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Home My WebLink About199-021C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-03-21_15913_KRU_2N-309_ArcherVividAcousticLDL_Run2_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15913 KRU 2N-309 50-103-20293-00 Archer Vivid Acoustic LDL 21-Mar-23 (run2) DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:199-021 T37618 Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.25 14:14:00 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-03-04_21127_KRU_2N-309_ArcherVividAcousticLDL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 21127 KRU 2N-309 50-103-20293-00 Archer Vivid Acoustic LDL 04-Mar-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM 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: CPAI KRU 2N-309 (PTD #199-021) failed the AOGCC witnessed MIT-IA yesterday. Date:Thursday, August 4, 2022 8:49:38 AM Attachments:image001.png AnnComm Surveillance TIO for 2N-309.pdf Diagnostic MIT-IA & DDT-IA 3 Aug 22.xlsx From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, August 4, 2022 7:58 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: CPAI KRU 2N-309 (PTD #199-021) failed the AOGCC witnessed MIT-IA yesterday. Chris- KRU 2N-309 (PTD #199-021) was shut in the 2nd of August 2022 for a failed AOGCC witnessed MIT- IA. DHD performed the initial diagnostics which yielded passing T & IC pack off tests, passing MIT-IA and passing IA draw down test. To investigate whether the pass/fail inconsistency is an online/offline based event, CPAI intends to bring the well back on injection for a maximum of 30 days and perform the MIT-IA again while the well is online. If the well passes the diagnostic MIT-IA, an AOGCC witnessed MIT-IA will be rescheduled. If the well fails the follow up MIT-IA while online, the well will be shut in and freeze protected. CPF2 is planning to shut down for their 10 day turn around on the 10th of August so the additional diagnostics will be conducted after the turnaround is complete. Please let me know if you have any questions or disagree with the plan. Attached is a 10- 426 form for the diagnostic MIT-IA and IA DDT, well bore schematic and 90 TIO plot. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, August 2, 2022 8:18 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI KRU 2N-309 (PTD #199-021) failed the AOGCC witnessed MIT-IA yesterday. Chris- KRU 2N-309 (PTD #199-021) failed the AOGCC witnessed MIT-IA yesterday. The well was shut in and freeze protected and the initial diagnostics have been scheduled to begin today. The proper paper work for repair or continued injection will be submitted as required. Attached is the 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: RKB 7,445.0 11/3/2018 2N-309 ferguspLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: ANNOTATE TUBING LEAK, INSTALL PATCH 12/29/2019 2N-309 condijwCasing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.06 Top (ftKB)34.6 Set Depth (ftKB)115.0 Set Depth (TVD) …115.0 Wt/Len (l…62.58 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)7 5/8 ID (in)6.87 Top (ftKB)34.6 Set Depth (ftKB)2,583.4 Set Depth (TVD) …2,302.8 Wt/Len (l…29.70 GradeL-80 Top ThreadBTC MODCasing DescriptionPRODUCTION 5.5"x3.5"OD (in)5 1/2 ID (in)4.95 Top (ftKB)33.0 Set Depth (ftKB)8,058.9 Set Depth (TVD) …5,587.5 Wt/Len (l…15.50 GradeL-80 Top ThreadLTC-MODTubing StringsTubing DescriptionTUBING String Ma…3 1/2 ID (in)2.99 Top (ftKB)30.4 Set Depth (ft…7,157.0 Set Depth (TVD) (…5,053.7 Wt (lb/ft)9.30 GradeL-80 Top ConnectionEUE8RDMODCompletion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 30.4 30.4 0.13 HANGER FMC GEN V 5M TUBING HANGER 3.500 510.7 510.7 0.28 NIPPLE CAMCO DS NIPPLE 2.875 7,030.4 4,977.5 53.54 SLEEVE-C BAKER CMU SLIDING SLEEVE; CLOSED 11/05/18 2.813 7,132.4 5,038.8 52.64 NIPPLE CAMCO D NIPPLE 2.750 7,139.5 5,043.1 52.64 LOCATOR BAKER LOCATOR 2.985 7,140.4 5,043.7 52.64 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,004.0 4,961.8 53.26 PATCH - UPR PKR (ME) 2.72" P2P PACKER, CPP352092, SPACER PIPE, ANCHOR LATCH, CPAL35120, OAL OF ASSEMBLY = 33.59' 12/29/201 9 1.625 7,008.0 4,964.2 53.30 SPACER PIPE 2-1/16" P110 SPACER PIPE 12/29/201 9 1.610 7,013.0 4,967.2 53.36 TUBING LEAK TUBING LEAK IDENTIFIED BY LDL, 0.15 BPM LLR AT 3000 PSI 11/10/201 8 2.992 7,037.0 4,981.5 53.57 PATCH - LWR PKR (ME) 2.72" P2P PACKER, CPP35234, OAL 4.01' 12/28/201 9 1.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,526.0 7,566.0 5,274.7 5,298.8 S-5, 2N-309 9/24/2005 6.0 APERF 2.5" HSD PJ HMX, 60 deg phase 7,571.0 7,611.0 5,301.8 5,325.7 S-3, 2N-309 4/3/1999 4.0 IPERF 2.5" HC/BH; 60 deg ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,594.4 3,505.3 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 7/31/1999 2 7,080.3 5,007.3 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 10/26/2001 2N-309, 12/31/2019 7:26:56 AMVertical schematic (actual) PRODUCTION 5.5"x3.5"; 33.0- 8,058.9 IPERF; 7,571.0-7,611.0 APERF; 7,526.0-7,566.0 LOCATOR; 7,139.5 NIPPLE; 7,132.4 GAS LIFT; 7,080.3 PATCH - LWR PKR (ME); 7,037.0 SLEEVE-C; 7,030.4 SPACER PIPE; 7,008.0 TUBING LEAK; 7,013.0 PATCH - UPR PKR (ME); 7,004.0 GAS LIFT; 4,594.4 SURFACE; 34.6-2,583.4 NIPPLE; 510.7 CONDUCTOR; 34.6-115.0HANGER; 30.4 KUP INJ KB-Grd (ft)41.21 Rig Release Date3/21/19992N-309...TDAct Btm (ftKB)8,075.0Well AttributesField NameTARN PARTICIPATING AREA Wellbore API/UWI501032029300 Wellbore StatusINJ Max Angle & MDIncl (°)55.21 MD (ftKB)6,284.61WELLNAME WELLBORE2N-309AnnotationLast WO:End DateH2S (ppm) DateCommentSSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-309 KUPARUK RIV U TARN 2N-309 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 2N-309 50-103-20293-00-00 199-021-0 W SPT 5043 1990210 1500 1700 1700 1700 470 470 470 4YRTST F Adam Earl 8/1/2022 MIT-IA failed 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 TARN 2N-309 Inspection Date: Tubing OA Packer Depth 1030 2510 2040IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803211059 BBL Pumped:0.7 BBL Returned:0.6 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 3UHVVXUHORVVH[FHHGHG 99 F MIT-IA failed James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:49:30 -08'00' Submit to: OOPERATOR: FIEL D / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 199-021 Type Inj W Tubing 1830 1820 1820 1820 Type Test P Packer TVD 5044 BBL Pump 1.0 IA 233 3040 2970 2940 Interval O Test psi 1500 BBL Return N/A OA 434 436 435 435 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 199-021 Type Inj W Tubing 1820 1820 1815 1815 1815 1815 Type Test O Packer TVD 5044 BBL Pump N/A IA 2940 210 231 233 234 235 Interval O Test psi 1500 BBL Return N/A OA 435 430 430 430 430 429 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 2N Pad Miller/Hills 08/03/22 Notes:Diagnostic MIT-IA Notes: KRU 2N-309 KRU 2N-309 Notes:Diagnostic IA draw down test Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c al In t eg r ity Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)Diagnostic MIT-IA DDT-IA 3 Aug 22 (002) 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: CPAI KRU 2N-309 (PTD #199-021) failed the AOGCC witnessed MIT-IA yesterday. Date:Wednesday, August 3, 2022 11:02:29 AM Attachments:image001.png AnnComm Surveillance TIO for 2N-309.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, August 2, 2022 8:18 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI KRU 2N-309 (PTD #199-021) failed the AOGCC witnessed MIT-IA yesterday. Chris- KRU 2N-309 (PTD #199-021) failed the AOGCC witnessed MIT-IA yesterday. The well was shut in and freeze protected and the initial diagnostics have been scheduled to begin today. The proper paper work for repair or continued injection will be submitted as required. Attached is the 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: RKB 7,445.0 11/3/2018 2N-309 ferguspLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: ANNOTATE TUBING LEAK, INSTALL PATCH 12/29/2019 2N-309 condijwCasing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.06 Top (ftKB)34.6 Set Depth (ftKB)115.0 Set Depth (TVD) …115.0 Wt/Len (l…62.58 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)7 5/8 ID (in)6.87 Top (ftKB)34.6 Set Depth (ftKB)2,583.4 Set Depth (TVD) …2,302.8 Wt/Len (l…29.70 GradeL-80 Top ThreadBTC MODCasing DescriptionPRODUCTION 5.5"x3.5"OD (in)5 1/2 ID (in)4.95 Top (ftKB)33.0 Set Depth (ftKB)8,058.9 Set Depth (TVD) …5,587.5 Wt/Len (l…15.50 GradeL-80 Top ThreadLTC-MODTubing StringsTubing DescriptionTUBING String Ma…3 1/2 ID (in)2.99 Top (ftKB)30.4 Set Depth (ft…7,157.0 Set Depth (TVD) (…5,053.7 Wt (lb/ft)9.30 GradeL-80 Top ConnectionEUE8RDMODCompletion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 30.4 30.4 0.13 HANGER FMC GEN V 5M TUBING HANGER 3.500 510.7 510.7 0.28 NIPPLE CAMCO DS NIPPLE 2.875 7,030.4 4,977.5 53.54 SLEEVE-C BAKER CMU SLIDING SLEEVE; CLOSED 11/05/18 2.813 7,132.4 5,038.8 52.64 NIPPLE CAMCO D NIPPLE 2.750 7,139.5 5,043.1 52.64 LOCATOR BAKER LOCATOR 2.985 7,140.4 5,043.7 52.64 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,004.0 4,961.8 53.26 PATCH - UPR PKR (ME) 2.72" P2P PACKER, CPP352092, SPACER PIPE, ANCHOR LATCH, CPAL35120, OAL OF ASSEMBLY = 33.59' 12/29/201 9 1.625 7,008.0 4,964.2 53.30 SPACER PIPE 2-1/16" P110 SPACER PIPE 12/29/201 9 1.610 7,013.0 4,967.2 53.36 TUBING LEAK TUBING LEAK IDENTIFIED BY LDL, 0.15 BPM LLR AT 3000 PSI 11/10/201 8 2.992 7,037.0 4,981.5 53.57 PATCH - LWR PKR (ME) 2.72" P2P PACKER, CPP35234, OAL 4.01' 12/28/201 9 1.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,526.0 7,566.0 5,274.7 5,298.8 S-5, 2N-309 9/24/2005 6.0 APERF 2.5" HSD PJ HMX, 60 deg phase 7,571.0 7,611.0 5,301.8 5,325.7 S-3, 2N-309 4/3/1999 4.0 IPERF 2.5" HC/BH; 60 deg ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,594.4 3,505.3 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 7/31/1999 2 7,080.3 5,007.3 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 10/26/2001 2N-309, 12/31/2019 7:26:56 AMVertical schematic (actual) PRODUCTION 5.5"x3.5"; 33.0- 8,058.9 IPERF; 7,571.0-7,611.0 APERF; 7,526.0-7,566.0 LOCATOR; 7,139.5 NIPPLE; 7,132.4 GAS LIFT; 7,080.3 PATCH - LWR PKR (ME); 7,037.0 SLEEVE-C; 7,030.4 SPACER PIPE; 7,008.0 TUBING LEAK; 7,013.0 PATCH - UPR PKR (ME); 7,004.0 GAS LIFT; 4,594.4 SURFACE; 34.6-2,583.4 NIPPLE; 510.7 CONDUCTOR; 34.6-115.0HANGER; 30.4 KUP INJ KB-Grd (ft)41.21 Rig Release Date3/21/19992N-309...TDAct Btm (ftKB)8,075.0Well AttributesField NameTARN PARTICIPATING AREA Wellbore API/UWI501032029300 Wellbore StatusINJ Max Angle & MDIncl (°)55.21 MD (ftKB)6,284.61WELLNAME WELLBORE2N-309AnnotationLast WO:End DateH2S (ppm) DateCommentSSSV: NIPPLE Wallace, Chris D (CED) From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Sunday, February 14, 2021 5:31 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler; Well Integrity Specialist CPF2 Subject: Kuparuk Injector 2N-309 (PTD# 199-021) report of slow IA pressure fall of update. Attachments: 2N-309 90 Day TO Plot 2.14.21.pdf Chris- Kuparuk Injector 2N-309 (PTD# 199-021) has completed its 30 day monitor period and has not displayed any further indications of IA pressure fall off. The well passed a diagnostic MIT -IA, T & IC pack off tests and an IA DDT. During the initial set of diagnostics DHD identified a potential leak point on the IA casing valve and the fitting was immediately replaced. CPAI believes the faulty fitting to be the