500 BWPD. STATE OFALASKA ~' 0 i{ 16 IN A L ALA~SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown ~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 95' FWL, Sec. 24, T12N, RSE, UM At top of productive interval 1675' FSL, 1400' FWL, Sec. 24, T12N, RSE, UM At effective depth NA At total depth 1563' FSL, 1537' FWL, Sec. 24, T12N, RSE, UM 5. Type of Well: Development . X Exploratory _ Stratigraphic _ Service (approx) (approx) 6. Datum elevation (DF or KB) RKB 89' 7. Unit or Property name Kuparuk River Unit feet 8. Well Number 3G-12 9. Permit number 90-73 10. APl number 50-103-20131 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 6746' feet (approx) true vertical 6072' feet Effective depth: measured NA feet (approx) true vertical NA feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 3003' 9 5/8" Intermediate Production 67 02' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Plugs (measured) None Junk (measured) None Cemented Measured depth True vertical depth (approx) 115' 115' 700 Sx AS III & 3040' 3040' 400 Sx Class G 350 Sx Class G 6737' 6377' & 210 Sx Class G tail 13. Attachments Description summary of proposal _ Detailed operation program X_~ BOP sketch -- 14. Estimated date for commencing operation November, 1 16. If proposal was verbally approved 15. Status of well classification as:, Oil ;~ Gas __ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~,/~. ///~~ Title Area Drilling Engineer / "' FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Commissioner IApproval No. /- / Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE 0. SMITH Approved Copy Returned SUBMIT IN TRIPLICATE ARCO Oil ~...a Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Ral~rt" on the first Wednesday after a well is spudded or workover operations are started, Daily worl( prior to spuddillg should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. County, parish or borough NORTH SLOPE Lease or Unit ADL: 25547 ALK: 2661 ITitle DRILLING Field KUPARUK RIVER Jstate AK l;ell no. U 3G-12 Auth. or W,O. no, AK4982 Operator ARCO Spudded or W.O. begun IARCO WI. 55.8533 Prior status if a W,O. SPUD Date 06/15/90 Date and depth as of 8:00 a.m, 06/15/90 (1) TD: 359'( 359) SUPV:RWS 06/16/90 (2) TD: 3060'(2701) SUPV:RWS 06/17/90 (3) TD: 3200'( 140) SUPV:RWS 06/18/90 (4) TD: 5088'(1888) SUPV:RWS 06/19/90 (5) TD: 6220' (1132) SUPV:RWS 06/20/90 (6) TD: 6746' ( 526) SUPV: TWA Complete record for each day reported DOYON 14 Hour 04: 15 DRLG MW: 8.5 VIS: 61 NU DIVERTER, S&C DRLG LINE,MU BHA, TEST DIVERTER, SPOT CUTTINGS BOX BECAUSE SOLIDS CONVEYOR COULD NOT REACH PAST PIT SIDEWALL, DRLG F/l15 T/359. DAILY:S32,147 CUM:$32,147 ETD:S32,147 EFC:$1,200,000 TD SURFACE MW: 9.3 VIS: 51 DRLG, CIRC AND CLEAN HOLE, POH, LD BHA, RIG UP TO RUN 9.625 CASING. DAILY:S74,752 CUM:$106,899 ETD:S106,899 EFC:$1,200,000 TRIP MW: 9.5 VIS: 35 RUN CASING, RU D/S AND CEMENT W/700 SKS ASlll AND 400SKS G, DISPLACE W/ H20, NU BOPE,TEST, OK, PU DC AND RIH TO FC, DRLD FC-CMT-FS-10'NEW FORMATION, TESTED FORMATION, OK, DRLD F/3070 T/3200,POH,CO BHA. DAILY:S171,565 CUM:$278,464 ETD:S278,464 EFC:$1,200,000 DRLG MW: 9.6 VIS: 38 CO BHA, RIH,DRLD F/3200 