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Home My WebLink About195-122MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-201 KUPARUK RIV U TABS 2T-201 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2T-201 50-103-20230-00-00 195-122-0 W SPT 2763 1951220 3000 1440 1440 1440 1440 140 140 140 140 REQVAR P Adam Earl 6/21/2025 MIT-IA tested as per AIO 2C.065 to max.ant.inj.psi 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 U TABS 2T-201 Inspection Date: Tubing OA Packer Depth 600 3300 3100 3100IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625075522 BBL Pumped:1.2 BBL Returned:1.2 Tuesday, July 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 2T-201 (PTD 195-122) Date:Wednesday, January 22, 2025 2:29:22 PM Attachments:AnnComm Surveillance TIO for 2T-201.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, January 22, 2025 1:25 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2T-201 (PTD 195-122) Hi Chris, CPAI has concluded its diagnostics and monitoring of KRU 2T-201 (PTD 195-122) which is an injection well waivered (AIO 2C.065) for water only injection due to a surface casing leak at 300ft. The well was showing signs of IA pressure fall off. CPAI conducted testing including an MIT-IA to 3000 psi which passed. The well was monitored and the IA pressure fall off was not observed when the well conditions stabilized. The well will continue to be operated per the AIO requirements. The TIO plot, schematic, and bleed log are attached. Please let me know if you have any questions or disagree with the plan. Thank you, Jaime From: Well Integrity Specialist CPF2 Sent: Monday, December 9, 2024 1:28 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2T-201 (PTD 195-122) Hi Chris, Apologies, the TIO plot, schematic, and bleed logs are now attached. Jaime From: Well Integrity Specialist CPF2 Sent: Monday, December 9, 2024 1:27 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2T-201 (PTD 195-122) Hi Chris, KRU 2T-201 (PTD 195-122) is an injection well waivered (AIO 2C.065) for water only injection due to a surface casing leak at 300ft. The well is showing signs of IA pressure fall off suspected to be IAxOA. CPAI will now conduct diagnostics to verify the integrity of the IA. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2T-201 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2T-201 2024-11-15 100 940 840 IA 2T-201 2024-11-15 1000 450 -550 IA 2T-201 2024-11-28 165 415 250 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (EST 135' of Rathole) 3,734.0 2T-201 7/27/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Gauges 2T-201 8/29/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered Well. Water only injection. OAxFormation Communication SC Leak at 300' lyonska NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 12/9/2010 haggea Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.0 Set Depth (ft… 121.0 Set Depth … 121.0 Wt/Len (lb/ft) 62.58 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 41.1 Set Depth (ft… 2,244.2 Set Depth … 2,025.6 Wt/Len (lb/ft) 40.00 Grade L-80 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 38.5 Set Depth (ft… 4,123.8 Set Depth … 3,781.3 Wt/Len (lb/ft) 26.00 Grade J-55 Top Connection BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.4 Set Depth … 2,763.9 String Ma… 3 1/2 Tubing Description Tubing – Production Set Depth (ftKB) 3,081.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 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) 36.4 36.4 0.21 HANGER 7.060 FMC Gen IV tubing hanger FMC Gen IV 2.992 2,976.8 2,665.1 20.55 GAS LIFT 5.968 Camco 3-1/2" x 1.5" MMG, RKB 2000 psi SOV,SN #034AH05 Camco MMG 2.915 3,033.6 2,718.5 19.08 SEAL ASSY 3.770 Baker 80-40 Locating Seal Assembly BAKER PBR 80- 40 2.992 3,038.5 2,723.2 18.96 PBR 5.000 Baker 80-40 PBR 4.000 3,061.1 2,744.6 18.38 PACKER 5.930 Baker FHL Packer Baker 47B2 - 7" 26# 2.890 3,079.0 2,761.6 17.93 LOCATOR 4.000 Baker KBH-22 Locator BAKER KBH-22 Anchore d 2.990 3,079.6 2,762.2 17.91 SEAL ASSY 2.990 Baker KBH-22 Anchored Seal Asembly BAKER KBH-22 Anchore d 2.992 Top (ftKB) 3,079.6 Set Depth … 2,788.9 String Ma… 3 1/2 Tubing Description Tubing – Production Set Depth (ftKB) 3,107.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd 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) 3,079.6 2,762.2 17.91 PACKER 6.000 BAKER SAB-3 PERMANENT PACKER BAKER SAB-3 3.250 3,095.6 2,777.4 17.50 NIPPLE 4.470 CAMCO D NIPPLE CAMCO D 2.750 3,106.7 2,788.0 17.23 SOS 4.750 BAKER SHEAR OUT BAKER 2.992 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) 2,976.8 2,665.1 20.55 1 DMY RK 1 1/2 0.0 1/13/2017 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,355.0 3,527.0 3,027.5 3,195.1 TABASCO, 2T- 201 9/27/1995 5.0 IPERF 3,568.0 3,599.0 3,235.3 3,265.7 TE_1, 2T-201 9/27/1995 5.0 IPERF 2T-201, 8/30/2022 7:09:46 AM Vertical schematic (actual) PRODUCTION; 38.5-4,123.8 IPERF; 3,568.0-3,599.0 IPERF; 3,355.0-3,527.0 SOS; 3,106.7 NIPPLE; 3,095.6 PACKER; 3,079.6 LOCATOR; 3,078.9 PACKER; 3,061.1 PBR ; 3,038.5 SEAL ASSY; 3,033.6 GAS LIFT; 2,976.8 SURFACE; 41.1-2,244.2 CONDUCTOR; 41.0-121.0 HANGER; 36.4 KUP INJ KB-Grd (ft) RR Date 8/17/1995 Other Elev… 2T-201 ... TD Act Btm (ftKB) 4,175.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032023000 Wellbore Status INJ Max Angle & MD Incl (°) 36.77 MD (ftKB) 1,946.98 WELLNAME WELLBORE2T-201 Annotation Last WO: End Date 1/10/2017 H2S (ppm) DateComment SSSV: NONE 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 2T-201 (PTD 195-122) Date:Monday, December 9, 2024 2:21:51 PM Attachments:AnnComm Surveillance TIO for 2T-201.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, December 9, 2024 1:28 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2T-201 (PTD 195-122) Hi Chris, Apologies, the TIO plot, schematic, and bleed logs are now attached. Jaime From: Well Integrity Specialist CPF2 Sent: Monday, December 9, 2024 1:27 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2T-201 (PTD 195-122) Hi Chris, KRU 2T-201 (PTD 195-122) is an injection well waivered (AIO 2C.065) for water only injection due to a surface casing leak at 300ft. The well is showing signs of IA pressure fall off suspected to be IAxOA. CPAI will now conduct diagnostics to verify the integrity of the IA. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2T-201 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2T-201 2024-11-15 100 940 840 IA 2T-201 2024-11-15 1000 450 -550 IA 2T-201 2024-11-28 165 415 250 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (EST 135' of Rathole) 3,734.0 2T-201 7/27/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Gauges 2T-201 8/29/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered Well. Water only injection. OAxFormation Communication SC Leak at 300' lyonska NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 12/9/2010 haggea Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.0 Set Depth (ft… 121.0 Set Depth … 121.0 Wt/Len (lb/ft) 62.58 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 41.1 Set Depth (ft… 2,244.2 Set Depth … 2,025.6 Wt/Len (lb/ft) 40.00 Grade L-80 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 38.5 Set Depth (ft… 4,123.8 Set Depth … 3,781.3 Wt/Len (lb/ft) 26.00 Grade J-55 Top Connection BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.4 Set Depth … 2,763.9 String Ma… 3 1/2 Tubing Description Tubing – Production Set Depth (ftKB) 3,081.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 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) 36.4 36.4 0.21 HANGER 7.060 FMC Gen IV tubing hanger FMC Gen IV 2.992 2,976.8 2,665.1 20.55 GAS LIFT 5.968 Camco 3-1/2" x 1.5" MMG, RKB 2000 psi SOV,SN #034AH05 Camco MMG 2.915 3,033.6 2,718.5 19.08 SEAL ASSY 3.770 Baker 80-40 Locating Seal Assembly BAKER PBR 80- 40 2.992 3,038.5 2,723.2 18.96 PBR 5.000 Baker 80-40 PBR 4.000 3,061.1 2,744.6 18.38 PACKER 5.930 Baker FHL Packer Baker 47B2 - 7" 26# 2.890 3,079.0 2,761.6 17.93 LOCATOR 4.000 Baker KBH-22 Locator BAKER KBH-22 Anchore d 2.990 3,079.6 2,762.2 17.91 SEAL ASSY 2.990 Baker KBH-22 Anchored Seal Asembly BAKER KBH-22 Anchore d 2.992 Top (ftKB) 3,079.6 Set Depth … 2,788.9 String Ma… 3 1/2 Tubing Description Tubing – Production Set Depth (ftKB) 3,107.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd 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) 3,079.6 2,762.2 17.91 PACKER 6.000 BAKER SAB-3 PERMANENT PACKER BAKER SAB-3 3.250 3,095.6 2,777.4 17.50 NIPPLE 4.470 CAMCO D NIPPLE CAMCO D 2.750 3,106.7 2,788.0 17.23 SOS 4.750 BAKER SHEAR OUT BAKER 2.992 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) 2,976.8 2,665.1 20.55 1 DMY RK 1 1/2 0.0 1/13/2017 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,355.0 3,527.0 3,027.5 3,195.1 TABASCO, 2T- 201 9/27/1995 5.0 IPERF 3,568.0 3,599.0 3,235.3 3,265.7 TE_1, 2T-201 9/27/1995 5.0 IPERF 2T-201, 8/30/2022 7:09:46 AM Vertical schematic (actual) PRODUCTION; 38.5-4,123.8 IPERF; 3,568.0-3,599.0 IPERF; 3,355.0-3,527.0 SOS; 3,106.7 NIPPLE; 3,095.6 PACKER; 3,079.6 LOCATOR; 3,078.9 PACKER; 3,061.1 PBR ; 3,038.5 SEAL ASSY; 3,033.6 GAS LIFT; 2,976.8 SURFACE; 41.1-2,244.2 CONDUCTOR; 41.0-121.0 HANGER; 36.4 KUP INJ KB-Grd (ft) RR Date 8/17/1995 Other Elev… 2T-201 ... TD Act Btm (ftKB) 4,175.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032023000 Wellbore Status INJ Max Angle & MD Incl (°) 36.77 MD (ftKB) 1,946.98 WELLNAME WELLBORE2T-201 Annotation Last WO: End Date 1/10/2017 H2S (ppm) DateComment SSSV: NONE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-201 KUPARUK RIV U TABS 2T-201 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2T-201 50-103-20230-00-00 195-122-0 W SPT 2763 1951220 3000 720 720 720 720 140 140 140 140 REQVAR P Guy Cook 6/10/2023 MITIA to maximum anticipated injection pressure per AIO 2C.065. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TABS 2T-201 Inspection Date: Tubing OA Packer Depth 300 3280 3070 3030IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230609155436 BBL Pumped:1.4 BBL Returned:1.4 Thursday, July 27, 2023 Page 1 of 1            MEMORANDUM To: Jim Regg / P.I. Supervisor FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 22, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2T-201 KUPARUK RIV U TABS 2T-201 Src: Inspector Reviewed B P.I. Supry Comm Well Name KUPARUK RIV U TABS 2T-201 API Well Number 50-103-20230-00-00 Inspector Name: Brian Bixby Insp Num: mitBDB210619073350 Permit Number: 195-122-0 Inspection Date: 6/18/2021 Rel Insp Num: Pretest Initial 15 Min 30 Min 45 Min 60 Min T -- Tubing 680 680 . 1 680- 680 IA 1120 3320 3170 - 3150 ' OA 130 130 130 130 Tuesday, June 22, 2021 Page 1 of 1 Packer Depth Well 2T-201 Type Inj w 'TVD 2763 PTD 1951220 Type Test SPT"TCSt psi 3000 ' BBL Pumped: 1 jBBL Returned: 1 Interval REQVAR PIF P Notes: 2 Year MITIA as per A10 2C.065 Pretest Initial 15 Min 30 Min 45 Min 60 Min T -- Tubing 680 680 . 1 680- 680 IA 1120 3320 3170 - 3150 ' OA 130 130 130 130 Tuesday, June 22, 2021 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg p DATE: Thursday, July 25, 2019 P.I. Supervisor SUBJECT: DrZ'L ( SUBJECT: Mechanical Integrity Tests (l ConocoPhillips Alaska, Inc. 2T-201 FROM: Jeff Jones KUPARUK RIV U TABS 2T-201 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TABS 2T-201 API Well Number 50-103-20230-00-00 Inspector Name: Jeff Jones Permit Number: 195-122-0 Inspection Date: 6/2/2019 Insp Num: miUJ190725101948 Rel Insp Num: Thursday, July 25, 2019 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -we -- - PTD 1461220 Type Inj w TVD Type Test SPT Test psi 000 Tubingi soo - - IA 1150 soo soo 3300 3180 500 - 80 - BBL Pumped: 1.3 .BBL Returned: 1.3 OA 120 - 120 - 120 120 - - --- Intervalj - '------ - RBQVAR P/F _ --` P ----J— - - Notes: MIT -IA to max. anticipated injection press, Per AIO 2C-065. I well inspected, no exceptions noted. Thursday, July 25, 2019 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 15,2017 TO: Jim Regg / P.I.Supervisor Iq ( l/7 SUBJECT: Mechanical Integrity Tests (((( ll CONOCOPHILLIPS ALASKA INC 2T-201 FROM: Lou Laubenstein KUPARUK RIV U TABS 2T-201 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry S ' NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TABS 2T-201API Well Number 50-103-20230-00-00 Inspector Name: Lou Laubenstein Permit Number: 195-122-0 Inspection Date: 6/5/2017 Insp Num: mitLOL170607155009 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-201 ' Type Inj W 'TVD 2763 - Tubing 400 . 400 . 400 400 • PTD 1951220 ' Type Test SPT Test psi 1500 - IA 1490 2110 • 2040 2040 BBL Pumped: 0.4 'BBL Returned: 0.2 OA 115 - 160 150 - 150- Interval T 4YRTST P/F P Notes: SCANNED F P 1 3 ;, Thursday,June 15,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,April 21,2017 TO: Jim Regg 2� 5l4I r 7 P.I.Supervisor i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-201 FROM: Lou Grimaldi KUPARUK RIV U TABS 2T-201 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name KUPARUK RIV U TABS 2T-201 API Well Number 50-103-20230-00-00 Inspector Name: Lou Grimaldi Permit Number: 195-122-0 Inspection Date: 2/14/2017 Insp Num: mitLG170214103620 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-201 • Type Inj W TVD 2763 - Tubing 600 600 -? 600 600 600 - PTD 1951220 - Type Test SPT Test psi 1500 IA 1520 2210 - 2255 - 2250 - 2250 - BBL Pumped: 0.3 - BBL Returned: 0.3 - OA 90 170 180 - 185 185 Interval Initial Test P/F Pass Notes: Good initial test post-workover.Held additional 15 minutes for stabilization(135 degreesF).All required paperwork supplied onsite. `" SCANNED AUG 1 5 201', Friday,April 21,2017 Page 1 of 1 STATE OF ALASKA , Allk KA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate I- Pull Tubing IF Operations Shutdown la Performed: Suspend E' Perforate Other Stimulate p I- Alter Casing F Change Approved Program Plug for Redrill Perforate New Pool l Repair Well 1 Re-enter Susp Well l l 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory 195-122 3.Address: Stratigraphic 1- Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20230-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25569 KRU 21-201 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Tabasco Oil Pool 11.Present Well Condition Summary: Total Depth measured 4175 feet Plugs(measured) None true vertical 3832 feet Junk(measured) None Effective Depth measured 3885 feet Packer(measured) 3061,3080 true vertical 3547 feet (true vertical) 2745,2762 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 2203 9.625 2244 2026 PRODUCTION 4085 7 4124 3781 RECEIVEDPerforation depth: Measured depth: 3355-3527,3568-3599 True Vertical Depth: 3027-3195,3235,3266 FEB 0 9 2017 Tubing(size,grade,MD,and ND) 3.5, L-80,3108 MD,2789 ND AAQC C Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 3061 MD and 2745 ND PACKER-BAKER SAB-3 PERMANENT PACKER @ 3080 MD and 2762 ND NONE-Type Not Found(Manual Entry Required)@ 0 MD and 0 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A NNE R K rkp} a.� 01 1 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 300 300 Subsequent to operation 0 0 6800 1360 570 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory -.� Development la Service F Stratigraphic I"- Copies of Logs and Surveys Run I- 16.Well Status after work: Oil P..... Gas (..-. WDSPL E Printed and Electronic Fracture Stimulation Data(. GSTOR r WINJ 3 WAG la GINJ SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-299 Contact Sara Heskin a 265-1027 Email Sara.Heskinaconocophillios.com Printed Name Sara Heskin Title Assoc. Wells Engineer Signature , Phone:265-1027 Date 4. SG111,c3t€A1L- c I ' II / 111.- 312 / 1- Form 10-404 Revised 5/2015 RBD i S L iso 1 t Lo I/ Submit Original Only • • Operations Summary (with Timelog Depths) �. {; .. 2T-201 riri'ConocoPhitrps .:. Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MB) 1/2/2017 1/3/2017 5.00 MIRU MOVE MOB P Rigged down and moved from 1D to 19:00 00:00 2T Pad. 1/3/2017 1/3/2017 12.00 MIRU MOVE MOB P Continue Move and Rig up. 00:00 12:00 1/3/2017 1/3/2017 7.00 MIRU MOVE RURD P Rigged up.Rig accepted 1900 Hrs. 12:00 19:00 1/3/2017 1/4/2017 5.00 MIRU MOVE RURD P Rigged up lines and tested line to 19:00 00:00 Flow Back Tank. 1/4/2017 1/4/2017 1.00 MIRU WELCTL SEQP P Pressured up line to Flow Back Tank 00:00 01:00 with Air and walked the line. Pressured line with water to 2,500 psi. Good. 1/4/2017 1/4/2017 1.00 MIRU WELCTL OWFF P Bled IA to FB Tank.OWFF. 01:00 02:00 1/4/2017 1/4/2017 1.75 MIRU WELCTL KLWL P Circulated SW into the well pumping 02:00 03:45 down the tubing taking returns to the FB Tank via the IA.2 BPM 185 psi. 1/4/2017 1/4/2017 0.25 MIRU WELCTL OWFF P OWFF Static. 03:45 04:00 1/4/2017 1/4/2017 0.50 MIRU WHDBOP MPSP P Installed BPV and tested 1000 psi 04:00 04:30 from below. 1/4/2017 1/4/2017 0.50 MIRU WHDBOP OTHR P Blew down lines and rigged down. 04:30 05:00 1/4/2017 1/4/2017 2.00 MIRU WHDBOP NUND P Nippled down Tree and inspect 05:00 07:00 hanger. 1/4/2017 1/4/2017 0.50 MIRU WHDBOP MPSP P Set Blanking Plug. 07:00 07:30 1/4/2017 1/4/2017 3.50 MIRU WHDBOP NUND P Nipple up DSA,Spacer Spool,and 07:30 11:00 BOP. 1/4/2017 1/4/2017 1.00 MIRU WHDBOP RURD P Rigged up to Test BOP. 11:00 12:00 Page 1/7 Report Printed: 1/17/2017 • • r � - Operations Summary (with Timelog Depths)Pat 440*M2T-201 ConocoPtaitiiprs h. A�xsk.n Rig: DOYON 142 Job: RECOMPLETION Time Log, Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/4/2017 1/4/2017 4.50 MIRU WHDBOP BOPE P Test gas alarms 12:00 16:30 Conduct initial BOPE test to 250/3000 psi with 3-1/2"test Jt.Test was waived by AOGCC inspector Guy Cook. Test 1.Annular,CV#1, 12, 13, 14,4" Kill Valve on mud manifold and XT39 dart valve. Test 2.Top Pipe rams(3-1/2"x 6" VBR's),CV#9, 11,Mezz kill valve and XT39 FOSV. Test 3. HCR Kill.Test 4. Manifold Valve#4 Test 5.Manifold Valves#8, 10 Test 6.Manifold Valves#6,7 and manual kill Test 7.Manifold Valve#2 Test 8.Bottom Pipe rams(3-1/2"x 6" VBR's), BOPE test to 250/3000 psi with 4"test Jt Test 1.Blind rams Test 2.Super choke. Test 3.Manual Choke Test 4.Annular and HCR choke. Test 5.Top Pipe rams(3-1/2"x 6" VBR's),and HCR choke. Test 6. Bottom Pipe rams(3-1/2"x 6" VBR's) Test 7.Upper IBOP Test 8.Lower IBOP Conduct Koomey Draw Down Test Starting Accumulator pressure=3000 psi Manifold pressure=1500 psi Annular psi=1150 psi, Pressure Gain of 200 psi attained in 14 secs. Full pressure gain attained in 59 secs. Average N2(6 bottles)=2550 psi. COP test-2 elec mtrs 20 secs,2 Air pumps 80 secs. Test PVT's 1/4/2017 1/4/2017 2.00 MIRU WHDBOP MPSP P Pulled Blanking Plug and BPV.Rig 16:30 18:30 down test Equipment. 1/4/2017 1/4/2017 1.00 MIRU RPCOMP PULL P RU Landing Jt and Backed out LDS. 3,004.0 2,968.0 18:30 19:30 Pulled Tubing Hanger to the Rig Floor. Max pull 119K String Wt 62K after free. 1/4/2017 1/4/2017 0.25 MIRU RPCOMP CIRC P CBU 5 BPM 192 psi. 2,968.0 2,968.0 19:30 19:45 1/4/2017 1/4/2017 0.25 MIRU RPCOMP OWFF P OWFF Static. 2,968.0 2,968.0 19:45 20:00 1/4/2017 1/4/2017 0.50 MIRU RPCOMP PULL P Laid down Tubing Hanger and pups. 2,968.0 2,968.0 20:00 20:30 1/4/2017 1/5/2017 3.50 MIRU RPCOMP PULL P POOH laying down 3 1/2"Completion 2,968.0 160.0 20:30 00:00 from 2,968'to 160'. 1/5/2017 1/5/2017 0.50 COMPZN RPCOMP PULL P L/D and strap remainng 160'of 3 1/2: 160.0 00:00 00:30 EUE tubing.Cut joint length 15.49' Page 2/7 Report Printed: 1/17/2017 • • Operations Summary (with Timelog Depths) 1 2T-201 C...... tai.itps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time, End Time Our(hr) Phase Op Code Activity Code Time P T-X Operation (ftKB) End Depth(ftKB) 1/5/2017 1/5/2017 1.50 COMPZN RPCOMP RURD P C/O handinling equipment on rig floor, 00:30 02:00 bring fishing tools to rig floor,attempt to install wear ring with no luck, tagging at 35'.ULDS @ 36.76' 1/5/2017 1/5/2017 2.50 COMPZN RPCOMP BHAH P P/U fishing BHA with 5 3/4"overshot. 