cause of the initial pressure fall off and will return the well to normal injection status. Attached is a copy of the most recent 90 day TIO plot. Please let me know if you have any questions of disagree with the plan. Cheers, Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM cWWC&'NYlps From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, January 13, 20219:32 AM To: Wallace, Chris D (CED) <chris.waIlace @a laska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: Kuparuk Injector 2N-309 (PTD# 199-021) report of slow IA pressure fall off. Chris- Kuparuk Injector 2N-309 (PTD# 199-021) was reported with a slow IA pressure falloff. Initially the downward trend of the IA pressure was following suite with the decrease in well head temperature. However, the well has thermally stabilized and the IA pressure has continued to decrease. CPAI intends to leave the well online and conduct the initial set of diagnostics to investigate the cause of the IA pressure reduction. If the initial set of testing suggests IA integrity, the IA will be left with an elevated pressure and will be monitored for 30 days to verify long term IA integrity. Depending on the results of the testing and monitor period the proper paperwork for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the well bore schematic and 90 day TIO plot. Cheers, Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Wallace, Chris D (CED) From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, January 13, 2021 9:32 AM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler; Well Integrity Specialist CPF2 Subject: Kuparuk Injector 2N-309 (PTD# 199-021) report of slow IA pressure fall off. Attachments: 2N-309.pdf; 2N-309 90 day TIO.pdf Chris- Kuparuk Injector 2N-309 (PTD# 199-021) was reported with a slow IA pressure fall off. Initially the downward trend of the IA pressure was following suite with the decrease in well head temperature. However, the well has thermally stabilized and the IA pressure has continued to decrease. CPAI intends to leave the well online and conduct the initial set of diagnostics to investigate the cause of the IA pressure reduction. If the initial set of testing suggests IA integrity, the IA will be left with an elevated pressure and will be monitored for 30 days to verify long term IA integrity. Depending on the results of the testing and monitor period the proper paperwork for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the well bore schematic and 90 day TIO plot. Cheers, Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 530-9777 WELLS TEAM Ca+omP Ps Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED APR 2 3 2020 AOGCC 19 90 21 32797 23 -Apr -20 WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 1 2N-309 50-103-20293-00 906207893 Tarn Packer Setting Record Final -Field 28 -Dec -19 0 1 2 2W-12 50-029-21240-00 906212841 Kuparuk Packer Setting Record Final -Field 2 -Jan -20 0 1 3 3H -14B 50-103-20092-02 906340305 Kuparuk Packer Setting Record Final -Field 1 -Mar -20 0 1 4 3H-26 50-103-20208-00 906340306 Kuparuk Leak Detect Log Final -Field 28 -Feb -20 0 1 5 3H-35 50-103-20805-00 906363845 Kuparuk Radial Cement Bond Log Final -Field 4 -Mar -20 0 1 6 3H -14B 50-103-20092-02 906349140 Kuparuk Multi Finger Caliper Final -Field 29 -Feb -20 0 1 7 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS _ANC@ha Iliburton.com Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AN 1 1 2020 1. Operations Abandon Plug Perforations LJ Fracture Stimulate Li Pull Tubing LJ Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Tbq patch ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska Inc ment Develo p ❑ Exploratory ❑ 199-021 3. Address: Stratigraphic El Service ❑✓ 6. API Number: PO Box 100360, Anchorage, AK, 99510 50-103-20293-00-00 7. Property Designation (Lease Number): 8. Well Name and Number. ADL 380054, ADL 375074 KRU 219-309 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Ku aruk River Field/Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 8075 feet Plugs measured NA feet true vertical 5597 feet Junk measured NA feel Effective Depth measured 7445 feet Packer measured 7140 feet true vertical 5226 feet true vertical 5044 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80, 16" 115' 115' Surface 2549' 7-5/8" 2583' 2303' Intermediate Production 8026' 5.5x3.5" 8059' 5588' Liner Perforation depth Measured depth 7526-7566',7571-7611' feet True Vertical depth 5275-5299',5302-5326' feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 7157' 5054' Packers and SSSV (type, measured and true vertical depth) Packer: 7140' MD, 5044' TVD Nipple: 511'MD, 511' TVD 12. Stimulation or cement squeeze summary: NA Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Tubing Pressure Pressure2300 Prior to well operation: 850 psi 1740 psi Subsequent to operation: 1440 1660 psi 1200 psi 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development❑ Service Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑� GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-565 Authorized Name: Sayeed Abbas Contact Name: Sayeed Abbas Authorized Title: Staff DrillsitteJP�etroleum Engineer Email: saveed.abbas(a.conocoohillios com �1.Con�ttact Authorizetl Signature: Date: � !(z Contact Phone: 907-265-1109 3�Jr�_r21a Farm 10-404 Revised 4/2017 0 %1Y17.0RBDMS AN 2 3 2020 Submit Original Only ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 January 20th, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find a 10-404 report of Sundry Well Operations for 2N-309. ConocoPhillips Alaska, Inc. has completed setting a retrievable tubing patch to regain tubing integrity above the seal assembly for 2N-309. The well passed an internal MITIA test and has been put on injection. After a period of stabilization, the well will undergo a state witnessed MITIA test. If you have any questions regarding this matter, please contact me at 907-265-1109. Sincerely, Saye d Abbas Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Email: sayeed.abbas@conocophillips.com Ph: 907-265-1109 Attachments: Report of Sundry Well Operations Daily report of Well Operations Well Schematic 1 A&IKUP INJ WELLNAME 2N-309 WELLBORE 2N-309 (An0001'himps 11Attnoutes Max Angie&MD TD Alaska. Im. FIeW Name WeIWreA%KNA Wellhote $talusMDIXK81 AC18, (XKBI NPARTICIPATING A 1 1 521 428461 $075.0 SSSV. NIPPLE H2SfPNn) pati p'mdetlen Em Due KIGMgg RIB ReW.M.D. Last WO: 41.21 312111999 3Nare.1gG1fiU1g7W:5d AM Last Tag Vdkalss undo pound) annoWYn DeplM1 (IINB1 EM Dale µpOWe last Mol By EMO Last Tag�RKB >0d401113 2N309 fergluD - - Last Rev Reason HANGER:JJ.1 M,ghlim EnJ Date WelWre Last IAA By Rev Reason'. ANNOTATE TUBING LEAK, INSTALL PATCH 12129/2019 2N-309 CoMijw casing Strings. caging Description ODI'") mfinl rap(nNB1 set Dapin mlcBl sM Depfn (IYD1-. wLLen IL_G,ede Tap"'an CONDUCTOR i6 15.06 34.6 115.0 1150 62.58 eW0 WELDED Casing cesplpb, OD(inI ID pnl Ep(rtl(B1 SNDeptn rytKBl SU DeptM1 (NDL.. YMen D... Gatle BTC MOD SURFACE 7518 8.87 34.8 2,583.4 2.302.8 2970 L-80 BTC MOD -na' Oaacription OOlin1 Ipllnl 33.7 Bl 9N Oepin (flKBI Sd OepN rrMp1,. 1550 P..... TOPTM1retl PRODUCTION 55"x3.5' 51/2 4.95 33.0 $W8.9 5,58).5 1550 L-80 LTC -MOD Tubing Strings co_rv_ou_cr_o_R:_aas_u_m Tubing Oescripoon String Ma... ID (in) Top(XKB) ScNnIh X. SMDepfn(1V011--WIdbMj G,atle iop Lonnxlion TUBING 31/2 299 30.4 7,157.0 5,053.) 9.30 L-80 EUEBRDMOD Completion Details MPPLF, 51x7 Top 1X1001 T('KB)01 TOP tinct nem�5 N -u-, Com 1. (1.) 30.4 304 0.13 HANGER FMCGENV5MTUBINGHANGER 3.500 510.7 510.7 0.28 NIPPLE CAMCO DS NIPPLE 2.875 7,030.4 4,977.5 JUAKtRCMU SLIDING SLEEVE', CLOSED 1110511-r-2.813 7,1324 5,038.8 52.61 NIPPLE CAMCO DNIPPLE 2.750 7,139.5 5,043.1 52.60 LOCATOR BAKER LOCATOR 2.985 7.1404 5.0433 52fi4 SEAL A$ Y BAKER 8040 SEAL ASSEM8LY 3.00 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top) ropincl SURFACE 3asg.5aB.a� Top (XKB) two) D•n Co. Run side ID Ont 7,04. 0 d,961. 53fl 26 PATCH -UPR PKR(ME) 2. IT P2P PACKER, CPPGS2092, SWERPIPE, ANCHOR LATCH, CPAL351 n, DAL OF ASSEMBLY= 1ffi900 9 1.625 3.59' 71008.0 4,964.2 .0 SPACER PIPE 2-1/16'P110 SPACER PIPE TOM1201 1.610 Gas U, 4.sw n 9 7,013.0 4,967.2 53.36 TUBING LEAK TUBING LEAK IDENTIFIED BY LDL, 0.15 BPM LLR AT 11110801 2.992 3000 PSI 8 PATCH -UPR PKR(ME); J.03J.0 d,981.5 53.5] PATCH-LWR PKR (ME) 2.72"p2P PACKER, CPP3523d, OAL 4.01' 12/281201 9 1625 Perforations 8 Slots 7N4A a aha TfsINGUA`t;7o15o SPACER PIPE: ],pY.O Top MKB1 Bnn MKB) Tov IN01 (X100) BM (1VD1 (XI(B) Mnketl Zane pM 1, 1 Type Cam 7,526.0 ,566.0 ,2747 5, .8 ,2N-709 W24/20p5 6.0 APERF 2S HS PJ HMX, 60 deg phase s1EVAE-.7031.10 ,571.0 7,611.0 5,301.8 5.25.7 S3. 143 1 4.d) (PERF .5"HGBH: 60 deg ph Mantlrel Inserts sl .1 an Top(Typ( N Top(Mon (11001 Make Model WIN 8nm y4Ne ryT< Latin pwSSlx Type (In) TRO PYn (pap Run DYe Com PATCH LMPPKR(ME). 7M 0 4,594.4 3.505.3 CA KBG2- 1 G LIFT DMY INT 0.0 0.0 7/711199 9 GAsuFT,7CP0.3 2 7p80.3 5,007.3 CAM KBO -2- 9 1 GASLIFT DMV BTM 0. 0.011006Q 1 NIPPLE;7.1324 LOCATOR.],13PS APERF: 7.5X6],SeSO� IPER1:751'0-'afl0- PX01 I 1014 ET,W 9 p 9..a KRU 2N-309 DAILY REPORT OF WELL OPERATIONS Tubing Patch for KRU 2N-309 12/29/2019: Set 2.72" P2P @ 7037' RKB. SET Test Tool in lower P2P @ 7037' RKB. Perform CMIT TBGxlA. Test Passed 12/30/2019: Set 2.72" Upper P2P Spacer Anchor assembly @ 7004' RKB. MIT IA - Test Passed. Well patch successfully set 1/20/2020: Well brought on water injection MEMORANDUM State of Alaska Insp Num: mitBDB200209080610 Alaska Oil and Gas Conservation Commission Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min DATE: Tuesday, February 11, 2020 TO: Jim R 71 P.I. Supervisor �� j Z Iq�vw SUBJECT: Mechanical Integrity Tess �+' ;TVD ConocoPhillips Alaska, Inc. Tubing - 2N-309 FROM: Brian Bixby KUPARUK RIV U TARN 2N-309 Petroleum Inspector Sre: Inspector 1990210 Reviewed By: SPT iTest psi P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N-309 API Well Number 50-103-20293-00-00 Inspector Name: Brian Bixby Permit Number: 199-021-0 Inspection Date: 2/22020 - Insp Num: mitBDB200209080610 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well zN_3o9 Type Inj �+' ;TVD so43 -Tubing Tubing - 3zs - 1325 1325 - 13zs' PTD 1990210 Type Test SPT iTest psi 1500 IA 230 2120 2110 2110 BBL Pumped: Lz BBL Returned: 671 674 ' I 674 675 ' Interval OTHER P/F P Notes: MITIA Post Patch Job SUNDRY #319-565 Tuesday, February 11, 2020 Page I of I MEMORANDUM State of Alaska Insp Num: mitBDB200209080610 Alaska Oil and Gas Conservation Commission Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min DATE: Tuesday, February 11, 2020 TO: Jim R 71 P.I. Supervisor �� j Z Iq�vw SUBJECT: Mechanical Integrity Tess �+' ;TVD ConocoPhillips Alaska, Inc. Tubing - 2N-309 FROM: Brian Bixby KUPARUK RIV U TARN 2N-309 Petroleum Inspector Sre: Inspector 1990210 Reviewed By: SPT iTest psi P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N-309 API Well Number 50-103-20293-00-00 Inspector Name: Brian Bixby Permit Number: 199-021-0 Inspection Date: 2/22020 - Insp Num: mitBDB200209080610 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well zN_3o9 Type Inj �+' ;TVD so43 -Tubing Tubing - 3zs - 1325 1325 - 13zs' PTD 1990210 Type Test SPT iTest psi 1500 IA 230 2120 2110 2110 BBL Pumped: Lz BBL Returned: 671 674 ' I 674 675 ' Interval OTHER P/F P Notes: MITIA Post Patch Job SUNDRY #319-565 Tuesday, February 11, 2020 