T/3915,MWD FAILURE, TRIP FOR REPLACEMENT,RIH,DRLD F/ 3915 T/4296,REPAIR GASKET ON MUD LINE,DRLD F/4296 T/5088. DAILY: $80,264 CUM: $358,728 ETD: $358,728 EFC: $1,200,000 MW: 9.6 VIS: 36 ~ F/ 5088 T/ 6200,CBU, DROP SURVEY, POH TO 9.625 CSG :SHOE, TEST FORMATION TO 11.3 EM~,OK, POH, LD TURBINE,PU ROTARY ASSY, RIH,CUT AND SLIP DRLG LINE, REAM AND TIE IN RLL, DRLG F/6200 T/6220. DAILY: $61,902 CUM: $420,630 ETD: $420,630 EFC: $1,200,000 RUN 7"CSG 7"@ 6735' MW:11.0 VIS: 39 DRLG F~ 6220T/6746,CBU, SHORT TRIP,CIRC HOLE CLEAN, DROP SS, SPOT DIESEL PILL, POH, LDDP,REMOVE RLL SOURCES,REMOVE WEAR ETD: $501,318 EFC: $1,200,000 BUSHING, RU AND RUN 7" CASING. DAILY:S80,688 CUM:$501,318 The above is correct Sign~,~ ~ For form prepara.,~ a.~d_d~stributi~' see Procedures ~ajnual, 5action 10, Drilling, Pages 8~,-~nd 87. Date AR3B-459-1 -D Number ell dally well history forms consecutively as they are prepared for each well. Page no, ARCO O~..,nd G~s Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion alld representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish /Slate ARCO AZ~SK~ ING, I NORTH SLOPE / AK Field ~Lease or Unit /Well no. KUPARUK RIVER I ADL: 25547 ALK: 2661 KR~ 3G-12 Auth. or W.O, no. ]Title AK4982 J DRILLING Operator ARCO Spudded or W.O. begun SPUD Date 06/15/90 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prtor status if a W.O. I 04:15 Date and depth as of 8:00 a.m. 06/21/90 (7) TD: 6746 PB: 6650 SUPV:TAB Complete record for each day reposed DOYON 14 RIG RELEASED 7"@ 6735' MW:10.9 NaCl RUN 7" CASING, CMT CASING, ND BOPE,ATTEMPTED TO INJECT DOWN ANNULUS,UNSUCESSFUL, RELEASE RIG. DAILY:S166,946 CUM:$668,264 ETD:S668,264 EFC:$1,200,000 Old TD New TD Released rig Classifications (oil, gas, etc.) Date IPB Depth Kind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production OII on test Gas per day · , Pump size, SPM X length IChoke size T.P. C.P. ~/~te~"% ....... ~ GOR' Gravity Allowable Effective date corrected The above i~correct sFe~ '~;~e~ruelPe~ra~uaaln,~dsed~r;nbU,'o°,n~ ' - -F I Drilling, Pages 86 and 87. AR3B-459-3-C Number all dally well history forms consecutively t Page no. as they are prepared for each well. I DIvlMon of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Date- August 3, 1990 Transmittal #: 7839 RETURN TO: ARCO Alaska, inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-11 19 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G- 1 2 Pulse Echo Cement Evaluation(PET) 7 - 6 - 9 0 2 4 0 6 - 6 6 2 6 3 G -4-2--¢o¢' Pulse Echo Cement Evaluation(PET) 7 - 6 - 9 0 6 4 4 8 - 8 6 3 7 3 G - 1 2 Acoustic Cement Bond Log 7 - 8 - 9 0 2 4 ~ 21 9 3 1 L - 1 I Acoustic Cement Bond Log 6 - 2 3 - 9 0 8 1 0 4 - 9 2 6 5 1 L - 0 9 Acoustic Cement Bond Log 6 - 2 7 - 9 0 8 9 7 0 - 1 0 0 2 7 Receipt Acknowledg ed: DISTRIBUTION: RECEIVED Date: AU 6 - 6 1990 Alaska 0[1 & Gas Cons. 6ommis~. Anchora§~ Drilling NSK .. State of Alaska(+Sepia) ARCO Alaska, Inc. Date' June 29, 1990 Transmittal #: 7799 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-12 2K-26 LIS Tape and Listing LIS Tape and Listing Please acknowledge receipt and return 6-23-90 2-18-90 AKRB900623 378829 Receipt