02:00 04:30 unable to get thru wellhead @ 37'.set down 10k and attempt to get overshot thru obstruction no luck. 1/5/2017 1/5/2017 0.50 COMPZN WELLPR BHAH P P/U sack washing tool with 5.10"OD 04:30 05:00 and drift thru down to 55'.LD washing tool. 1/5/2017 1/5/2017 0.50 COMPZN WELLPR BHAH P P/U lift sub with a 5.53"OD and tag up 05:00 05:30 at 37'no success getting thru obstuction at LDS 1/5/2017 1/6/2017 18.50 COMPZN WELLPR WAIT T Phase 3 weather conditions wait on 05:30 00:00 weather 1/6/2017 1/6/2017 5.50 COMPZN WELLPR WAIT T Wait on Phase 3 conditions to lift. 00:00 05:30 1/6/2017 1/6/2017 4.00 COMPZN WELLPR PULD P Begin P/U 33 stands of 4"DP&3 05:30 09:30 stands of HWDP. Trucks sent to deadhorse for IBP and mills. 1/6/2017 1/6/2017 1.50 COMPZN WELLPR TRIP P POOH and stood DP back in the 09:30 11:00 Derrick. 1/6/2017 1/6/2017 1.00 COMPZN WELLPR RURD T Cleared and cleaned Rig Floor. 11:00 12:00 1/6/2017 1/6/2017 0.50 COMPZN WELLPR SVRG P Serviced Rig and Topdrive. 12:00 12:30 1/6/2017 1/6/2017 1.50 COMPZN WELLPR WAIT P Waiting on Truck from Deadhorse with 12:30 14:00 IBP,delayed due to Phase 3 Conditions. 1/6/2017 1/6/2017 0.50 COMPZN WELLPR BHAH P Made up Baker IBP on HWDP.Hung 0.0 181.0 14:00 14:30 up @ 181'and would not go down. 1/6/2017 1/6/2017 0.50 COMPZN WELLPR BHAH T POOH and stood back HWDP. 181.0 0.0 14:30 15:00 1/6/2017 1/6/2017 0.25 COMPZN WELLPR BHAH T Made up IBP on a stand of 4"DP 0.0 115.0 15:00 15:15 1/6/2017 1/6/2017 0.25 COMPZN WELLPR TRIP T RIH to 181'No Problem. 115.0 181.0 15:15 15:30 1/6/2017 1/6/2017 1.25 COMPZN WELLPR TRIP P RIH From 181'to 2,480'. 181.0 2,480.0 15:30 16:45 1/6/2017 1/6/2017 0.25 COMPZN WELLPR MPSP P Broke Circulation and Dropped ball. 2,480.0 2,480.0 16:45 17:00 Inflated IBP.Set©2,480'. 1/6/2017 1/6/2017 0.25 COMPZN WELLPR PRTS P Picked up 10'and Tested IBP to 1,000 2,480.0 2,470.0 17:00 17:15 psi for 10 Min.Good test. 1/6/2017 1/6/2017 2.00 COMPZN WELLPR TRIP P POOH from 2,470'to Surface. 2,470.0 0.0 17:15 19:15 1/6/2017 1/6/2017 0.25 COMPZN WELLPR BHAH P Layed down Running Tool. 0.0 0.0 19:15 19:30 1/6/2017 1/6/2017 0.50 COMPZN WELLPR TRIP P RIH wit DP to 472'. 0.0 472.0 19:30 20:00 1/6/2017 1/7/2017 4.00 COMPZN WELLPR CIRC P RU Sand Hopper and Dumping Sand 472.0 472.0 20:00 00:00 1500 Lbs. 1/7/2017 1/7/2017 1.50 COMPZN WELLPR NUND P ND BOPE,bleed off OA 80 psi 0.0 00:00 01:30 dropped to zero after 5 mins. Page 3/7 Report Printed: 1/17/2017 • • Operations Summary (with Timelog Depths) 2T-201 CortocdPhilllps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (W8) End Depth(ftKS) 1/7/2017 1/7/2017 7.50 COMPZN WELLPR CUTP P Begin ND tubing spool via hydro-tight. 01:30 09:00 Casing growth 35 1/2"before stretching.R/U cutter and cut off damaged top of 7"in order to spear 7" and stretch casing. 1/7/2017 1/7/2017 1.50 COMPZN WELLPR CUTP P R/U 7"spear and stab casing.P/U 09:00 10:30 175K(45 blocks,60K string weight, 70K over-set emegency slips). Stretch additional 16"-total=51.5" 1/7/2017 1/7/2017 1.50 COMPZN WELLPR CUTP P R/U wachs cutter-cut 7" 10:30 12:00 1/7/2017 1/7/2017 2.50 COMPZN WELLPR WWSP P NU Tubing head adapter test pack off 12:00 14:30 250/3000 psi. 1/7/2017 1/7/2017 3.50 COMPZN WELLPR NUND P NU BOPE and Riser. 14:30 18:00 1/7/2017 1/7/2017 0.50 COMPZN WELLPR BOPE P Filled Stack with water and tested 18:00 18:30 Break 250/3000 psi for 5 min.Good Test. 1/7/2017 1/7/2017 0.75 COMPZN WELLPR BOPE P Pulled Test Plug,set Wear Bushing 18:30 19:15 and laid down Test Jt. 1/7/2017 1/7/2017 0.50 COMPZN WELLPR BHAH P Picked BHA Wash Nozle and 6.15" 0.0 34.0 19:15 19:45 String Mill. 1/7/2017 1/7/2017 1.50 COMPZN WELLPR TRIP P RIH from 34'to Top of Sand @ 2,350'. 34.0 2,350.0 19:45 21:15 1/7/2017 1/7/2017 2.00 COMPZN WELLPR CIRC P Washed out sand from 2,350'to 2,350.0 2,461.0 21:15 23:15 2,392'.427 GPM @ 700 psi.Pumped Hi Vis 30 Bbls 595 GPM @ 1220 psi. Continue Washing out sand from 2,392'to 2,461'.427 GPM @ 650 psi. Pumped Hi Vis 30 Bbls 595 GPM @ 1,147 psi. Pumped until shakers cleaned up. 1/7/2017 1/7/2017 0.25 COMPZN WELLPR OWFF P OWFF for 10 Min Static. 2,461.0 2,461.0 23:15 23:30 1/7/2017 1/8/2017 0.50 COMPZN WELLPR TRIP P 'POOH from 2,461'to 1,394'. 2,461.0 1,394.0 23:30 00:00 1/8/2017 1/8/2017 0.50 COMPZN WELLPR TRIP P TOOH from 1394'to sutfce. 1,394.0 0.0 00:00 00:30 1/8/2017 1/8/2017 2.00 COMPZN WELLPR BHAH P Lay down clean out BHA/P/U IBP 0.0 0.0 00:30 02:30 retrieval BHA 1/8/2017 1/8/2017 1.50 COMPZN WELLPR TRIP P TIH down to top of IBP @ 2467'- 0.0 2,467.0 02:30 04:00 engage fish,swallow 2 ft,set down 3K,P/U 6K over to shear.Equalize for 2 mins,monitor well for 10 mins. 1/8/2017 1/8/2017 1.50 COMPZN WELLPR TRIP P TOOH with IBP 2,467.0 0.0 04:00 05:30 1/8/2017 1/8/2017 1.00 COMPZN WELLPR BHAH P Lay down IBP,P/U overshot assembly 0.0 322.0 05:30 06:30 with 3 stands of HWDP&jars. 1/8/2017 1/8/2017 2.00 COMPZN RPCOMP TRIP P TIH with overshot BHA down to top of 322.0 2,997.0 06:30 08:30 3.5"tubing @ 2997' 1/8/2017 1/8/2017 2.00 COMPZN RPCOMP FISH T P/U weight 90K,DW 85K,pump 5 2,997.0 2,997.0 08:30 10:30 bpm @ 200 psi.Seen weight drop off @ 2997'-P/U and begin rotating down over fish.No improvements,P/U seen drag up to 20K over then drops off quickly(fish getting wedged into carbide madrel).Make two more milling attempts no luck)with max torque of 3K. Page 4/7 Report Printed: 1/17/2017 „ 0 e 0.1„ Operations Summary (with Timelog Depths) eit 2T-201 cooPhiilips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time. Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/8/2017 1/8/2017 1.50 COMPZN RPCOMP TRIP T TOOH to inspect BHA 2,997.0 322.0 10:30 12:00 1/8/2017 1/8/2017 1.50 COMPZN RPCOMP PULD T Lay down carbide mandrel,run with 0.0 320.0 12:00 13:30 same overshot and grapple. 1/8/2017 1/8/2017 1.25 COMPZN RPCOMP TRIP T TIH down to top of fish @ 2997' 320.0 2,997.0 13:30 14:45 1/8/2017 1/8/2017 0.50 COMPZN RPCOMP FISH P P/U weight 90K/Down 85K.pumping 4 2,997.0 3,002.0 14:45 15:15 bpm @ 110 psi.Good indication of going over the fish and bottom out on no go 5 ft of swallow set down 5K, pressure increase of 30 psi.P/U weight 93K.Set back down 10K. Begin pumping sweep to clean out below seal assembly.P/U weight 93K. 1/8/2017 1/8/2017 0.50 COMPZN RPCOMP CIRC P Circulate out Hi Vis Sweep.6 BPM 3,002.0 3,002.0 15:15 15:45 266 psi. 1/8/2017 1/8/2017 0.25 COMPZN RPCOMP OWFF P OWFF Static 3,002.0 3,002.0 15:45 16:00 1/8/2017 1/8/2017 1.50 COMPZN RPCOMP TRIP P POOH from 3,002'to Overshot. 3,002.0 0.0 16:00 17:30 1/8/2017 1/8/2017 0.50 COMPZN RPCOMP RURD P RU Tubing Tongs 0.0 0.0 17:30 18:00 1/8/2017 1/8/2017 0.50 COMPZN RPCOMP PULL P Lay down Fish. 0.0 0.0 18:00 18:30 1/8/2017 1/8/2017 0.50 COMPZN RPCOMP BHAH P Laid down fish BHA. 0.0 0.0 18:30 19:00 1/8/2017 1/8/2017 1.00 COMPZN RPCOMP BHAH P Clean and clear Rig Floor. 0.0 0.0 19:00 20:00 1/8/2017 1/8/2017 1.00 COMPZN RPCOMP SVRG P Serviced Rig and TopDrivre. 0.0 0.0 20:00 21:00 1/8/2017 1/8/2017 0.75 COMPZN RPCOMP PUTB P PU Baker K Anchor with PBR and 0.0 308.0 21:00 21:45 Seal Set.PU 3 Stands HWDP. 1/8/2017 1/8/2017 1.75 COMPZN RPCOMP RCST P RIH to 3,055'. 308.0 3,055.0 21:45 23:30 1/8/2017 1/9/2017 0.50 COMPZN RPCOMP PACK T Attempt to engage K Anchor.Would 3,055.0 3,073.0 23:30 00:00 not latch up. 1/9/2017 1/9/2017 1.50 COMPZN RPCOMP RURD T Blow down TD. 3,073.0 3,073.0 00:00 01:30 P/U single and tg @ 3072',set down 20K,PT seals to 1000 psi.P/U weight 94K,DN 88K. Blow down TD,install stripping rubber 1/9/2017 1/9/2017 4.00 COMPZN RPCOMP PULD P TOOH layind down DP as planned. 3,073.0 0.0 01:30 05:30 1/9/2017 1/9/2017 1.00 COMPZN RPCOMP RURD T C/O floor equipment,R/U GBR and 0.0 0.0 05:30 06:30 lay down seal assembly. 1/9/2017 1/9/2017 1.50 COMPZN RPCOMP WWWH P Pull wear bushing,wash out stack and 0.0 0.0 06:30 08:00 landing ring area 1/9/2017 1/9/2017 1.00 COMPZN RPCOMP PRTS P Test casing to 2500 psi.Good test 0.0 0.0 08:00 09:00 down to CR-2 plug 1/9/2017 1/9/2017 0.50 COMPZN RPCOMP SFTY P PJSM-Running completion and pre- 0.0 0.0 09:00 09:30 rig move. 1/9/2017 1/9/2017 5.00 COMPZN RPCOMP PUTB P M/U seal assembly,followed by 0.0 3,070.0 09:30 14:30 Stacker pcker,and GLM with SOV& 3.5"EUE completion as per running order. 3070'-up and down weight 66K. Page 5/7 Report Printed: 1/17/2017 S • Operations Summary (with Timelog Depths) 2T-201 conocoPhillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/9/2017 1/9/2017 1.00 COMPZN RPCOMP HOSO P P/U 10 ft pup,M/U test manifold. 3,070.0 3,073.0 14:30 15:30 TIH pumping 1 bpm,bottom seals @ 3071'-bleed off presure-tag no-go 3073.5'.Set down 10 K.P/U and pump 60 bbls 1%CI SW followed by 35 bbls of heated 110 degree CI SW, cahse with 17 bbls of SW all down the tubing. 1/9/2017 1/9/2017 0.50 COMPZN RPCOMP PACK P Set back into lower anchor seal 3,073.0 3,073.0 15:30 16:00 assembly,Tag no-go @ 3073.5' - Pressure up to 2500 psi set Stacker packer hold for 10 mins,bleed down to 1000 psi.Pull out of upper PBR @ 3031'.P/U weight 17K over to shear. Packer set @ 3053' 1/9/2017 1/9/2017 2.00 COMPZN RPCOMP THGR P P/U and measure 4ft space out.Lay 3,073.0 3,031.0 16:00 18:00 down joints and P/U spacer pups and landing joint. Landed Hanger and ran in LD Screws. 1/9/2017 1/9/2017 0.50 COMPZN RPCOMP RURD P Rigged up to test Tubing and IA. 3,031.0 0.0 18:00 18:30 1/9/2017 1/9/2017 2.25 COMPZN RPCOMP PRTS P Pressure tested Tubing to 3,500 psi 0.0 18:30 20:45 for 30 Min.Passed.Pressure tested IA to 3,000 psi for 30 Min.Passed. Sheared out SOV. 1/9/2017 1/9/2017 1.00 COMPZN RPCOMP RURD P Rigged down test lines and laid down 20:45 21:45 Landing Jt. 1/9/2017 1/9/2017 0.50 COMPZN WHDBOP MPSP P Set Back Pressure Valve and tested 21:45 22:15 from below 1000 psi for 10 Min. Passed. 1/9/2017 1/10/2017 1.75 COMPZN WHDBOP NUND P Nipple down BOP. 22:15 00:00 1/10/2017 1/10/2017 0.75 COMPZN RPCOMP NUND P Continue to ND 13-5/8"BOPE 00:00 00:45 1/10/2017 1/10/2017 1.75 COMPZN RPCOMP NUND P NU Adapter and 3 1/8 5M Tree 00:45 02:30 1/10/2017 1/10/2017 0.50 COMPZN RPCOMP DHEQ P Test hanger void to 250/5000 psi 02:30 03:00 Good Test Sim Ops-Lower skate trough 1/10/2017 1/10/2017 0.25 COMPZN WHDBOP MPSP P Pull BPV and Set test valve via dry rod 03:00 03:15 1/10/2017 1/10/2017 1.50 COMPZN WHDBOP DHEQ P RU test equipment and flood lines, 03:15 04:45 Test tree at 250/5,000 psi for 5 minutes each on chart. RD Test equipment 1/10/2017 1/10/2017 0.25 COMPZN WHDBOP MPSP P Pull Test plug via dry rod 04:45 05:00 1/10/2017 1/10/2017 2.75 COMPZN RPCOMP FRZP P RU Little Red Services and test 05:00 07:45 treating equipment at 250/2,500 psi.- good test.FP well with 80 bbls of diesel©2 bpm at 700 psi ICP and 800 psi FCP. Pull back treating lines and disconnect. Utube well Sim Ops-RD Beaver slide Page 6/7 Report Printed: 1/17/2017 • • 0 Operations Summary (with Timelog Depths) 444w ..... ,, 2T-201 coo immm Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/10/2017 1/10/2017 0.50 COMPZN RPCOMP OTHR P Blow down lines and drain tree. 07:45 08:15 Sim Ops=Latch up and pull pipe shed away from the sub base. 1/10/2017 1/10/2017 1.25 COMPZN WHDBOP MPSP P Dry rod in BPV and secure well and 08:15 09:30 dress tree. Final SI Pressures=TBG=0 psi, IA= 0 psi,and OA=40 psi. Sim Ops-Latch up to motor complex and rock washer, pull complexes away from sub base Release Doyon 142 at 09:30 hours on 1-10-17 Page 7/7 Report Printed: 1/17/2017 KUP INJ III 2T-201 • ConocoPhillips S aL Well Attributes Max Angle&MD TD A(,c1S1<B lrlc ;/ Wellbore API/UWI Field Name Wellbore Status Incl(") MD(ftKB) Act Btm(ftKB) a1ps-, 501032023000 TABASCO INJ 36.77 1,946.98 4,175.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2T-201,2/8/2017 11 04:42 AM SSSV:NONE Last WO. 1/10/2017 8/17/1995 Vertcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLM 3,716.0 6/1/2016 Rev Reason'RECOMPLETION pproven 1/31/2017 ...................................................... HANGER;36.4 l�aii`I Casing Strings Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 41.1 2,244.2 2,025.6 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) "Set Depth(ftKB) "Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 38.5 4,123.8 3,781.3 26.00 J-55 BTC Tubing Strings Tubing Description Strang Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(2776)3(..9..Wl(lb/ft) Grade Top Connection TUBING 2017 RWO 31/2 2.992 36.4 3,081.4 9.30 L-80 EUE Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) • 36.4 36.4 0.21 HANGER FMC Gen IV tubing hanger 2.992 3,033.6 2,718.5 19.08 SEAL ASSY Baker 80-40 Locating Seal Assembly 2.992 3,038.5 2,723.2 18.96 PBR Baker 80-40 PBR 4.000 -A-AJCONDUCTOR;41.O-121.0• 3,061.1 2,744.6 18.38 PACKER Baker FHL Packer 2.890 3,079.0 2,761.6 17.93 LOCATOR Baker KBI-522 Locator 2.990 • • 3,079.6 2,762.2 17.91 SEAL ASSY Baker KBH-22 Anchored Seal Asembly 2.992 Tubing Description String Ma...ID(in) Top(ftKB) -Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection • TUBING 31/2 2.992 3,079.6 3,107.6 2,788.9 9.30 L-80 EUE-8rd Completion Details • Nominal ID • Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 3,079.6 2,762.2 17.91 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 SURFACE:41.1-2,2442 w 3,095.6 2,777.4 17.50 NIPPLE CAMCO D NIPPLE 2.750 3,106.7 2,788.0 17.23 SOS BAKER SHEAR OUT 2.992 Perforations&Slots shot GAS LIFT;2,976.8 ! Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) etm(86KB) (ftKB) (ftKB) Zone Data Q Type Com 3,355.0 3,527.0- 3,027.5 3,195.1 TABASCO, 9/27/1995 - 5.0 IPERF 2T-201 3,568.0 3,599.0 3,235.3 3,265.7 TE 1,2T-201 9/27/1995 5.0 IPERF Mandrel Inserts St ati SEAL ASSY;3,033.6 f>R'. on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Corn P68:1,038.5 1 2,976.8 2,665.1 Camco MMG 11/2 DMY RK 0.000 0.0 1/13/2017 1. Notes:General&Safety # End Date Annotation : '• 12/9/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PACKER;3,061.1 LOCATOR;3,078.9 PACKER;3,079.6 1t®I t. NIPPLE;3,085.6 r. SOS;3,106.7 I.-, lit IPERF;3,355.0-3427.0- • rI IPERF;3,568.0-3,599.0- PRODUCTION;38.54,123.8 ` • •• v Iii N: .0 I ° °u n X. a i co t o Q Q N L o o @ Y U' Q�- 0A E ro E Y O a ro [� O C N co U N 1 > j V d a C OC +o+ N 0 C +O+ 13 C15 Yo 0 a N O aC 0,, LU f0 !O to l� n t� ron � N a) G 0 Cr m J on v" e1 ., E C O In Q _r 0 U d d C C C C i -p v, Y L w p 0 0 ? 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Q O N U N 0 Z N 0 0 S 1= F"."; tCD c y E E OC/i ctba ' 1 H a` aF F°- .1.,or Tji • • .0,1 yy,_s� THE STATE Alaska Oil and Gas i�. 1,, ofALASKA Conservation Commission W,,Ti333 West Seventh Avenue " t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 77 Main: 907.279.1433 OFA =sly Fax: 907.276.7542 www.aogcc.alaska.gov Diana Guzman F U l•- Sr. Well Engineer JAN 0 9 201 Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, KRU 2T-201 Permit to Drill Number: 195-122 Sundry Number: 316-299 Dear Ms. Guzman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Pa44-e47/ Cathy P. oerster Chair DATED this IA-lay of June, 2016. RBDMS t.A JUN 1 3 2016 RECtiVED • • STATE OF ALASKA J U N 0 1 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 0 7'S ��//� APPLICATION FOR SUNDRY APPROVALS AOG6C 20 AAC 25.280 1.Type of Request: Abandon n Plug Perforations E Fracture Stimulate r Repair Well Operations Shutdown E Suspend 1- Perforate E Other Stimulate)! Pull Tubing F. Change Approved Program 1-- Plug Plug for Redrill fl Perforate New.Pool E Re-enter Susp Well E Alter Casing F.Other: I- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. ' Exploratory E Development E 195-122. 3.Address: 6.'API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service t 50-103-20230-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes E No F KRU 2T-201 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 • Kuparuk River Field/Tabasco Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 4,175' ' 3,832' • 3885 ' 3547' 1 1'7 Z none none Casing Length Size MD TVD Burst Collapse - Structural Conductor 80' 16" 121' 121' Surface 2,203' 9.625" 2,244' 2,026' Intermediate Production 4,085' 7" 4,124' 3,781' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): • 3355-3527,3568-3599 ' 3027-3195,3235-3266 3.500" L-80 3,107' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER SAB-3 PERMANENT PACKER , MD=3080 TVD=2762 12.Attachments: Proposal Summary D Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory E Stratigraphic E Development E Service F 14.Estimated Date for 15.Well Status after proposed work: 7/1/2016 Commencing Operations: OIL WINJ F - WDSPL E Suspended E y.�+� 16.Verbal Approval: Date: GAS E WAG t GSTOR E SPLUG Commission Representative: GINJ E Op Shutdown Abandoned E 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Diana Guzman @ 265-6318 Email Diana.Guzman@conocophillips.com Printed Name Diana Guzman e Title Sr.Wells Engineer Signature / ' Phone: 265-6318 Date u COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test CR------- Mechanical Integrity Test Location Clearance ❑ Other: 30p rrs t to Z 5 U 47,}✓Lvr a t/pre t/Gw�t t5 1- �0 2 SU n /�3� ,q Wa 1'I/er- /5 9'a� filed 10 a bl as-� joct.0 {r a b t �� 7 v h e top J c/- (2044-C25, -11 ,)` - Post Initial Injection MIT Req'd? Yes L`1 No ❑ ,L Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /i,--- �� 7 RBDMS l/JUN 1 3 2016 APPROVED BY Approved by: p 9644_44 , ,.� t GOMISSIONER THE COMMISSION Date: _/a /m n Form 10-403 Rei d G0�15 j/` - v , ,dv i applicetior\i valid for 12 months from the date of approval.44/�/j� Attachments in Duplicate • P'h lli �.C�1'1oCC� s Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 27,2016 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover the Tabasco Well 2T- 201 (PTD: 195-122). Well 2T-201 was drilled by ARCO Alaska, Inc as 2T-Tab-01, a Tabasco dedicated well back in 1995. One of the purposes of the Tabasco Dedicated Well test was to determine fluid and rock properties and the production potential of the Tabasco accumulation encounter at drill site 2T.All the test activities were conducted off-rig.Once the testing was completed,the well was freeze protected and completed by Nordic#1 on August and September of 1995. 2T- Tab-01 was granted approval to officially change its name to 2T-201 in 1998.By June of 1998,2T-201 was converted to a water injector.At the end of the same year,a rig workover was performed on the well to upsize the completion from 2%8"to 3 '/2"tubing after an unsuccessful CTU squeeze job left numerous hard cement stringers between 3231' and 3459'below the original packer. During the rig workover performed in 1998, a permanent premier packer was set at 3080' with an anchored seal assembly.Since the seals are anchored it is impossible to pull the tubing free and a pre-rig tubing cut will be necessary. The Report of Sundry Well Operations, 10-404,dated April 13, 1999 documents the permanent packer placement at 3080'(outside of the designated 200'MD prescribed by 20 AAC 25.412(b)).In order to stack a new packer,I would like to request permission for an alternate packer placement depth which is outside of the designated 200' MD prescribed by 20 AAC 25.412(b).The reasoning for this request is to avoid additional runs to mill and fish the existing permanent packer at 3080',to prevent losses by being isolated from the reservoir with a tested tubing tail plug and packer combo and to avoid setting the new packer in casing that has been subject to stagnant fluid between the deepest GLM and the existing packer. 