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Home My WebLink About175-069MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 30, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-04 PRUDHOE BAY UNIT NGI-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/30/2025 NGI-04 50-029-20183-00-00 175-069-0 N SPT 7543 1750690 3500 2045 2403 2380 2372 0 0 0 0 REQVAR P Kam StJohn 5/14/2025 2 Year AOGCC MIT_IA for AA AIO 4E.024 Max injection pressure 3500 psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT NGI-04 Inspection Date: Tubing OA Packer Depth 618 3707 3690 3684IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250514151900 MITOP000010940 BBL Pumped:3.9 BBL Returned:3.9 Wednesday, July 30, 2025 Page 1 of 1          CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: NGI-04 (PTD#1750690) AOGCC MIT-IA passed Date:Thursday, May 11, 2023 10:04:24 AM Attachments:image003.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, May 11, 2023 9:18 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: NGI-04 (PTD#1750690) AOGCC MIT-IA passed Mr. Wallace, Slickline performed a passing AOGCC witnessed MIT-IA on 05/10/23. The well will now be classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Friday, April 28, 2023 11:08 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE NGI-04 (PTD#1750690) Requires Regulatory Compliance AOGCC MIT-IA Mr. Wallace, Gas Injector NGI-04 (PTD #1750690) requires 2 year AOGCC MIT-IA per AA AIO 4E.024 in the month of April 2023. At this time, slickline has been unable to pull the SSSV and will be returning with braided line. The well is now classified as NOT OPERABLE until the 2 year AOGCC MIT-IA is completed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, November 6, 2017 9:51 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS1 DS Ops Lead <AKOPSFS1DSOpsLead@bp.com>; AK, OPS FS1 Facility OTL <AKOPSFS1FacilityOTL@bp.com>; AK, OPS FS1 Field OTL <AK_OPSFS1FieldOTL@bp.com>; AK, OPS FS1 OSM <AKOPSFS1OSM@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Dean, James A <James.Dean@bp.com>; G GPB FS1 Drillsites <ggpbfs1drillsites@BP.com>; Stone, Christopher <Christopher.Stone@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: OPERABLE NGI-04 (PTD#1750690) SSSV reset to repair anomalous IA pressure trend All, Gas Injector NGI-04 (PTD #1750690) was made under evaluation on 10/09/17 for exhibiting an anomalous IA pressure trend. Slickline pulled and reset the SSSV on 10/31/17. The well was placed back on injection and monitored for the remainder of the evaluation period. The well has shown no signs of IA pressurization. The well is now classified as OPERABLE. Please respond if in conflict, Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110Cell: 307-399-3816 From: AK, GWO Well Integrity Engineer Sent: Monday, October 09, 2017 4:39 PMTo: AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Dean, James A; G GPB FS1 Drillsites; Stone, Christopher; 'chris.wallace@alaska.gov'Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; Tempel, Joshua; Worthington, Aras JSubject: UNDER EVALUATION: NGI-04 (PTD#1750690) Anomalous IA pressure trend All, Gas Injector NGI-04 (PTD #1750690) has begun to exhibit an anomalous IA pressure trend. The well operates under AA 4E.024 for slow TxIA communication. The well is now classified as Under Evaluation and is on the 28 day clock to be repaired or secured. Plan Forward: 1. Operations: Shut in well as soon as operationally feasible 2. Slickline: Pull and reset SSSV 3. Operations: Put on injection 4. Downhole Diagnostics: Monitor 5. Well Integrity Engineer: Additional diagnostics as needed Please reply if in conflict with proposed plan. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110Cell: 307-399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 16, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-04 PRUDHOE BAY UNIT NGI-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/16/2023 NGI-04 50-029-20183-00-00 175-069-0 N SPT 7543 1750690 1886 1994 2204 2196 2191 0 0 0 0 REQVAR P Kam StJohn 5/10/2023 2 Year AOGCC MIT-IA for AA AIO 4E.024 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:PRUDHOE BAY UNIT NGI-04 Inspection Date: Tubing OA Packer Depth 2040 3703 3695 3691IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230510174051 BBL Pumped:2 BBL Returned:2 Friday, June 16, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9AIO 4E.024 James B. Regg Digitally signed by James B. Regg Date: 2023.06.16 14:09:16 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 24, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-04 PRUDHOE BAY UNIT NGI-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2023 NGI-04 50-029-20183-00-00 175-069-0 N SPT 7543 1750690 3500 1994 2204 2196 2191 0 0 0 0 REQVAR P Kam StJohn 5/10/2023 2 Year AOGCC MIT-IA for AA AIO 4E.024 to MAIP. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT NGI-04 Inspection Date: Tubing OA Packer Depth 2040 3703 3695 3691IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230510174051 BBL Pumped:2 BBL Returned:2 Monday, July 24, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 99 9 9 9 9 5(9,6(' 3500 2 Year AOGCC MIT-IA AA AIO 4E.024 James B. Regg Digitally signed by James B. Regg Date: 2023.07.25 09:44:39 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE NGI-04 (PTD#1750690) Requires Regulatory Compliance AOGCC MIT-IA Date:Tuesday, May 2, 2023 8:33:12 AM Attachments:image003.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, April 28, 2023 11:08 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE NGI-04 (PTD#1750690) Requires Regulatory Compliance AOGCC MIT-IA Mr. Wallace, Gas Injector NGI-04 (PTD #1750690) requires 2 year AOGCC MIT-IA per AA AIO 4E.024 in the month of April 2023. At this time, slickline has been unable to pull the SSSV and will be returning with braided line. The well is now classified as NOT OPERABLE until the 2 year AOGCC MIT-IA is completed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, November 6, 2017 9:51 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS1 DS Ops Lead <AKOPSFS1DSOpsLead@bp.com>; AK, OPS FS1 Facility OTL <AKOPSFS1FacilityOTL@bp.com>; AK, OPS FS1 Field OTL <AK_OPSFS1FieldOTL@bp.com>; AK, OPS FS1 OSM <AKOPSFS1OSM@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Dean, James A <James.Dean@bp.com>; G GPB FS1 Drillsites <ggpbfs1drillsites@BP.com>; Stone, Christopher <Christopher.Stone@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: OPERABLE NGI-04 (PTD#1750690) SSSV reset to repair anomalous IA pressure trend All, Gas Injector NGI-04 (PTD #1750690) was made under evaluation on 10/09/17 for exhibiting an anomalous IA pressure trend. Slickline pulled and reset the SSSV on 10/31/17. The well was placed back on injection and monitored for the remainder of the evaluation period. The well has shown no signs of IA pressurization. The well is now classified as OPERABLE. Please respond if in conflict, Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110Cell: 307-399-3816 From: AK, GWO Well Integrity Engineer Sent: Monday, October 09, 2017 4:39 PMTo: AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Dean, James A; G GPB FS1 Drillsites; Stone, Christopher; 'chris.wallace@alaska.gov'Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; Tempel, Joshua; Worthington, Aras JSubject: UNDER EVALUATION: NGI-04 (PTD#1750690) Anomalous IA pressure trend All, Gas Injector NGI-04 (PTD #1750690) has begun to exhibit an anomalous IA pressure trend. The well operates under AA 4E.024 for slow TxIA communication. The well is now classified as Under Evaluation and is on the 28 day clock to be repaired or secured. Plan Forward: 1. Operations: Shut in well as soon as operationally feasible 2. Slickline: Pull and reset SSSV 3. Operations: Put on injection 4. Downhole Diagnostics: Monitor 5. Well Integrity Engineer: Additional diagnostics as needed Please reply if in conflict with proposed plan. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110Cell: 307-399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:175-069 6.50-029-20183-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11015 10898 8475 9579 11010 none 7543 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 84 20" 29 -113 28 - 108 1530 520 Surface 2683 13-3/8" 28 - 2711 31 - 2711 5380 2670 Intermediate Production 9914 9-5/8" 27 - 9942 27 - 7807 6870 4760 Perforation Depth: Measured depth: 10216 - 10844 feet True vertical depth:8010 - 8437 feet Tubing (size, grade, measured and true vertical depth)7-5/8" x 7" 26 - 9629 26 - 7578 Packers and SSSV (type, measured and true vertical depth) Liner 1358 7" 9624 - 10982 7548 - 8481 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Dave Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ 5 SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8556 Sundry Number or N/A if C.O. Exempt: 320-541 7" Camco Bal-O SSSV 2209 2209 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Water Wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028302, 034632 PBU NGI-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations L-80 By Meredith Guhl at 11:13 am, May 13, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.13 10:41:19 -08'00' Bo York SFD 5/13/2021DSR-5/13/21 RBDMS HEW 5/13/2021MGR26JUL2021 ACTIVITYDATE SUMMARY 4/17/2021 Gas Injector Pickle (TUBING WASH/PICKLE) Pumped 8 bbls DSL into IA. Pumped 10 bls 60/40 meth, 50 bbls of 120* DSL and 438 bbls of 160* FW w/ F-103 down Tbg. Let soak for 2 hours. Pumped 145 bbls 160* FW w/ F-103 and 15 bbls 60/40 meth down Tbg for flush. DSO notified of well status per LRS departure.SV,WV,SSV=C MV=O IA,OA=OTG 4/25/2021 T/I/O=0/0/0 Temp=S/I Assist Slickline W/ Load and Test (Pressure Test Integrity) Drove to location. Unit needed on another job. Did not pump any fluids. 4/27/2021 T/I/O=2700/220/40 Temp=40* Assist Slickline Load and Test. (Pressure Test Integrity) Pumped 695 bbls of 100* 2% SKL down TBG, capped with 5 bbls 60/40 and 95 bbls 28* diesel for freeze protect. Slickline set plug and DSSSV. Pressured up TBG to 2000 psi with 21 bbls diesel TBG lost 23 psi in 15 min, plug holding. Pressured up IA to 4000 psi with 8 bbls diesel. IA lost 14 psi in 15 min. Bled IAP to 500 psi and recovered a total of 6 bbls. Slickline in control of well upon departure. IA OA= OTG. Final Whp's=1880/500/10 4/27/2021 ***WELL INJECTING ON ARRIVAL***(integrity) GAUGED TO SSSV @ 2192" SLM W/ 6.05" GAUGE RING PULLED 7" A-1 INJECTION VALVE FROM SSSVN @ 2192' SLM. SET 5.65" CAT STANDING VALVE IN RN @ 9603' MD. LRS LOADED THE TUBING SET DSSSV IN SSSVN @ 2192' SLM. ***CONT WSR ON 4/28/21*** 4/28/2021 ***WSR CONTINUED FROM 4-27-21***(integrity) AOGCC WTINESSED MIT-IA.(passed) PULL DSSSV FROM SSSVN @ 2209' MD PULLED CAT STANDING VALVE FROM RN @ 9603' MD SET MODIFIED A-1 INJECTION VALVE IN SSSVN @ 2209' MD (BWS-138 MODIFIED PKG) DRAW DOWN TEST PASSED (1350PSI -1000PSI) BAL LINE BLED TO ZERO ***DSO NOTIFIED, JOB COMPLETE*** 4/28/2021 T/I/O=923/756/7 Temp= 40* AOGCC MIT-IA Passed @ 3971 psi. (Witnessed by Bryan Bixby) Max applied 4000 psi. Target pressure 3900 psi. Pressured up TBG to 2004 psi with 10 bbls diesel. Pressured up IA to 3993 psi with 4 bbls diesel. 