Page I of I TI3E STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sayeed Abbas Staff Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-309 Permit to Drill Number: 199-021 Sundry Number: 319-565 Dear Mr. Abbas: Alaska Oil and Cas ConsenTation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.a og c c.a I as ka.gov Enclosed is the approved application for the 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, e y Price Chair DATED this Q day of December, 2019. RBDMWQ4-6'4 DEC 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 DEC 13 ?D19 AOCCC % 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Tbg patch ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ Stratigraphic ❑ Service 199-021 3. Address: 6. API Number: PO Box 100360, Anchorage, AK, 99510 50-103-20293-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2N-309 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 380054, ADL 375074 1 Ku aruk River Field/Tarn 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): 60%�—-a5ee-ri J')-% 7445 5226 N/A N/A Casing Length Size MD TVD Burst Collapse Structural iy Conductor 80' 16" 115' 115' Surface 2549' 7-5/8" 2583' 2303' Intermediate Production 8026' 5.5x3.5" 8059' 5588' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7526-7566',7571-7611' 5275-5299',5302-5326' 3.5" L-80 7157• Packers and SSSV Type: No SSSV. Camco DS nipple. Packers and SSSV MD (ft) and TVD (ft): 511' MD, 511' TVD (Nipple), Baker 80-40 Seal Assembly 7140' MD, 5044' TVD (Packer) 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigrephic ❑ Development ❑ Service ❑� 14. Estimated Date for 1/15/2020 - 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑� ' GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sayeed Abbas Sayeed Abbas Contact Name: y Authorized Title: StafffD�rillllsite Engineer Contact Email: sa eed.abbas Conoco hilli s.Corn ��Peetft((r'oleum Contact Phone: 907-265-1109 Authorized Signature: �•�/� /Wlt! Date: d �� COMMISSIOIN USE bNLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �_/ Plug Integrity 71 BOP Test E] Mechanical Integrity Test L✓J Location Clearance ❑ Other: DEC 19 2019No Post Initial Injection MIT Req'd? Yes O/F-1RBDMS Spacing Exception Required?Yes No Subsequent Form Required: /O / THEAPPROVEDBY Approved by: COMMISSIONER THE COMMISSION Date: TL `//••��, DD (1 1` A ' submit Form and rm 10-403 R vise /2017 Approved applic G RJdG 1K Nt1�Yr,m the date of approval. Attachments in Duplicate ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 December 10th, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska Inc well KRU 2N-309 (PTD 199-021). The request is for approval to set a retrievable tubing patch to regain tubing integrity above the seal assembly. The prior sundry approval for the tubing patch (Sundry # 318-528) has expired. A prior attempt to set the patch and fix the tubing leak failed. A new attempt will be made, for which a new approval is required. If you have any questions regarding this matter, please contact me at 907-265-1109. Sincerely, Sayeed Abbas Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Email: sayeed.abbas(cDconocophillips.com Ph: 907-265-1109 Attachments: Sundry Application Proposed Steps Well Schematic 1 KRU 2N-309 DESCRIPTION SUMMARY OF PROPOSAL Tubing Patch for KRU 2N309/ V KRU 2N-309 is aWAG injector that was reported to the AOGCC on October 27, 2018 for showing signs of TxIA communication. n oO' TJ =ember 4, 2018 a diagnostic MITIA failed failed after circulating out the inner annulus. A subsequent LDL identified a tubing leak at 7013' RKB. An initial patch attempt was made on 12/26/2018. Subsequent MITIA tests failed. A new attempt will be made to patch the leak on this well CPAI proposes the following repair plan: 1. Set retrievble tubing patch across the leak 2. MITIA to AOGCC requirements 3. Return the well to injection 4. AOGCC witnessed MITIA once thermally stabilized V' 5. ubmit -404 post -repair KUP INJ WELLNAME 2N-309 WELLBORE 2N-309 ConocoPhillips 1AttAtluOths I Max Angie&MD TD Alaska Inc. FleioName Wellmm APIIUtM Wellbore status d(°I MO mNBI Pd 6nn (RKBI TARN PARTICIPATING AREA 5010320 0 IN 521 6,284.61 8,0]50 Comment H]s 1ppm) Date MnWelion Entl Oale K9GM IN) RI9Releace0ale SSSV: NIPPLE Lest W0: 41.21 3M111999 2N.i09,'Eh.ot 555'.]3 AM Last Tag Vwkg acbemalb(aclwp Mnebtbn I Depth RKBI I End Npe Welltarc Iut Moi By Last Tag: RKB .7,445.0 11/30018 2Nd09 fergusp Last RAV Reason -_. ....-- ..._..... _....... RANGER: 3]A Annotation Entl rale WeIIMre Inst Mod By Rev Reason: Pull Patch, set WRP 4112019 261-309 ot., ng strings casing Dwaripllen 00 00 m gn1 Top(NKM sM Depth MINER set Depto (Nrl._ wtlLen p... creae roprnreaa CONDUCTOR 16 15.08 34.6 115.0 115.0 62.58 H-00 WELDED Causing Dwcripllon OD(in) nuonl Top IttKB) Bel Depm lttl<RI set Depm lrvDL.. wtn:n p... Grade Top Thread $DRFgDE JSIB 6.BJ 34.6 2,583.4 2,302.8 29.]0 L-80 BTC MOD Casing Description ODllnl Int," iap{pKBI 3H DeptM1 p"'o Se[OepIM1 IT VDI... -LE. o... Grade Tep iM1read PRCOUCTION'S5'x3s" 512 4.95 33.0 8,058.9 5.58.7.5 15.50 L-80 LTC -MOD Tuning Strings Tuhmg Dr:aipron smog Ma... m lint Top(XKBI see Depm lx.. set Depm lrvol G.. wylhml areae Tnpennnncr0n TUBING 3112 299 304 .7,157.0 5,053] 9.30 L-80 EUEBRDMOD Completion Details coNpucroR _]a_61t_50 pmcl NominalTop IRKBI1'1 Dem Des eom ID(in) 3040.13 HANGER FMC GEN V 5M TUBING HANGER 3.boo NIPPLE, 510] 510.70.28 NIPPLE CAMCO DS NIPPLE 2875 W774 .7030.453.54 BLEEVE-C BAKER CMU SLIDING SLEEVE; CLOSED 1110&18 28137,132.452.64 NIPPLE CANDO 0 NIPPLE2.]50 7,139.552.64 LOCATOR BAKER LOCATOR 2.985 7,140452.64 SEALASSY BAKER 80-40 SEAL ASSEMBLY 3.000 PeHoretkM4...&Slots Shot Den Top l}r(BI Btm (hKRI mp(nJD- (XKBI atm nvDl Linked Date pnm:m I Type Cpm J,526A ],S6fi.0 4274] 5.29 5.298.88-5,261-309 09 9242005 6.0 APERF 25"HSDPJ HM%, 60 deg SVRFACE;b62.5W.4- Pope. 5,301.8 5,325) 5-3,261-309 41311999 4.0 IPERF 25' HCrEH; 60 deg ph Mandrel Manlirel Inserts ts s B GAS LIFT; I,flaq N Top l594. Top ITUp) IRKBI Make Mme- 101)(1.11 Valve Latch Type Type Porl Bxe TRORon (Pa0 Ron999 Cqm 1 4,594.4 3,505.3 CAMCO KBG-2- 1 LIF GAS LIFT 0MY INT 0.0 0.000 0.0 ]13111999 9 2 ],0803 5,007.3 CAMCO KBG.2- 1 GAS LIFT DMY BTM 0.000 0.0 10/26/2001 9 sLEEv£-c 7433.4 Notes: General &;S$€aty Entl Date on-ot ion 11119(2010 NOTE: View SDEematiCwl Alaska S<hemat-c9.0 GA6 DET;'peo,t NIPPLE, 7.1314 LOCATOR;],1395 APERF, 752a.LL7,5 O- IPERF:75716],811,0 PROOVCTIONSSl3,5"; ]3,4 0,65&9 199021 WELL LOG TRANSMITTAL # 3 0 3 3 1 To: Alaska Oil and Gas Conservation Comm. January 9, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED FEB 0 51019 RE: Multi Finger Caliper (MFC) and Leak Detect Log: 2N-309 AOGCC Run Date: 11/10/2018 and 11/11/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-309 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20293-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: V z/V Signed: A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 15, 2019 To: Jim Regg 5 1 e(y II 15 SUBJECT: Mechanical Integrity Tests P.1. Supervisor ALASKA, INC. CONOCOPHILLIPS 2N-309 FROM: Guy Cook KUPARUK RIV U TARN 2N-309 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ZE12— NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N-309 API Well Number 50-103.20293-00-00 Inspector Name: Guy Cook Permit Number: 199-021-0 Inspection Date: 1/8/2019 Insp Num: mitGDC190109070114 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2N-309- iType [nj TVD 5043 - Tubing 1650 oso 1650- 050 1650. 1650 PTD 99ono - Type Tests psi soo IA ao Bio z4so2400+2306o - 23w BBL Pumped: X08 BBL Returned: 0.6 - OA �0 425 4n - 390_ Interval OTHER P/F I F Notes: MIT -IA post patch per sundry #318-528 The well failed to show a stabilizing trend with the bleed off of pressure doing testing. Testing performed with a Little Red Services pump truck and analog gauges from KRU DHD. Tuesday, January 15, 2019 Page I of 1 I►A 1 D) UV 0�10 TO: Jim Regg P.I. Supervisor ✓� \rl 11911r7 FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 15, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, MC. 2N-309 KUPARUK RIV U TARN 2N-309 Ste: Inspector Reviewed By: P.I. Supry 3 Ge - Comm Well Name KUPARUK RIV U TARN 2N-309 API Well Number 50-103-20293-00-00 Inspector Name: Guy Cook Permit Number: 199-021.0 Inspection Date: 1/8/2019 Insp Num: mi[GDC]90115085017 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2Na09 jType Inj I w TVD 5043 Tubing 1710 1710 1710 - 1710 --- PTD 1990210 IType Test SPT Test psi 1500 IA 780 2520 - 2430 2330 BBL Pumped: 10.6 " IBBL Returned: 0.6 OA 224 436 403 390 - Interval OTHER P/F F Notes: Retest MIT -IA post patch per sundry 8318-528 Tuesday, January 15, 2019 Page 1 of I XHVZE Pages NOT Scanned in this Well History ~File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Mildred Dareth~owel! Date: [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ • Regg, James B (DOA) From: Phillips, Jim (ASRC Energy Services) [Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 3:57 PM ~ ~~~Iw To: Regg, James B (DOA) , `~~; Subject: RE: State MITIA test results for 2N pad on 8/24/10 ~ I ~2°( --~ zl Follow Up Flag: Follow up Kf~ 21v-3U Z Flag Status: Red Attachments: MIT KRU 2N Pad DRAFT.xIs Jim, I apologize for the mix up I am filling in for Brent this week and by mistake I did not double check the form before sending it off. Therefore I did not notice that it was showing 12 water injectors SI. I have attached the correct copy and again I am sorry about this mistake on my part. If you have any more questions please feel free to contact me. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 25, 2010 2:36 PM To: Phillips, Jim (ASRC Energy Services) Subject: RE: State MITIA test results for 2N pad on 8/24/10 Why were all the wells SI except the gas injector? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~ .. r;_... ~: ~, ~ . From: Phillips, Jim (ASRC Energy Services) [mailto:Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 8:57 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: State MITIA test results for 2N pad on 8/24/10 All, Attached is the MITIA tests for 2N pad that were waived by Chuck Shieve on 08/24/10. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 Page 1 of 1 8/26/2010 Email to:jim.regg@alaska.gov; phoebe.brooks~alaska.gov; tom.maunder~alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConowPhillips Alaska Inc. ~Q~q ~(~I( t, FIELD /UNIT /PAD: Kuparuk /KRU / 2N ~(/ DATE: 08/24/10 OPERATOR REP: Ives/Mouser AES AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test l~ Packer De th Pretest Initial 15 Min. 30 Min. Well 2N-302 T e In'. W ND 5,185' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 201 t 150 T e test P Test si 1500 Casin 1,210 2,540 2,520 2,520 P/F P Notes: OA 235 265 260 260 Well 2N-306 T e In'. W TVD 5,174' Tubin 2,150 2,150 2,150 2,150 Interval 4 P.T.D. 2040620 T etest P Test si 1500 Casin 1,245 2,820 2,760 2,760 P/F P Notes: OA 375 550 520 520 Well 2N-307 T e In'. W TVD 5,141' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1990170 T etest P Test si 1500 Casin 810 2,180 2,150 2,150 P/F P Notes: OA 250 350 300 300 Well 2N-309 T e In'. W ND 5,042' Tubin 1,600 1,600 1,600 1,600 Interval 4 .T.D. 1990210 T etest P Test si 1500 Casin 775 2,225 2,100 2,080 P/F P Notes: OA 300 365 340 340 Well 2N-310 T e In'. W ND 5,004' Tubin 1,550 1,550 1,550 1,550 Interval 4 P.T.D. 2070900 T e test P Test si 1500 Casin 440 2,300 2,250 2,250 P/F P Notes: OA 270 390 350 350 Well 2N-314 T e In'. W ND 5,046' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 2001930 T e test P Test si 1500 Casin 600 2,300 2,270 2,270 P/F P Notes: OA 225 240 240 240 Well 2N-321A T e In'. W ND 4,915' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1981730 T e test P Test si 1500 Casin 575 2,280 2,250 2,250 P/F P Notes: OA 250 450 450 450 Well 2N-326 T e In'. W ND 4,821' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2001550 T e test P Test si 1500 Casin 1,150 2,760 2,720 2,710 P/F P Notes: OA 360 460 460 460 Well 2N-331 T e In'. W TVD 4,770' Tubin 1,460 1,460 1,460 1,460 Interval 4 P.T.D. 1981170 T etest P Test si 1500 Casin 460 2,200 2,150 2,150 P/F P Notes: OA 300 480 480 480 Well 2N-335 T e In'. W ND 4,966' Tubin 1,950 1,950 1,950 1,950 Interval 4 P.T.D. 1982040 T e test P Test si 1500 Casin 560 2,800 2,600 2,590 P/F P Notes: OA 200 430 430 430 Well 2N-343 T e In'. G ND 4,937' Tubin 3,350 3,350 3,350 3,350 Interval 4 P.T.D. 1980920 T e test P Test si 1500 Casin 850 2,780 2,630 2,620 P/F P Notes: OA 400 420 420 420 Well 2N-348 T e In'. W TVD 4,374' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 2011420 T e test P Test si 1500 Casin 630 2,280 2,240 2,240 P/F P Notes: OA 190 320 320 320 Well 2N-349A T e In'. G ND 5,078' Tubin 1,625 1,625 1,625 1,625 Interval 4 P.T.D. 2001390 T e test P Test si 1500 Casin 280 2,320 2,250 2,250 P/F P Notes: OA 150 250 250 250 Well 2N-325 T e In'. W TVD 5015' Tubin 1,975 1,975 1,975 1,975 Interval 4 P.T.D. 1981630 T e test P Test si 1500 Casin 750 2,675 2,630 2,630 P/F P Notes: OA 220 250 240 240 TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Interval Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2N Pad 08-24-10 Revisedl.xls ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~; N0~ ~ ~ Zp07 Dear Mr. Maunder: ~9~1 0~. Enclosed please find a (revised 10/3/07)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 a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, t. __... _ ~~ ~~ on Arend ConocoPhillips Well Integrity Field Supervisor a ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/28/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9!27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" n/a 18" n!a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 • • • ConocoPhill~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2007 Mr. Torn Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~, '~ ~~ NC~~ ~ 20D7 ~~C~ o~T ~~E® .~ieska o;;& og ~ 2 ~oo~ Aneho ale ~0mm;ssi Op .`~~.oa~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRtn. Each of these wells was found to have a void in the conductor. These voids were filled with a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, .' M.J. vel d 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) Date Kuparuk Field 9/28/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-It03 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 5" n/a 5" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 19&190 6" n/a 6" n/a 3 9/27/2007 2N-317 19&143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 c~ 04/20/07 - Schfum~el'gel' NO. 4239 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 0' uTC- ~tAy 0 4 2007 10c} --Q ~ ( Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Oil (10 Con!;. (~)IJ1mis!;¡on 1"1 20m scANNED MA'f () Kuparuk Field: Well BL CD Color Job# Log Description Date 2F-17 11632699 INJECTION PROFILE 04/30/07 1 1G-17 11632696 PRODUCTION PROFILE 04/27/07 1 1J-170L 1 11661143 MEM INJECTION PROFILE 04/25/07 1 3H-04 11665424 PRODUCTION PROFILE 04/25/07 1 2N-309 11632693 INJECTION PROFILE 04/24/07 1 3A-01 11632691 PRODUCTION PROFILE 04/22/07 1 2H-17 11665423 INJECTION PROFILE 04/24/07 1 1J-180 11632690 PRODUCTION PROFILE 04/20/07 1 2X-11 11632700 PRODUCTION PROFILE 05/01/07 1 2X-13 11632701 PRODUCTION PROFILE 05/02/07 1 Please sign and return one copy of this transmittal to Beth atthe above address or fax to (907) 561-8317. Thank you. (0 . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ---¡J I K,c?1tl c¿ r 1'0, .:: £:: , l DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASK" INC 2N- 309 KUPARUK RIV U TARN 2N-309 \qq' O:}\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv:lf5jZ-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2N-309 API Well Number 50-103-20293-00-00 Insp Num: mitCS060808185539 Permit Number: 199-021-0 Rei Insp Num Inspector Name: Chuck Scheve Inspection Date: 8/812006 ~---,--;;;;;--r.:; , Well t 2N-309 ¡Type Inj. : W i TVD P.T. ! 1990210 iTypeTest: SPT : Test psi Interval 4YRTST P/F P 540 Initial 1840 15 Min. 30 Min. 45 Min. 60 Min. Packer Depth 5043 Pretest 320 350 350 350 -------,- I I I ---+--------t--~--- i 1500 ,.. ! IA i i OA i Tubing i 1820 1820 ,/ llOO 1100 1100 llOO Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNED AU G 2 4 2.0nf) Wednesday, August 09, 2006 Page 1 of 1 ) ) Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 ConocóP'hillips October 17, 2005 RECEIVED OCT 2 7 2005 tUaska ml & fo" "'0 ("'" ,.... '" l.:ødS ,fms. (.omnmsswn A ¡ru:: ~~ (»I' a !H~ Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2N-309 (APD # 199-021) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforations operations on the Kuparuk well 2N-309. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, II. Jd~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells SCANNED NOV {} 1 2005 MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONSf\~«:i)~\IŒ ) Repair Well 0 Pull Tubing 0 Operat. ShutdownD Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Performed: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 155' 8. Property Designation: ADL 380054, ALK 4602 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING PROD CASING Perforation depth: measured 8075' 5597' ) ("'~' E' w \/'E C)' ~,,,' r~IT'/III1 I ,\~ ~-- I I ¡ ~ OCT 2 7 Z005 true vertical measured true vertical Length Size Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 L~ Gas Cons.Commissim Ar@orage Time Extension 0 Re-enter Suspended Well 0 115' 2385' 7007' 897' 16" 7-5/8" 5-1/2" 3-1/2" Stimulate 0 Waiver 0 Other Measured depth: 7526'-7566',7571'-7611' true vertical depth: 5275'-5299', 5302'-5326' Exploratory 0 o 5. Permit to Drill Number: 199-021 1 6. API Number: 50-103-20293-00 Service 9. Well Name and Number: 2N-309 10. Field/Pool(s): Kuparuk River Field 1 Tarn Oil Pool feet feet feet feet Plugs (measured) Junk (measured) MD TVD Burst Collapse 115' 2540' 7162' 8059' 115' 2277' 5057' 5588' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7157' MD. Packers & SSSV (type & measured depth) no packer SSSV= Cameo DS nipple 511' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none ¡RBDMS 8Ft () CT ,2 8 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SI Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney 4fJ J1Mj Title Phone Wells Group Team Lead Date / Ò/2 7/0> Preoared by §;a;on Allsup-Drake 263-4612 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only ) 2N-309 Well Events Summary ) Date Summary 09/24/05 40' OF 2.5" HSD GUNS WERE SHOT FROM 7526'-7566': GUN #1 INTERVAL WAS 7546'-7566'. GUN #2 INTERVAL WAS 7526'-7546'. ALL SHOT WERE FIRED. WELL RETURNED TO INJECTION. PAD OPERATOR NOTIFIED. [Perf] MEMORANDUM TO: Camille Taylor Chair State of Alaska · Alaska Oil and Gas Conservation Commission DATE: April 25, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder P.I. Supervisor Phillips Alaska Inc. 2N 309;326, 335 FROM: John H. Spaulding Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Mi~'. - \ ] -! We,,] 2N-309I P I T.v.~. ] 5043 ITUbing]2250 ]2250 ]2255 'l 2255 J,nterva,] , -- P.T.D.I 1990210 ITypetestl U ]Testpsi] 1261 ]Casing] 2250 ] 2960]2950 .] 2950] P/F ] _P Notes: Wellii!ii':~i~ ~iiTypelnj.] ' P I T.V.D. ] 482i ]Tubing ] 245(,]24~0 12~40 'l 2420 ]Interval] I P.T.D.['"'"'"~:'~'"':'"~lTypetest] M ITestpsiI 1205 .J Casing J ~;25(~I 2955I 2960I 2950 ] PIF I P Notes: we,I 2.-335 I Type,nj.I P I T.V.D. I,~ I Tubingl2,00 / 2400 I 2"00 J2400 J,nt~a,J ~ P.T.D.I 1982040 ITypetestl a ITestpsil 1241 I Casi. ngI !150 I 2940 I 2920 I 2900 I P/F I --P Notes: ~ we,,I I Type Inj, P.T.D. I I Type test Notes: WellI [Type Inj. P.T.D. I I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details As noted in the above test report form no failures were observed. All wells are ·operating within the area's injection orders. M.I.T.'s performed: 3 Attachments: Number of Failures: 0 Total Time during tests: 3 hrs. cc: none MIT rePort form 5/12/00 L.G. mit's KRU 3N 4-25-02 Revised js.xls 7/8/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. IName of Operator Phillips Alaska, Inc. 3. ,Address P. O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface 20' FNL, 598' FEL, Sec. 3, T9N, R7E, UM p,t top of productive interval 1257' FNL, 2466' FWL, Sec 34, T9N R7E, UM At effective depth 5. Type of Well: Development ._X Exploratory _ Stratigraphic __ Service._ At total depth 791' FNL, 2178' FWL, Sec. 34, TION, R7E, UM 12. Present well condition summary Total depth: measured true vertical 8075 feet Plugs (measured) 5597 feet Effective depth: measured 7930 feet Junk (measured) true vertical 5512 feet 6. Datum elevation (DF or KB feet) RKB 155 feet Perforation depth: 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-309 ~ 9. ~Permit number / approvaJ number 199-021 / 10. APl number 50-103-20293 11. Field / Pool Kuparuk River Field/Tam Oil Pool C:asing Length Size Cemented Measured Depth' True vertical Depth E;ONDUCTOR 115' 16" 9 cu yds High Early 115' 115' SURF CASING 2385' 7-5/8" 260 Sx AS III & 240 Sx Class G w/ 2540' 2277' P ROD CASING 7007' 5-1/2" 220 Sx C~ass G 7162' 5057' P ROD CASING 897' 3-1/2" Included above 8059' 5588' P ROD CASING measured RECEIVED APR i true vertical: 13. Stimulation or cement squeeze summary Treatment description including volumes"U~'~: 14. Pdor to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations ~X Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbt Casing Pressure Tubing Pressure 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedJeffA. ~'~-'4-~--~'~ Title Production Engineering Supervisor Questions? Call Jeff Spencer 659-7226 Dat eTZ~/~.~: (~,~ Prepared b,F ,Robert Chrfstensen 659-7535 SUBMIT IN DUPLICATE 2N-309 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Attachment #1 2N-309 The water injection test at drill site 2N provides an opportunity to utilize injection water as a power fluid source for a jet pump installation in production Well 2N-309. The production history of Well 2N-309 indicates that the proposed jet pump installation will result in sustained production. Mixing the "warm" power fluid into the production stream is expected to mitigate paraffin deposition. The jet pump is a reverse circulation pump, and "hard line" with a check valve will tie the injection header to the production annulus. The jet pump will be installed in the production tubing at an open sliding sleeve at 7030', which will result in tubing by annulus communication. A variance for Well 2N-309 is requested from August 1, 1999 to October 15, 1999 to test the jet pump application. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (< 90 days), and the low annulus injection rate (- 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion inflow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than - 10 mils/year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is - 1-2 mils/year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the test. WELL LOG TRANSMITrAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 August 12, 1999 MWD Formation Evaluation Logs 2N-309, AK-MM-90094 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-309: 2"x 5"MD Resistivity & Gamma Ray Logs: 50-103-20293-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20293-00 2" x 5" MD Neutron & Density Logs: 50-103-20293-00 2" x 5" TVD Neutron & Density Logs: 50-103-20293-00 1 Blueline 1 Folded Sepia ! Blueline 1 Folded Sepia 1 Btueline 1 Folded Sepia 1 Blueline . .. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMIT'FAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2N-309, July 29, 1999 AK-MM-90094 1 LDWG formatted Disc with verification listing. API#: 50-103-20293-00 PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING THE A'I'FACHED COPY OF THE TRANSMI'VrAL LETYER TO THE ATI'ENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company .. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 11, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-309 (Permit No. 99-21) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 2N-309. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Drilling Team Leader Gas Cons. o0mmias Anchorage PM/skad STATE OF ALASKA ALA~SKA OIL AND GAS CONSERVATION COMt~'~SION WELL COMPLETION OR RECOMPLETION REPORT Oil [] Gas [] Suspended [] Abandoned [] Service []. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-21 3. Address 8. APl Number ~,JasKa P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20293 Anchorage 4. Location of well at suflace :, .~ ,; ~-_-. ~;,~".~ '; 9. Unit or Lease Name 20' FNL, 588' FEL, Sec. 3, T9N, R7E, UM '.':' '"': ; At Top Producing Inte~al ~ ,~,, 10. Well Number 1257' FNL, 2466' FWL, SEC 34, T10N, R7E, UM ' ~'~i~:JE:~~]~~ 2N-309 .__ ~ ~~~ 11. Field and Pool At Total Depth - 791' FNL, 2178' FWL, SEC 34, T10N, R7E, UM ' ' 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. Kuparuk River Field,am Oil Pool RKB 35 feet~ ADL 380054, ALK 4602 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or ~an~. ~f~ ~15. Water Depth, if offshore 16. No. of Completions March11, 1999 March 18, 1999 ~~/~IN/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey 20. Depth where SSSV set 21. Thic~e~ of Permafrost 8075' MD / 5597' TVD 7930' MD / 5512' TVD YES ~ No ~ DS n pp e ~ 510' feet MD 1208' (approx) 22. T~e Electric or Other Logs Run GR/Res, CCL 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP BOSOM HOLE SIZE CEME~ING RECORD~ AMOUNT PULLED 16" 62.5¢ H-40 Surface 115' 24" 9 cu. Yds. High Ear~ 7.625" 29.7¢ L-80 Surface 2583' 9.875" 370 sx AS III L & 235 sx Cla~ G 5.5" x 15.5~ L-80 Surface 7162' 6.75" 280 sx Cla~ G 3.5" 9.3¢ L-80 7162' 8059' 6.75" (included above) 24. Pedorations open to Production (MD + TVD of Top and BoSom and 25. TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7157' 7142' (CSR) ~71' - 7611' MD; 5302' - 5326' TVD; ~ 4 spf 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7571'-7611' 207M lbs proppant placed behind pipe, 21M lbs le~ in wellbore 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas li~, etc.) April 27, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL ~S-MCF WATER-BBL CHOKE SIZE I~S-OIL RATIO 5/4/1999 12.0 Test Pedod > 510 473 12 0~ 1273 Flow Tubing Casing Pressure Calculated OIL-BBL ~S-MCF WATER-BBL OIL G~VI~ - APl (co~) ~ Pre~. 0 psi 0 24-Hour Rate > 1048 1334 28 0 .28. CORE DATA Brief description of lithology, porosi~, fractures, ~parent dips and pressence of oil, gas or water. Submit core chips. * This10-407 is submitted as directed per the10-401form approved (Permit~9-21) ~ ~ ,; r ~ ~ J Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top of T-3 Top of T-2 GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 5198' 7397' 7620' 5331' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations and Directional Survey 32. I he~~~e following is true and correct to the best of my knowledge. .~~_.~Z/~~~T:Io Ddllinq Team Leader Date INSTRUCTIONS Prepared by Sharon AIIsup-Drake 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 4/19/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-309 WELL_ID: AK9733 TYPE: AFC: AK9733 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:03/ll/99 START COMP: RIG:P00L 6 BLOCK: FINAL: WI: 0% SECURITY:0 AP1 NIIMBER: 50-103-20293-00 03/10/99 (D1) MW: 9.6 VISC: 60 PV/YP: 19/31 APIWL: 9.5 TD: 115'( 115) WORK ON SCR'S FOR TOP DRIVE SUPV:FRED HERBERT / RICK 0VERSTREET MOVE RIG FROM 2N-307 TO 2N-309, RIG ACCEPTED ON 2N-309 AT 1600 HRS, NU AND TEST DIVERTER. UPCOMING OPERATIONS:SPUD WELL & DRILL TO CASING POINT 03/11/99 D2) MW: 10.0 VISC: 85 PV/YP: 30/43 APIWL: 6.8 TD: 1069' 954) DRILLING AHEAD ~ 1463' SUPV:FRED HERBERT / RICK OVERSTREET Function test diverter system. Drilling 9-7/8" hole from 115' to 396' Hold pad evacuation drill. Simulated gas blow out. Drilling 9-7/8" hole from 396'-1069' UPCOMING OPERATIONS:SHORT TRIP, DRILL TO CASING POINT 03/12/99 D3) MW: 10.2 VISC: 82 PV/YP: 33/61 APIWL: 5.8 TD: 2595' 1526) POH AND LD BHA. (HYDRATES WERE 400 UNITS). SUPV:FRED HERBERT / RICK OVERSTREET DRILL F/ 1033 TO 2595, WITH WIPER TRIP AT 1741. UPCOMING OPERATIONS:RUN 7-5/8" CASING AND CEMENT. 03/13/99 (D4) MW: 10.2 VISC: 82 PV/YP: 33/61 APIWL: 5.8 TD: 2595'( 0) ND DIVERTER, NU BOPE. SUPV:FRED HERBERT / RICK OVERSTREET CUM COST:360897,PROGRESS:0,OPERATIONS:,LAST CASING:16" ~ ll5',NEXT CASING:7 5/8" @ 2540',EST COST TO DATE:400000, UPCOMING OPERATIONS:TEST BOPE. PICK UP BHA ~2. 03/14/99 (D5) MW: 10.2 VISC: 47 PV/YP: 24/21 APIWL: 7.8 TD: 2595' ( 0) TEST CASING TO 2000 SUPV:FRED HERBERT / RICK 0VERSTREET WOC, NIPPLE DOWN DIVERTER, NIPPLE UP BOPE, TEST BOPE, RIH WITH BIT #2. UPCOMING OPERATIONS:HOLD STRIPPING EXERCISE, TEST CASING, LOT, DRILL TO TD Date: 4/19/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 03/15/99 (D6) MW: 9.6 VISC: 40 PV/YP: 12/18 APIWL: 5.8 TD: 2595' ( 0) REPACK SWIVEL AND RUN BACK IN HOLE FROM JUST INSIDE CASING S SUPV:FRED HERBERT / RICK OVERSTREET RIH WITH BHA #2. CLEAN OUT CASING FROM 2443' TO 2470'. TEST CASING. LEAN OUT FLOAT COLLAR AND SHOE. DRILL 20' NEW HOLE. CIRCULATE NEW MUD AROUND. CLEAN OUT FLOW-LINE AND SHAKERS. DRILL FROM 2615 TO 3826. PERFORM LOT. UPCOMING OPERATIONS:DRILL ON FROM 4110' 03/16/99 (D7) MW: 9.6 VISC: 43 PV/YP: 13/18 TD: 5600' (3005) DRILLING @ 6152 SUPV:FRED HERBERT / SCOTT REYNOLDS Drill 6.75" production hole from 3826' to 5600' UPCOMING OPERATIONS: SHORT TRIP, DRILL TO TD AP IWL: 5.5 03/17/99 (D8) MW: 9.6 VISC: 38 PV/YP: 9/14 APIWL: 5.2 TD: 7263'(1663) DRILLING ~ 7685' SUPV:FRED HERBERT / SCOTT REYNOLDS Drlg 6.75" hole from 5600' to 7263' UPCOMING OPERATIONS:DRILL TO TD, SHORT TRIP, POOH, RUN CASING 03/18/99 (D9) MW: 9.6 VISC: 44 PV/YP: 14/18 APIWL: 4.2 TD: 8075'(812) POOH TO RUN CASING SUPV:FRED HERBERT / SCOTT REYNOLDS DRILL FROM 7263 TO 8075. POOH TO SHOE. RIH TO BTM. CIRCULATE AND CONDITION TO RUN CASING. UPCOMING OPERATIONS:RUN CASING, COMPLETE WELL 03/19/99 D10) MW: 9.6 VISC: 37 PV/YP: 10/ 7 APIWL: 5.8 TD: 8075' 0) INSTALL PACK OFF SUPV:FRED HERBERT / SCOTT REYNOLDS Run 3.5" and 5.5" casing. UPCOMING OPERATIONS:COMPLETE WELL & MOVE TO 2L-307 03/20/99 Dll) MW: 8.5 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 TD: 8075' 0) L/D DRILL PIPE SUPV:FRED HERBERT / SCOTT REYNOLDS Cement casing. Install packoff and test to 5000 psi. Run 3.5" tubing. ND BOPE. UPCOMING OPERATIONS:RELEASE RIG & MOVE TO 2L-307 03/21/99 (D12) MW: 8.5 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 TD: 8075'( 0) RIG MOVE F/2N TO 2L PAD SUPV:FRED HERBERT / SCOTT REYNOLDS ND BOPE. Install tree adatper flange and master valve and test to 5000 psi. Release rig @ 1800 hrs. 3/21/99. UPCOMING OPERATIONS:MOVE CAMP, SPUD 2L-307 · Date 04/03/99 Upcoming Well Na 2N-309 Service Type ELECTRIC LINE Desc of Work GR/CCL LOG - PERFORATE Supervisor KOLSTAD Complet Accident Injury spill I- Summary Job Num 0329991832.5 Unit 8345 AFC AK9733 0 Prop 35TN2N81X Uploaded to Set Contractor Key Perso SWS-STEPHENSON Successful r~' Initial Tbg Press 500 Final Tbg Press 100 Initial Int Csg Press 500 Final Int Csg Press 0 Initial Out Csg Press 0 Final Out Csg Press 0 RUN GR/CCL CORRELATION LOG - PERFORATE 7,571' - 7,611' WITH 2.5" HC / BH / 4 SPF / 60 DEG PHASING - MADE 2 TWENT' RUNS - ALL SHOTS FIRED [Perf] Date printed: 05/11/99 at: 11:14:39 UpcOming ~-- Job Num Unit Date 04/22/99 Well Na 2N-309 Service Type PUMPING Desc of Work FRACTURE STIMULATION 0418991401.3 AFC AK9733 Prop 180KNU2T 0 Uploaded to Sen Supervisor ODELL Contractor Key Perso DS-GALLEGOS Complet ~-- Successful I-- Accident I-- Initial Tbg Press 60 Final Tbg Press 30 Injury I-- Initial Int Csg Press 1350 Final Int Csg Press 500 Spill I-- Initial Out Csg Press 50 Final Out Csg Press 350 Summary PUMPED HYDRAULIC FRACTURE TREATMENT, 207M LBS 16-20 PROPPANT PLACED BEHIND PIPE, 21M LBS LEFT IN WELLBORE, 11 PROPPANT ON FORMATION. SCREENED OUT WITH 10 PPG TO SURFACE. TREE SAVER CUPS LEFT IN HOLE. [Frac-Refrac] Date printed: 05/11/99 at: 11 '15:04 22-Mar-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-309 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 8,075.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 1999 ,~ska 0~i & ~s Cons. Comn~ion 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2N, Slot 2N-309 2N-309 Job No. AKMM90094, Surveyed: 18 March, 1999 SURVEY REPORT 0 RI GINAL 22 March, 1999 Your Reft AP1-501032029300 Surface Coordinates: 5911987.11 N, 461005.39 E (70° 10' 13.7660"N, 150° 18'49.8035" W) Kelly Bushing: 154.50ft above Mean Sea Level RECEIVED ,~,~IAR 2 6 1999 A~i~..a Oil & Gas C, ons. ~ss'~n Survey Ref: svy8425 Sperry-Sun Drilling Services Survey Report for 2N-309 Your Ref: API-501032029300 Job No. AKMM90094, Surveyed: 18 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -154.50 0.00 170.00 0.750 195.000 15.50 170.00 288.00 0.590 167.050 133.49 287.99 388.00 0.200 321.300 233.49 387.99 479.50 0.230 341.600 324.99 479.49 570.00 0.370 323.430 415.48 569.98 661.00 0.600 313.140 506.48 660.98 751.00 0.700 341.570 596.48 750.98 840.29 3.800 17.880 685.69 840.19 927.90 6.690 14.980 772.92 927.42 1018.22 8.870 12.660 862.41 1016.91 1109.37 9.400 359.400 952.41 1106.91 1199.67 9.790 341.560 1041.47 1195.97 1293.46 12.830 339.410 1133.42 1287.92 1386.53 15.070 348.430 1223.75 1378.25 1480.63 18.780 355.730 1313.77 1468.27 1572.70 24.500 356.940 1399.32 1553.82 1667.65 27.980 357.870 1484.47 1638.97 1762.77 34.750 355.700 1565.65 1720.15 1857.08 36.700 354.020 1642.21 1796.71 1952.22 38.680 348.270 1717.51 1872.01 2045.39 40.750 345.870 1789.18 1943.68 2138.89 42.860 340.300 1858.90 2013.40 2232.07 44.840 335.910 1926.11 2080.61 2326.37 48.850 332.290 1990.61 2145.11 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5911987.11 N 461005.39 E 1.07 S 0.29 W 5911986.04 N 461005.10 E 2.41 S 0.35 W 5911984.70 N 461005.03 E 2.78 S 0.35 W 5911984.33 N 461005.03 E 2.48 S 0.50 W 5911984.63 N 461004.87 E 2.07 S 0.73 W 5911985.04 N 461004.64 E 1.51 S 1.26 W 5911985.61 N 461004.12 E 0.67 S 1.78 W 5911986.45 N 461003.61 E 2.67 N 1.04 W 5911989.78 N 461004.36 E 10.36 N 1.17 E 5911997.47 N 461006.62 E 22.24 N 4.06 E 5912009.33 N 461009.56 E 36.54 N 5.52 E 5912023.62 N 461011.10 E 51.20 N 3.01 E 5912038.29 N 461008.67 E 68.52 N 3.17 W 5912055.64 N 461002.57 E 90.05 N 9.23 W 5912077.21 N 460996.62 E 117.15 N 12.82 W 5912104.33 N 460993.18 E 151.02 N 14.94 W 5912138.21 N 460991.23 E 192.95 N 16.82 W 5912180.15 N 460989.56 E 242.34 N 19.69 W 5912229.55 N 460986.95 E 297.18 N 24.64 W 5912284.41 N 460982.28 E 354.59 N 33.65 W 5912341.87 N 460973.57 E 412.59 N 46.99 W 5912399.94 N 460960.52 E 472.15 N 65.17 W 5912459.59 N 460942.65 E 532.00 N 89.27 W 5912519.56 N 460918.86 E 593.82 N 119.37 W 5912581.53 N 460889.08 E Alaska State Plane Zone 4 Kuparuk 2N Dogleg Vertical Rate Section (°/lOOff) (fi) Comment o.0o 0.441 -o.80 0.304 -1.94 0.775 -2.26 0.089 -1.93 0.185 - 1.46 0.269 -o.71 o.371 0.28 3.654 2.84 3.312 8.50 2.438 17.49 2.376 29.29 3.308 43.33 3.272 61.48 3.348 83.25 4.536 108.69 6.231 139.35 3.690 176.94 7.215 221.54 2.314 271.91 4.239 326.49 2.765 383.70 4.566 444.61 3.894 508.64 5.090 577.30 Continued... 