2T-201 showed its first signs of subsidence in 2013 when heavy pick up weights and swings were observed. The drifting problems became more apparent during a drift performed at the beginning of May 2016. Only shorter toolstrings can drift the tight spots in the tubing.A MIT-OA was performed on May 24 unsuccessfully.A LLR of 1.3 GPM was established as part of the pre RWO testing. The purpose of this workover is to perform a subsidence repair and return the well to injection since it's one of two injectors at Tabasco.To accomplish the objective,the existing 3 '/2"tubing will be pulled from a planned pre-rig cut at 3056',the 7"production casing will be cut and pull above the top of cement,a new 7"production casing will be tied in and cemented from the casing stub,and new 3 '/2"stacked packer completion will be installed. If you have any questions or require any further information, please contact me at 907-265-6318 or Diana.Guzman@conocophillips.com. Since ely, ��-...-47 f.2.. Diana Guzman- Wells Engineer �.... CPAI Drilling and Wells • • 2T-201 Rig Workover Subsidence Repair (PTD #: 195-122) Current Status: This well is currently shut-in and awaiting pre-RWO well work. Scope of Work: • Pull the existing 3 ''h"completion to the pre-rig cut depth. • Cut and pull the 7"production casing above the top of cement. • Tie in and cement the new 7"production casing. • Install a new 3 Y2"completion with a stacked packer General Well info: Well Type: )njector MPSP: 1172 psi using 0.1 psi/ft gradient(Most recent SBHP= 1450 psi on 10/18/13) Reservoir Pressure/TVD: 1450 psi/2778' TVD(10.0 ppg)on 10/18/13 Wellhead type/pressure rating: FMC Gen IV/5M psi BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results: GMIT—IA passed August 2,2015(Pressured IA w/lift gas to 1350 psi) MIT—OA failed May 24,2016 Earliest Estimated Start Date: July 1,2016 Drillsite Petroleum Engineer: Vanessa Angel Workover Engineer: Diana Guzman Work:265-6318 E-mail:Diana.Guzman@conocophillips.com Pre-Rig Work 1. RU Slickline: a. RIH w/gauges and obtain a SBHP. b. Set plug with catcher on top at D-nipple at 3096'. c. Perform DDT to confirm plug integrity and MIT-T. d. Pull dummy valve from Station#1 for circulation during the RWO. 2. RU E-line a. Cut 3 '/2"tubing at 3056' and perform CMIT TxIA. 3. FT LDS's. 4. Set BPV. Proposed Procedure: 1. MIRU 2. Pull BPV. Circulate workover fluid.Obtain SITP& SICP, if still seeing pressure at surface,calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,ND tree,NU BOPE and test to 2500 psig. 4. Pull blanking plug&BPV.Screw in landing joint,BOLDS's,and pull tbg hgr to the rig floor. 5. POOH laying down 3 '/2"tubing. 6. RU E-line.RIH with SCMT to locate TOC.POOH 7. Set 7"RBP below TOC.PT/DDT the RBP.Dump sand.POOH with DP. 8. Cut the 7"casing above TOC. 9. Monitor OA for flow.ND BOPE.Remove tubing head.NU the BOPE to the casing head. 10. Spear casing and PU. 11. Reverse circulate out the Arctic Pack from the OA. • 2T-201 Rig Workover Subsidence Repair (PTD #: 195-122) 12. POOH laying down the 7"casing. 13. Set the test plug in the casing head. Shell test the BOPE.The BOPE will be on diverter due to a possible OA leak noticed on 5/24/16 during a MIT-OA to 1800 psi(established LLR of 1.3 GPM). 14. RIH with 9%"casing scraper to the 7"casing stub. POOH with DP. 15. Run new 7"casing. PT the 7"casing. NU cement head. 16. RU SLB cementers. Run the inner cementing BHA.Pick up to ensure indicating collet is latched and inner string is in proper position for cementing.Open cementing valve and pump cement job. 17. PT cementing valve for 5 minutes and POOH. 18. ND cement head. 19. ND BOPE. Land 7" casing in the slips. Cut excess casing off. Install packoff. NU new tubing head and BOPE. InstallPV and blanking plug. Shell test BOPE. Pull BPV. 20. PT the casing. Record test on chart for 30 minutes. 21. RIH with wash string and circulate sand out from on top of the RBP. POOH with DP. 22. RIH with RBP retrieving assembly. Retrieve RBP. POOH laying down DP. 23. Run new 3 V2"completion with poor boy and stacked packer. 24. Spot a balanced pill of CI brine in the tbg and IA to above the new packer. 25. Engage poorboy overshot and space out lft from fully located. 26. Drop the ball&rod and set packer.PT the IA to confirm packer is set.Shear the PBR,space out,mark the pipe,and pull out of the sealbore. 27. MU tubing hanger. Swap the well over to corrosion inhibited brine. Land the hanger and RILDS. 28. PT tubing.Pressure test the IA.`' 29. Bleed T and IA. Shear the SOV.Bleed tubing and IA pressures to zero. Monitor for flow. 30. Pull landing joint. Install BPV. Pressure test IA to test BPV from below. 31. ND BOP stack,NU tree. Pull BPV and install test plug.PT tree and tubing hanger packoffs. 32. Remove test plug. 33. Freeze protect w/diesel. Set BPV. 34. RDMO. Proposed Post-Rig Work: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline.Pull SOV,ball&rod,catcher and plug. Set up for injection. 4. Handoff to operations to put back on injection. 0 • - - 2T-201 ConocoPhi I I ps Proposed Completion Subsidence RWO 4 Cemented OA from TOC -Surface io Casing-7" 26#, L-80 Hydril 563 From TOC-Surface Casing-9-5/8"40#, L-80 BTC @ 2244' MD 3 1/2"x 1 1/2" MMG Injection Mandrel f—PBR ZqB� — � ' _J f— Baker FHL Packer @-2980' MD ] 0 — 2.812" DS-Nipple Nipple 5 Baker Poor-Boy Overshot @ 3055' MD k Pre-Rig Tubing Cub @ 3056' MD t Tubing Cut To be Performed Pre-Rig Baker KBH 22 anchor seal assembly - in _ ' -'41----Baker SBA-3 Permanent Packer @ 3080' MD 2.75" D-Nipple @ 3096' MD Tubing-3-1/2"9.3#, L-80, 8rd EUE lo ill CA-2 Plug to be set Pre-Rig @ 3107' - l a f Shear Out Sub @ 3107' MD 33') ITABASCO @ 3355'-3527' TE_1 @ 3568'-3599' m Casing-7"26#, J-55 ETC @ 4124' Date: May 25,2016 Drawn By: Diana Guzman S KUP ii 2T-201 :;aa Well Attribu Max An g111110 I D TD g Ataska Inc, Wellbore APVUWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) Lovoophi:hp: 501032023000 TABASCO INJ 36.77 1,946.98 4,175.0 ... Comment H2S(ppm) Date Annotation End Date 1 KB-Grd(k) Rig Release Date 2T-201,5/31/20169.30:39 AM SSSV:NIPPLE Last WO: 12/25/1998 11 8/17/1995 Vertical schematic..(actual) Annotation Depth(kKB) End Date Annotation Last Mod By End Date Last Tag:SLM 3,759.0 4/25/2016 Rev Reason:TAG pproven 5/1/2016 HANGER;36 4 'Pt , -Casing Strings . Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)... Wt/Len g...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(kKB) Set Depth)kKB) Set Depth)TVD)... Wt/Len(1..Grade Top Thread SURFACE 95/8 8.835 41.1 2,244.2 2,025.6 40.00 L-80 _BTC Casing Description OD(in) ID(in) Top(kKB) Set Depth)ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 38.5 4,123.8 3,781.3 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..I Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 36.4 3,107.6 2,788.8 9.30 L-80 EUE-8rd iir Completion Details t 4 Nominal ID I Top(kKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 3 36.4 36.4 0.21 HANGER FMC GENT IV TUBING HANGER 3.500 �- CONDUCTOR;41.0-121.0- 514.3 513.0 8.79 NIPPLE CAMCO DS NIPPLE 2.812 3,078.6 2,761.2 17.94 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSEMBLY 2.992 3,079.5 2,762.1 17.91 PACKER BAKER SAB-3 PERMANENT PACKER 3250 3,095.5 2,777.4 17.50 NIPPLE CAMCO D NIPPLE 2.750 3,106.7 2,788.0 17.23 SOS BAKER SHEAR OUT 2.992 i NIPPLE;514.3 at Perforations&Slots i Shot Dens Top(ND) Btm(ND) (shots/ Top(kKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com • 3,355.0 3,527.0 3,027.5 3,195.1 TABASCO, 9/27/1995 5.0 IPERF 2T-201 3,568.0 3,599.0 3,235.3 3,265.7 TE_1,2T-201 '9/27/1995 5.0'IPERF Mandrel Inserts St ati N Top(ND) Valve Latch Port Size TRO Run Top(MB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,026.7 2,712.1 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/16/1999 SURFACE;41.1-2,244.2 Notes:General&Safety End Date Annotation 12/9/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT;3,026.7 I I SEAL ASSY;3,078.8 MIN IMPACKER;3,079.5 NIPPLE,3,095.5 1 F I SOS 3 106 7 11 — Nem.- IPERF;3,355.0-3,527.0—. .,,.. I..- -.el IN.— IPERF;3,568.0-3,599 0 PRODUCTION;38.5-4.123.8 • • MAY 17 Atti WELL LOG TRANSMITTAL#903273382 L, OCC To: Alaska Oil and Gas Conservation Comm. May 13, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 995015/. i. K.BENDER RE: Injection Profile : 2T-201 Run Date: 4/28/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-201 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20230-00 Injection Profile Log 1 Color Log 50-103-20230-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A - EOPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating SCANNED , Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ,,aizadtw ..-eA'-erC • • /q5-lz Guhl, Meredith D (DOA) From: Richmond, Lorna K <Lorna.Richmond@conocophillips.com> Sent: Wednesday, February 17, 2016 5:24 PM To: Guhl, Meredith D (DOA) Cc: Harris, Vanessa A; Elgarico, Richard E; Lemke, Sandra D Subject: RE: Mud log for KRU TABS 2T-201, PTD 195-122 Hi Meredith I am the GKA Geoscience Manager for ConocoPhillips. To the best of our knowledge, no mudlog was completed for this well. Please let me know if you require anything further from us. Best Regards, Lorna From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday, February 12, 2016 9:57 AM To: Lemke, Sandra D <Sandra.D.Lemke@conocophillips.com>; Elgarico, Richard E <Richard.E.Elgarico@conocophillips.com> Subject: [EXTERNAL]Mudlog for KRU TABS 2T-201, PTD 195-122 Hello Sandra and Ricky, I'm looking for a mudlog for KRU TABS 2T-201, PTD 195-122, completed September 28, 1995. According to the AOGCC well file history a mudlog was required on the Permit to Drill form, but was never received. Was a mudlog completed on this well? If so, can CPAI please provide, at minimum, a digital image file of the mudlog for the AOGCC archive? Thank you, Meredith SCANNED MAY 1 9 2016 Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl(caalaska.gov. 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: 3i1' _, ~~ I ~~ i ~~V ~~ I '~~~~~ st~(= l~ Z01C~ ~~sk~ ~ G~ ~„ e~trtis. ~'#°~~~+a~r4~g~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 21St. The corrosion inhibitor/sealant was pumped July 30th, 31St 2010. 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 Loveland ~, _, ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off . _..~... Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 ~R ~k ~T oen ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date _, _, Corrosion inhibitor Corrosion inhibitor) sealant date ft bbls ft al 2B-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7131!2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n!a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-20t .50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7!30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 MEMORANDUM To: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-201 KUPARUK RIV U TABS 2T-201 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.LSuprv J~'jf'`~ Comm Well Name: KUPARUK RN U TABS 2T-201 API Well Number: 50-103-20230-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090608130647 Permit Number: 195-122-0 .. Inspection Date: 6/1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-201 Type Inj. W TVD 2763~~ IA 390 1700 '' 1670 1670 ~~ P.T.D i9slzzo TypeTest SPT Test pst ]soo ~ ( pA z2o zlo zls zlo Interval 4YRTST p~F P '~ Tubing 900 900 - 900 900 - NOtes: lwell inspected; no exceptions noted. Wednesday, June 10, 2009 Page 1 of 1 Scblullbepger NO. 4468 Schlumberger ·DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 - r1 ~ 1 2007 ~,<í'..~\...\MED 0 y '" ",J1ut'd~Jti- Field: Kuparuk Well Job# Date BL Color CD Log Description 2N-327 11839673 PERF/SBHP .;)O~ ~ {)G"q 1 0/24/07 1 2T-201 (REPLACES 11839656 INJECTION PROFILE ù-¡:C-IG\'S"'"'-I::J;:) 09/03/07 1 1A·23 11837520 PRODUCTION PROFILE ¡OJ l-ðC:P, 10/04/07 1 2M-09A 11846446 WFL t):t..Q.. IC':(_ -(--At) 10/04/07 1 31-08 11837517 LDL ,<¿'{", - (WI) 1 0/02107 1 2M-24 11839670 PRODUCTION PROFILE ìoC\ i;:) -()5l) 10/03/07 1 1J-102 11846451 INJECTION PROFILE 0-¡:Q.. ~ -/tò 10/10/07 1 1Y-02 11837516 INJECTION PROFILE i JT0.1 '5í~ -059 10/01/07 1 1E-112 11846450 INJECTION PROFILE Uï(l ::::J,..U -rA ( 10/10/07 1 2T-12A 11839669 LDL J«Ú - I Q 5<" 10/02/07 1 2B-07 11837522 INJECTION PROFILE UT ~ , "kL/ -r-ÇJ<..( 10/05/07 1 1E-12 11846447 DDL , -'¡(.J - N" Ò 10/08/07 1 2N-327 11839671 SCMT '+0 '1--- o'=> '9 10/23/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. £3 10/25/07 . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Ke1¿/t(D 7 DA TE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-201 KUPARUK RIV U TABS 2T-201 ?7 -S ... \ \0\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ::J3I2-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TABS 2T-201 API Well Number: 50-103-20230-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603 I 50024 Permit Number: 195-122-0 Inspection Date: 6/2/2007 /' Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-201 Type Inj. w TVD 2763 IA 560 2550 2500 I 2490 P.T.D 1951220 TypeTest SPT Test psi 1500 OA 225 225 225 I 225 Interval 4YRTST P/F P v Tubing 1875 1875 1875 I 1875 Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. ,,/ i~ JUN 2 1 ZOO? Wednesday, June 06, 2007 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 2T-201 02/24/04 Rogers / Sauvageau NA 0 P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE I NJ 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 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 2004-0224_MIT_KRU_2T-201.xls 2/2512004 ~(GAtNHf~E(} M}~~~ 1. 5 2004 MEMORANDUM TO: Randy Ruedrich Commissioner P.I. Supervisor ~(~"~[~i State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 14, 2003 SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 2T Pad Kuparuk River Unit FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I We,,I 2T-36 I Type,,j.I S I~.v.D. I~ I Tubingl~0 I~0 I~0 I~0 I lntervall 4 I P.T.D.I 1951020ITypetestl P ITestpsil 3000 I Casingl 1300I 3050I 3000I 3000I P/F I --P I Notes: OA 500 psi. pretest 720 psi. during test. 4.1 BBL. Pumped. I WellI 2T-201 ITypelnj. I SI T.V.D. I~ I Tu~,.,/ ,~00 I~00 I,~00 I ~,00 I,nterva, I4I P,T,D.I 1951220 ITypetestl P ITestpsil 3000 I Casing/ 1350I 2875I 2820I 2800I P/F I ~P I Notes: OA 350 psi. during test. 1 BBL. Pumped. WellI IType,nj.IN I T.V.D. I ITubing I I I I Ilntervall 4 P'T'D'I IType testl P ITM psil I Casing I I I I I P/F I P Notes: WellI P.T,D.I Notes: WellI Type Inj. P.T.D.I 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 Test's Details I traveled to C/P's Kuparuk River Field to witness 4 year MIT's. No failures witnessed. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 2 Number of Failures: 0 Attachments: Total Time during tests: 2 hrs. CC: MIT report form 5/12/00 L.G. ~CANNED AUG 0 & 2003 2003-0614_MIT._.KRU_2T-201_jc.xls 6/24/2003 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: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/2T 06/14/03 Sauvageau/Brake - APC John Cdsp Well 12T-t 0 P.T.D. IIS60960 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I TypeInj I ~I I T"bing I Interval Type Test Test psi I 1500 I Casing I 11501 30801 30501 30401 P/F Well 12T-t8 P.T.D. 11950170 Notes: ] ITypeTestPI Test psiI 1500 I Casing I 18001 29701 29501 29401 P/F Well 12%26 P.T.D.I J950820 Notes: Type Test Test psil 1500 I Casing I 10201 30101 30001 30001 P/F Well 12%28 P.T.D.I ~950920 Notes: Type Test Test psiI 1500 I CasingI 13401 3o501 30001 29801 P/F . P.T.D.I1950750 TypeTest Test psiI 1500 I Casing I 2401 29501 29251 29101 P/F Notes: P.T:D;I~951020 TypeTest Test psiI 1500 I Casing I 13001 30501 30001 3oooI P/F Notes: P.T.D,~.I~95~220 TypeTest Test psiI 1500 I Casing I 13501 29501 29201 28751 P/F . Notes: Carried MIT out for one hour Pressure at 45 min 1100/2820 1 hr 1100/2800 Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 05/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 2003-0614_M IT_K RU_2T-10_-18..-26_-28_-29_-36_-201 .xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) 6~25~2003 KRU 4 yr M1T's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23 -0800 From: "NSK Problem Well Supv" <nl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls)(See attached file: MIT KRU 2K 06-14-03 .xls) [~,MIT KRU 2T 06-14-03.xls MIT KRU 2T 06-14-03.xls l Name:Type: EXCEL File (application/msexcel) I' Encoding: base64 ~MIT KRU 2K 06-14-03.xls Type: EXCEL File (application/msexcel)~I Encoding' base64 ..... i I of I 6/25/2003 1:45 PM 4-13,59 ;12:081~1 ; ARCO ALASKA-~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPOE? OF SUNDRY WI=iL OPERATIONS Opef6tion ShutdOwn ._ PuI~ ~J bif'~, i. Operations perlo[med: 2. Name'of Opefdlor: ARCO Ak3ska, Inc. 3. Address: P.O, Box 1 (~360 Anchorag_e, AK 99510-O3Z~ 4. Location bf well al {urface: 239' FSI. 555' F-WI, Sec, 1, T11 N, R8E, UN Af top of productive intervoh 43' FNL 689' FEb Sec. 11, 111N. RSE, UN At effective depth: Alter casing . 5, Type of Well: Development _., Exploratory ., Strafigraphlc ~ Service __,X, At total depth: 87' FNL 843' FEb Sec. 11, T11N. RBE, UN '12. Present well cana~lion summary /)07 276 7542;# 2/ 2 l~ugglr~ ... Perforate _ r, fepalr well . Other X Converted Well 6, Datum of elevation (Df br K~feel): RKB 41 ?. Unit or Property: Kuparuk River Unit 8. Weft number; ' 2%201 ~i~l~'rmit numbei/appraval number: 95 ~22 / 398-258 10. APl number, 50 103-20230 11. Field/POol: Kuparuk River Field Tatar Death: measured 4175 feet Plugs (meosurecO Irue vortical 3832 reef EffecBve Deptt measured 3885 feel Junk (measured) true vertlca~ 3547 feel Casing LenCh Size Cemented Conductor 80' 16" 180 ~x AS I Surface 2203' 9-5/8" 08o sx As il~ a ~4o sx elms Measured depth True verlic~l depth 121' 121' 2244' 2026' Production 4083' /" 230 Sx (';Ir~s G 4124' 3782' Liner Perforation Depth measured true vorlJcal 3355'-352/', 3568'-3b~ 3L"T2/'-3195', 3235'-326( Tubing (size, grade, and measured depth) 3.8% 9,3#, L-80 @ 3107' Packers and SSSV (type and measured depth) Bak¢;r SAB-3 pk~ ¢__ 3080' 13. SFmnulation or Cemenl squeeze summary Intervals treated (measured) Converted ~o Water Injector 6/98 Ir'fl'ervois treated (measured) 14. R~pm"senlotWe Dally Average Produci~n or Injecllen Data Prior to well oporallon OII-Bbl Gas-Mcr Wuter-Bbl Casing Pressure rtJbir~l Pres,sure Su._bs. eClUOr)r to operation 15, Attachments J16. $1afus of well ~la~lflccflion as: Copies of I.ags and Surveys run ~ Dally Raporl of: Wail Op, eratlons _X OII C-)as ~ 11. I hereby certify that th~ foregoing is true anti COrre t to the b-"~st of my knowledge. Signed ¢-~,4,~. )/~~ title: Tabasco Team Leader la~ul ~zzof~,i (~.le~11on.-. ? C.