1st 15 min IA lost 14 psi. 2nd 15 min IA lost 8 psi for a total loss of 22 psi in 30 min. Bled IA to 755 psi and recovered 4 bbls. Bled IA back down to 100 psi and TBG to 1000 psi for slickline. Slickline in control of well upon departure. IA OA= OTG. Tags hung. FWHPS=1000/100/7 Daily Report of Well Operations PBU NGI-04 MEMORANDUM State of Alaska Inspection Date: 428/2021 Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 4, 2021 TO: Jim Regg 1 �` I�'� SUBJECT: Mechanical Integrity Tests Mq"q P.1. Supervisor l / Well NGI-o4 Hilcorp Noah Slope, LLC N NGI-04 FROM: Brian Bixby PRUDHOE BAY UNIT NGI-04 Petroleum Inspector z33ozz93zz79 Ste: Inspector Ell Reviewed By: PTD P.I. Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-04 API Well Number 50-029-20183-00-00 Inspector Name: Brian Bixby Permit Number: 175-069-0 Inspection Date: 428/2021 Insp Num: mitBDB210429043539 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-o4 Type Inj N TVD 7543 Tubing t96t - z33ozz93zz79 - Ell PTD 1750690 Type Test I SPT Test psi 3500 IA 756 3993 3979 - 3971 - BBL Pumped: 1 4 BBL Returned: 4 OA 7 1 7 Interval REQVAR PAF P Notes: 2 Year MIT -IA as per AID 4E.024 i Tuesday, May 4, 2021 Psec I of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y Jody Colombie at 11:05 am, Dec 28, 2020 'LJLWDOO\VLJQHGE\%R<RUN '1FQ %R<RUNF 86R +,OFRUS $ODVND//&RX $ODVND1RUWK 6ORSHHPDLO E\RUN#KLOFRUSFRP 'DWH %R<RUN $'/ 6)''65 6)' 0*5'(& <HVWLRQ5HTXLUHG" &RPP 12/29/2020 dts 12/29/2020 RBDMS HEW 1/26/2021 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗NGI-04 W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϬϭϴϯͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐ/ŶũĞĐƚŽƌ >ĞŐ͗ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗&Ğď ϯƌĚ͕ϮϬϮϭ ZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂů ZĞƋ͛Ě͍ϭϬͲϰϬϯ ĂƚĞ ZĞŐ͘ƉƉƌŽǀĂů ZĞĐĞŝǀĞĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌƌŝĞ :ĂŶŽǁƐŬŝ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϳϱͲϬϲϵϬ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϰϲϳϮ Ğůů͗ϵϬϳͲϰϰϬͲϬϯϯϭ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶdŚŽŵƉƐŽŶ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϱϮϴϬ Ğůů͗ϵϬϳͲϯϬϭͲϭϮϰϬ 'ĂƐ/ŶũĞĐƚŝŽŶZĂƚĞ͗ ϭϲϲ͕ϴϴϰ DƐĐĨͬĂǇ /ŶũĞĐƚŝŽŶWƌĞƐƐƵƌĞ͗ϯ͕ϯϳϲ ƉƐŝ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ;ƐƚŝŵĂƚĞͿ͗ϯϱϬϬƉƐŝ WƌŽŐƌĂŵKďũĞĐƚŝǀĞ;ƐͿ͗ E'/ͲϬϰ ŝƐĂŐĂƐ ĐĂƉ ŝŶũĞĐƚŝŽŶǁĞůůƚŚĂƚŚĂƐĚĞŵŽŶƐƚƌĂƚĞĚĂĚĞĐƌĞĂƐĞŝŶŝŶũĞĐƚŝǀŝƚǇ͘dŚĞǁĞůůŚĂƐŶŽƚďĞĞŶǁĂƚĞƌ ǁĂƐŚĞĚƐŝŶĐĞϮϬϭϮ͘tĂƚĞƌǁĂƐŚĞƐĂƌĞ ĚĞƐŝŐŶĞĚƚŽĚŝƐƐŽůǀĞƐĂůƚƐĂŶĚĂƐƉŚĂůƚĞŶĞƐŝŶƚŚĞƚƵďŝŶŐĂŶĚĨŽƌŵĂƚŝŽŶ͘ dŚĞŽďũĞĐƚŝǀĞŝƐƚŽƉĞƌĨŽƌŵĂƚƵďŝŶŐǁĂƚĞƌǁĂƐŚƚŽŝŶĐƌĞĂƐĞŝŶũĞĐƚŝǀŝƚǇĂŶĚƉĞƌĨŽƌŵĂŐĞŶĞƌĂůŵĂŝŶƚĞŶĂŶĐĞŽŶ 'ĂƐ/ŶũĞĐƚŝŽŶtĞůůƐ͘ WƌŽƉŽƐĞĚWƌŽŐƌĂŵ͗ WƵŵƉĚŝĞƐĞůĨŽůůŽǁĞĚďǇ&ƌĞƐŚtĂƚĞƌĂŶĚ^ƵƌĨĂĐƚĂŶƚĂƐƉĞƌĂƚƚĂĐŚĞĚƉƵŵƉŝŶŐ ƚĞŵƉůĂƚĞ͘ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ +LOFRUS1RUWK6ORSH//& Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, May 6, 2019 2:04 PM To: Wallace, Chris D (DOA) Cc: AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; Regg, James B (DOA) Subject: NGI-04 (PTD #1750690) Failed SSSV state test Chris, NGI-04 (PTD #1750690) failed as state witnessed SSSV test today and was immediately shut in. Slickline is currently working to get out to location to reset the valve. If the valve cannot be reset and successfully tested it will be reclassified in a follow up communication. Please let me know if you have any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 MEMORANDUM TO: Jim Regg / 1 P.I. Supervisor ) FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 8, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. NGI-04 PRUDHOE BAY UNIT NGI-04 Sire: Inspector Reviewed By:pn � P.I. Supry NON -CONFIDENTIAL Comm rRI ame PRUDHOE BAY UNIT NGI-04 API Well Number 50-029-20183-00-00 Inspector Name: Lou Laubenstein Permit Number: 175-069-0 Inspection Date: 4/29/2019 am: MaLOL190508140929 sp Num: Wednesday, May 8, 2019 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I4oITYPe -- - Inj 'TVD ;1 _— z Lubin« , i a3 z26osi 2291 2304 - PTD 1750690 ITYpeTest M" Test psi "0o IA -04 - �y'- 3925 3876 - 3834 ' 3795 - _N BBL Pumped c. _ 48 -IBBL