22 March, 1999- 15:39 - 2- DrlllQuest Sperry-Sun Drilling Services Survey Report for 2N-309 Your Ref: AP1-$01032029300 Job No. AKMM90094, Surveyed: 18 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2421.07 51.970 328.830 2050.96 2205.46 2515.12 53.710 327.140 2107.77 2262.27 2620.67 53.360 327.810 2170.51 2325.01 2715.25 54.390 328.360 2226.26 2380.76 2809.60 55.090 327.810 2280.73 2435.23 2904.85 54.380 329.170 2335.73 2490.23 2998.29 53.300 328.730 2390.86 2545.36 3093.92 53.310 329.340 2448.00 2602.50 3188.22 53.080 328.990 2504.50 2659.00 3285.04 52.920 329.040 2562.77 2717.27 3377.69 53.030 329.240 2618.56 2773.06 3471.36 54.060 328.650 2674.21 2828.71 3567.73 55.130 328.350 2730.05 2884.55 3661.98 52.480 328.750 2785.70 2940.20 3758.24 52.880 328.130 2844.06 2998.56 3852.42 53.740 328.300 2900.33 3054.83 3943.68 51.740 328.240 2955.58 3110.08 4038.84 51.430 327.890 3014.71 3169.21 4131.26 52.420 327.920 3071.70 3226.20 4225.44 53.360 327.360 3128.52 3283.02 4321.02 53.410 329.220 3185.53 3340.03 4415.01 52.280 327.590 3242.30 3396.80 4507.76 53.250 327.310 3298.42 3452.92 4599.54 52.180 328.690 3354.02 3508.52 4693.88 52.260 329.170 3411.82 3566.32 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 657.32 N 155.27W 5912645.22 N 460853.51 E 720.86 N 195.01W 5912708.97 N 460814.10 E 792.43 N 240.65W 5912780.77 N 460768.83 E 857.28 N 281.03W 5912845.83 N 460728.78 E 922.67 N 321.76W 5912911.43 N 460688.39 E 988.97 N 362.41W 5912977.93 N 460648.08 E 1053.60 N 401.32W 5913042.77 N 460609.51 E 1119.35 N 440.77W 5913108.72 N 460570.39 E 1184.18 N 479.47W 5913173.75 N 460532.03 E 1250.47 N 519.28W 5913240.24 N 460492.56 E 1313.97 N 557.22W 5913303.93 N 460454.95 E 1378.51 N 596.09W 5913368.67 N 460416.41 E 1445.48 N 637.13W 5913435.86 N 460375.72 E 1510.36 N 676.81W 5913500.94 N 460336.37 E 1575.59 N 716.88W 5913566.37 N 460296.64 E 1639.78 N 756.66W 5913630.77 N 460257.19 E 1701.56 N 794.86W 5913692.74 N 460219.31 E 1764.83 N 834.30W 5913756.22 N 460180.20 E 1826.47 N 872.95W 5913818.05 N 460141.86 E 1889.91N 913.15W 5913881.70 N 460101.99 E 1955.17 N 953.47W 5913947.17 N 460062.00 E 2018.98 N 992.71W 5914011.17 N 460023.10 E 2081.22 N 1032.44W 5914073.62 N 459983.69 E 2143.14 N 1071.14W 5914135.74 N 459945.31E 2207.00 N 1109.62W 5914199.80 N 459907.15 E Alaska State Plane Zone 4 Kuparuk 2N Dogleg Vertical Rate Section (°/100fi) (fi) Comment 4.333 650.24 2.339 725.08 0.609 809.81 1.186 886.10 0.881 963.04 1.384 1040.73 1.217 1116.12 0.512 1192.75 0.384 1268.22 0.170 1345.49 0.209 1419.42 1.211 1494.71 1.139 1573.18 2.832 1649.17 0.660 1725.64 0.925 1801.07 2.192 1873.62 0.435 1948.08 1.072 2020.72 1.105 2095.70 1.563 2172.32 1.832 2247.15 1.073 2320.85 1.670 2393.77 0.411 2468.28 Continued... 22 March, 1999 - 15:39 - 3 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2N-309 Your Ref: API-501032029300 Job No. AKMM90094, Surveyed: 18 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4787.67 52.990 328.590 3468.75 3623.25 4881.81 53.810 328.020 3524.88 3679.38 4976.42 54.440 329.030 3580.32 3734.82 5070.71 53.580 329.670 3635.73 3790.23 5163.55 50.630 329.340 3692.75 3847.25 5252.95 50.190 329.820 3749.72 3904.22 5347.61 50.720 329.930 3809.99 3964.49 5440.82 51.140 329.940 3868.74 4023.24 5534.62 51.970 329.900 3927.06 4081.56 5630.49 52.800 330.670 3985.58 4140.08 5724.18 53.680 330.740 4041.65 4196.15 5818.35 52.000 329.340 4098.53 4253.03 5911.02 52.580 329.360 4155.21 4309.71 6005.22 53.620 328.200 4211.77 4366.27 6099.36 54.960 329.940 4266.72 4421.22 6194.55 54.910 328.240 4321.41 4475.91 6284.60 55.210 326.150 4372.99 4527.49 6379.00 53.330 327.020 4428.11 4582.61 6475.39 54.210 325.070 4485.08 4639.58 6569.14 53.190 326.340 4540.59 4695.09 6661.69 51.330 327.480 4597.23 4751.73 6760.86 51.520 324.910 4659.07 4813.57 6848.39 52.420 326.670 4713.00 4867.50 6942.33 52.620 329.270 4770.17 4924.67 7035.44 53.590 329.760 4826.07 4980.57 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2270.81N 1148.14W 5914263.81 N 459868.96 E 2335.11 N 1187.85W 5914328.31 N 459829.58 E 2400.50 N 1227.88W 5914393.90 N 459789.90 E 2466.13 N 1266.77W 5914459.73 N 459751.34 E 2529.25 N 1303.94W 5914523.05 N 459714.50 E 2588.66 N 1338.83W 5914582.63 N 459679.92 E 2651.80 N 1375.46W 5914645.96 N 459643.61E 2714.42 N 1411.71W 5914708.77 N 459607.68 E 2778.00 N 1448.54W 5914772.53 N 459571.19 E 2843.95 N 1486.18W 5914838.68 N 459533.89 E 2909.41N 1522.90W 5914904.33 N 459497.50 E 2974.43 N 1560.37W 5914969.54 N 459460.37 E 3037.50 N 1597.74W 5915032.80 N 459423.32 E 3101.92 N 1636.79W 5915097.42 N 459384.60 E 3167.49 N 1676.07W 5915163.19 N 459345.66 E 3234.33 N 1716.09W 5915230.24 N 459305.99 E 3296.37 N 1756.08W 5915292.48 N 459266.32 E 3360.33 N 1798.29W 5915356.66 N 459224.44E 3424.81N 1841.72W 5915421.36 N 459181.34 E 3487.22 N 1884.29W 5915484.00 N 459139.09 E 3548.53 N 1924.25W 5915545.51 N 459099.45 E 3612.94 N 1967.38W 5915610.14 N 459056.65 E 3669.96 N 2006.14W 5915667.36 N 459018.19 E 3733.15 N 2045.67W 5915730.75 N 458978.98 E 3797.32 N 2083.44W 5915795.12 N 458941.54 E Alaska State Plane Zone 4 Kuparuk 2N Dogleg Vertical Rate Section (°ll00ff) (fi) Comment 0.920 2542.76 0.997 2618.25 1.092 2694.84 1.065 2771.10 3.190 2844.33 0.643 2913.20 0.567 2986.18 0.451 3058.53 0.885 3131.98 1.074 3207.91 0.941 3282.97 2.142 3358.00 0.626 3431.29 1.479 3506.56 2.068 3582.94 1.463 3660.81 1.931 3734.46 2.127 3810.85 1.870 3888.31 1.541 3963.53 2.233 4036.53 2.035 4113.77 1.888 4182.42 2.207 4256.86 1.124 4331,29 Continued... 22 March, 1999 - 15:39 - 4 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2N-309 Your Ref: API-501032029300 Job No, AKMM90094, Surveyed: 18 March, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 7130.81 52.640 329.930 4883.31 5037.81 3863.28 N 2121.76W 5915861.27 N 458903.56 E 7225.46 52.630 328.620 4940.75 5095.25 3927.94 N 2160.20W 5915926.13 N 458865.46 E 7319.59 53.150 328.230 4997.55 5152.05 3991.90 N 2199.50W 5915990.29 N 458826.49 E 7413.58 54.190 326.640 5053.23 5207.73 4055.70 N 2240.26W 5916054.30 N 458786.06 E 7505.25 52.880 328.490 5107.71 5262.21 4117.91N 2279.81W 5916116.72 N 458746.83 E 7603.30 53.340 329.350 5166.57 5321.07 4185.08 N 2320.29W 5916184.09 N 458706.70 E 7694.63 54.250 330.350 5220.52 5375.02 4248.80 N 2357.30W 5916248.00 N 458670.02 E 7789.79 54.920 329.390 5275.66 5430.16 4315.87 N 2396.23W 5916315.27 N 458631.43 E 7883.91 53.470 326.750 5330.73 5485.23 4380.65 N 2436.58W 5916380.26 N 458591.42 E 7976.41 54.420 327.970 5385.17 5539.67 4443.62 N 2476.91W 5916443.44 N 458551.41 E 8005.74 54.630 325.760 5402.20 5556.70 4463.62 N 2489.96W 5916463.50 N 458538.46 E 8075.00 54.630 325.760 5442.29 5596.79 4510.31 N 2521.74W 5916510.36 N 458506.92 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.677° (18-Mar-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 331.020° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8075.00ft., The Bottom Hole Displacement is 5167.41ft., in the Direction of 330.790° (True). Alaska State Plane Zone 4 Kuparuk 2N Dogleg Rate (°/lOOff) Vertical Section (ft) Comment 1.006 1.10o 0.644 1.755 2.162 0.844 1.332 1 .o82 2.747 1.480 6.178 0.000 4407.56 4482.75 4557.73 4633.30 4706.88 4785.25 4858.92 4936.46 5012.68 5087.30 5111.13 5167.36 Projected Survey Continued... 22 March, 1999 - 15:39 - 5- DrlllQuest Sperry-Sun Drilling Services Survey Report for 2N-309 Your Ref: API-501032029300 Job No. AKMM90094, Surveyed: 18 March, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2N ~'~. Comments Measured Depth (ft) 8075.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5596.79 4510.31 N 2521.74 W Comment Projected Survey 22 March, 1999 - 15:39 - 6 - DrlllQuest TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION March 8, 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 995104)360 Re: Kupamk River Unit 2N-309 ARCO Alaska, Inc. Permit No: 99-21 Sur Loc: 20'FNL, 588'FEL, SEC. 03, T09N, R07E, UM Btmhole Loc. 775'FNL, 2710'FWL, SEC. 34, T10N, R07E, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal of drilling wastes will not be approved for tiffs well until sufficient data is sub~nitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity. Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to file Com~nission on form 10403 prior to fire start of disposal operations. Please note that any disposal of fluids generated from this drilling operation wlfich are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2N must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater titan 35,000 barrels through file annular space of a single well or to use flint well for disposal purposes for a period longer titan one year. The permit to drill docs not exempt you from obtaining additional permits required by law from other govermnental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) ~nust be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice ma3' be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Clu-istenson, P.E. Clmirman BY ORDER OF THE COMMISSION dlffEnclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Enviromnental Consen,ation w/o encl. STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION PERI,lIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill [] Redrill [] lb. Type of well. Exploratory Bi .......... ~tiatigi~l:)~ic-~s'i[] Development Oil[] Re-entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0361 ADL 380054 ALK 4602 Tarn Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 20' FNL, 588' FEL, Sec. 3, T9N, RTE, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1172' FNL, 2411' FWL, Sec. 34, T10N, R7E, UM 2No309 #U-630610 At total depth 9. Approximate spud date Amount 775' FNL, 2710' FWL, Sec. 34, T10N, R7E, UM March 8, 1999 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 775' @ TD feet 2N-308 14.6' @ 180' feet 2560 8109' MD/5610' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 800 MD Maximum hole angle 53.54 Maximum surface 1357 psig At total depth (TVD) 1610 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 83' 35' 35' 118' 118' 9 cu. Yds. High Early 9.875" 7.625" 29.7# L-80 BTC 2505' 35' 35' 2540' 2300' 280 sx AS III, 240 sx Class G 6.75" 5.5"x 15.5# L-80 LTC-M 7048' 35' 35' 7083' 5000' 290 sx Class G 6.75" 3.5" 9.3# L-80 8RD EUE 1026' 7083' 5000' 8109' 5610' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true verlical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Liner . true vertical 20. Attachments Filing fee [] Properly Plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby c~rtify that the foregoing is true and correct to the best of my knowledg6 Questions? Carl Bill Lloyd265-653 Signed Title: Drilling Team Leader Date ~ 9.