~I Tom ~l~.kway 2Y~3-4 f35 Suspended _ Service _X Form 1U-404 Rev 06/15/88 SUBMIT IN DUPUCATb Date: 2/11/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:2T-201 WELL ID: 999293 TYPE: AFC: 999293 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:12/09/98 START COMP:12/08/98 RIG:NORDIC # 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20230-00 12/08/98 (C1) TD: 4175' PB: 4043' 12/09/98 (C2) TD: 4175' PB: 4043' 12/10/98 (C3) TD: 4175' PB: 4043' 12/11/98 (C4) TD: 4175' PB: 4043' 12/12/98 (C5) TD: 4175' PB: 4043' 12/13/98 (C6) TD: 4175' PB: 4043' 12/14/98 (C7) TD: 4175' PB: 4043' MOVING RIG ON 2T PAD @ 0 MW: 0.0 SUPV:DONALD L. WESTER Prepare rig for turn key rig move. Move rig from iQ pad to 2T pad. N/D TREE MW: 8.6 SW SUPV:DONALD L. WESTER Continue to move rig. MIRU. Accept rig @ 0800 hrs. 12/9/98. Circulate kill fluid. SAFETY STAND DOWN MW:10.1 BRINE SUPV:DONALD L. WESTER Continue to pump kill fluid. N/D tree and NU BOPE. Rig on safety standdown. TESTING BOPE TO 3500 PSI SUPV:DONALD L. WESTER Continue safety stand down. NU BOPE. MW:10.1 BRINE PULL AND LAY DOWN 2-7/8" MW:10.1 BRINE SUPV:DONALD L. WESTER Test BOPE to 300/3500 psi. Hydril 250/2500 psi failed. Change out. Test Hydril to 300/2500 psi, OK. Test BOPE. Circulate around 10.1 ppg brine fluid. LOADING PIPE SHED W/ 3-1/ SUPV:DONALD L. WESTER Pull 2-7/8" tubing. MW:10.1 BRINE P/U 3-1/2" DP 3 JOINTS FR MW:10.1 BRINE SUPV:DONALD L. WESTER Continue to pull 2-7/8" tubing. Load pipe shed w/ DP. P/U BHA %1 make up, break out, clean box & pin, remake up and torque up pipe. Date: 2/11/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/15/98 (C8) TD: 4175' PB: 4043' 12/16/98 (C9) TD: 4175' PB: 4043' 12/17/98 (CI0) TD: 4175' PB: 4043' 12/18/98 (Cll) TD: 4175' PB: 4043' 12/19/98 (C12) TD: 4175' PB: 4043' 12/20/98 (C13) TD: 4175' PB: 4043' 12/21/98 (C14) TD: 4175' PB: 4043' 12/22/98 (C15) TD: 4175' PB: 4043' 12/23/98 (C16) TD: 4175' PB: 3885' CIRCULATE AT TOP OF PACKE MW:10.1 BRINE SUPV:R. L. MORRISON JR. Spear into fish. Attempt to pull packer, release mechanism appeared to shift but packer did not release. Jar on packer. Attempt to release. Release spear. RIH with BHA %2 to washover packer. RIH W/BHA %3, MILL ~1 35% MW:10.1 BRINE SUPV:R. L. MORRISON JR. Mill on packer with washover shoe from 3186' to 3187' Losing mud at 1-3 bpm. Spot hi-vis HEC pill. No fluid losses while increasing viscosity. Continue to mill on packer from 3187' to 3188', packer possibly spinning. Pumping at 1 bpm losing 24 bph. Started dry drilling. ON BOTTOM WITH SPEAR MW:10.1 BRINE SUPV:R. L. MORRISON JR. Mill on packer with washover shoe from 3188' to 3199' Continue to fish packer. POOH WITH WO SHOE %3.WASH MW:10.1 BRINE SUPV:R. L. MORRISON JR. RIH w/spear assembly. Jar on fish. No movement. POOH. RIH with washover pipe and mill. Mill with washover shoe from 3190' to 3191.5' LAY DOWN FISH, RECOVERED MW:10.1 BRINE SUPV:R. L. MORRISON JR. Wash over packer. POOH. RIH with chemical cutter, could not get deep enough to make cut. Bullhead brine down tubing. RIH with chemical cutter. Make cut at 3199' ON BANK W/OS, NO FISH, SA MW:10.1 SUPV:R. L. MORRISON JR. RIH with spear and spear fish. POOH with packer. BRINE WORKING ON SCR, PIPE ON B MW:10.1 BRINE SUPV:R. L. MORRISON JR. Work overshot over fish. POOH. No fish. RIH. Mill over tail pipe. CIRCULATE @ 3660' MW:10.1 BRINE SUPV:DONALD L. WESTER RIH w/BHA %10, wash over shoe. Pump high vis HEC pill. Start milling over fish @ 3202' to 3208' broke free. Clean out to 3276' reaming out cement ledges. RUNNING 3-1/2" COMPLETION MW:10.1 BRINE SUPV:DONALD L. WESTER Clean out from 3261' to 3697'. Circulate hole clean frac sand. Clean out from 3697' to 3885'. Run USIT log 3845' up to 2867' Date: 2/11/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 12/24/98 (C17) TD: 4175' PB: 3885' 12/25/98 (C18) TD: 4175' PB: 3885' RELEASED RIG @ 0300 HRS F MW:10.1 BRINE SUPV:DONALD L. WESTER Run 3.5" completion. ND BOPE, NU tree and test to 250/5000 psi. Freeze protect well. RIG RELEASED @ 0600 HRS 1 SUPV:DONALD L. WESTER Release rig @ 0600 hrs. 12/25/98. MW:10.1 BRINE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert C h riste nso n,,/,~/~ DATE: Chairman December 19,1998 THRU: FILE NO: Blair Wondzell, ~ P. I. Supervisor /,Zj'=jb FROM: Larry Wade,~,..,.d~- SUBJECT: Petroleum Irfspectof .DOC BOP Test Nordic 3 KRU 2T-201 PTD 95-122 December 19,1998: I traveled to Kuparuks 2T-201 to witness a BOP test on Nordics newest rig. ! found the rig lacking in a couple of areas. They didn't have the standing orders posted on the rig and lacked a gas detector log on the rig. We also couldn't find a wrench for the manual valve on the top drive. All these problems are fixed to my satisfaction. I raised the question about having an MSDS manual on the rig. The answer of the ARCO and rig rep was that all the pertinent data was on the computers in the camp, which is located on 2A pad and that all the rig employees were welcome to the information. The rig itself is well thought out as far as the design. It's a little busier than Nordic 2 but has a lot of good improvements. The BOP test went slow but well with the new crews trying to get used to equipment and procedures. SUMMARY: I witnessed a BOP test on Nordic 3, 4 hours, 0 failures. Attachments: ab9glsfe.xis cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Nordic Rig No. 3 PTD # 95-122 ARCO Rep.: KRU 2T-201 Rig Rep.: 7" Set @ 4175' Location: Sec. Weekly X Other DATE: 12/19/98 Rig Ph.# Bobbie Morrison Mike Spaulding 1 T. 11N R. 8E Meridian Umiat Test Pressures 250/3000 MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: ok Well Sign X;X' Upper Kelly/IBOP Housekeeping: ok (Gen) Drl. Rig XX' Lower Kelly/IBOP PTD On Location X Hazard Sec. XX Ball Type Standing Order Posted X Inside BOP Test Quart. Pressure P/F 1 250/3000 P 1 250/3000 P 2 250/3000 P I 250/3000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Quan. Test Press. P/F 1 250/3000 P 1 250/3000 P 250/3000 P 250/3000 P 250/3000 P 250/3000 P 250/3000 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 12 250/3000 P 36 250/3000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure Visual Alarm 200 psi Attained After Closure minutes 12 sec. x x System Pressure Attained minutes 50 sec. X X Blind Switch Covers: Master: x Remote: x' x x Nitgn. Btl's: 2500-2550 X X 2575-2540 X X 2, 750 I 2,150 Psig. Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to tlqe AOOCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: Grig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade FI-021L (Rev.12/94) Abgglsfe.xls MEMORANDUM TO: THRU: David Johnsio~, -~--- Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 12, 1998 FILE NO: ab9kllfe.doc FROM: Chuck Scheve, ~- ~; SUBJECT: Petroleum Inspector BOPE Test Nordic 3 KRU 2T-201 Saturday, December 12 1998: I traveled to Arco's KRU 2T Pad to witness the initial BOPE Test on Nordic Rig 3. As the attached AOGCC Test Report shows the test lasted 4 hours and there were no failures. The lower pipe and blind rams could not be tested at this time but will be t~'sted as soo-'-'---n as the completion tubing is laid down. The Rig was clean and all related equipment appeared to be in good condition. SUMMARY: I witnessed the initial BOPE test on Nordic Rig 3 working over Arco's KRU 2T-201 Well. Nordic 3, 12/12/98, Test Time 4 hours, 0 Failures Attachments: ab9klife.xls X Unclassified Classified Unclassified with Document Removed ...... I' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: ~ Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X 12/12/98 Workover: X DATE: Nordic Rig No. 3 PTD # Rig Ph.# ARCO Rep.' Don Wester 2T-201 Rig Rep.: Lance Johnson T. R. Meridian Umiat Set @ Location: Sec.~ Weekly Other 659-7653 Well Sign NO Drl. Rig OK Hazard Sec. YES Test FLOOR SAFETY VALVES: Quan. Pressure Upper Kelly / IBOP ~ I 250/3,000 Lower Kelly / IBOP 1 I 250/3,000 Ball Type I 250/3,000 Inside BOP I 250/3,000 MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gert) PTD On Location N/A Standing Order Posted Yes P/F P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check VaNe Quan. Test Press. 1 250/3000 I 250/3,000 I 250/3,000 I 250/3,000 2 250/3,000 N/A N/A P/F P P P P N/A Test CHOKE MANIFOLD: Pressure P/F No. Valves 12 250/3,000 P No. Flanges 36 250/3,000 P Manual Chokes ~ Functioned P Hydraulic Chokes ~ Functioned ,P ACCUMULATOR SYSTEM: System Pressure 2900 I Pressure After Closure 1950 ! MUD SYSTEM: Visual Alarm 200 psi Attained After Closure~ minutes ~5 sec. Trip Tank OK OK System Pressure Attained 1 minutes ~5 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: Yes Remote: Yes Flow Indicator OK OK Nitgn. Btl's: 4 bottels at Meth Gas Detector OK OK · 2200 Psig. H2S Gas Detector OK OK - Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 18 Repair or Replacement of Failed Equipment will be made within 0 days.~lotify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Blinds and Lower pipe rams to be tested when tubing, is out of hole. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector F1-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO I I I I Waived By: Witnessed By: abgtdlfe Chuck Scheve STATE OF ALASKA ALASKA 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 m Time extension _ Stimulate _ Pull tubing X Variance__ Perforate__ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 239' FSL, 555' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 43' FNL, 689' FEL, Sec. 11, T11 N, R8E, UM At effective depth At total depth 87' FNL, 843' FEL, Sec. 11, T11N, R8E, UM 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) 41' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-Tab-01 9. Permit number 95-122 10. APl number 50-103-20230 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical Casing Length Structural Conductor 80' Surface 2203' Intermediate Production 4083' Liner 4175 3832 4043 3702 Size 16" 9.625" 7" Perforation depth: measured 3355'-3527', 3568'-3599' true vertical 3027'-3195', 3235'-3266' Tubing (size, grade, and measured depth) 2.875", 6.5#, L-80 @ 3220' Packers and SSSV (type and measured depth) Baker 'FH' Pkr @ 3189' MD, Camco 'q'RDP-1A" @ 2991' feet feet feet feet Plugs (measured) Junk (measured) Cemented 180 sx AS I 680 sx AS III & 240 sx Class G 230 sx Class G Measured depth 121' 2244' 4124' True verticaldepth 121' 2026' 3782' RECEIVED Alaska 0il & 6as Cons. Anchorage 13. Attachments Description summary of proposal X Contact Paul Mazzolini at 263-4603 with any questions. Detailed operation program __ BOP sketch X 14. Estimated date for commencing operation October 15, 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service 17 I hereby certify that the foregoina is true and correct to the best of my knowledge.. _ · ~"?-- /// /"'/~/ ~"~ /¢¢C'~::~/'¢Y-"'"~T-~e~n~L~a~d; Signed~'""~/ ~ ~/~/' ~,/'~ Title rtuparu~. FOR COMMISSION USE ONLY IConditions of approval: Notify Comrflission so represe, rltative may witness IApproval Plug integrity BOP Test _v/ Location clearance __ OO~J .. I Mechanical In~grity Test_ Subsequent form require 1 Oavid ",N, Johnston Approved by the order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PRE-RIG WORK: TABASCO 2T-201 GENERAL WORKOVER PROCEDURE 1. RU wireline unit. Pressure test 2-7/8" x 7" annulus to 3000 psi for 15 minutes. This well has been converted from a producer to an injector so all GLM's have been dummied off. 2. RIH and pull DV from GLM #3 @ 3119'. An unsuccessful CTU squeeze cement job in April 1998 may have left cement in the GLM's. If the DV can not be pulled with wireline, continue as outlined below: A. RU perf guns on wireline and RIH. B. Shoot perfs in the 2-7/8" tubing just below GLM #3 @ 3119' 3. Set BPV in tubing and install VR plug in annulus valve. 4. Remove flow riser and gas lift riser, well house and scaffolding as required. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 10.1 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE to 3000 psi. Record results. 4. Screw in landing joint. POOH w/2-7/8" tubing. Lay down all tubing and jewelry. 5. PU DP and RIH with overshot. Latch onto slick stick and pull retrievable packer free. POOH with packer and tubing tail. 6. PU bit and scraper. RIH cleaning out well to PBTD. Circulate hole clean. 7. Set storm packer and ND BOPE. Change out tubing head and packoff. 8. NU BOPE. Pull storm packer and verify well is dead. Circulate well clean. POOH laying down DP. 9. RIH with 3-1/2" tubing completion and permanent packer as per attached schematic. 10. ND BOPE. NU and test tree. Freeze protect well with diesel. Lower Limit: 5.5 days Expected Case: 7.0 days Upper Limit: 8.5 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running new completion 2T-201 WO TAB, 09/23/98, v.1 Surface csg. 9 5/8' 36~ J-55 BTC (+/- 3400' MD / 3071' TVD) Production csg. 7" 26# J-55 BTC-Mod (4175' MD) Tabasco 2T-201 Proposed Completion K. 3-1/2" 5M FMC "Prudhoe Bay" Gen 4 tubing hanger w/3-1/2" L-80 EUE8RD pin down J. 3-1/2' 9.3# L-80 EUE8RD tubing to surface I. 3-1/2" Camco 'DS' landing nipple with 2.813" No-Go profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE8RD. Set at +/- 500' MD. H. 3-1/2" 9.3# L-80 EUE8RD tubing to nipple G. 3-1/2" x 1-1/2" Camco 'MMG-2' mandrel w/DY & latch, 3-1/2" x 6' L-80 pups installed above and below, BTCM x EUE8RD F. I jt 3-1/2" 9.3 # L-80 EUE8RD tubing E, Baker 7" x 3-1/2" 'SAB-3' permanent packer w/K-22 seal assembly, 6' handling pup on top, set at +/- 3265' MD D. Pup jt 3-1/2" x 10' 9.3~ L-80 EUE8RD tubing C. 3-1/2" Camco 'D' landing nipple with 2.75" ID No-Go profile, EUE8RD B. Pup jt 3-1/2" x 10' 9.3# L-80 EUE8RD tubing A. Baker 3-1/2" shear out sub (3500 psi shear). Tubing tail at +1- 3285' Tabasco Interval Perforations: 3355 - 3527 3568 - 3599 PBTD @ 4043' TAB, 9/23/98, v.1 S TACK .M. EA S UR. E3~E~¥TS Company/Operator Rig name Well Name ' Date ii Inside Rotary Beams , , ....... .;.. --'::.-:?~: ';-,::-..--':::..,t;~-::.',--:-:~. -'-~.':,.:.','.'¢:}~---::: 't::-'.'.:.",".-:',':'-":'-;.: .'<-:".-' J ' [- . g .O,P. Rotary to bottom 1- - , ,*, FLc,.~c,,u Ram ~t?Yi;'e'f:'':-- ~'q~¢;\ ~"~e ~!.'.-:.':[.~-'. ' ~ ...... ~ -- .'--.'Rating :'"'-..:t~t~(~::~,)'.~.:!...;?.:'~l':-'.:¢~.'.'~.~;:/. i -' -- i-~ 5- ---:; .- - -,- ::: ~i Rarrl : ~,~ I , ~ ~ -:;'-:~: .:-; ,..;; - :.>:., I ~-:_i I - A -' ! . :-'--:'-'* '-'"~'" ':: :--,'--'.-..;:-~i: ::.,_ .,.-.~ :".-, 7:, 't :~,,.:.-,::<-:~:~.:!-.::-:: ':'.:: ".-.' [ ' ~ ' '~ ' ~ --,f , , -, - PfE~$:st,lre-',-~..,~-.::----~'.:..,t :.u'...;.:';:'.::~:-;.-.-;;-..;:. ! ,' ~ ~ - ,, i - ~ ~-: Ram } - B ,- --..,. .... 1~' , . , ~. -.-.-,:..=.~~ .... Y ... '~.~ .......................:...~: ! I ~q~, t -':~-':~ '":":":'.'-.-". :',::~.--'.':':.~:-:~-, ..... :~,.,_~-~-.,-'::.:-:: .... I !. ~ ~'~ '~' ::" ' ~ · . ¢ ,=;;4¢~ ' , "- I - '- - ' -- .~ -- ,. .. :~:..,,o:~-~ ,,. ,.,b, ... -.:..: - -: - ¥ -' ".- ....... ,, ,~ ~ ,;,' '- ' '::" -.-~,'~'f-,~".-'-.'": ':~.:' ;"::~-'~:--';': ,".-'.;.¢-" .~:~i:~'-'- :7 ;' ,v , ::':'-"---':':'~:.Z-: ..:i..' '~ - ~1 L:'.:-' ....... ,.'---",~:-.:'-~, ....... ~uthor: Jack Hartz at DOA-- .... 'CC Date: 3/9/98 3:00 PM Priority: Normal TO: Steve McMains .CC: Bob Fleckenstein Subject: Tabasco Steve, See email from jaCk Walker, ARCO. They want to change the well name of their Tabasco well to 2T-201. I agree this will fit databases better and should not be a problem. Copy this email to the file and go ahead and make the change. Contact Mr. Walker if you need any more paper work. Thanks, Jack Forward Header Subject: Tabasco Author: JAWALKER@mail.aai.arco.com ("Jack A Walker") at CC2MHS1 Date: 3/9/98 2:23 PM Jack, I left a phone message about this, but thought I would try your e-mail on a couple of questions regarding Tabasco: 1) We would like to change the official well name for 2T-Tab-01 to 2T-201 for future correspondence both with AOGCC and internal. The 2T-201 well name more easily fits in our computer database. Does this e-mail suffice for the name change? If not, please advise. 2) Did you receive the letter application for injection and production practices for the pilot waterflood we proposed? If not, we'll run one .over. If you got it, I'm happy to answer any questions. Thanks, Jack Walker TO' RE: Data DATE' ARCO Alaska_Inc. AtlanticRichfieldCompany Mr. Bob Crandall Alaska Oil & Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, AK 99501 Transmittal FROM: ARCO Alaska P. O. Box 100360 Anchorage, AK 99510 8/15/97 Transmitted herewith is the following: Cuttings Description, Arco 2T-Tab-01 well, Kuparuk River Unit Receipt: '/'~ Da~: ~'~,-"-. ',., :, '.:, ,' ..-' Return receipt to: A'i-I'N: ., :'--' ,,9,,~ .,.7 Prepared by: Well 2T-Tab-01 Test Summary The first dedicated Tabasco well was drilled and tested in 1995 from Drill Site 2T in the Kuparuk River Unit. The test was conducted in two phases. First, the well was flowed to tanks for 59 hours and was followed by a 93 hour shut-in period to collect pressure buildup data. During this initial flow period, 749 barrels of 16.5°API crude was produced as well as a unexpectedly high amount of gas. The final oil rate recorded during this period was 388 BOPD. The flow period was initiated on 10/8/95 at 4:40 AM and was terminated for the buildup at 3:23 PM on 10/10/95. To measure the gas rate, a second test was conducted producing the well into the Drill Site 2T test separator. During this test, an additional 756 barrels of 16.5 APl crude was produced over a total flow period of approximately 80 hours. The second test consisted of a 37.8 hour flow period (initiated at 6:41 PM on 10/23/95), a 51 hour shut-in period (initiated at 8:24 AM on 10/25/95) and a final 42 hour flow period (initiated at 1:36 AM on 10/27). The average flowrate prior to the shut-in period was 120 BOPD with an average GOR of 11,700 scf/stb. Phase segregation between the pressure bomb and perforated interval, as a result of high GORs, lead to an unusual drop in BHP during the first hour of shut-in. During the final, 42 hour flow period, production logs were run to identify the source of the high gas rates. These production logs identified a thin, 10' thick gas layer at the top of the oil column. During all of the testing, the BHP and BHT data was taken at a gauge depth of 3042' MD RKB (2727' TVD RKB). The four attached floppy disks contain all of the pressure and temperature data recorded throughout all phases of the testing. The test interval was perforated from 3355' MD RKB (3028' TVD RKB ) to 3527' MD RKB (3195' TVD RKB) and from 3568' MD RKB (3235' TVD RKB) to 3599' MD RKB (3266' TVD RKB). Attachments: 2T-Tab-01 test pressure and temperature data on floppy disks (4) TO: State AOGC 3001 Porcupine Anchorage, Alaska 99503 DATE: AUGUST 6, 1997 AIRBILL: 864025 AFT#: ABV07-08-06-01 CHARGE CODE: 15768 OPERATOR: AAI NAME: KRU 2T-TAB-01 SAMPLE TYPE: DITCH CUTTINGS NUMBER OF BOXES: I SAMPLES SENT: WET DITCH CUTTINGS FROM THE FOLLOWING DEPTHS: 3341'~ 3353'~''- 3360"-"'- 3370'~''~ 3380'~'''- 3390'-'--' 3400''-//~ 3410',----~ 3420~-''~- 3430''-''/ 3440'""" 3450'~'''' 3460,~-'~ 3470~.-~ 3480~...~ 3490,~-- 3500,~-" 3510,~.--- 3520'"'"- 3530~-- 3540'c'''' 3545'~''- 3550'L.--" 3555'~ 3560,`'/ 3565,~ 3570,>,'/ 3575,~ 3580'~ 3585'~ 3590,~-'- 3595,/." 3600,~ 3605,~'/ END OF SAMPLES SENT BY: D.L. PRZYWOJSKI UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: ATTN: DOUG HASTINGS ATO1264 ARCO ALASKA, INC. BAYVIEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 D. L. Przywojski ABV-100 DA~E: F' E R k11 T D/:', T A T D A T A j::' L U S -"2.,~ ~/x.. 122 689~ O~ g092 .... ~ r',H/C,, DS8i (] °5 .... 'J 2'~ .~.~r'~.2700 '~ 399 z~ 95 .... 122 CDN 95 ...... i 22 35 ~ 122 CDR DSSI COL. OR D S S I/" E!, H C/' D l U S I T DALLY WELl.. OPS L~f~ 22SS-h175 2700 .....4025 ~,:2, HPLETION DATE ,'~i"e dr'y ~--. W a s t h e V.)e 'l '1 -i s ,3, 0 h'i H K N T S d i: t c h s a rn p ] e s r' e q u ~ r' e d ? '~ n o A J-] d F' ~[: C e 'i V (~ d ? y e s w e '1 'l c o r' e d 0 y e s ~ A n a '1 y s 'i s & d e s C r" -i p 'L 'i: o n r" e c: e 'i v e ~..t 9 'l:::est. s r"equ'ifed? yes no Rece'ived? yes no 'i'n coinpl'¥ance i n 'i' i: 'i' a' I ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 13, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-TAB-01 (Permit No. 95-122) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 2T- Tab-01. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Petroleum Engineering WSldskad ORIGi L STATE OF ALASKA I AL~dKA OIL AND GAS CONSERVATION CONi ..... 3SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~ GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE r'~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-122 3 Address 8 APl Number P.O. Box 100360, Anchora~le, AK 99510-0360 1 .,,~..._~"'""*'""""~"~'~.__,.,.~.~, 50-103-20230 4 Location of well at surface r,a~m,e~ .[,,~m.~'; 9 Unit or Lease Name 239' FSL, 555' FWL, Sec. 1, T11 N, RSE, UM .... ,~~ Kuparuk River Unit At Top Producing Interval i-/~0//~:: ~ : j 10 Well Number 43' FNL, 689' FEL, Sec. 11 , T11N, RBE, UM : -/~-"~-' ~/"~ ~i.~ ~ ~ )~" ' ' _:.~'~. 2T-TAB-01 At lotal Dopth i 11 Field and Pool . _ . 87' FNL, 843' FEL, Sec. 11, T11N, RSE, UM .... KUPARUK RIVER 5 Elevati°n in feet (indicate KB' DF' etc')RKB 41 ', Pad 81' I6 Lease Designati°n and Sedal N°'ADL 25569 ALK 2667 ~1POI~/ 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore J16 No. of Coml~letions August 12, 1995 August 15, 1995 28-Sep-95 (completed) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permatrost 4175' MD & 3832' TVD 4043' MD & 3702"1'VD YES ~ NO L_JI 2991' feet MDI 1460' GL APPROX 22 Type Electric or Other Logs Run 1, GR/CDR/CDN, GR/CCL/USIT/CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENTRECOFID 16" 151.53# X-65 Surf. 121' 24" 180 sx AS I 9-5/8" 40# L-80 Surf. 2244' 12.25" 680 sx AS III Lead, 240 sx Class G Tail 7" 26# L-80 Surf. 4124' 8.5" '230 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 3220' 3189' 3355'-3527' MD 5 spf 3027' - 3195' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 3568'-3599' MD 5 spf 3235' - 3266' TVD DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 8, 1995 F ow ng Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 10/8 - 10/28 138.50 TEST PERIOD 1:3 150 5 22700 0 124I 15083 FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press 500 1380 24-HOUR RATE¢ 260 3934 0 16.8° 28 CORE DATA Brief description of Iithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,,.~ .~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC ~RS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. K-lO 3328' Colville Sand 3353' 3023' Base Colville Sand 3601' 3268' FEe 1 4 1996 AJaska Oii& '-"'-~._,,.-.3 Cons. Comrr,~ission At, steerage 31. LIST OF A'FrACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so 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 ,,.,~ Alaska, inc." ~ Cuttings Description Operator and Well Name: Arco Alaska, Inc. 2T-Tab-01 APl# 50-103-20230-00 Section of C~,_~, I~-- I [1 Location: Kuparuk River Unit; 239'FSL, 555'FWL, SI-T11N-R8E, UM Date 15, August 1997 Conglomerate clasts description key (in the form: 1/2/3/4/5) (Description of well cuttings collected from the shale shaker by D.S. 1. Black chert Hastings, E. Goebel and L. Gipson, Aug.16, 1995. Sample depths 2.Gray cherts - dk to light were estimated by Anadrill.) 3. Light to white cherts 4. Vein quartz 5. Clear quartz Depth Description Oil Oil Fluor Cut Cut Show ft. Stain Q:b' % Intensit Color color fluor color sum Y 3353 Cgl ¥cg - pebbles (est. 4mm max diam), dk br dull mostly as fractured chips; no cement; gold / traces of pyrite. green composition: 25/55/10/5/2 ish- gold 3360 Cgl a.a.; slightly coarser; live oil bubbling from microporous cherts comp: 15/60/10/10/5 3370 Cgl a.a, w/S.s., c-vcg, mod sorting comp: 30/40/10/10/5; slightly finer 3380 Cgl a.a.; comp:l 0/60/10/15/15 3390 Cgl a.a.; slightly coarser; tr calcite cement Comp: 10/60/10/15/5 3400 Cgl a.a.; no cement comp: 5/60/10/20/5 3410 Cgl a.a 3420 Cgl s.s.: slightly coarser. comp: 10/65/10/10/5 3430 Cgl a.a.slightly coarser comp: 5/65/10/10/5 3450 Cgl a.a.; comp: 10/60/10/10/5 ORIGINAL 3460 Cgl a.a.; .1 - 1.5 cm comp: 10/70/10/5/5 3470 Cgl a.a.; w/minor S.s., f-mg, slight cement mod. sorting. 3480 Cgl a.a.; comp: Tr/70/10/5/5 3490 Cgl a.a.; comp: Tr/70/10/5/5 3500 Cgl a.a.; comp: Tr/70/10/5/5 3510 Cgl a.a.; w/S.s., m-cg, poor to mod sil(?) cement comp: 2./80/7/7/tr 3520 Cgl a.a.; moderate calc. cement comp: 3/70/10/10/5 3530 Cgl a.a.; comp: 5/75/5/10/5 3540 Cgl a.a.; comp: 20/45/15/15/5 3545 Cgl a.a.; w/S.s., m-cg, poor to mod sorting; -5% coal fragments. 3550 Cgl a.a.; coal fragments decrease; comp: 5/60/15/15/5 3555 Cgl a.a.; variable calcite and siderite(?) cement; coal fragments comp: 5/54/20/20/1 3560 Cgl a.a.; coal frags diminishing; comp: 15/54/20/20/1 3565 Cgl a.a.; S.s. m-cg - 15%; coal frags diminishing; comp: 15/54/20/20/1 3570 Cgl a.a.; coal flags increasing in abund. 3575 Cgl a.a.; 3580 Cgl a.a.; no coal frags; comp: 5/58/15/20/2 3585 Cgl a.a.; 3590 Cgl a.a.; comp: 2/50/20/20/5 3595 Cgl a.a.; c~P: 3600 Cgl a.a.; trace S.s.; comp: 2/50/20/20/5 .,,,,~u I Cgl a.a.;(likely cavir ,m above) Remarks Described by D.S. Hastings AR3B-2389-B i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-70703 Sidetrack No. Pa~ Company ARCO ALASKA, INC. Rig Contractor & No. PARKER - 245 Field KUPARUK, RIVER UNIT Well Name & No. PAD 2T/2T-TAB-01 Survey Section Name ANADRILL BHI Rep. WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S 240.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL [~ SS~ , Target Description Target Coord. E/W Slot Coord, E/W 556.00 Magn. Declination 28,440 Calculation Method MINIMUM CURVATURE -- Target Direction (DP) Buil~Walk\DL per: lOOft~ 30mO 1OmO Vert. Sec. Azim. 257.19 Magn. to Map Corr. 28.440 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'I~ (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) · \ MWD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 13-AUG-95 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 9 1/2"MACH 1C-AKO-1.2 DEG. 13-AUG-95 MWD 287.80 1.63 245.17 166,80 287.78 2.32 -1.00 -2.15 0,98 0.98 13-AUG-95 MWD 380,43 5,02 252.61 92.63 380.24 7,65 -2.76 -7.22 3.68 3.66 8.03 13-AUG-95 MWD 470.36 8.09 253.21 89.93 469.57 17,89 -5,77 -17.03 3,41 3.41 0.67 13-AUG-95 MWD 561.26 9.54 254.78 90.90 559,39 31.79 -9,59 -30.43 1.62 1.60 1,73 ,,. 13-AUG-95 MWD 651.28 11.26 267.81 90.02 647,94 47,89 -11.89 -46.41 3.23 1.91 14.47 13-AUG-g5 MWD 740.61 13.97 265.86 89.33 735.11 67.12 -13.00 -65.88 3.07 3.03 -2.18 .__ 13-AUG-95 MWD 830.86 17.65 266.58 90.25 821.93 91.40 -14.60 -90.41 4.08 4.08 0.80 13-AUG-95 MWD 921.79 21.56 265.91 90.93 907.57 121.53 -16.62 -120.85 4.31 4.30 -0.74 13-AUG-g5 MWD 1011.25 23.91 265.69 89.46 990.08 155.71 -19.15 -155.33 2.63 2.63 -0.25 -- 13-AUG-g5 MWD 1103.05 25.60 263.92 91.80 1073.44 193.81 -22.65 -193,60 2.01 1.84 -1.93 1~__~G-95 MWD 1196.25 26.27 265.19 93.20 1157.25 234.23 -26.51 -234.18 0.93 0.72 1.36 -- 1 3-,~0 G-95 MWD 1289.06 27.76 262.66 92.81 1239.94 276.09 -31.00 -276.09 2.03 1.61 -2.73 13-AUG~95 MWD 1383.56 29.44 259.94 94.50 1322.91 321.20 -37.87 -320.79 2.25 1.78 -2.68 13-AUG-95 MWD 1477.11 31.80 257.44 93.55 1403.41 368.82 -47.24 -367.49 2.87 2.52 -2.67 13-AUG-95 MWD 1570.94 33.66 257,12 93.83 1482.34 419.55 -58.42 -416.97 1.99 1.98 -0.34 13-AUG-95 MWD 1760.22 36.60 256.20 189.28 1637.13 528.45 -83.58 -522.93 1.58 1.55 -0.49 13-AUG-95 MWD 1946.99 36.77 255.80 186.77 1786.90 640.00 -110.57 -631.20 0.16 0.09 -0.21 13-AUG-95 MWD 2163.78 36.64 257.32 216.79 1960.71 769.56 -140.69 -757.21 0.42 -0.06 0.70 14-AUG-g5 MWD 2259.78 35.56 258.84 96.00 2038.28 826.12 -153.33 -812.34 1.1 6 -1.12 -0.50 6 3/4"MACH 1C-AKO-1 DEG. 14-AUG-95 MWD 2353.35 34.16 257.72 93.57 2115.06 879.60 -165.11 -864.51 1.59 -1.50 0.94 14-AUG-95 MWD 2446.68 32.27 255.83 93.53 2193.30 930.82 -176.81 -914.38 2.30 -2.02 -2.02 14-AUG-95 MWD 2540.72 30.29 253.25 93.84 2273.50 979.49 -189.77 -961.34 2.55 -2.11 -2.75 6 3/4'MACH 1C-AKO-1 DEG. iii i ,- SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-70703 Sidetrack No. Page Company ARCO ALASKA, INC. Rig Contractor & No. PARKER - 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 2T/2T-TAB-O1 Survey Section Name ANADRILL BHI Rep. WELL DATA Target TVD (Fr) Target Coord. N/S Slot Coord. N/S 240.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SSE Target Description Target Coord. E/W Slot Coord. F_./W 556.00 Magn. Declination 28.440 Calculation Method MINIMUM CURVATURE -- Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mF~ 1om0 Vert. Sec. Azim. 257.19 Magn. to Map Corr. 28.440 Map North to: OTHER ii i SURVEY DATA Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Build (+) Right (+) Comment Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (FT) (DD) (DD) (FT) (FT) (FT) (FI') (Per 100 ET) Drop (-) Left (-) ~ -~.UG-95 MWD 2635.05 28.85 252.58 94.33 2355.54 1025.91 -203.44 -1005.83 1.57 -1.53 -0.71 , UG-95 MWD 2728.70 27.02 251.43 93.65 2438.28 1069.60 -216.98 -1047.56 2.04 -1.95 -1.23 14-AUG-95 MWD 2822.78 24.65 251.02 94.08 2522.95 1110.37 -230.16 -1086.38 2.53 -2.52 -0.44 14-AUG-95 MWD 2917.01 22.10 253.12 94.23 2609.44 1147.59 -241.70 -1121.93 2.85 -2.71 2.23 -- 14-AUG-95 MWD 3010.13 19.68 253.24 93.12 2696.43 1180.71 -251.31 -11 53.71 2.60 -2.60 0.13 I 14-AUG-95 MWD 3103.56 17.30 251.73 93.43 2785.03 1210.24 -260.21 -1181.97 2.60 -2.55 -1.62 14-AUG-95 MWD 3198.10 15.23 250.27 94.54 2875.79 1236.57 -268.81 -1207.01 2.23 -2.19 -1.54 14-AUG-95 MWD 3384.17 13.98 251.80 186.07 3055.85 1283.17 -284.07 -1251.34 0.71 -0.68 0.82 14-AUG-95 MWD 3570.15 10.94 252.77 185.98 3237.43 1323.11 -296.30 -1289.51 1.63 -1.62 0.52 15-AUG-95 MWD 3756.30 11.07 253.55 186.15 3420.16 1358.56 -306.60 -1323.52 0.11 0.07, 0.42 15-AUG-95 MWD 4093.44 10.28 257.00 337.14 3751.47 1420.94 -322.53 -1383.88 0.30 -0.23 1.02 15-AUG-95 MWD 4175.00 10.28 257.00 81.56 3831.72 1435.50 -325.80 -1398.06 0.00 0.00 0.00 CLO.DIST= 1435.53 AZI =256.88 ,.~, FEB ' 4 i~;~ __ _ Date: 10/12/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-TAB-01 RIG:PARKER 245 WI: 0% SECURITY:0 WELLID: 2T-TAB AFE: AK8205 TYPE:DEV AFE EST:$ OM/ 1324M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20230 FIELD: KUPARUK SPUD:08/13/95 START COMP: FINAL: 08/13/95 ( 1) TD: 1150' (1150) SUPV:DWG 08/14/95 ( 2) TD: 2255' (1105) SUPV: DWG 08/15/95 (3) TD: 4175' (1920) SUPV: DWG 08/16/95 (4) TD: 4175' ( 0) SUPV: RLM 08/17/95 (5) TD: 4175' ( 0) SUPV: RLM 08/18/95 (6) TD: 4175'( 0) SUPV:RLM MW: 9.9 PV/YP: 43/41 APIWL: 5.8 DRILLING Move rig 301' from 2T-37 to 2T-Tab-01. Accept rig at 1800 hrs 8/12/95. Drilling 121' to 1150'. DAILY:S189,059 CUM:$189,059 ETD:SO EFC:$189,059 MW: 8.3 PV/YP: 0/ 0 APIWL: 0.0 DRILLING Drilling from 1150' to 2255'. Run 9-5/8" casing. Cement. DAILY:S108,670 CUM:$297,729 ETD:SO EFC:$297,729 MW: 9.5 DRILLING Drilling from 2265' to 4175'. DAILY:S98,393 CUM:$396,122 PV/YP: 29/24 APIWL: 4.8 ETD:SO EFC:$396,122 MW: 10.0 PV/YP: 24/20 APIWL: 5.5 RUN IN WITH E-LINE Pull out of hole, took a 10 bbl kick. Circulate out gas. Condition mud. Well static. Tried to pull out of hole again. Took a little more gas. Circulate and condition mud. Another 10 bbl gain, circulate and condition mud again. Pull out of hole. Well OK. DAILY:S83,623 CUM:$479,745 ETD:SO EFC:$479,745 MW: 10.0 PV/YP: 24/20 CEMENTING, CASING Ran 7" casing to 4104'. Cement casing. DAILY:SO CUM:$479,745 ETD:SO APIWL: 5.5 EFC:$479,745 MW: 10.0 PV/YP: 24/20 APIWL: 5.5 RIG RELEASED Finish cement job. CIP at 0625 hfs 8/17/95. Freeze protect annulus. Release rig 2400 hfs 8/17/95. DAILY:S116,839 CUM:$596,584 ETD:SO EFC:$596,584 Date: 10/12/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: 2T-TAB AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8205 TYPE:DEV AFE EST:$ OM/ 1324M STATE: API NUMBER: START COMP: FINAL: 09/24/95 (7) TD: 4175' PB: 4043' SUPV:DCL PREP FOR HESITATION SQUEE MW: 9.9 NACL BRINE Move rig from 2T-38 to 2T-Tab-01. Perf 7" casing with 6 spf. Squeeze. DAILY: $47,425 CUM: $644,009 ETD:SO EFC: $644,009 09/25/95 (8) TD: 4175' PB: 4043' SUPV:DCL RIH W/BLADED MILL MW: 9.9 NACL BRINE Perform hesitation squeeze. Test 7" casing. Drill firm cement. Run in hole with bladed mill and 2 boot baskets. DAILY:S73,194 CUM:$717,203 ETD:SO EFC:$717,203 09/26/95 (9) BRINE/KCL TD: 4175' PB: 4043' SUPV:DCL DISPLACE WELL W/CLEAN BRI MW: 9.9 NACL Drill out cement retainer @ 3300', cement to 3404' and bridge plug at 3404'. POH w/bladed mill. Run USIT and CBT logs. DAILY:S34,984 CUM:$752,187 ETD:SO EFC:$752,187 09/27/95 (10) BRINE/KCL TD: 4175' PB: 4043' SUPV:DLW DISPLACE WELL W/CLEAN BRI MW: 9.9 NACL Perf Tabasco with 4.5" casing guns. With 5 spf 60 phasing from 3568' - 3599' Total 31' and 3355' - 3527'. Total 172' with 13 runs. Run in hole with 2-7/8" completion. DAILY:S73,888 CUM:$826,075 ETD:SO EFC:$826,075 09/28/95 (ll) BRINE/KCL TD: 4175' PB: 4043' SUPV:DLW LAND 2-7/8" TBG Continue running 2-7/8" completion. DAILY: $73,338 CUM: $899,413 ETD:SO MW: 9.9 NACL EFC: $899,413 09/29/95 (12) TD: 4175' PB: 4043' SUPV:DLW COMPLETED MW: 6.7 DIESEL Test 2-7/8" tbg. OK. Freeze protect well. Secure well. Release rig @ 1700 hfs 9/28/95. DAILY: $48,402 CUM: $947,815 ETD:SO EFC:$947,815 End of WellSummary for Well:2T-TAB State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage AK 99501-3192 The AOGCC releases confidential data to authorized employees of the Division of Oil and Gas (DNR/DOG). Blueline logs and copieo reports are inventoried by prior to release. These confide~e ther~respo~bili~,)f the u,p, dersigned D~R/DOG employee. Print Name \~'v.,~ ~'..Y.~ Slgnature~_~--~'"'(-J/---~(~_.-/.,1-,~ ate, 401 SURVEY Description __..__ Analysis ____ 403 CORE Conventional SWC 407 DWOP Production Tests PICKS Formation Picks or DSTs Geological Markers rev 08/03/95 confidnr, doc II I I Facsimile Cover Sheet To: Company: Phone: Fax-' LARRY GRANT Alaska O&G Conservation Comm. 907-279-1433 907-276-7542 From-. Company: Phone: Fax: Email: Timothy J. Ryherd Alaska D.N.R.- Div. of Oil & Gas (907)269-8771 (907)562-3852 rjr@ dog.dnr.state.ak, us Date: 2/7/96 Pages including this =over page: 1 Please prepare the following well data for me to pick up for our files tomorrow aft=moon, 2/8/95: // ARCO Bufflehead #1(g$-0063)-all well logs, well history, completion report, drilling permit, horizon picks, directional surveys, core descriptions, core analyses, production test summaries and production test cletailed reports. Marathon Core~ Creek #1 (95-0123)--all well logs, well history, completion report, ddlllng permit, horizon picks~ directional surveys, core descriptions, core analyses, production test summaries and production test detailed reports. Stewart W McArthur River #4 (95-0127)--all well logs, well history, completion report, dHIIlng permit, horizon picks, directional surveys, core deacriptlons, core analyses, production test summaries and production test detailed /~ARCO Tobasco #1(I can't find any permit information for this well, but it is the subject of Conservation Order No./' · ,.~t~V- 361 dat.,ed 8/16/9S, this well may be identified as a Kuparuk River Unit development well)-all well logs, well history, ~' I~ ~"omplat~on report, drilling permit, horizon picks, directional surveys, core descriptions, core analyses, production 0~,~.% test summaries and production te~t detalle~l reports. I will be over to pick up this data tomorrow. Call me if you can't have it mary by then. Thank you. Sincerely, Tim Ryherd ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276-1215 December 11, 1995 To: Recipients of Gas Venting Incident Reports . _ Enclosed is a copy of the October 1995 Gas Venting Incident Report for the 2T Tabasco Well (2T-TAB-01). If you have any questions, please contact Patty Rafter at (907) 265-1518. Sincerely, . day Thomas, Supervisor Production & Revenue Accounting JT/PAR Enclosures PAR/Od2 ARCO ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS 2T-TAB-01 Well (2T Tabasco) October 1995 DATE TIME VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNNED ACTION TAKEN TO ELIMINATE CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR 1 0/8/95 0440-2400 2,815 1 0/9/95 0000-2400 4,800 10/10/95 0000-1523 3,401 Short term test of a new reservoir with flowback to tanks and venting the associated gas to the atmosphere. Short term test of a new reservoir with flowback to tanks and venting the associated gas to the atmosphere. Short term test of a new reservoir with flowback to tanks and venting the associated gas to the atmosphere. PLANNED PLANNED PLANNED Testing still in progress. Testing still in progress. Shut in well at the end of the test period. TOTAL OVER 1 HOUR Flare or Vent Volumes: Greater than I hour Less than I hour Continuous Assist Pilot and Purge 11,016 11,016 0 0 TOTAL FLARED/VENTED 11,01 6 ARCO Alaska, Inc. Date: October 20, 1995 Transmittal #: 9305 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Taleak Kuparuk Operations File Clerk ATO-1270A P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy 'of this transmittal. 2T- Cement Bond Log 9/8/95 CDN 5/28/95 CDR 5/28/95 Lb-01 Cement Bond Log 9/25/95 Ultrasonic lmager 9/25/95 CDN 8/16/95 CDR 8/16/95 CDR 6/24/95 CDR 4/6/95 Please acknowledge APl #50-029-22584 APl #50-103-20221 APl #50-103-20221 APl #50-103-20230 APl #50-103-20230 APl #50-103-20230 APl #50-103-20230 APl #50-103-20224 APl #50-103-20216 Date: DISTRIBUTION: I EC.£1V£ OCT 2 6 Alaeka Oil ~ Gas'cons. AnChorage Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 ~,,,,.~~~ No. 9786 COMPANY · LOCATION · ATTENTION · WELL NAME · - SERVICES · 500 W. INTERNATIONAL AIRPORT ROAD '-.....~ ANCHORAGE, ALASKA 99518 AK OIL & GAS CONN COMM 3001 PORCUPINE DR. LARRY GRANT DATE · I RFOLDED SEPIA OF DS I SERVICES · OCTOBER 6~ 1995 NO. OF BOXES: JOB NO. · ADD'L TAPES · I NO. OF BOXES: 95288 JOB NO. ' --- ADD'L TAPES · WELL NAME · SERVICES · WELL NAME · SERVICES · NO. OF BOXES: JOB NO. · ADD'L'TAPES · NO. OF BOXES: JOB NO. ' · ADD'L TAPES · WELL NAME · SERVICES · WELL NAME · SERVICES .. NO. OF BOXES: JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: NO. OF BOXES: JOB NO. ' ADD'L TAPES · RECEIVED BY: No. 9772 COMPANY LOCATION ATTENTION wELL NAME SERVICES · NO. OFBOXES' JOB NO. · ADD'L TAPES · ~ SCHLUMBERGER GEOQU INTERPRETATION AND COMPUTING SERVICES ~.00 W. INTERNATIONAL AIRPORT ROAD ~NCHORAGE, ALASKA 99518 /./ . AK 0IL & 6AS CONN C0MM DATE LARRY GRANT 2T-TAB-01 ~/~/'~~ b(-'''~Y . NAME ' 1 OH ED IT TAPE, I COLORED SERVICES · PRINT DSI 1 95288 NO. OF BOXES: JOB NO. · ADD'LTAPES · OCTOBER 2, 1995 WELL NAME · SERVICES · NO. OF BOXES: JOB NO. · ADD'LTAPES · WELL NAME · SERVICES · NO. OFBOXES: JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · WELL NAME SERVICES NO. OF BOXES: JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: NO. OF BOXES: JOB NO. · ADD'L TAPES · DATE DELIVERED: RECEIVED BY: ARCO Alaska, Inc. Date' September 8, 1995 Transmittal Cf: 9298 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Taleak Kuparuk Operations File Clerk ATO-1270A P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole i{ems. receipt and return one signed copy of this transmittal. Please acknowledge 2T-tab-01 USIT 8/29/95 2T-tab-01 r-,~-r 8/29/95 Receipt Acknowledge' Date' DISTRIBt, ITION: Sharon AIIsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 2700-4025 2700-3994 "/0~, Erickson/Zuspan NSK Central Files NSK-box 69 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9712 9/8/95 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 2T'Tab-01 95289 CDR/(31~ 950816 1 2T-Tab-01 95289 C[~ 950816 I 1 2T-Tab-01 95289 ~ 950816 I I SIG · .' ~J';'"'""-°- ..... NED. _ ......... -- ~_~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh~-~on, DATE: Chairrr~~ ' September 23, 1995 THRU' FILE NO: Blair Wondzell, ~ P. I. Supervisor FROM: Bobby Foster,~~~ SUBJECT: Petroleum Inspector ABUIIWCD.doc BOPE Test - Nordic #1 ARCO - KRU -Tabasco #1 PTD # 95-0122 Kuparuk River Field Saturday, September 23, 1995: I traveled this date to ARCO's KRU 2T Pad and witnessed the BOPE test on Nordic rig #1 which is completing the test well in the West Sak sand. ' As the attached AOGCC BOPE Test Report shows all components in the BOPE system test with no failures. The rig seemed to be in good working order and the pad was clean and all related equipment stored properly. Summary: I witnessed the BOPE test on Nordic dg #1 completing ARCO's Tabasco # 1 - test time 2.5 hours - no failures. Attachment: ABUIIWCD.XLS _. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial Workover: x NORDIC Rig No. 1 PTD # 95-0122 ARCO Rep.: TABASCO #1 Rig Rep.: Set @ 4043' Location: Sec. ~ X Weekly Other DATE: 9/23195 Rig Ph.# 659-7115 DONNIE LUTRICK SHANE McGEEHAN 1 T. 11N R. 8E Meridian U MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YE~ Standing Order Posted YES BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl, Rig OK Hazard Sec. YES Test Quart. Pressure P/F I 300/3,000 P 300/3500 300t3500 300/3500 1 300 / 3500 P' 1 300 / 3500 1 1 2 N/A MUD SYSTEM: Visual Alarm Tdp Tank NO NO Pit Level Indicators NOTE NoTE Flow Indicator NOTE NOTE Meth Gas Detector YES YES H2S Gas Detector YES YES , , FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 300 / 3500 P 1 300/3500 2 300/3500 1 300/3500 P P F/P CHOKE MANIFOLD: No. Valves 12 No. Flanges 28 Manual Chokes 1 Hydraulic Chokes 1 Test Pressure 300 / 3500 3OO~35OO P/F P P Functioned P Functioned P , ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 1 Blind Switch Covers: Master: Nitgn. Btl's: 3 (~ 2200 3,100 I P 2,400 . P minutes 18 sec. minutes 22 sec. YES RemOte: YES Psig. Number of Failures: 1 Equipment will be made within the AOGCC Commission Office at: Fax No. 276-7542 InapectorNorth$1opePagcrNo. 659-~OTor~687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at: ,Test Hrs.: 2.5 Hours. Number of valves tested 21 Repair or Replacement of Failed 0 days. Notify the Inspector and follow with Written or Faxed verification to REMARKS: FAILURE: The inside BOPE floor safety valve would not close - repaired and tested OK. NO TE: A new drilling fluid monitoring system is being installed- should be operating with in 5 days. 1,279-1433 . Distribution: orig-Well File c - Oper./Rig c- Database c - Tdp Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W~nessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) ABUIlWCD.XLT ARCO Alaska, Inc. Post Office Box 100360 Anchorage, A~aska 99510-03,30 Telephone 907 276 i215 August 31, 1995 Mr. Bob Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska SE? O6 &~as~ ~[t ~ G~s Cons. Co. mmlssl.oa ..... , ~cliorage ' Dear Mr. Crandall, Per our telephone discussion on 8/30/95, I've attached a copy of the procedure for the upcoming Tabasco testing activities. The procedure involves producing small quantities of oil to tanks followed by a pressure build-up test to measure basic reservoir parameters and pressure. Oil and gas samples will be taken both on the surface and downhole during the testing activities and all fluids produced to tanks will be trucked to one of Kuparuk's recycle facilities and blended with Kuparuk crude production. Based on oil samples taken from oil-cut drilling muds and side wall cores, moderately heavy oil ranging from 18°- 21° APl with Iow GOR is expected. Once the sampling and buildup testing are complete, critical drawdown testing for formation failure will be conducted. Following this work, the well will be displaced with diesel for freeze protection pending evaluation of the test results. If you have any additional questions about the testing program, please feel free to contact me at 265-6850. Sincerely, 'Larry J.~son Senior Petroleum Engineer CC: C. Foerster ATO-1270 D. Petrash ATO-1286 M. Zanghi ATO-1276 AR3B-6003-93 242 2603 TEST PROCEDURE TABASCO DEDICATED WELL WELL 2T-TAB-01 Test Objectives: The purpose of the Tabasco Dedicated Well test is to determine fluid and rock properties and the production potential of the Tabasco accumulation encountered at Drill Site 2T, All test activities will be conducted off-rig and include production data gathering, pressure buildup testing, oil and gas sample collection and critical drawdown testing, Completion work (including initial perforating) will be done with the Nordic rig, The test plan is outlined as follows: Test Procedure: , Hook-up surface computer and record static bottomhole pressure and temperature. , NU all surface equipment required for testing the well (well lines, choke manifold, tanks, heat trace tie-in, etc,), Hydrotest the surface lines to the appropriate test pressure, 3. Hold safety meeting. , MIRU slickline and PT equipment. Pull any plugs left from the completion rig, install dummy/check valves in mandrels as necessary and tag fill. Install a backup memory pressure gauge in the lowermost mandrel (1.5") to record producing and buildup pressure data. , Slowly open choke to initiate flow. Monitor downhole pressures and restrict drawdown increases to 25 - 50 psi increments. Once flow is established, restrict drawdown to a maximum of 400 psi, to prevent potential formation failure. If flow is not initiated by opening the production choke, begin swabbing operations. Tanks should be strapped at least once per hour throughout testing operations and more frequently during the first few hours or production. . Once a stabilized oil gravity is established, collect wellhead gas samples and a 6 drums of dead oil. A sample from each drum should be taken for flash point measurements prior to shipping. , Once stabilized flow conditions have been maintained for a minimum of 24 hours, or as determined by the responsible onsite engineer, shut-in well for a buildup test utilizing the downhole shut-in device (SSSV) to minimize storage effects. Once the SSSV has been closed, the master valve and wing valves should be closed immediately thereafter. Length of shut-in period to be based on pressure buildup data or as determined by the responsible onsite engineer. . . 10. 11. 12. 13. 14. RDMO wireline unit. Once the pressure buildup data has been analyzed and data quality has been confirmed, proceed to downhole fluid sampling and formation failure testing. MIRU E-line unit and PT equipment. ***** NOTE ***** Calculate the required shut-in time required for reservoir stabilization/gas resaturation prior to sampling. RIH with downhole sampler/gradio tool string to identify fluid contacts and collect oil sample. RDMO E-line unit. ***** NOTE ***** If oil-water interface is too shallow, use coiled tubing to lift out water column maintaining adequate backpressure to minimize drawdown on perforations. If diesel is used during the water cleanout, a minimum of 3 tubing volumes should be produced prior to sampling. MIRU slickline unit, PT equipment and tag fill to establish baseline. Initiate production to tanks. Perform a step rate test with intermediate slickline tags to determine critical drawdown for formation failure. ***** NOTE ***** The step rate test should be based on 100 psi drawdown increments. Monitor BS&W throughout the step rate testing. Once step rate testing is complete, suspend all testing operations and displace the tubing with diesel for freeze protection. KRU 2T-Tab-01 Change to Approved Tabasco Target Location The Tabasco test well, 2T-Tab-01, was originally permitted to drill to Target location 526' FSL, 535' FEL, Sec. 2, T11N, R8E, UM with Permit No. 95-122, API No. 50-103-20230. This location was AAI's second choice for a target (called Target B henceforth) to test the Tabasco formation. The first choice target (Target A) was preferred due to the better offset well control and thicker prognosed net pay. However, Target A required an exception to the spacing requirements of 20 AAC 25.055. Timing was very close on getting the exception approved before the drilling rig was ready to spud 2T-Tab-01, so AAI permitted Target B in order to be prepared for the drilling rig timing. The exception was approved in time and AAI submitted a Sundry application in order to drill to Target A. Robert Crandall with the AOGCC was notified by the Drilling Engineer, James Trantham, on 8/8/95 of the intended change to the approved permit. The new target location was verbally approved, pending the approval of the spacing exception after the required 15 days public notice had passed. If you have any questions or comments regarding the above discussion, please contact Denise Petrash at 263-4183. i995 2'5~PM ARC~O-ALASKA INC ARCO Alaska, Inc. FACSIMILE · TRAI~ISMISSI,ON II iIiqll . umber of Pages (Cover +): i ! From: C'~w~' S Phone: 2___ Location: A-~ 1 _ III II I ~ '~'- I __ I Iici·III --- L__~ Location; Copies To: Subject: No. 285] · I II II I II II I ~1 II I II II I I II II II I I II I1 II I IIIIIlII III I II II · I1 II · I II II · II II I I II II I II II · i II II I II II I I II II I II II I I II II I II II I i ii i! i i! !! !l I Ii II · II II I I II II I II II · II II II · Ii II Ii I1 II II · II ii ii ~iilll II II · II ii ii II II II I Ii ii ii II II II I iii ii ii II II Ii I i1 ii II ii il ii II I II ii ii ii i1 · TI III II II I1 · II ii ii III ii · II IT I IT II ,I I II II i1 ii IT I II .'I Il !.' ."! ! !! P, 1/2 Kuparuk Drill Site Development P. O. BOX 100360 ANCHORAGE, AK 99510-0360 FAX # 907 265-6224 . _A_TO-1209 FAX #: Phone #: iii I ---II I II iii Comments: '~ e_~ se. i i , i i i Alaska Oit & Gas Cons. /.4. 1995 2:547M AIC~-ALASKA INC No. 2851 2/2 KRU 2T-Tab-01 Change to Approved Tabasco Target Location The Tabasco test well, 2T-Tab-01, was originally permitted to drill to Target location 526' FSL, 535' FEL, Sec. 2, TI IN, R8E, UM with Permit No. 95-I22, APl No. 50-I03-20230. This location was AArs second choice for a target (called Target B henceforth) to test the Tabasco formation. The ~st choice target (Target A) was preferred due to the better offset well control and thicker prognosed net pay. However, Target A required an exception to the spacing requirements of 20 AAC 25.055. Timing was very close on getting the exception approved before the drilling rig was ready to spud 2T-Tab-01, so AAI permitted Target B in order to be prepared for the drilling rig timing. The exception was approved in time and AAI submitted a Sundry application in order to drill to Target A. Robert Crandall with the AOGCC was notified by the Drilling Engineer, lames Trantham, on 8/8/95 of the intended change to the approved permit. The new target location was verbally approved, pending the approval of the spacing exception after the required 15 days public notice had passed. If you have any questions or comments regarding the above discussion, please contact Denise Petrash at 263-4183. REEEIVE.'5 AUG 25 t995 Dit .& Gas Cons. GommiSS~o~' AL~ ,, OIL AND GAS CONSERVATION COMMIL; )N APPLICATION FOR SUNDRY APPROVALS?,, Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspende¢/w-b'.Jl Alter casing _ Repair well_ Plugging _ Time extension_ Stimulate ._/ Change approved program x Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, IBC. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 240' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 49' FNL, 713' FEL, Sec. 11, T11N, R8E, UM At effective depth 49' FNL, 713' FEL, Sec. 11, T11N, R8E, UM At total depth 90' FNL, 893' FEL, Sec. 11, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 2 2 5 5 true vertical 2 0 2 5 6. Datum elevation (DF or KB) .,- KB 41', Pad 7. Unit or Property name ADL 25569, ALK 2667 "' feet · 8. Well number 2T-T~b-01 9. Permit number 95-1 2"~ 10. APl number 50-103-20230 11. Field/Pool Kuparuk River Field, Tabasco Oil feet Plugs (measured) feet Effective depth' measured true vertical 2255 feet Junk (measured) 2 025 feet None Casing Length Structural Conductor 16" Surface 21 7 4' Intermediate Production 4 0 5 0' Liner Perforation depth: measured Size Cemented 16 9 - 5 / 8" 600sx AS3 240sx AS1 7" 290 sx "G" true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) Measured depth True vertical depth 121' 121' 2215' 2O00' 4091' 3723' AUG 6 1995 A~s~ 0ii & Gas C0ns. Commission Anchorage 13. Attachments Description summary of proposal_ Change BHL, directional plots attached Detailed operation program BOP sketch 14. Estimated date for commencing operation Aug 14, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas _ Suspended Service cert y regoing is true and correct to the best of my knowledge. Signed Title 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 Original Signe(~ ay David W. Johnston Approved by the order of the Commission lO_ ~;z,'¢/~o p"oved Copy' '"'~ Returned Commissiohe, D~ t e ~2'/~"~//~~''' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO ALASKA, !nc. 2OO _~ ~ i s.oo soo d ~,, ~.oo , '. 2.00 SOO ~ ; ;5.oo ~ : ~.~0 ; OO0~ ; 21.00 t.. 1200~ :8002 2200J 2400~ i :6002 :8ooq~ 3000~ 3200~ 1 2400~ 2800~ : ] i i ; O 200 RKB ELEVATION: 123' KOP TVD=3OO TMD=3OO DEP=O BUILD 3 DEC / I00' 4-.00 -~, 27.00 x~30.O0 Slrucfure : Pod 2T Field : Kuporuk River Unit ',Veil : Tcbasco Location : North Slope, Alaska ESTIMATED SURFACE LOCATION 240'FSL, 556' FWL SEC.1, Tl lN, RBE West Scale ,' 75.00 1350 !200 1050 900 750 500 ~50 300 i i500 150 0 TARGET LOCATION: 49' FNL. 713' FEL SEC. 11, T, IN. R8E TD LOCATION: sEC. :,. T,~N. RB~ S 77.19 1301' (TO EGO TV0=1424 llvID=1502 OEP=366 B/ PERMAFROST TVD=1503 TMD=1599 OEP=423 T/ UGNU SNDS TV0=1548 TMD=1655 OEP=456 MAXIMUM ANGLE 36.06 DEC-:- - x,~36.oo BEGIN ANGLE DROP TVO=2089 TMD=2325 OEP=850 ~ .34.00 %N. 32.OO r/ W SAK SNDS ,TVD=2257 TMD=2527 OEP=963 ~ 28 00 DROP 2 DEC / 100' ~ 26.00 Alaska 0il & Gas Cons, Commission \ 'x'~.24-00 8/ W SAK SNDS TVD=2673 TMD=2996 DEP=1178 Anchorage 22.00 DEG t¥ AUG 1 b !995 K-10 / TABASCO (EOD) TVD=3034 TMD=3378 DEP=I301 B/ TABASCO INTERVAL TVD=3213 TMD=3563 DEP=134g TAP. GET ANGLE 15 DEG 20.00 8.00 16.00 150 150 0 ~ 150 _ 300 ! ~ 450 _ 7~'~D TVD=3723 TMD=4091 DEP--I486 400 600 BO0 ~ GO0 : 2OO ~ 400 ~ 600 Ver~/cal Section on 257.19 azimuth with reference 0.00 N, 0.00 E from Slot ~Tabasco Created by : ]ones For: b PETffRASHi Dote plotted : 11-Apr--g5 Plot Reference is l'oba$co Version #4. Coordinates are in feet reference Slat ,~Taba~.co.; True Vertical Oepth$ ore reference wellhead. Structure : Pad 2T Well : Tcbosco F:eld : Kuparuk River Unit Location : North Slope, Alaska Created Dv : ~ones Date plotted : ',Z-Apr-95 ?!at Reference is Tabasco Version /~4. : Coordinates ore in feet reference Slot #Tabasco. I True Vertical Depths ore reference wellhead. 560 520 I I ! I I I ~ i i i i I I I I I I I I I I I I 1400 :60 J '[& Gas Cons. Commission ~o ~ ~o~ ~ ; < - - W e s f Scale 1 ' 20.00 480 -:'40 400 .~50 520 280 240 200 ] 60 120 80 40 0 40 80 2OO 160 120 8O 0 40 8O 120 _ 160 200 240 < West co,e ,. o.oo 0 I I V &RC KA ., Structure : Pad 21 Well : Tabasco : Field : Kuporuk River Unit Lccotion : North Slope, Alosko l Created by : jones Date plotted : 12-Apr-95 iPIot Reference is Tabasco Version #4. :Coordinates ore in feet reference Slot ~Tobosco. True Vertical Depths ore reference wellhead. < Wesf Scale 1. 20.00 1520 1480 1440 1400 1360 1320 1280 1240 1200 ~ ~ 60 1120 1080 1040 1000 960 920 880 I I I I I I I I [ I I i I I I I I I I I I I I I I I I I I I I i .1 0 J (~ o 80 80 ~ ~ :20_~ _120 " ~soJ 200_ 240_ :8DJ 320_ 360_ 400. q 480_ 520_ I 1520 1480 1440 1400 1Z~O 1320 1250 1240 1200 1160 1120 1080 1040 1000 960 920 880 < Weal Scale 1. 20.00 0 I I V MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David J~', DATE: Chairman~ August 14, 1995 THRU' Blair Wondzell, ~ FILE NO' P. i. Supervisor ~ ~- FROM: Lou Grimaldi, ~,¢'0<.~ SUBJECT: Petroleum Insiaector ABXJHNCD.DOC BOP test Parker rig ¢245 'Arco well ¢2T-TAB-01 Kuparuk~ver%Field PTD ~ Monday, August 14,1995: ! witnessed the initial BOP test on Parker rig ¢245 which is presently drilling Arco's well ¢2T-TAB-01 in the Kuparuk River field. The test went very well with all components functioning and holding their pressure test properly. The rigs gas detection system was in place and operational but due to the late houri opted not to test the system as the electrician was asleep and his log book was kept well up to date. There was documentation showing the regular testing of these systems. All other equipment I observed had the appearance of regular maintenance. SUMMARY: I witnessed the initial BOP test on Parker rig ¢245. Test time 2 hours. No failures. Attachments: ABXJHNCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Parker Drilling Co. Operator: Arco Alaska Inc. Well Name: 2T-TAB-01 Casing Size: 9 5/8 Set @ Test: Initial X Weekly Rig No. 245 PTD # 95-122 Rep.: Rig Rep.: Location: Sec. Other DATE: 8/14/95 Rig Ph.# 659-7697/7670 Dead Gladden John Crisp I T. 11 R. 8E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign Y Drl. Rig Y Hazard Sec. Y BOP STACK: Quan. Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Press. P/F 250/3, OO0 P 250/3,000 P 250/3,000 P 250/3,000 P 250/3,000 250/3,000 2 250/3,000 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank Yes N/A Pit Level Indicators Yes Yes Flow Indicator Yes Yes Meth Gas Detector Yes Yes H2S Gas Detector Yes Yes FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Test Pressure P/F 250/3, 000 P 250/3,000 250/3,000 25O/3, OOO P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F 250/3,000 P 36 25O/3, OOO P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: Six Bottles 2000 Average 3,000 I P 1, 700 P minutes 33 sec. minutes 24 sec. OK Remote: OK Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 2.0 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good Test/Rig in top shape. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X' NO 24- HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grirnaldi FI-021L (Rev. 12/94) ABXJHNCD.XLS TONY KNOWLE$, GOVERNOR ~KA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (o~)7) 276-7542 August.Il, 1993 Mike Zanghi, Drill Site Develop. Supv ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 --Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2T-TAB-01 ARCO Alaska Inc 95-122 240'FSL, 556'FWL, Sec 01, T11N, R08E, UM 1042'FSL, 565'FEL, Sec 02, T11N, R08E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting ddlling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal-use. Notify AOGCC, Robert Crandall, when ready to formation foot so we can witness test of Tabasco Sands. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Yours very truly, Russell A. Douglass~~~~ Commissioner BY ORDER OF THE COMMISSION Ijb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ~ AL,. ~KA OIL AND GAS CONSERVATION COMMIS, i PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill E] lb Type of Well Exploratory X Stratigraphic Test ~] Development Oil [] Re-Entry D Deepen D service E] Development Gas E~ Single Zone X Multiple Zone D 2, Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41'~ Pad 81' feet Kuparuk River Field 3. Address 6. Property Designation Tabasco Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25569, ALK 2667 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 240' FSL, 556' FWL, Sec. 1, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 526' FSL, 535' FEL, Sec. 2, T11N, R8E, UM 2T-Tab-01 #U-630610 At total depth 9. Approximate spud date Amount 1042' FSL, 565' FEL, Sec. 2, T11N, RSE, UM 8/1 2/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-08 4254' MD 565'@ TD feet 12.0' ~ 200' MD feet 2560 3640' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 40.46o Maximurnsurface 1 184 psig At total depth (TVD) 1 370 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD TVD MD 'I'VD linclude sta~le data/ 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC 2174' 41' 41' 2215' 2000' 680 Sx Arcticset III HF-ERW 240 Sx Arcticset I 8.5" 7" 26.0# L-80 BTCMO£ 4213' 41' 41' 4254' 3640' 310 SxClass G HF-ERW Top 500' above Tabasco 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing ~ Length Size Cemented Measured depth True Vertical depth Structural '~'~ Conductor ~ i' Surface .. Ii.. I ~( Intermediate Production Liner AUG 1 0 1995 Perforation depth: measured AJ~,$~, (JiJ & Gas Cone. Commission true vertica~ Anchorage 20. Attachments Filing fee X Property plat [~ BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r~ Refraction analysis D Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify ti'jet the forgoing is true and correct to the best of my knowledge Signed ~.'