Acknowledged: DISTRIBUTION: Date' RE 'EIVED J LJ [_ - 2 Alasl~'~i] -~-~;s Cons. Commission Anchorage Lynn Goettinger state of Alaska ARCO Alaska, Inc. Date: . June 29, 1990 Transmittal #: 7798 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-12 3G-12 Receipt Dual Gamma Ray Elecromagnetic Wave 6 - 2 0 - 9 0 Resistivity Dual Gamma Ray Compensated Neutron 6 - 2 0 - 9 0 Porosity Simultaneous Formation Density Acknowledged: 2920-6749 2920-6749 REcEIVE D a t g, iaska Oit -A-Gag£°ns' Anchorage DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) Todd Salat TO: THRU: FROM: MEMORAh UM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C.. Smi~L DATE: June 21 1990 Commissioner ~f- / ' FILE NO: JT. BF. 621.2 Bobby D. F o~e~%~ Petroleum Insp6e~or TELEPHONE NO: SUBJECT: BOP Test AAI KRU 3G- 12 Permit No. 90- 73 Kuparuk Oil Pool Saturday June 16, 1990: I traveled this date to Doyon rig 14 and ~i-tnessed "the BOPE test. As the attached BOPE test report shows, there were no failures~' In summary, I witnessed the BOPE Test on AAI 3G-12. Attachment 02-00lA (Rev. 6/89) 20/ll/MEMOI.PM3 SLATE OF ALASKA ALASKA OIL AND OAS CONSERVATION BOPE Inspection Report , _ Locatton (general) _ / ,,, Well ~tgn ~/ General housekeeping / Reaerve pit ~/~ _,_ MUD SYSTEMSI Trip tank Pit gauge Flow monitor Visual Audto / .......... IIi _ Ji __ ~1 i i i ii. Tes~ P~seure · I I ii i i _ ii % Upper Ke11¥ Lower Ke11~ .......~.../ Ball ~pe ~. J In~ide BOP Choke mantfold I i Number vulvae Number flanges , AdjuStable chorea N~dreul~oaT1¥ opera,ed choke A__~CUHULATDR SYSTEH ~ Full charge prea~ure .,.r~)~.~ pmtg Pump tncr elco pre~ 200 p~ig Full charge press ~tatned ~mtn Control~ Maurer ...... Remote. B1 ind sw~tch eove~_ K~LLY AND FLOOR SAF~Y VALVES I ,,., . _ t , ,_~ Test prom.ute Te~t preo~ure ~/,~o ,.(¢ ........... TEST RESULTS~ I,,._ i , --~ Repair or eeplaeement of fa(led equlpment to be made within end In~pe~tor/¢om~sston offtce not~fted, do~vs Remarkal : i i ii1_ J ii i · . Distr~_but~on~ orJg - AOGCC ¢ - Opera,or c - Supervisor C,O0~ (rev 03/17/8~) I I "1 1- ' J I i I ii j lin, .. l_ ..... _ i _1 ~ i. I II. Ill I I I I. i ii J Il '"" ~ J __t .111~_ " ' '' ' -- -- .... I iiii ii I_ Telecopy No. (907) 276-7542 June i3, i990 P J ArChey Area Drilling Engineer ARCO Alaska inc P 0 Box 100360 AnchOrage, AK 99510-0360 Re: Kuparuk River Uni~ 3G-i2 .: ~CO Alaska Inc ~' Permit # 90-73 :~ .Sur£ Loc~. 2538'FNL, ~5'FWL, Sec 24, T12N, RSE, UM Btmhole Loc 1563'FSL, ~'1537'FWL, Sec 24, T]2N, RSE, UM Dear Mr Archey: Encios~ed 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 au[horize conducting drilling operations until all other required permi~tting determinations are made. The Commission'~iil advise you of those BOPE tests that it wishes to witness. Very truly yours, ,: ::.,~ / /, / : , , I ." :. , :, . Chatterton Chairman Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMR.~ISSION. jO Enclosure C: Dept off'Fish & Game, Habitat Sec.Cion - w/o encl Dept of Environmental. Conserva~t:~on - w/o encl ' ' STATE OFALASKA ALA~,. ~, OIL AND GAS CONSERVATION COMMISo,ON PERMIT TO DRILL 20 AAO 25.005 I la. Type of Work Drill X.. Redrill -- I lb. Type of Well Exploratory__ Stratigraphic Tes _ Development Oil Re-Entry _ Deepen --I Service _ Development Gas __ Single Z)ne ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. :laid and Pool ARCO Al~.ska, Inc, RKB 89'. Pad 53' GL feet Kul,aruk River Field !3. Address 8. Property Designation Ku)aruk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at surface 7. Unit or property Name 11. TyI e Bond (see 20 AAC 25.025) 2538' FNL, 95' FWL, Sec. 24, T12N, R8E, UM Kuparuk River Uni. t At top of productive interval (TARGET) 8. Well number Numb~ r 1675' FSL, 1400' FWL, Sec. 24 , T12N, R8E, UM 3G-12 #U630610 At total depth 9. Approximate spud date Amount 1563' FSL, 1537' FWL, Sec 24, T12N, R8E, UM 06-15-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-09 6704 MD 1563' @ TD feet 75' at surface feet 2560 6080 VD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 3180 feet Maximum hole angle 40° Maximum surface 1880 psig At total depth (TVD) 5800' 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~ih IVD TVD IVD 'rVD (include sta~le data/ 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 3060 35' 35' 3060 3060' 1350 Cu. Ft. AS III & HF-ERW 450 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 6704' 35' 35' 6704' 6080' 200Cu. Ft. ClassG ~-E~ Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sCu%~dacUeCt°rR E ¢ E IV E D Intermediale Produclion Liner JUN 0 8 1990 Perforation depth: measured Ali~.0ii & Gas Coos. Commission true vertical ~ ~ch0rage 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements , 21. I hereby Certify that the foregoing is true and correct to the best of my knowledge Signed ~)~t(/~ ~'"~ Title Area Drilling Engineer Date / Commission Use Only Number J APl number J Approval date J0 See cover letter for Permit, L.,'' 7,,..~ 50-/o~- .Zo/,3' / 0 6 / '13 / 9other recjuirements Conditions of approval Samples required __Y e s 22(' N o Mud log required__ Y e s .,~ N o Hydrogen sulfide measu[.¢~, __ Yes ,~N o Directional survey required ,,~'Yes __ N o Required working pre,~'~e J~:)r BOP/~ ~ .~ 3 M; ,-.. 5 M; __ 10 M; __ 1 5 M / _ Approved by ' Commissioner the commission Date Form 10-401 Rev. 7-24-89 / ' in triplicate DRILLING FLUID PROGRAM (3G-12) Spud to 9-5/8" Drill out to surface casing weight UD Density 8.6-10.0 8.6-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 1 5-4 0 4 - 8 APl Filtrate 1 0-1 2 8- 1 0 pH 9-10 8.5-9 % Solids 10 +/- 4- 7 Weight up to TD 11.3 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drillina Fluid System: ~ _ - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes' JUN 0 ~nchora~ 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 1880 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-12 is 3G-09. As designed, the minimum distance between the two wells would be 75' at surface. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ARCO ALASKA. Inc. Ped ;30. We l I No, 12 Kuparulc Field. Nor'Eh Proposed SI ope, AIseke 0 .., RKB ELEVATION, go' m Frl I'rl 1000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000_ B/ PERHAFROST TVD=1605 T/ UGNU SNDS TVD=1785 T/ W SAK SNDS TVD=2405 B~ W SAK SNDS TVD=2860 9 5/8' CSG PT TVD=3060 KOP TVD=3180 TMD=3180 DEP=O 3 K~I 0 '~' TVD=3310 TMD=3310 DEP=4 Jt,JN o ]99t? e ~:i~ O~ & Gas Cons. Commhs~n ' 15 BU[LD3 DEe Anchom~ 9 EOC TVD=4414 1,D=4522 DEP=452 ~x,K-5 TVD=4690 TMD=4SS3 DEP=686 AVERAGE ANGLE 40 DEG 15 H[N ~. T/ ZONE C TVD=5790 TMD=6325 DEP=1617 "~ T/ ZONE A TVD=5815 THD=6357 DEP=1638 ,,, \ :,,TARGET CNTR TVD=5871 THD=6431DEP=1686 ~ B/ KUP SNDS TVD=5927 THD=6504 DEP=1733 TD (LOG PT) TVD=6080 THB=6?04 DEP=1862 VERTICAL I I 1 OOO 2000 SECT I ON HORI_JNTAL PROJECT ION SCALE 1 IN. = 1000 FEET 1000 SURFACE LOCAT ! OH, 2538' FNL. 95' FIlL SEC. 24. T12N. RSE O m z 0 1000 _ 2000 _ 3000 _ ARCO ALASKA. Ina. Pad 39. Well No, 12 Proposed Kuparuk Field. North Slope. Alaska WEST-EAST 1 000 0 1000 2000 I I I 5000 I SUR~ TARGET CENTER TVD=5871 THO=6431 DEP=1686 SOUTH 1067 EAST 1305 TARGET LOCAT I ON, 1675' FSL. 1400' FWL SEC. 24. T12N. RSE TD LOCATION' 15~3' FSL. 1537' FWL SEC. 24. T12N. RSE $ 50 DE(~ 44 MI N E 1686' (TO TARGET) 2400 _ 2450 _ 2500 _ 2550 _ 2600 _ 2650 _ 2700 _ 5O i, , 100 I 150 200 250 300 350 /, ,,'~ 300 /"1700 / ,/ / 500 400 450 24OO .2450 .2500 50 _ 2550 . ~~- 2600 ? , I '4~xx I _ 2650 ~, o~ ?o ~ I / I I I I I ~ I ~ 100 150 200 250 300 350 400 450 GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 3G PAD w e 1 1 . Si t . 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. KJPARUK RIVER UNI'i 20" DIVERTER SCHEMATIC 5 6 I 5 4 3 , o f i o 2 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10.' HCR BALL VALVES WITH 10.' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20'' - 2000 PSI ANNULAR PREVENTER SRE 2./6/90 .I 7 6 5 4 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC 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 STACKAND MANIFOLD WITH ARCTIC DIESEL. 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. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X)O PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BO'I-rOM PIPE RAMS. TEST BO'FI-OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND 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. 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. 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" - 5(X)O 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 SRE 8/22/89 DOYON 14 ITEM (1) Fee Ai~PROVE DATE .... YES NO' ~c'~ .... ~//?~z'~ 1. Is the permit fee attached .......................................... ~ -- (2) Loc (~i~ru 8~ (8) (3) Admin A~.; 6 ~ (10 and 13) (14 thru 22) thru 28) _ 2. Is well td be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is we!lbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... e 10. 11. 12. 13. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. ~,~ Is this Well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ , ,, Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/,~ Are necessary diagrams and descriptions of diverter and BOPE attached._~L Does BOPE have sufficient pressure rating - Test to ~OO~ psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ~,~ (6) · ('29- thru 31) Geolo g7 :- EngSneering: rev: 01/30/89 6.011 · For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential ore:pressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON'OFF POOL CLASS