~ ~ Paul Mazzolini ' Pr~-n~ r~.fl hv ,~h~rnn A Il.~t ln-Drak¢ Commission Use Permit Number APl number Approval date ~.-~_ ~ Isee cover letter ? ? -. / so-/o 2- z. o .2. 73 ' Ifor other re,uireme,ts Conditions of approval Samples required [] Yes [~] No Mud Icg required [] Yes ,J~ No Hydrogen sulfide measures [] Yes 1~ No Directionalsurvey required [] Yes [] No Required working pressure for DOPE [] 2M; [] 3~ [] 5M; [] 1OM;[] [] Other: O.161N^L SlGNEE)B¥ by order of Approved by I:~h~rt ki ¢'.h.ri.~t~n~on Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCE"~URE KUPARUK RIVER FIELD - PRODUCER KRU 2N 309 1. Move in and rig up Pool #6. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. . Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing _+1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 6. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(0). 8. Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. Set TVVC, ND BOPE and install production tree. 12. Secure well. Rig down and move out. 13. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 309 Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.5-10.2 ppg 16-26 25-35 50-120' 10-20 15-40 7-15 9.5-10 +10% Drill out to TD 9.1 - 10.0 ppg 6-20 5-20 35-50 2-6 4-8 <6 through Tarn 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 fi)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be ~2,350 psi (0.50 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.2 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a -I-VD of 5,226'. Target (Midpoint T2 T3) (2350+150)/(0.052'5226)=9.2. Well Proximity Risks: The nearest well to 2N-309 is 2N-308. of 180'. The wells are 14.6' from each other at a depth ARCO Alaska, Inc. Drilling Area Risks: The primary risk in the 2N-309 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.5 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.5-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extendedshut down (> 4 hr) in pumping operations. The 2N-309 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2N-309 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe -I-VD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" ~29.7 ~L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3½" 9.3 L-80 ,2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). : Tarn Drill Slfe 2N Well: 309 I rn Ommlopment Field Laaaflon: North S~ope, Ala.kaI 400 800 1200 1600 2000 2400 2800 5200 3600 4o0o 4400 4800 5200 5600 6000 C35 TO - Casino_ Pt ~ RKB ELEVATION: 155' PROFILE COMMENT DATA Paint MD Inc Dir TVD North East V. Sect De9/1 O0 KOP 800.00 0.00 0.00 800.00 0.00 0.00 0.00 0.00 Port Collar 1000.37 6.01 5.00 1000.00 10.49 0.55 8.91 5.00 Bose of Permafrost 1208.10 12.24 $.00 1205.00 43.$8 2.27 56.84 3.00 Top of West Sok Sand 1255.24 13.60 5.00 1249.00 55.46 2.80 45.41 5.00 Begin Turn to Target 1600.00 24.00 5.00 1576.81 164.89 8.64 140.06 5.00 Base of West Sok Son 2108.61 59.82 337.95 2009.00 421.82 -47.68 592.11 4.00 EOC 2490.63 53.54 328.60 2270.78 667.78 -174.39 668.66 4.00 7 5/8 Casing Pt. 2559.79 53.54 328.60 2500.00 701.53 -194.98 708.16 0.00 C80 2857.81 55.54 328.60 2489.00 919.85 -528.22 965.70 0.00 Camp Sst 2958.58 53.54 328.60 2557.00 975.29 -562.06 1028.60 0.00 C50 5063.75 53.54 328.60 3800.00 2434.20 -1252.43 2736.22 0.0(3 C40 5415.42 55.54 528.60 4009.00 2675.62 - 1399.77 3018.80 0.0(3 Calculated iceberg I 6727.88 55.54 328.60 4789.00 5576.61 -1949.64 4075.59 0.0(3 T3.1 7285.15 53.54 328.60 5119.00 $957.80 -2182.28 4519.56 0.00 T3 - Top of Bermuda 7400.93 5,7,.54 328.60 5189.00 4038.65 -2231.63 4814.20 0.0(3 Target - Mid Bermuda 7552.18 55.54 328.60 5267.00 4128.75 -2286.62 4719.66 0.01 T2 - Base of Bermuda 7663.42 53.54 328.60 5545.00 4218.85 -2,:341.61 4825.12 0.00 7809.81 53.54 328.60 54,52.00 4519.35 -2402.94 4942.75 0.00 8109.81 53.54 328.60 5610.29 4525.29 -2528.63 5183.80 0,00 <- West (feet) I TD LOCATION: I 775' FNL, 2170' FWL 2800 2400 2000 1600 1200 800 400 0 40~ SEC. 34, TI ON, R7E ~ ~ m I I I ~ s I I I i I I I m 4800 .eTD - Casing Pt KOP '~ 4400 3 O0 C35 ' Port Collar ...... I '~-~--~T2 - Base of Bermuda 6.00 TARGET LUL. AHUN: /~. N -,- · · -. ~ , 9.00 D~: 5.00 de9 per 100 ft I 1172' ~L, 2411' ~Lm ( )large[ - MIO ~ermuoo ~'nn12 O0 Bose of Pe~ofros[ m SEC. 34, TION, R7E I~T3 - Top of Be~udo ~:~ Top of Wes~ Sok Sands XTB. 1 Beg~n Turn to Target ~26 68 ~Colculated Iceberg Inte~al 36~ ~ 2~.65 ~ 52.79 D~: 4.00 deg per 100 ft ~36.10 ~45.05 Bose o~ West Sok Sands - ~ 32~ ~ 50.22 EOC ~ 7 5/8 Casing Pt. omp 331.02 AZIMUTH Z 4129 (TO TARGET ~ XComp Xc o EOC AVERAGE ANGLE Bose of West Sok Sands 53.54 DE G co,c.,o,. ICeberg Int.~o, ~ Dose ?r ,es~ ~oK ~?nos X ~0 ~se o~ ~e~orrost ~ 0 ' C55 - TD - Casing Pt SURFACE LOGA~ON: m 20' ~ 588' FEL m SEC. 3, TgN, R7E , I i i i i i i i i i i ii i ii i ii ! i i [ i i i 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 Vertical Sect)on (feet) ->. Azimuth 551.02 with reference 0.00 N, 0.00 E from slot #509 c,,~,~ ~ ~,, FOR: LLOYD Oot~ plotteg: ~f~tH am ~n f~t m~e ~ot F~ ~1 ~ o~ m~nc~ ~B (Pool 280 260 240 220 200 180 160 140 I 120 -I-- ~._ 100 '12 6o 20 20 40 60 80 [A-RCO Alaska, I"c. Sfrucfure : Tarn Drill sire 2N Well : 509 Torn I~velopmen! Field Locofion : North Slope. Alaska <- West (feet) ~ I 260 ~ I i I [ ~ 1600 - 240 t 1700 1200 220 2o0 I 1500 ,I, 1600 180 j 1100 160 I 1400 140 I 1500 1000 f 1000 A I [ 120 , oz 1 1.300 lOO gOO I 4~30 j 900 // ~" 1~oo / 2~2Oo :,.oo /-o ,' + J 700 / 12~/ ~ ~ / ~ ~1oo~-~ . I / 1100~ / ~ ~... ~9Oo ~ooo ~oo ~~~~ ~' ~ 5OO ~ 8005 500 ~', e oo;oO ,oo 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 160 1~ 120 100 80 60 ~ 20 0 20 ~ 60 80 100 120 <- Wes, (fee,) [A c0 Alaska, ,nc. ]Structure: Tarn Drill Site 2N Well : Field : Tarn Development Field Location : North Slope. Alaska ^ I 600 -4-- ,~_ 560 520 48O 440 400 360 32O 280 240 <- West (feet) 4443 400 560 .320 280 240 200 160 120 80 40 0 40 80 120 160 g20 , I I I , ~ I , , , I , , , , , , , , 1~.~1 , , , , , , , I , 880 ~ \\\\ ~ \i200 840 \ \ ~ 2400 800 \\ \ \ ~go0 760 \ \ \ 680720 XkXX X . ~ ~ ~1 O0 X~ 2200 1500 ! 2000 XXXX . ~1700 1400 2000 ~ ~ 150q 8 ~ ~ 300 ~~ 900 O0 ~ ~ ~ 700 ' '.~30~ ,1800 13b0 1200 ~ 200 I I I I I I I I I I I I I I I I I I I I I I I I 441 ~0 560 520 280 2¢0 200 160 120 80 40 0 <- West (fool) 880 840 8O0 760 720 680 64-0 6O0 560 --~- 520 440 400 z6o 320 28O 24O f200 c,~t~,~ ~v ~,~ FOR: LLOYD Oat* I~ott~d: 25-F~-l~9 c~r~t~ am In f~t reface ~t ~3~. T~ V~cal ~ om mfe~e ~B (P~l ~6). 2000 1900 1800 1700 1600 1500 1400 h 1500 I '+- 1200 1100 0 Z 1000 90O :ARCO Alaska, Inc. Strucfura : Tar~ Drill Srfe 2N Well : 509 Reid: Tarn Development Field Location: North Slope, Alaska <- West (feet) 1100 1000 900 800 700 600 500 400 500 200 100 0 100 200 300 400 I I ~.~ I I I I I I I I ~ I I ! I 2800 3400% \ \ \ \ \ \ \ 3200% 2200 \ \ \ \ \ \ \ 5ooo ~. \ \ \ 2000 1800 2000 2600 \ \ \ \ 2800 1800 1600 \ \ \ \ \ 2600~- \ 1600 ~000 14oo \ \ \ \ \ \ 2400 1400 \ \ \ 200( 2200 2000 \ 2000 ~, \ ~ 1800 800 % 2400 340(~ ~ 700 % 3000 '~ -, 500 '~1 600 300 1900 1800 1 7OO 16OO 1500 1400 1500 A I Z 1200 0 11oo ,,-.., laDD -'- 9O0 800 700 600 500 2000~ 400 500 11 O0 1000 900 800 700 600 500 400 300 200 1 O0 0 1 O0 200 500 4-00 <- West (feet) 5000 48O0 4500 4400 4200 4000 5800 5600 5400 5200 5000 2800 2600 24O0 220O 2000 1800 16OO ARCO AlaSka, ~)¢. Structure: Torn Drill Site 2N Well : Field : Tarn Development Field Location: North Slope, Alaska <- West (feet) 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 §00 400 200 , , i , ~ , I , , , , , , ~ i I , ~ , , _,~ , , i , , 5800 4600 4800 4400 ~5600 \ \ \\54oo \~5200 4600 340~ 4400 \N5ooo \ \ \~4aoo \ \ \x46oo \ \~ 44O0 2800 \ \ 320~ 3000 2800 2000 5400 3200 4000 \ \ \ \ \ 3000 300( 320( 4200 \~200 O0 2600 ~\ '\~ ~03800 2400 ~ ~ ~°° ~ .~- ~ ~oo ~o~ 4000 4200 3600 \ \ \~3400 \ \ \% 3200 \ 3800 o 3800 3600 ~ 3400 3600 5400 $2O0 3000 \ 2800 / 26oo 2800 3200 ~, I 2400 ~ 2200 2600 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 <- West (feel) 2000 1800 1600 ARCO Alaska, Inc. Struofure: Tarn Drill Site 2N Well: 509 Field : Tarn Development Field Location : North Slope, Alaska WELL PROFILE DATA 3~132° 540 550 35O TRUE NORTH 0 210 10 2O 300 4O c~,~ ~, ~ FOR: LLOYD DaB platted: 25-F~Vo-1gg9 Pto~ R~erence ;. 509 Ve~"~o. ~ Coordlnat~ ~'~ ~ f~ mfe~ ~ ~9. 5O 6O 7O 280 8O 270 26O I00 250 110 1500 23O 130 120 220 / / 2~0~ 2OO 190 140 150 180 170 160 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Tarn Drill Site 2N 3O9 slot #309 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : 309 Version#8 Our ref : prop2835 License : Date printed : 25-Feb-99 Date created : 23-Feb-98 Last revised : 25-Feb-99 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 13.766,w150 18 49.803 Slot Grid coordinates are N 5911987.115, E 461005.406 Slot local coordinates are 19.19 S 587.88 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. Object wellpath PMSS <O-9134'>,,313,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <O-10655'>,,337,Tarn Drill Site 2N PMSS <7090-10245'>,,337A,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <O-12339'>,,341,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <O-12077'>,,335,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <0-7039'>,,319,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <O-8500'>,,317,Tarn Drill Site 2N PMSS <5303 - 11526'>,,321,Tarn Drill Site 2N PGMS <0-9175'>,,32IA,Tarn Drill Site 2N PMSS <9235 - lO028'>,,321A,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N GSS <O-266'>,,320,Tarn Drill Site 2N PMSS <266'-11061'>,,320,Tarn Drill Site 2N PMSS <O-10520'>,,308,Tarn Drill Site 2N PMSS < 2250 - 7162'>,.3A,TARN #3 Closest approach with 3-D Last revised 4-Aug-98 21-3ul-98 18-2un-98 29-~ul-98 30-Sep-98 30-Sep-98 9-0ct-98 9-0ct-98 27-0ct-98 9-0ct-98 9-0ct-98 28-May-98 23-3ul-98 14-Aug-98 21-Dec-98 21-Dec-98 21-Dec-98 21-Dec-98 26-~an-99 9-Feb-99 24-Feb-99 13-~ul-98 Distance )58 9( )538 5( )417 7( )417 7( )89 O( )479 7( )329 O( )507 1( )380 9( )444 3( )147 5( )296.9( )209.6( )117,4( )179.9( )179.9( )179.9( )239.7( )161.8( )159.3( )14.6( )1198.1( Minimum Distance method M.D. 22O 0 400 0 320 0 320 0 220 0 140 0 240 0 340 0 888 9 380.0 822.2 420.0 180.0 600.0 100.0 100.0 100.0 50.0 260.0 440.0 180.0 8109.8 Diverging from M.D. 220.0 7800.0 320.0 320.0 220.0 7940.0 240.0 340.0 7500.0 380.0 822.2 7160.0 6850.0 7950.0 5080.0 8109.8 8109.8 700.0 260.0 440.0 180.0 8109.8 PMSS <0-6864'>, ,Arete,Tarn 329A PMSS <2506 - 6190').,329A. PMSS <0-11140>..313.Tarn Drill Site 2L PMSS <0-9210'>,.305.Tarn Drill Site 2L PMSS <0-9200'>,,325,Tarn Drill Site 2L 315 PMSS <0-8236'>,.315,Tarn Drill Site 2L 323 PMSS <0-10400'>,.323,Tarn Drill Site 2L PMSS <0-12403'>..321.Tarn Drill Site 2L PMSS <0- 7650 '>..Tarn~2,TARN #2 PMSS < 0 - 6150'>,.TARN~4,TARN #4 Tarn #1 (Straight Hole). ,1.TARN #1 1 2L 16-Nov-98 'n DrTll Site 16-Nov-98 15-Dec-98 15-Dec-98 19-Nov-98 29-Dec-98 29-Dec-98 11-Jan-99 7- Dec- 98 13-Nov-98 12-Aug-97 ) 11452.6 )10328.3 )10854.4 ) 11682.1 ) 7824 4 ( )9598 9( )9389 0 ( )9539 7( )9760 1( )6449 9( 13235.6 8109 8109 8109 8109 8109 8109 8109 8109 8109 1022 8109 8 8 8 8 8 8 8 8 5 8 ]109.8 <~8109.8 8109.8 8109.8 8109.8 8109.8 8109.8 8109.8 8109.8 1022.5 8109.8 RCO Alaska, Inc. Diverter Schematic Pool #6 21%" 2,000 psi wP DRILLING SPOOL w/16" Outlet Flowline 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT MANUAL GATE ~--] KILL LINE ~ 3" 5,000 psi WP Shaffer GATE VALVE L w/hydraulic actuator ~l J USA 13-5/8" 5,000 psi WP L x 11" 3,000 psi WP \ r-I 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE i_~ ;/hydraulic actuator ~L~~CHOKE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL L_I ~ wi two 3" 5M psi WP outlets I SINGLE 13-5/8" 5,000 psi WP, J HYDRIL MPL BOP wi pipe rams ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 March 1, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-309 Surface Location: 20' FNL 588' FEL Sec 3 TgN R7E, UM Target Location: 1172' FNL, 2411' FWL Sec. 34, T10N, R7E, UM Bottom Hole Location: 775' FNL, 2710' FWL. Sec. 34, T10N, R7E, UM Dear Commissioner Christenson, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-309, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Pool #6 will drill the well. If commercial, the well will also completed with Pool #6. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be preferentially ground at the on-site ball mill and injected down an approved, existing well annulus on 2N pad or stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H~S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H~S. The following are ARCO's designated contacts for reporting respor~i~ 1 N A L to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Bill Lloyd at 265-6531 or me at 263-4603 in our Anchorage office. ,r. ii; -~. ,~ Sincerely, ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Robert Christensor Application for Pern-,,~ to Drill Page 2 KRU 2N-309 Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-309 Well File ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360~ March 1, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re~ Application for Permit to Drill KRU 2N-309 Surface Location: 20' FNL 588' FEL Sec 3 TgN R7E, UM Target Location: 1172' FNL, 2411' FWL Sec. 34, T10N, R7E, UM Bottom Hole Location: 775' FNL, 2710' FWL Sec. 34, T10N, R7E, UM Dear Commissioner Christenson, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-309, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drilisite. The well is accessed via a new gravel road originating at 2M Pad. Pool #6 will drill the well. If commercial, the well will also completed with Pool #6. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well, Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be preferentially ground at the on-site ball mill and injected down an approved, existing well annulus on 2N pad or stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H~S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H=S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug HaStings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, Please contact Bill Lloyd at 265-6531 or me at 263-4603 in our Anchorage office. Sincerely, ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Robert Christensor, Application for Pern...-to Drill Page 2 KRU 2N-309 Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-309 Well File ARCO Alaska, Inc. ,.~,AI PAYABLES !".~.O. Box 102776 Anchorage, AK 99510-2776 ~=AY TO THE 'RDER OF: ~,.~. ~.. 205088369 73-426 839 FEBRUARY 19, 1999 0997579 I~ ~ ALASKA DEPT OF RE~/ENUE ALASKA OIL &, GAS', CONSERVATION COMMI 3001 PORCUPINE DRtVE i .;~ '~ :'... ~ : i.. .: i~ ' ':.. : · *~*i: ~0ID~AFTER 90 DAYS *** .... : '!~' !:~:' ..: ~ :.~ .i EXACTLY ******~*****'!OO DOLLARS AND O0 CENTS. ~***********100.00 The F,rSt National Bartk:iof Chicag°-0710 ' i .' '~ . : i: .... :i::!.. i:::.!.: ~"".' .... '~ ChicagOi:l'.ll'inois :. Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 205088369 "-08 :~cIoh 2r= 21: OC~C~ ? S WELL PERMIT CHECKLIST COMPANY /,'~c.__ ~ WELL NAME./~"_~/~,~/-.~:::~,C~ PROGRAM: exp dev ~ redrll__ serv ~ wellbore seg ~ ann. disposal para req t,//'' FIELD & POOL ADMINISTRATION INIT CLASS '~ ~--z,' ..,/-c~.~l// ENGINEERING DATE GEOLOGY D,'I' 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 drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. 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 ........... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. APPR DATE Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... GEOL AREA Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ¥ N BOPEs, do they meet regulation ................ '(~ N BOPE press rating appropriate; test to ~'~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Permit can be issued w/o hydrogen sulfide measures ..... Y,'~NN//~'YY N_// /~ Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratory o~y] Y N With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ON UNIT# //'~' D'c;, ON/OFF SHORE ~,,~-'~ 4..,,J GEOLOGY: ENGINEERI_N~.: UIC/Annular COMMISSION: "' JDH ___--- ' co Comments/Instructions: O Z O c:\msoffice\wordian\diana\checklist Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drillin9 Services LIS Scan Utility Tue Jul 27 10:04:39 1999 Reel Header Service name ............. LISTPE Date ..................... 99/07/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writin~ Library. Tape Header Service name ............. LISTPE Date ..................... 99/07/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writin9 Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL MWD/MAD 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: MWD RUN 2 AK-MM-90094 J. PITCHER F. HERBERT RECEIVED 291999 ~.~- 3 0 9 ,~Jaska Oil & Gas Oons. Commission 5 01032 0~. 93 oo /blC, Orai~e ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 27-JI/L-99 3 09N 07E 20 588 .00 154.50 119.90 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 118.0 9.875 7.625 2583.0 6.750 8075.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIOND~L ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PPIkSE-4 (EWR-4), COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC. ON 23 MARCH, 1999. EPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 2N-309. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8075'MD, 5596'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SC02 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: FIXED HOLE SIZE = MUD WEIGHT = MUD SALINITY = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 6.75" 9.6 PPG. 200 - 250 PPM. 19149 PPM. 1.oo G/CC. 2.65 G/CC. SANDSTONE Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEA~DER FILE NLIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMFLARY PBU TOOL CODE START DEPTH ROP 2475 5 FCNT 2570 0 NCNT 2570 0 NPHI 2570 0 FET 2570 0 RPD 2570 0 RPM 2570 RPS 2570 RPX 2570 GR 2570 PEF 2581 DR/40 2581 RHOB 2581 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 8075.0 7983 0 7983 0 7983 5 8027 5 8027 5 8027 5 8027.5 8027.5 8020.5 7999.0 7999.0 7999.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2575.0 8075.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 R_HOB MWD G/CC 4 1 68 DR/qO MWD G/CC 4 1 68 PEF MWD BA/~N 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 2570 8075 5322.5 11011 GR 37.65 330.32 122.947 10902 RPD 0.58 2000 6.09553 10916 ROP 0.02 1946.34 143.871 11002 RPX 1.2 2000 4.7564 10916 RPS 0.85 2000 4.92492 10916 RPM 0.25 2000 6.18648 10916 FET 0.2 62.14 0.945166 10916 NPHI 10.58 58.59 33.7071 10828 R_HOB 1.91 3.46 2.3439 10837 DRHO -0.07 1.17 0.0773867 10837 PEF 1.66 10.6 3.33042 10837 FCNT 110.09 878.42 283.998 10827 NCNT 12848.3 32832.5 20418.6 10827 First Reading 2570 2570 2570 2574.5 2570. 2570 2570 2570 2570 2581 2581 2581 2570 2570 Last Reading 8075 8020.5 8027.5 8075 8027.5 8027.5 8027.5 8027.5 7983.5 7999 7999 7999 7983 7983 First Reading For Entire File .......... 2570 Last Reading For Entire File ........... 8075 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP FCNT NCNT NPHI FET RPD RPM RPS RPX GR PEF DRHO RHOB $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2475.5 2570 0 2570 0 2570 0 2570 0 2570 0 2570 0 2570 0 2570 0 2570 0 2581 0 2581 0 2581 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8075.0 7983.0 7983.0 7983.5 8027.5 8027 5 8027 5 8027 5 8027 5 8020 5 7999 0 7999 0 7999 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS 18-MAR-99 INSITE 3.2. (UPGRADE 3) CIM 5.46,SP4 5.16,SLD 10.87 MEMORY 8075.0 2575.0 8075.0 50.2 55.2 TOOL NUMBER P1256NL4 P1256NL4 P1256NL4 P1256NL4 6.750 6.8 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 CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.60 38.0 9.0 250 5.2 3.300 1.300 5.000 4.500 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 P.U. 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/CC 4 1 68 44 12 DRHO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 BAR/N 4 1 68 52 14 57.2 First Name Min Max Mean Nsam Reading DEPT 2570 8075 5322.5 11011 2570 ROP 0.02 1946.34 143.871 11002 2574.5 Last Reading 8075 8075 GR 37.65 330.32 122.947 RPX 1.2 2000 4.7564 RPS 0.85 2000 4.92492 RPM 0.25 2000 6.18648 RPD 0.58 2000 6.09553 FET 0.2 62.14 0.945166 NPHI 10.58 58.59 33.7071 FCNT 110.09 878.42 283.998 NCNT 12848.3 32832.5 20418.6 RHOB 1.91 3.46 2.3439 DR/qO -0.07 1.17 0.0773867 PEF 1.66 10.6 3.33042 10902 2570 8020.5 10916 2570 8027.5 10916 2570 8027.5 10916 2570 8027.5 10916 2570 8027.5 10916 2570 8027.5 10828 2570 7983.5 10827 2570 7983 10827 2570 7983 10837 2581 7999 10837 2581 7999 10837 2581 7999 First Reading For Entire File .......... 2570 Last Reading For Entire File ........... 8075 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/07/27 Origin ................... STS Tape Name ................ UNKI~OWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/07/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL OPERATIONS 2. Name of Operator Phillips Inc. 3..Address P. O. Box ! 00360 AK 99510-0360 4. Location of ~ 5, Type of Well: 20' FNL, 598' FEL, Sec. 3, T9N, R7E, UM ,~,t top of productive interval 1257' FNL, 2466' FWL, Sec 34, T9N R7E, UM At effective depth At total depth 791' FNL, 2178' FWL, Sec. 34, T10N, R7E, UM 12. Present well condition summary Total depth: measured true vertical 8075 feet Plugs (measured) 5597 feet 6. Datum elevation RKB 155 fee~.,,... 7, Unit or Property namb feet) River Unit 8. Well number 2N-309 number / approval number 10. APl number 50-103-20293.. 11. Field I Pool . Kupamk River F'mld/Tam 0il Pool.. Effective depth: measured 7930 feet Junk (measured) true vertical 5512 feet Casing Length Size Cemented Measured Depth' True vertical Depth ~.ONDUCTOR 115' 16" 9 cu ycIs High Early 115' 115' $URF CASING 2385' 7-5/8" 260 Sx AS III & 240 8x Class G w/ 2540' 2277' P ROD CASING 7007' 5-1/2" ~ Sx C~ass G 7162' 5057' P ROD CASING 897' 3-1/2" Included above 8059' 5588' RECEIVED ~size nmde md me~ur~ d~ ' 13. StimulatiOn or c~ent squ~ze summ~ lnte~als treat~ (memur~) .... Trea~ent de~dpfi~ i~uding volumes ..~e~. "14. ' ' R~esentafive DNIv Avemqe Pr~duCfi~ er Ini~flm Data ' Oib~l Gm~M . Watm-~ Ca~ng ~um Tu~ P~um ~: .;:=:~..~::::,~: ' ~ ~.~...~ ~:: ~ ~.~:~ .~:~:::;..::~A-~: ~:;: ~' ~: ~.':~: ~:::~g~::~:~ ~J-:~.~.~.~-~:~:~ · ~:~=;..~A~:~ :,,:~,~=:., ~:.::,.:;.-..:.:::;~.. ~x~..~.~.~,.~;~:=:~' ".---;- 15. Affa~ments L ~Hes of L~s ~d Suweys mn D~ly Re~ of Well O~rations _X ' 17~ I ~reby ce~i~ ~at ~e foregoing is ~e and coff~t t° ~ ~t of my ~ge. Q~s? C~! J~ Sp~cer 6~7~ Sign~ ~~~~ Tffie P~ucfi~ Engineefi, Su,~sor Dat~~/~ ~~ Jeff A ~cer .................. OR GINAL ............... ,,=,oo. SUBMIT IN DUPLICATE 0 m