~:~ Title Drill Site Develop. Supv. Date ' \ L/J. ~ Commission Use Only Perrp~ Number , -- I~"~I~,PI number _ J Approval ¢i~te .. ~ ..~,- J See cover letter for I /'/'-/IIother requirements Conditions of approval Samples required ~1 Yes r'] No Mud log required [~ Yes ~] No Hydrogen sulfide measures r'~ Yes ~;~ No Directional survey required ]~ Yes D No Required working pressure for BOPE ~ 2M r-! 3M D 5M r"] 1OM ~] 15M Other: ORIGINAL SIGNED BY RUSSELL A. DOUGL4SS by order of ~;~/// Approved by ~ : Commissioner the commission Date ....... Form 10-401 Rev. 7-24-89 Submit triolicate GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 2T-Tab-01 , , , , . , , . , 10. 11. 12'" 13. 14. 15. 16. 17. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (2,215')according to directional plan. Run and cement 9-5/8" casing. Arcticset I cement is being a tail due to the proximity of the permafrost, and will be brought a minimum of 500' above the surface shoe. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (4,091') according to directional plan. Run open hole evaluation logs and LWD tools as needed. Run and cement 7" casing. We will not attempt to bring cement the required 500' above the West Sak to avoid problems with cement entering the surface by production casing annulus. Instead we will downsqueeze cement into the annular space between the casing strings after the primary cement job is completed. The West Sak is projected to come in +_260' below the surface casing shoe. ND BOPE. NU tubinghead & master valve ain preparation for Nordic's completion. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for testing equipment. DRILLING FLUID PROGRAM Well 2T-Tab-01 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin~ 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to open hole swap 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Open hole swap to TD 9.6 10-18 7-10 35-45 2-4 4-8 4-5 7.0-8.0 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators AUG 1 0 1995 AJa$._ka Oil & 6as Cons, Commission '.Anchorage *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. A weighted 2% KCl mud will be used to drill through the Tabasco section to minimize potential damage to the formation. This mud will be swapped into the wellbore right above the Tabasco Sands. MASP' 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 1,700 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. (The leak off EMW was chosen based on an open hole leak-off test on 2T-09 taken to 13.6 ppg; surface casing was set at 1,996' TVD.) The nearest existing well to 2T-Tab-01 is 2T-08. As designed, the minimum distance between the two wells would be 12.0'@ 200' MD. Annular Pumpin~ Activities' Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on DS 2T. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr)in pumping operations. The 2T-Tab-01 surface/production casing annulus will be filled with diesel after setting 7" and pdor to the drilling rig moving off of the well. The annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface. Drilling Area Risks: Risks in the 2T-Tab-01 drilling area are limited to lost circulation and potential borehole instability in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on the DS 2T expansion drilling results, 9.6 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. Although 2T-Tab-01 will be the first time AAI has tested the flow capabilities of the Tabasco reservoir, it is not a true exploratory well since we have drilled through this formation many times in Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction/reflection analysis, respectively) be waived for the drilling of 2T-Tab-01. ARCO ALASKA, Inc. Structure : Pad 2T Well : TTa i I Y 200 _ -- 400 _ -- 600 _ 800 _ - lOOO_ 1200 2000 _ -- 2200_ -- 2400_ - 2600_ - 2800_ - 3000_ - 3200_ i 3400_ -- 3600_ -- 58OO Field : Kuporuk River Unit Location :Norfh Slope, Alaska .... Point nd of Ho~d nd of Build OP nd of Build orget End of Hold [nd of Hold KOP 3.00 6.00 9.00 24.00 27.00 TD LOCATION: est Sok Sands Bo~ W~t Sok ~s ~B~in Build ~ Turn to Target I I I I I I I I I I I I I I I 0 200 400 600 800 1000 1200 1400 ~co!~ 1 : 100.00 WELL PROFILE DATA MD Inc Dir TVD 0 0.00 257.19 0 3(30 0.00 257.19 300 t200 I I Vertical Section on 284.71 azimuth with reference 0,00 N, 0.00 E from slot #TTa 1502 36.06 2214 36.06 5155 40,46 3457 40.46 3654 40.46 ~4 40.4~ No~h o o 257.19 1424 -81 257.19 2000 -174 556.65 2805 91 356.63 3034 286 556.63 3184 414 3~6.63 3640 Crated by : ~s For: J TRANTHAM J Dote pk)tt~ : 8-NJg-95 Plot Refer~ce is ~o Ve~ion ~6. Coordln~tee we ~ feet[ reference sbt ~o. True Ve~ Del)be we reference RKB ( Po~ ~245). <-- West 1 ooo 800 600 400 TARGET LOCATION: 526' FSL, 535' FEL SEC. 2, TllN, RSE Tabasco Rvsd 2-Aug-95 ~1~1: 100.00 200 0 [ I I [looo 80o _ 600 -- _ 400 _ _ 200 -- o _ F 200 ESTIMATED SURFACE LOCATION: 240' FSL. $56' ~gL SEC. 1. 7~t',. ~SE AUG '~ 0 1995 Oil & Gas C0ns. C0mmisSl0D ~nchorago East Deg/lO0 0 0.00 0 0.00 -357 3.00 0.00 -766 6.00 -lOgO - 1091 o.oo] - 1098 0.00 -1121 0.001 I I Z 0 ARCO ALASKA, Inc. Pad 2T TTa slot #TTa Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT Baker Hughes I NTEQ Your ref : TTa Version #6 Our ref : prop1375 License : Date printed : 8-Aug-95 Date created : 8-Aug-95 Last revised : 8-Aug-95 Field is centred on nTO 16 18.576,w150 5 56.5]6 Structure is centred on nTO 19 45.172,w150 0 47.0]4 Slot location is nTO 19 47.527,w150 0 30.801 Slot Grid coordinates are N 5970219.612, E 498945.102 Stol local coordinates are 239.50 N 556.00 E Reference North is True North ( WARNING: DATA BELOW IS A SUMMARY, DETAIL PROXIMITIES NOT TABULATED ) Object ~el lpath PMSS <380 - 11400'>,,31,Ped 2T PMSS <918" - 108~O'>,,28,Ped 2T PMSS <O-10570'>,,29,Pad 2T PflSS <1287-1725'>,,2,Pad 2T PGHS <O-8890">,,2A,Pad 2T PGHS <O-7897'>,,3,Pad 2T PflSS <4757-6800'>,,1gA,Pad 2T PGHS <O-6725'>,,12B,Pad 2T PMSS <.~115 - ~645'>,,12,Pad 2T PGHS <0-7868~>,,13,Pad 2T PGHS <O-8262'>,,14,Pad 2T PGMS <O-7625'>,,15,Ped 2T PMSS <1604-3625'>,,16,Ped 2T PGMS <O-8947'>,,16B,Pad 2T PMSS <5917-7957'>,,16A,Pad 2T PGMS <O-8445'>,,17, Pad 2T PflSS <O-9845'>,,19, Pad 2T PMSS <921-10235'>,,20,Pad 2T PMSS <O-12821'>,,21,Ped 2T PMSS <893 - 12977'>,,23,Ped 2T PMSS <O-9298'>,,27, Pad 2T PMSS <469-10632'>,,18, Ped 2T PMSS <0 ' 9210'>,,26,Pad 2T PMSS <O-5924'>,,32,Pad 2T PMSS <4850 - 5918'>,,32A,Pad 2T PMSS <5497-13787'>,,32B,Pad 2T PMSS <O-4749'>,,30,Pad 2T Closest approach with 3-D minimu~ distance method Last revised Distance M.D. Diverging from M.D. 14-Jul-95 313.5 120.0 3155.4 13-Jul-95 267.5 240.0 3155.4 15-Jun-95 282.1 350.0 3380.0 22-Jan-92 162.0 240.0 240.0 22-Jan-92 162.0 240.0 3412.2 21-Jan-92 137.5 100.0 4254.0 16-Feb-95 129.7 675.0 2740.0 16-Feb-95 129.7 675.0 2740.0 16-Feb-95 129.7 675.0 2740.0 22-Jan-92 158.3 675.0 675.0 16-Feb-95 178.7 725.0 725.0 16-Feb-95 207.8 703.0 703.0 16-Feb-95 237.6 60.0 425.0 16-Feb-95 237.6 60.0 425.0 16-Feb-9~ 237.6 60.0 425.0 15-Feb-~ 262.4 160.0 160.0 27-Jun-95 281.4 825.0 2480.0 15-Jun-95 264.0 875.0 3155.4 15-Jun-95 322.4 200.0 200.0 15-Jun-95 191.8 350.0 3240.0 15-Jun-95 252.5 120.0 3155.4 15-Jun-95 260.6 1520.0 1520.0 23-Jun-95 237.5 120.0 3155.4 15-Jun-95 326.8 350.0 3240.0 7-May-95 326.8 350.0 3240.0 7-May-95 326.8 350.0 3240.0 15-Jun-95 298.5 120.0 3155.4 PM$S <4627 - 10c >,,30A,Pad 2T PNSS <741-15~71'>,,36,Pad 2T PHSS <?39-13363'>,,38,Pad 2T PI~qS <O-8160'>,,4,Pad 2T PG~S <O-7670'>,,5,Pad 2T PGI~$ <O-8208'>,,6,Pad 2T PI:iHS <0-6975'>,,7, Pacl 2T PGHS <O-7650'>,,8,Pad 2T PGJqS <O-6370'>,,9,Pad 2T PGMS <O-8250'>,,10,Pad 2T PGHS <O-6789'>,,11,Ped 2T PMSS <918 - 10193'>,,22,Pacl 2T PMSS <650 - ???'>,,37, Pad 2T 15-May-95 298.5 120.0 3155.4 28-Jut-95 223.1 ' ~625.0 625.0 3-Aug-95 172.4 1352.5 1352.5 21-Jan-92 112.6 100.0 3260.0 22-Jan-92 87.6 100.0 3155.4 22-Jan-92 62.7 60.0 3155.4 22-Jan-g2 37.1 300.0 4254.0 22-Jan-92 12.0 240.0 3155.4 22-Jan-92 12.4 180.0 375.0 22-Jan-92 85.5 625.0 2620.0 22-Jan-92 110.8 575.0 575.0 29-Jun-95 177.0 350.0 3000.0 8-Aug-g5 322.0 700.0 700.0 AUG 1 0 19 5 Oit & Gas Cons. Commission Anchorage ,6 , I I 4 I3 . 13 5/8" 5000 PSI JOP 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 UMIT IS 4S SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSi AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ~'~'~U~ PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 77'TEST TO 250 PSI AND 31:XX) PSI AS IN STEP 4. ~UE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE 'THAT IS NOT A FULL CLOSING PosrrivE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE Bo'FrOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING J'r AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST'TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WI'I'H KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2000 PSI STARTING HEAD 2. 11' - 3(X:X) PSI CASING HEAD 3. 11'- 3000 PSI X 13-S~-- ~ ~ SPACER SPOOL 4. 13-S/8' - 50(X) PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SP(:X3L W/ CHOKE AND KILL MNES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 13-,6/8' - .6000 PSI ANNULAR AUG 0 '~995 0[[ & Gas Cons. CommissioD k~chorage KL?ARUK RIVER UNIT 20" DIVERTER SCHEMATIC , I I I4 5 3 2 DO NOT SHUT IN DiVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 1. 2~ MAINTENANCE & OPERATION UPON. INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON- CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20". 2000 PSI ANNULAR PREVENTER. AUG 1 0 1995 Naska 0it & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 9,1995 Mr. David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Facsimile (907) 276-7542 Subject: Tabasco Test Well 2T-Tab-01 Dear Mr. Johnston: Attached is the Permit to Drill application for 2T-Tab-01, the Tabasco formation test well being drilled by ARCO Alaska, Inc., this month. The test well will be drilled from DS 2T, which has recently been the site of a large Kuparuk expansion program. The application is styled after one for a typical Kuparuk development well rather than an exploratory well due to the formation and all strata above it being fairly well known from this and previous development programs. Please let us know if you feel more information needs to be supplied with the Permit application. If there are any questions please contact the Parker 245 Drilling Engineer, Denise Petrash at 263-4183; the 2T-Tab-01 well test engineer, Larry Gipson at 265-6850; or myself at 265-6206. Sincerely, Mike Zanghi Supervisor Kuparuk Drill Site Development AUG '~ 0 ~995 0i~ & Gas Cons. C0mmi¢O~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of ARCO Alaska, Inc. for exception to 20 AAC 25.055 to allow drilling the Tabasco No. 1 development oil well. ARCO Alaska, Inc. by letter dated July 25, 1995 has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of a development oil well to an undefined oil pool within the Kuparuk River Unit on the North Slope. The exception would allow ARCO to drill the Tabasco No. 1 development oil well to a producing location that is closer than 500 feet from a quarter section line. The well will be drilled as a deviated hole with a surface location of 240' from the south line and 556' from the west line of Section 1, T11N, R8E, Umiat Meridian (UM) and a bottomhole location of 90' from the north line and 893' from the east line of section 11, T11N, R8E, UM. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM August 15, 1995 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 am on August 31, 1995 in conformance with 20 AAC 25.540. If a hearir~g is to be held, interested parties may confirm this by calling the Commission's office, (907) 279- 1433 after August 15, 1995. if no protest is filed, the Commission will consider the' issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than August 23, 1995. 'D~a~vid W. Johnsto'n'~ Chairman Published July 29, 1995 ARCO Alaska, Inc. Post Office aox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 july 10, 1995 RECEIVED _ - JUL 1 I I995 A~$ka 0il & Gas Cons. Commission Mr. David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Tabasco Formation Planned Testing Program Dear Mr. Johnston: This letter is in response to your request for more information on the Tabasco Sands seen at DS 2T, and AAI's plans to obtain more definition of the reservoir. After many negotiations all of the co-owners (AAI, BP, and Unocal) appear to be firmly committed to a dedicated Tabasco test well. We are planning to drill the well from DS 2T in late July or August. The bottom hole location is planned to intersect the formation near the current 2T-10 intersection with the Tabasco Sands. The planned testing program includes: · Anadrill LWD resistivity/GR logs · Schlumberger open hole electric line logs (LDT/CNL/Dipole Sonic/GR/Cal) · low rate flow testing to minimize sand production, into onsite tanks · collection of oil and gas samples · PBU analysis after +3 days of production AAi's main objectives for this testing program are to: 1.) Quantify' reservoir performance capability, 2.) determine gas and crude oil properties, and 3.) achieve data needs at low cost. We hope to determine formation fluid and gas properties, well productivity capability, reservoir Kh, and initial reservoir pressure and temperature. Future development of the Tabasco Sands will be based on these findings. Coring options were examined, but it was felt that the high expense and probable low success rate with the extremely unconsolidated formation was prohibitive. Likewise, long term testing to Kuparuk facilities and/or portable test setups, and any form of sand control were seen as too expensive for the initial test well. Once shown to be productive, additional completion investments and data gathering will be justified on this or the subsequent test well. AR3B-6003-93 Mr. David Johnston/, ~OGCC July 10, 1995 Page Two We will not attempt any additional data gathering on the remaining DS 2T wells other than the standard LWD GR/resistivity and occasional neutron/density logs that are currently planned. The remaining wells on 2T are prognosed to have very little Tabasco Sand (<10'); and the option of using a Kuparuk well for additional data gathering and testing was felt to add much less benefit than a dedicated Tabasco well, for only slightly less cost. AA! has always felt that the Tabasco Sands have had potential to become economically viable with the proper development plan. In the case of searching for low cost disposal options during the ongoing DS 2T expansion drilling, we have been careful to ensure logging shows less than 10' of net hydrocarbon pay based on GR and resistivity cutoffs. Based on our current understanding of the reservoir properties, .AAI feels this cutoff is well below any economic net pay limit. If there are any questions on the above please contact the Parker 245 Drilling Engineer, Denise Petrash at 263-4183; the Tabasco well test engineer, Larry Gipson at 265-6850; or myself at 265-6206. Specific details of the operations will be included in the Permit to Drill application, but can be sent to you sooner if you wish. Sincerely, te Development Supervisor CC: R. Crandall B. Wondzell D. Petrash L. Gipson AOGCC - Anchorage AOGCC - Anchorage ATO-1286 ATO-1262 · ,,"LL PERMIT CHECKLIST dev~ redrll [] serv [] ON/OFF SHORE ~3/~ ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... ENGINEERING APPR 14 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. DA~E ? /26. 28. · Conductor string provided ............... iY~~. N Surface casing protects all known USDWs ........ N CMT vol adequate to circulate on conductor & surf csg. N CMT vol adequate to tie-in long string to surf csg . . N CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. N If a re-drill, has a 10-403 for abndnmnt been approved..Y----~ Adequate wellbore separation proposed .......... ~ N If diverter required, is it adequate .......... iQ~ N Drilling fluid program schematic & equip list adequate N ROPEs adequate .................... N press rating adequate; test to '~(~'~-t~ pstg.~ ROPE N Choke manifold complies w/API RP-53 (May-84) ....... Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis Qf shallow gas zones .......... Y//N /</~ ~--~.,' ~ 33. Seabed condition survey (if off-shore) ........ ~/~ N 34. Contact name/phone for weekly progress reports . . . /'. Y N [exploratory only] // GEOLOGY: ENGINEERING: COMMISSION: HOW/jo - A:~FORMS~cheklist rev 03/94 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. '~~ COMPANY NAME : ARCO ALASKA~ INC. ~3 WELL NAME : 2T-TAB-O'~ Alaska FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 5M-lM3-2M23M-MM REFERENCE NO : 95288 LIS Tape Verification Listing Schlumberger Alaska Computing'Center 14-seP-1995 15:36 · ~** REEL HEADER SERVICE NAME : EDIT DATE : 95/09/14 ORIGIN : FLIC REEL NAME : 95288 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 2T-TAB-01, API #50-103-20230-00 · *** TAPE HEADER SERVICE NAME : EDIT DATE : 95/09/14 ORIGIN : FLIC TAPE NAME : 95288 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2T-TAB-01, API ~50-103-20230-00 TAPE HEADER KUPARUK RIVER UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 95288 D.WARNER HASTINGS 1ST STRING 2ND STRING 2T-TAB-O1 501032023~00 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 14-SEP-95 RUN 2 RUN 3 1 lIN 8E 239 555 122.00 122.00 80.