Returned: 4,J -- - . OA -7 -' -6 -6 -6 -6 Interval REQvAR P/F —�-- Notes: 2yr MIT -IA per AA 4E.024 for Tx1A communication, test to 4000 psi was found to be inconclusive (see retest report mid-OL190430151532), 75 Min. TIO - 2321/3749/-6 Wednesday, May 8, 2019 Page I of I MEMORANDUM TO: Jim Regg L%q 51 jl iq P.I. Supervisor rr FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 3, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. NGI-04 PRUDHOE BAY UNIT NGI-04 Ste: Inspector Reviewed By: P.I. Supry \Bz— NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-04 API Well Number 50-029-20183-00-00 Inspector Name: Lou Laubenstein Insp Num: mitL01-190430151532 Permit Number: 175-069-0 Inspection Date: 4/29/2019 ' Rel Insp Num: Friday, May 3, 2019 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well �ci-oa Type Inj N TVD 7543 - Tubing zou 2„i. 25'_5 esu - PTD oaeo Type Test SPT Test psi 3700 [A asz 1016- ooz pie, BBL Pumped: 3.9 - IBBL Returned: 3.9 OA -4 -I -1 -2 Interval REQVARP/F P ✓ Notes: 2yr MIT -IA per AA 4E.024 for TxIA communication, test to 4000 psi Friday, May 3, 2019 Page 1 of I i Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, November 6, 2017 9:51 AM To: AK, OPS EOC Specialists;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Dean,James A; G GPB FS1 Drillsites; Stone, Christopher;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua; Worthington, Aras J; Regg,James B (DOA) Subject: OPERABLE NGI-04 (PTD#1750690) SSSV reset to repair anomalous IA pressure trend r - All, Gas Injector NGI-04(PTD#1750690)was made under evaluation on 10/09/17 for exhibiting an anomalous IA pressure trend.Slickline pulled and reset the SSSV on 10/31/17.The well was placed back on injection and monitored for the remainder of the evaluation period.The well has shown no signs of IA pressurization.The well is now classified as OPERABLE. Please respond if in conflict, Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 , 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, October 9,2017 4:39 PM To: AK, OPS EOC Specialists;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OIL;AK, OPS FS1 Field OTL;AK, OPS FS1 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Dean,James A; G GPB FS1 Drillsites; Stone, Christopher;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Regg,James B (DOA); Tempel, Joshua;Worthington,Aras J Subject: UNDER EVALUATION: NGI-04 (PTD#1750690)Anomalous IA pressure trend Attachments: NGI-04.pdf All, Gas Injector NGI-04(PTD#1750690) has begun to exhibit an anomalous IA pressure trend.The well operates under AA 4E.024 for slow TxIA communication. The well is now classified as Under Evaluation and is on the 28 day clock to be repaired or secured. Plan Forward: 1. Operations: Shut in well as soon as operationally feasible 2. Slickline: Pull and reset SSSV 3. Operations: Put on injection 4. Downhole Diagnostics: Monitor 5. Well Integrity Engineer:Additional diagnostics as needed Please reply if in conflict with proposed plan. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska � � �� Office:907-659-8110 Cell:307-399-3816 1 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, May 4, 2017 4:47 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AKOpsProdEOCTL;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists; AK, OPS Prod Controllers;AK, OPS FS1 DS18 Operator; Stone, Christopher; Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R; Worthington, Aras J Subject: UNDER EVALUATION: Injector NGI-04 (PTD#1750690)Anomalous IA Pressure Trend All, Gas Injector NGI-04 (PTD#1750690) has begun to exhibit an anomalous IA pressure trend.The well operates under AA 4E.024 for slow TxIA communication.The well recently passed an AOGCC witnessed MIT-IA on 04/27/17. It's suspected that the communication is through the SSSV control