STATUS AREA NO. SHORE 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. ** REEL HEADER ** **** LIS READ **** (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/06/23 ORIGIN OF DATA: 3G12 REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/06/23 ORIGIN OF DATA: 3G12 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAM~: 3G-12 .MWD SERVICE NAME: RLL VERSION #: V 2.4 DATE: 90/06/23 MAX. RECORD LENGTH: FILE TYPE: MM PREVIOUS FILE NAME: 1024 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE ID DEPT CAL MWD NPSC MWD RHOB MWD NF0 MWD NFl MWD NN0 MWD NN 1 MWD GRC MWD EWR MWD FXE MWD ROP MWD ORDER# LOG TYP CLS MOD NO. FT 0 0 0 0 1 INCH 0 0 0 0 1 P.U. 0 0 0 0 1 GM/C 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 API 0 0 0 0 1 OHMM 0 0 0 0 1 HOUR 0 0 0 0 1 FT/H 0 0 0 0 1 SZE PROC SPL REPR LVL CODE 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT CAL MWD NPSC MWD RHOB MWD NFO MWD NFl MWD NN0 MWD NN1 MWD GRC MWD EWR MWD FXE MWD ROP MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 GM/C 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CT$ 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 ** DATA VERIFICATION (every 200 FT) ** · DEPT CAL NPSC RHOB NF0 NN1 GRC EWR FXE ROP NFl NN0 2900.000 8.420 50.336 2.536 2344.000 49.899 14.119 -999.250 426.000 -999.250 426.000 2296.000 3000.000 8.320 47.094 2.609 415.038 2464.911 61.606 10.987 .512 191.602 449.215 2359.392 3200.000 8.990 44.173 2.135 481.000 2376.000 78.647 3.448 4.111 69.231 559.000 2328.000 3400.000 8.630 40.666 2.261 532.918 2492.602 98.458 3.029 .541 300.000 524.480 2514.082 3600.000 8.450 40.563 2.276 519.000 2552.000 83.475 2.880 .535 328.999 543.000 2456.000 3800.000 8.570 37.311 2.252 571.256 2654.466 91.581 2.592 .636 285.306 531.767 2616.000 4000.000 8.620 36.807 2.182 559.000 2552.000 100.676 2.741 .649 176.911 615.000 2648.000 4200.000 8.570 35.522 2.453 575.000 2696.000 88.601 2.641 .777 350.124 519.000 2808.000 4400.000 8.710 39.499 2.371 559.000 2472.000 144.501 1.921 .713 290.986 623.000 2440.000 4600.000 8.850 3~390 2.618 579.638 2408.000 149.790 3.357 .636 288.067 592.277 2530.216 4800.000 8.630 40.343 2.370 535.248 2467.381 110.243 3.857 .591 290.509 556.938 2512.248 5000.000 8.460 36.740 2.361 567.000 2648.000 94.823 3.643 .560 226.099 559.000 2648.000 5200.000 8.470 37.033 2.284 559.000 2664.000 101.202 3.808 .701 390.762 535.000 2664.000 5400.000 8.520 35.475 2.232 581.898 2732.966 101.557 4.447 .810 217.555 579.415 2645.796 5600.000 8.660 34.253 2.400 599.000 2728.000 107.935 4.762 .786 313.037 607.000 2712.000 5800.000 8.650 36.543 2.392 579.900 2564.900 114.714 4.070 1.167 153.223 618.100 2627.700 6000.000 8.820 36.706 2.376 710.989 2426.818 232.969 3.737 2.087 122.813 738.293 2423.988 6200.000 9.380 50.099 2.072 472.619 2189.900 90.959 2.249 11.490 87.556 475.340 2228.298 <~6400.000 8.520 34.754 2.311 537. ~7398.096 67.576 9.301 .992 60. 826 421 604.453 2765.651 ** 367 DATA RECORDS ** ** FiLE TRAILER** FROM 2900.00 TO 6750.00 FT FILE NAME: 3G-12.MWD SERVICE NAME: RLL VERSION #: V 2.4 DATE: 90/06/23 MAX. RECORD LENGTH: FILE TYPE: MM NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) **********