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2244.0 PAGE: LIS Tape Ver fication Listing, Schlumberger Alaska Computing Center 14-SEP-1995 15:36 3RD STRING PRODUCTION STRING REMARKS: This Schlumberger Dipole Sonic was logged 1852~ over the open hole section of this well and 1257~ over the cased hole section. Both were reprocessed at AKICS. Because of a disk drive failure, the field logs show the cased hole interval in separate files. The data was merged for ease of processing and organization. **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH DAS 4094.0 2242.0 $ BASELINE CURVE FOR SHIFTS: GRCH.USIT CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR.DAS 88888 3951 3921 3886 3808 3796 3772 3751 3726 3723 3710 370e 3624 357e 3559 0 88890.5 0 3953.5 5 3924.5 0 3889.0 5 3812.5 5 3799.0 0 3774.0 5 3753.5 0 3729.5 0 3726.0 0 3714.5 5 3705.5 5 3628.5 ,5 3574.5 .0 3562,5 LIS Tape Verification Listing Schlumberger Alaska Co~puting'Cen~er 14-SEP-1995 15:36 3555 5 3545 5 3520 5 3501 0 3498 5 3491 0 3484 5 3471 0 3419,5 3405 5 3347 0 3344 5 3336 5 3327 0 3236 ~ 3229 ~ 3225 ~ 3190 5 3159 0 3~98.5 3051.0 3020.0 2973.5 2952.5 2897.5 2872.5 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE 3558.5 3549.0 3525.0 3505.0 3503 5 3494 5 3488 5 3475 0 3424 5 3410 0 3351 5 3348 5 3341 0 3331 0 3240,5 3232,5 3229,0 3194,5 3163.0 3102,5 3054.5 3024.0 2977.5 2956.5 2902.0 2877.0 104.5 RUN NO. PASS NO. MERGE TOP MERGE BASE $ REMARKS: This open hole da~a shifted to the SWS USIT GRCH. $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 3 73 4 66 5 66 6 73 7 65 0 24 1 LIS Tape Verification Listing Schlumberger Alaska Computing'Center 14-SEP-1995 15:36 PAGE: TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 SET TYPE - CHAN *= NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645356 00 000 00 DT DAS US/F 645356 00 000 00 DTSH DAS US/F 645356 09 999 99 CALl DAS IN 645356 99 999 99 GR DAS GAPI 645356 99 999 90 GRCH USIT GAPt 645356 99 999 99 9 1 1 I 4 68 9999990999 9 1 1 1 4 68 9999999999 9 I 1 1 4 68 9999999999 9 1 1 1 4 68 9999999999 9 1 1 1 4 68 9999999999 9 1 1 1 4 68 9999990999 ** DATA DEPT. 4172.999 DT.DAS GR.DAS -999.259 GRCH.USIT DEPT. 2941.599 DT.DAS GR.DAS -999.259 GRCH.USIT , ** END OF DATA ** -999.259 DTSH.DAS -999.259 -999.259 DTSH.DAS -999.259 -999.259 CAL1.DAS -999.259 CAL1.DAS -999.259 -999.259 **** FILE TRAILER FILE NAME : EDIT SERVICE : FLIC VERSION : 991C91 DATE : 95/99/14 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER =*** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/14 MAX EEC SIZE : 1024 FILE TYPE : LO LAST FILE : 14-SEP-1995 15:36 PaGe: FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH DAS 2242.0 985.0 $ BASELINE CURVE FOR SHIFTS: GR,DAS CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH, BASELINE DEPTH GRCH.DAS 88888.0 88892.5 2238.0 2242.5 100.o 104.5 $ REMARKS: GRCH block shif%ed 4.5 to magch ~he top of ~he OH ingerval which was shifted that amoung go GRCH.USIT. Because of a disk drive failure, ~he field logs show ghe cased hole interval in separage files. The data was merged for ease of processing and organization. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verifica%ion Lis%in9 Schlumberger Alaska Compu~|ng Cen%er 14-SEP-1995 15:36 PAGE: TYPE REPR CODE VALUE 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 o 66 1 SET TYPE - CHAN ,, NAME SERV UNIT SERVICE AP1 AP1 API AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT - 645356 00 000 eO e 2 I 1 4 68 00000e00~0 DT DAS US/F 645356 eO 00~ 00 ~ 2 1 I 4 68 0ee0000000 DTSH DAS US/F 645356 ~0 ~00 00 ~ 2 1 1 4 68 000~00~0~0 GRCH DAS GAPI 645356 00 00~ ~0 0 2 1 I 4 68 000000~0~ ** DATA ** DEPT. 2242.500 DT.DAS DEPT. 984.500 DT.DAS END OF DATA ** -999.250 DTSH.DAS 11~.582 DTSH.DAS 302.663 GRCH.DAS 273.667 GRCH.DAS 38.8~6 -999.250 **** FILE TRAILER **** FILE NAME : EDIT .0~2 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing, Schlumberger Alaska Computing Cenber **** FILE HEADER FILE NAME : EDIT .OO$ SERVICE : FLIC VERSION : OOLCO1 DATE : 95/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 14-SEP-1995 15:36 PAGE: FILE HEADER FILE NUMBER RAW OPEN HOLE MAIN PASS Curves and log header daba for each run and tool string in separate files RUN NUMBER: 1 TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DSI $ # LOG HEADER DATA 4092.0 2238.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 16-AUG-gE 7C0-428 2~0 16-AUG-g5 603 16-AUG-95 4175.0 4104.0 1010.0 4076.0 TOOL NUMBER AMM TCC GR DSI DSI DSI DSI $ AUX. MEAS. SONDE TELEMETRY CARTRIDGE GAMMA RAY DIPOLE SONIC DIPOLE SONIC DIPOLE SONIC DIPOLE SONIC BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): AMM-AA 712 TCC-B SGC-SA 60 ECH-MKA 789 DRS-C 4824 SPAC-AA 8025 SMDX-AA 8026 8.500 2244.0 2238.0 LIS Tape Verification Lis%|ng. Schlumberger Alaska Co~pu%ing Cen%er 14-SEP-1995 15:36 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): kXL POLYMER i0.00 63.0 8.0 0.374 0.296 0.751 66.0 66.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: USED PRIMARY DEPTH CONTROL INCLUDING USE OF MAGNETIC MARKS REPROCESSING DONE BY ANCHORAGE COMPUTING CENTER ONLY PRESENTED UPPER DIPOLE IN CASING BUT ALL WAVEFORMS WERE RECORDED. $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 ~ 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing. Schlumberger Alaska Computing Center 14-SEP-1995 15:36 PAGE: TYPE REPR CODE VALUE 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645356 00 000 00 0 3 1 1 4 68 0e00000000 DTRP PTE US/F 645356 00 0e0 0~ 0 3 1 ! 4 68 00~0000~00 DTRP ITP US/F 645356 90 000 00 0 3 1 1 4 68 000000000~ DTTP PTE US/F 645356 00 000 0~ ~ 3 1 1 4 68 0~00000000 DTTP ITP US/F 645356 00 0~0 00 0 3 1 1 4 68 0~0000~000 CHTP DSI 645356 90 000 Oe 0 3 1 1 4 68 000000~000 DTT2 PTE US/F 645356 00 oee 00 0 3 1 1 4 68 0000eoe000 DTT2 ITP US/F 645356 90 000 00 0 3 1 1 4 68 00~000000 CHR2 DSI 645356 00 000 e~ 0 3 1 1 4 68 000eoe00~o DTR2 PTE US/F 645356 00 ~eO Oe e 3 1 1 4 68 0~00000~0 DTR2 ITP US/F 645356 90 eoe ~0 0 3 I 1 4 68 00~0~00000 DT2 PTE US/F 645356 90 000 00 0 3 1 1 4 68 0000000000 DT2 ITP US/F 645356 90 000 Oe 0 3 1 1 4 68 0000000000 DT4P PTE US/F 645356 00 000 00 0 3 I 1 4 68 0000~00000 DT4P ITP US/F 645356 00 0~ 00 0 3 I 1 4 68 e~e0000000 CHRP DSI 645356 00 000 00 0 3 1 ! 4 68 00e00000~0 CALl DSI IN 645356 00 0~0 ~0 0 3 1 1 4 68 0~000000~0 GR DSI GAP1 645356 00 000 00 0 3 1 1 4 68 000~000000 PR DSI 645356 00 0e0 00 0 3 1 ! 4 68 0000900000 RSHC DSI 645356 90 000 00 0 3 I 1 4 68 0000e000~0 DATA DEPT. 4~92.000 DTRP.PTE -999.250 DTRP.ITP -999.250 DTTP.PTE DTTP.ITP -999.250 CHTP.DSI -999.250 DTT2.PTE -999.250 DTT2.ITP CHR2.DSI -999.250 DTR2.PTE -999.250 DTR2.ITP -999.25~ DT2.PTE DT2.ITP -999.250 DT4P.PTE 28.483 DT4P.ITP 28.483 CHRP.DSI CALI.DSI 2.803 GR.DSI 81.699 PR.DSI -999.250 RSHC.DSI DEPT. 2238.000 DTRP.PTE 140.350 DTRP.ITP 14,0.35~ DTTP.PTE DTTP.ITP -999.250 CHTP.DSI 0.~00 DTT2.PTE -999.250 DTT2.ZTP CHR2.DSI 0.639 DTR2.PTE 312.578 DTR2.ITP 312.578 DT2.PTE DT2.ITP 301.052 DT4P.PTE 14~.893 DT4P.ITP 141.893 CHRP.DSI CALI.DSI 9.209 GR.DSI 38.138 PR.DSI 0.361 RSHC.DSI -999.250 -999.250 -999.250 -999.250 -999.250 -999.259 -999.250 308.344 0.727 2.145 END OF DATA LIS Tape Verification Listing. Schlumberger Alaska Computing Center **** FILE TRAILER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 14-SEP-1995 15:36 PAGE: **** FILE HEADER FILE NAME : EDIT ,004 SERVICE : FLIC VERSION : 00iC01 DATE : 95/~9/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass~ tool string~ and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DSI $ LOG HEADER DATA 3682.0 3213,~ DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 16-AU0-95 7C0-428 2~0 16-AUG-g5 603 16-AUG-gs 4175.0 41~4.0 1010.0 4076.0 TOOL NUMBER AMM TCC GR DSI AUX. MEAS. SONDE TELEMETRY CARTRIDGE GAMMA RAY DIPOLE SONIC AMM-AA 712 TCC-B SGC-SA 60 ECH-MKA 789 LIS Tape Verii~icaf, ion Lisf, ing. Schlumberger Alaska Co~pu~ing Center 14-SEP-~995 15:36 PAGE: 13. DSI DIPOLE SONIC DRS-C 4824 DSI DIPOLE SONIC SPAC-AA 8025 DSI DIPOLE SONIC SMDX-AA 8026 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 2244.0 2238.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): KXL POLYMER i0.00 63.0 8.0 0.374 0.296 e.751 66.0 66.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) REMARKS: USED PRIMARY DEPTH CONTROL INCLUDING USE OF MAGNETIC MARKS REPROCESSING DONE BY ANCHORAGE COMPUTING CENTER ONLY PRESENTED UPPER DIPOLE IN CASING BUT ALL WAVEFORMS WERE RECORDED. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 5 66 LIS Tape Veri~ica%ion Lis%in~ Schlumberger Alaska Computing Cen%er 14-SEP-1995 15:36 PAGE: 12 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API AP1 API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645356 9~ 0~0 00 0 4 1 1 4 68 ~000009000 DTRP PTE US/F 645356 ~ 090 00 0 4 I 1 4 68 ~000000000 DTRP ITP US/F 645356 00 ~0 0~ 0 4 1 1 4 68 0090900000 CHRP DSI 645356 00 000 00 ~ 4 1 1 4 68 000~000000 DTR2 PTE US/F 645356 00 9~0 e~ 0 4 1 1 4 68 0090000~00 DTR2 ITP US/F 645356 0~ ~90 0~ ~ 4 1 1 4 68 00000000~0 DT2 PTE US/F 645356 Oe 9~0 0~ 0 4 1 1 4 68 00000~0000 DT2 ITP US/F 645356 00 000 0~ 0 4 1 1 4 68 0990000000 CHR2 DSI 645356 eO 000 00 0 4 I 1 4 68 999eeeeeee CALl DSI IN 645356 00 000 e~ 0 4 1 I 4 68 egeeeeeeee GR DSI GAPI 645356 00 0~0 00 0 4 I I 4 68 0000000000 DATA DEPT. 3700.000 DTRP.PTE -999.250 DTRP.ITP -999.250 CHRP.DSI DTR2.PTE -999.250 DTR2.ITP -999.250 DT2.PTE -999.25~ DT2.ITP CHR2.DSI -999.250 CALI.DSI 2.803 GR.DSI 123.417 DEPT. 3212.5e0 DTRP.PTE 123.888 DTRP.ITP 123.888 CHRP.DSI DTR2.PTE 297.931 DTR2.ITP 297.931 DT2.PTE 290.763 DT2.ITP CHR2.DSI 0.936 CALI.DSI -999.250 GR.DSI -999.25e -999.250 -999.25~ 0.974 290.763 END OF DATA LIS Tape Verification Listing. Schlumberger Alaska Computing Center **** FILE TRAILER FILE NAME : EDIT ,904 SERVICE : FLIC VERSION : 991C91 DATE : 95/99/14 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT ,995 SERVICE : FLIC VERSION : 991C91 DATE : 95/99/14 MAX RE¢ SIZE : 1924 FILE TYPE : LO LAST FILE : 14-SEP-1995 15:36 PAGE: 13 FILE HEADER FILE NUMBER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing, PASS NUMBER: 1 DEPTH INCREMENT: 9,5999 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DSI $ LOG HEADER DATA 2238.9 974.9 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 16-AUG-95 7C9-428 299 16-AUG-g5 693 16-AUG-g5 4175.0 4,194.9 1919.~ 4076.9 TOOL NUMBER AMM TCC GR DSI DSI DSI AUX. MEAS. SONDE TELEMETRY CARTRIDGE GAMMA RAY DIPOLE SONIC DIPOLE SONIC DIPOLE SONIC AMM-AA 712 TCC-B SGC-SA 69 ECH-MKA 789 DRS-C 4824 SPAC-AA 8925 LIS Tape Verif|cation Listing Schlumberger Alaska Computing Center 14-SEP-1995 15:36 DSI DIPOLE SONIC $ SMDX-AA 8026 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 2244.0 2238.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C$): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): kXl POLYMER 10.00 63 .e 8.0 0.374 0.296 0.751 66.0 66.0 66 .~ NEUTRON TOOL TOOL TYPE-(EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: USED PRIMARY DEPTH CONTROL INCLUDING USE OF MAGNETIC MARKS REPROCESSING DONE BY ANCHORAGE COMPUTING CENTER ONLY PRESENTED UPPER DIPOLE IN CASING BUT ALL WAVEFORMS WERE RECORDED. $ LIS FORMAT DATA PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 2 66 3 73 4 66 5 66 6 73 7 65 0 0 64 LIS Tape Verification List|nQ, Schlumberger Alaska Co~puting Center 14-SEP-1995 15:36 PAGE: 15 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645356 00 ~0 00 0 5 1 1 4 68 000000~000 DTR2 PTE US/F 645356 00 000 00 e 5 1 1 4 68 000000ee00 DTR2 ITP US/F 645356 00 00e 00 e 5 1 1 4 68 0000000e00 DT2 PTE US/F 645356 00 0e0 00 0 5 1 1 4 68 OeOOOe0000 DT2 ITP US/F 645356 00 0~0 00 ~ 5 1 1 4 68 0000000000 CHR2 DSI 645356 00 000 00 0 5 1 1 4 68 0~00~000 DT4P PTE US/F 645356 ~0 000 00 0 5 1 I 4 68 000~00~000 DT4P ITP US/F 645356 00 00~ 00 ~ 5 1 1 4 68 0~00000e00 DTRS PTE US/F 645356 00 00e 00 0 5 1 1 4 68 000eoOe000 DTRS ITP US/F 645356 00 00e 00 0 5 I 1 4 68 0000e00000 CHRS DSI 645356 ee eee ee e 5 I 1 4 68 eeeeeeeeee CHRP DSI 645356 eO e00 Oe 0 5 1 1 4 68 0000000000 CALl DSI IN 645356 00 000 00 0 5 1 1 4 68 0000000000 GR DSI GAPI 645356 00 0~ 00 ~ 5 1 1 4 68 0~00000~00 PR DSI 645356 00 0~0 00 0 5 1 1 4 68 0~00000000 RSHC DSI 645356 00 000 00 0 5 1 I 4 68 0000000000 DATA ** DEPT. 2238.eOe DTR2.PTE 310.646 DTR2.ITP 310.646 DT2.PTE DT2.ITP 302.663 CHR2.DSI 0.472 DT4P.PTE -999.25~ DT4P.ITP DTRS.PTE -999.250 DTRS.ITP -999.250 CHRS.DSI 0.0e0 CHRP.DSI CALI.DSI 9.180 GR.DSI 38.806 PR.DSI -999.250 RSHC.DSI DEPT. 98~.00e DTR2.PTE 278.797 DTR2.ITP 278.797 DT2.PTE DT2.ITP 273.667 CHR2.DSI 0.433 DT4P.PTE 110.582 DT4P.ITP DTRS.PTE -999.25~ DTRS.ITP -999.250 CHRS.DSI 0.000 CHRP.DSI CALI.DSI -999.250 GE.DSI -999.250 PR.DSI 0.402 RSHC.DSI 302.663 -999.250 -999.250 -999.250 273.667 110.582 ~.468 2.475 END OF DATA LIS Tape Verification Listin~ Schlumberger Alaska Computing Center 14-SEP-1995 15:36 PAGE: **** FILE TRAILER FILE NAME : EDIT .OO5 SERVICE : FLIC VERSION : OO1CO1 DATE : 95/09/14 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : ***= TAPE TRAILER SERVICE NAME : EDIT DATE : 95/09/14 ORIGIN : FLIC TAPE NAME : 95288 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2T-TAB-O1, API #50-103-20230-90 **** REEL TRAILER SERVICE NAME : EDIT DATE : 95/09/[4 ORIGIN : FLIC REEL NAME ,: 95288 CONTINUATION # : PREVIOUS REEL COMMENT : ARCO ALASKA INC., KUPARUK 2T-TAB-O1, API #50-[03-20250-00 ALASKA COMPUTING CENTER SCHLUMBERGER RECEIVED COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE AP1 NUMBER REFERENCE NO : ARCO ALASKA~ INC. : 2T-TAB-O1 : KUPARUK RIVER UNIT : NORTH SLOPE : ALASKA : 50-103-20230-~0 : 95289 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-SEP-1995 16:06 **** REEL HEADER SERVICE NAME : EDIT DATE : 95/09/ 6 ORIGIN : FLIC REEL NAME : 95289 CONTINUATION ~ : PREVIOUS REEL : COMMENT : ARCO ALASKA INC,, KUPARUK 2T-TAB-01, API #50-103-20230-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 95/09/ 6 ORIGIN : FLIC TAPE NAME : g52Bg CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC,, KUPARUK 2T-TAB-01, API #50-105-2~230-00 TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 2T-TAB-01 501032023000 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 6-SEP-95 BIT RUN 1 BIT RUN 2 BIT RUN 3 JOB NUMBER: 95289 LOGGING ENGINEER: RUMINER OPERATOR WITNESS: GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: 8E FNL: FSL: 239 FEL: FWL: 555 ELEVATION(FT FROM MSL 0) KELLY BUSHING: 122.00 DERRICK FLOOR: 122.00 GROUND LEVEL: 80.5~ WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.5~0 9.625 2244.0 2ND STRING PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-SEP-1995 16:06 3RD STRING PRODUCTION STRING REMARKS: Well drilled 14-AUG through 16-AUG-95 with CDR and CDN. All data was collected in a single bit run, $ $ **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged, DEPTH INCREMENT.: 0.5~00 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 2124.0 4130.0 CDN 2048.0 4064.0 $ BASELINE CURVE FOR SHIFTS: GRCH,USIT CURVE SHIFT DATA (MEASURED DEPTH) -EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR.MWD 88888.0 88885.5 397~.0 3967.5 39S7.5 3954.5 3934.5 3934.5 3890,~ 3889,~ 3856.0 3855.~ 3841.5 3840.0 3831.5 3831,0 3813.5 3812.0 3755.0 3755.0 3705.5 3705.5 3665.5 3666.0 3628.5 3628.5 3613.0 3612.5 3601.0 3600.5 3567.5 3567.5 3563.0 3562.5 3556.5 3556.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-SEP-1995 16:06 3549.5 3549.0 3543.5 3543.5 3536.5 3535.5 3524.5 3524.5 3508.0 3507.0 3503.5 3503.5 3495.5 3494.5 3434,0 3433.5 3352.5 3352.0 3349,5 3348.5 3332,5 3331.5 3328.5 3328,0 3289,5 3289,0 3239.0 3238.0 3230.0 3229.0 32~7.0 3206.0 3182.5 3180.5 3173.0 3172.0 3152.0 3150.5 3139.0 3138.0 3093.5 3092.5 3065.0 3063.5 3049.0 3047.0 2979.0 2977.5 2930.5 2929.5 2896.5 2895.0 2893.0 2892.0 2876.5 2875.5 100.0 99.0 $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE REMARKS: The depth adjustments shown above reflect the MWD GR to the USIT GR logged by SWS. All other MWD curves were carried with the GR. This file also contains the Very Enhanced ~RO resisitiVity with 2' average tha~ was reprocessed at GeoQuest. LIS FORMAT DATA PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-SEP-1995 16:06 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 $ 75 60 4 66 1 5 66 6 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API AP1 API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 52226 00 000 Oe 0 1 1 1 4 68 00~0~00000 RA MWD OHMM 52226 0~ 000 00 0 1 I 1 4 68 00~00000~0 RP MWD OHMM 52226 00 000 00 0 1 I 1 4 68 0000000~00 VRA MWD OHMM 52226 0~ 000 00 0 1 1 1 4 68 00~000~00 VRP MWD OHMM 52226 00 ~00 00 ~ 1 1 1 4 68 ~000~000~0 DER MWD OHMM 52226 00 000 eO 0 1 1 1 4 68 00~0000e00 ROP MWD FPHR 52226 00 000 00 0 1 I 1 4 68 00~00~0000 FET MWD HR 52226 00 000 00 0 1 1 1 4 68 00eOeOOeO~ GE MWD GAPI 52226 00 000 00 0 1 1 1 4 68 ooeoeeeooe RHOB MWD G/C3 52226 Oe ~00 00 0 1 1 1 4 68 000000~0~ DRHO MWD G/CS 52226 00 e00 00 0 1 1 I 4 68 00eoeoooee PEF MWD BN/E 52226 00 000 00 0 1 1 I 4 68 00eOOOe000 CALN MWD IN 52226 eO 000 ~0 0 1 1 I 4 68 0000000000 NPHI MWD PU-S 52226 00 ~00 ~0 0 1 1 1 4 68 00~0000~00 GRCH US~T GAPI 52226 0~ 000 0~ 0 I 1 1 4 68 00~0000~ DATA DEPT. 4172.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 119.205 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 GRCH.USIT -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-SEP-1995 16:06 PAGE: DEPT. 2041.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP,MWD -999.250 DER.MWD -999,250 ROP,MWD -999.250 FET,MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD 48,200 GRCH.USIT -999.250 ** END OF DATA ** -999.250 -999.250 -999.250 **** FILE TRAILER **** FILE NAME : EDIT SERVICE : FLIC VERSION : OOlCO1 DATE : 95/09/ MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION .: 001C01 DATE : 95/09/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CDR 2124.0 CDN 2048.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): 4130.0 4064.0 16-AUG-95 FAST2.5/20.4 V4.0C MEMORY 4175.0 2244.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-SEP-[995 [6:06 PAGE: BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 417S.0 10.3 36.6 TOOL NUMBER CDR CDN $ RESISTIVY/GAMMA RAY NEUTRON/DENSITY RGS035 NDS052 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.500 2244.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 9.70 57.e 20¢0 ~.374 0.296 66.0 66.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: **************** BIT RUN RES TO BIT: 42.03'; GR TO BIT: 52.45'. NEUT TO BIT: 114.64'; DENS TO BIT: 107.66' Well drilled from 2255' %o 417~' Res. mud: 0.374 Filt: 0.2~6 Cake: 0.751 666 degf Gamma Ray may be sl|ghtl¥ elevated due to 900~ ppm K Well TD'd at e5:39 on 15-AUG-95. TD deviation le.28 Data from downhole recorded memory, V4.0C software. $ LIS FORMAT DATA LIS Tape Verii~ica%ion Listing Schlumberger Alaska Computing Cen%er 6-SEP-1995 16:06 DATA FORMAT SPECIFICATION RECORD · * SET TYPE - 64EB ~, TYPE REPR CODE VALUE 1 66 2 66 0 S 75 64 4 66 5 66 6 7S 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ~, PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 52226 00 000 00 0 2 1 1 4 68 0000000000 ATR LW1 OHMM 52226 ~ ¢~0 0~ 0 2 1 1 4 68 0000000000 PSR LW1 OHM,M 52226 ~0 0~0 00 0 2 1 1 4 68 00000~00~0 DER LW1 OHMM 52226 0~ ~0 00 0 2 1 1 4 68 00000~0000 ROPE LW1 F/HR 52226 00 ~0 0~ 0 2 1 1 4 68 000000000~ TABR LW1 HR 52226 eO 0~0 0~ 0 2 1 1 4 68 0000000000 GR LW1 GAP/ 52226 00 eeo 00 0 2 1 1 4 68 00000~00e0 RHOB LWl G/C3 52226 Oe e~O 0~ 0 2 1 1 4 68 eoo~o~ooeo DRHO LW1 G/C3 52226 Oe e~O 00 0 2 1 1 4 68 0000000e00 PEF LWl BN/E 52226 00 CALN LWl IN 52226 ~0 e00 0~ 0 2 1 1 4 68 000~000e00 TNPH LW1 PU 52226 ~ ~00 0~ 0 2 1 I 4 68 ~0~0000000 TABD LW1 52226 00 DPHI LW1 PU 52226 00 000 00 0 2 1 1 4, 68 ~000000000 DCAL LWl IN 52226 00 000 00 0 2 1 1 4 68 ~0000e0000 NSI LW1 52226 00 000 00 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 4174.500 ATR.LW1 -999.250 PSR.LW1 -999.250 DER.LW1 ROPE.LWl 119.205 TABR.LWl -999.250 GR.LW1 -999.250 RHOB.LW1 DRHO.LWl -999.250 PEF.LW1 -999.250 CALN.LW1 -999.250 TNPH.LW1 TABD.LWl -999.250 DPHI.LW1 -999.250 DCAL.LW1 -999.250 NSI.LW1 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Sch ~ umberger A ~ aska Comput ing Center 6-SEP-1995 16:06 PAGE: DEPT. 2042.500 ATR.LW1 -999.250 PSR.LW1 -999.250 ROPE.LW[ -999.250 TABR.LW1 -999.250 GR.LW1 -999.250 DRHO.LW[ -999.250 PEF.LW[ -999.250 CALN.LWl -999.250 TABD.LW[ -999.250 DPHI.LW[ -999.250 DCAL.LW[ -999.250 DER.LW[ RHOB.LWl TNPH.LW[ NSI.LW[ -999.250 -999.250 48.200 -999.250 END OF DATA **** FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C0~ DATE : 95/09/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATE : 95/09/ 6 ORIGIN .: FLIC TAPE NAME : 95289 CONTINUATION # : ~ PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2T-TAB-O1, AP1 ~50-~03-20230-00 **** REEL TRAILER SERVICE NAME : EDIT DATE : 95/09/ 6 ORIGIN : FLIC REEL NAME : 95289 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 2T-TAB-O1, API #50-[03-20230-00