lines and started sometime after the SSSV was reset on the 04/29/17. The well is now classified as Under Evaluation, and is on a 28 day clock to be repaired or secured. Plan Forward: 1. Operations: Shut in well as soon as operationally feasible 2. Slickline: Pull and reset SSSV 3. Operations: POI well 4. Downhole Diagnostics: Monitor 5. Well Integrity Engineer: Additional diagnostics as needed Please reply if in conflict with proposed plan. Thanks, Joshua Stephens goidelEpMAY 10 2017 Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9038 Y Y 1 S • 4,000 3,800- 3,600- 3,400- • 3.200- 3,000- 2,800 2.600 2.400 2,200- 2.000- 1,800- 1,600 1,400 1,200- 1,000 800- 600 400- 200- 01/04/17 01/11/17 01112,1117 0112517 02101117 02106117 02/15/17 02/22117 3,500 3.000 2.500 - a-2.000 - E. 1.500 1,000 - 500- . 01/04/17 01/11117 01118/17 01125/17 02101/17 02108/17 02/15/17 02/22/1: 2 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,May 03,2017 Jim Regg P.I.Supervisor �-C-6/6 D It(./7 SUBJECT: Mechanical Integrity Tests l BP EXPLORATION(ALASKA)INC. NGI-04 FROM: Lou Laubenstein PRUDHOE BAY UNIT NGI-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Tr- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-04 API Well Number 50-029-20183-00-00 Inspector Name: Lou Laubenstein Permit Number: 175-069-0 Inspection Date: 4/27/2017 Insp Num: mitLOL170427132139 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-04 Type Inj G TVD 7543 - Tubing 2460 2553 2547- 2549 - PTD 1750690 " Type Test SPT Test psi 3800 - IA 1961 3995 3991 - 3989 • BBL Pumped: 2.6 - BBL Returned: 2.6 - OA 5 4 . 5 • 4 - Interval REQVAR P/F P Notes: AA 4E.024 MITIA every 24 months SCANNED AUG 2. 4 20I? Wednesday,May 03,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday,July 22, 2016 9:19 AM To: AK, OPS FS1 OSM;AK, OPS FS1 Field OIL;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OTL;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AKOpsProdEOCTL;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;AK, OPS Prod Controllers;AK, OPS FS1 DS18 Operator; Stone, Christopher; Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: OPERABLE:Injector NGI-04 (PTD#1750690) Stable Inner Annlus Pressure All, Gas Injector NGI-04(PTD#1750690) has shown stabilized annulus pressure post pull/reset of SSSV.The well has been on injection for 10 days and monitoring indicating inner annulus re-pressurization has been resolved.The well is now reclassified as Operable. Please call with any questions or concerns. Ryan Holt err are rte BP Alaska-Well Integrity GWGlobal Wells Organization SCANNED VQV 1 82016 Office: 907.659.5102 From: AK, GWO SUPT Well Integrity Senturday, July 09, 2016 8:08 PM To: AK, O 1 OSM; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; Cismoski, Doug A; Daniel, Ryan; AK, GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, OPS EOC Specjalists; AK, OPS Prod Controllers; AK, OPS FS1 DS18 Operator; Stone, Christopher; 'chris.wallace@alaska.gov' (chrls apace@alaska.gov) Cc: AK, GWO DHD Well Integrity; AIDC IVO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.reg alaska.gov)' (jim.regg@alaska.gov); Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitc .Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Injector NGI-04 (PTD 0690) Anomalous IA Pressure Trend All, Gas Injector NGI-04(PTD#1750690) has begun to exhibit an anomalous l'ktrfe&sure trend.The well operates under AA 4E.024 for slow TxIA communication. It is suspected that the recent increase in i (epressurization rate is due to communication at the SSSV.The well is reclassified as Under Evaluation,and is on a'284ay clock to be repaired or secured. 1 N,, • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWeIllntegrityCoordinator@bp.com> Sent: Saturday, July 09, 2016 8:08 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, OPS EOC Specialists; AK, OPS Prod Controllers;AK, OPS FS1 DS18 Operator; Stone, Christopher; Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy;Worthington, Aras J Subject: UNDER EVALUATION:Injector NGI-04 (PTD #1750690) Anomalous IA Pressure Trend Attachments: Injector NGI-04 (PTD #1750690) TIO Plot 2016-07-09.docx All, Gas Injector NGI-04(PTD#1750690) has begun to exhibit an anomalous IA pressure trend.The well operates under AA 4E.024 for slow TxIA communication. It is suspected that the recent increase in IA repressurization rate is due to communication at the SSSV. The well is reclassified as Under Evaluation, and is on a 28 day clock to be repaired or secured. Plan Forward: 1. Operations: Shut in well as soon as operationally feasible 2. Slickline: Pull and reset SSSV 3. Operations: P01 well 4. Downhole Diagnostics: Monitor 5. Well Integrity Engineer:Additional diagnostics as needed TIO and Injection plots are attached. Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H: 2376 Email: AKDCWeIllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, April 06)---2.0.1A 8:47 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations TeamLL a J AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, EAC&ojects Well Integrity Engineer; 1 • • Injector NGI-04(PTD#1750690) TIO Plot 2016/07/09 W I 114104 1,a -4-CODA 1 --- 04991£ 04'53 0421"16 04303 164416 601416 652416 052616 064416 051116 06161 06'516 1133216 Injection Plot Well 616401 34101 .£'A 3.63.61424,20 . ata, 1000 za � -ls 1412600 :1�;<c 1436 , 2106. -166116E _ 2000 -4166:'. -qy 1600 '2- 1600 —661 tt9 -ts:146 —01•• 1106 la a '306 :AOS 406 200 049016 861616 642116 64363 054114 p51416 662116 0612416 064416 0611116 661616 0425'3 65,92116 6109€ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,April 02,2015 TO: Jim Regg � � I P.I.Supervisor ltp Jl 4 113(15 SUBJECT: Mechanical Integrity Tests ` BP EXPLORATION(ALASKA)INC NGI-04 FROM: Matt Herrera PRUDHOE BAY UNIT NGI-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JAC— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-04 API Well Number 50-029-20183-00-00 Inspector Name: Matt Herrera Permit Number: 175-069-0 Inspection Date: 3/26/2015 Insp Num: mitMFH150329181018 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min — NGI-04 a Test 0 (Testpsi 7s43 IA 1645 2sla- 2502 2495 2491 Well' iType InjTVD Tubing 1 3988 - a — 4 3333— --- � I PTD 1750690 ryp SPT I 1886972 4008 3998 3992 - 3988 Interval 'REQVAR 1 P/F 1 P i 1 OA 18 19 - 18 I 18 18 - Notes: IA pressure to 4000 PSI per Operator's procedure Tubing pressure up to 2000 PSI Methanol 3.49 BBL's to bring up to required pressure. Well tested per AA 4E 024(2)Year interval SCANNED :- Thursday,April 02,2015 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, December 09, 2014 4:52 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; Wallace, Chris D (DOA); Redmond, Randy; Weiss, Troy D; Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator, AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: NOT OPERABLE: Injector NGI-04 (PTD #1750690) Remote Transmitters not in compliance with AA Attachments: image001jpg SCANNED ITEC 10 2014 All, Gas Injector NGI-04 (PTD # 1750690) currently operates under AIO AA 4E.024 for slow TxIA communication. Per the approved AA: BPXA shall install, operate and maintain remote pressure monitoring equipment on the well's IA; an alarm set point of no higher than 2,000 psi shall be maintained to allow for time to respond and bleed pressure from the IA; At this time, the well remote sensors are not functioning in a consistent manner. The well has been reclassified as Not Operable until competent monitoring equipment can be demonstrated. Please call with any questions. Thank you, Laurie Climer (Alternate: Jack Disbrow) BP Alaska - Well Integrity Coordinator WOfganlz5trun WIC Office: 907.659.5102 WIC Email: AKDCWelllnteerityCoordinator@BP.com Wallace, Chris D (DOA) From: Regg, James B (DOA) Sent: Friday, November 14, 2014 9:40 AM To: AK, D&C Well Integrity Coordinator; Wallace, Chris D (DOA) Subject: RE: NGI-04 (PTD #1750690) AOGCC Witnessed Test Attachments: image001.png MIT is not necessary Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Friday, November 14, 2014 5:18 AM To: Regg, James B (DOA); Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: NGI-04 (PTD #1750690) AOGCC Witnessed Test Jim, Chris, A SSSV has been reset in NGI-04 (PTD #1750690) and tubing x inner annulus communication is no longer present. Please advise if the AOGCC wishes to witness a MIT -IA on NGI-04 post SSSV reset. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@bp.com SCWED NOV 18 2D14 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIIIntegrityCoordinator@bp.com> Sent: Thursday, November 13, 2014 1:42 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: OPERABLE: Injector NGI-04 (PTD #1750690) Inner Annulus Repressurization Has Stopped Attachments: image002.png; image003 jpg; Injector NGI-04 (PTD #1750690) TIO and Injection Plot.docx MM SCANNED NOV 1 4 2014 Injector NGI-04 (PTD #1750690) has stopped showing signs of inner annulus repressurization after the subsurface safety valve was pulled and reset on 10/30/2014. The inner annulus pressure has been monitored for 2 weeks since the subsurface safety valve was pulled and reset and has not shown any signs of repressurization. The well is reclassified as Operable. Well status is Operable A SSSV is required for injection Copies of the 110 and injection plot are included for reference. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, October 28, 2014 1:14 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Injector NGI-04 (PTD #1750690) IAP repressurization through SSSV Ma Injector NGI-04 (PTD #1750690) has begun exhibiting faster inner annulus repressurization. The well currently operates under AA 4E.024 for slow TxIA communication with suspected communication at the SSSV. At this time the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Slickline: Pull and reset SSSV 2. WIE: Additional diagnostics as needed A copy of the wellbore schematic, TIO and Injection plots have been included for reference. Please call with any questions. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator GWG ,n: 4 , e ,s WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 I Injector NGI-04 (PTD #1750690) TIO Plot WNI: NGHX a ulo 3.000 —0 Tbg —i -1A 2.000 —0 OOA t OOOA On U00 C8'16!14 0923'14 0i -K 14 090614 09'1314 0924'14 0927/14 10.W14 1WI114 10IM14 102514 '11114 1lmi4 Injector NGI-04 (PTD #1750690) Injection Plot Well: NGFm 200.00 3.600 3.400 190.000 3.200 3.000 160.000 290(! 2-600 140.000 2.4000 — WHW 2.200 120.[0 —SW �� 100.000; —M 1600 — G 1.406 8D.000 $ — Ower 1,200 64.000 1.000 w0 44000 600 400 20000 200 08'1614 0923'14 09'36'14 0806+14 WW4 0926'14 092;!14 104014 14'11;14 10.1814 ID2514 1M1'14 11,WA Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, October 28, 2014 1:14 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Injector NGI-04 (PTD #1750690) IAP repressurization through SSSV Attachments: image001jpg; NGI-04 TIO and Injection Plot 10-28-14.docx; NGI-04 Wellbore Schematic.pdf M1 Injector NGI-04 (PTD #1750690) has begun exhibiting faster inner annulus repressurization. The well currently operates under AA 4E.024 for slow TxIA communication with suspected communication at the SSSV. At this time the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Slickline: Pull and reset SSSV 2. WIE: Additional diagnostics as needed A copy of the wellbore schematic, TIO and Injection plots have been included for reference. Please call with any questions. Thank you, Laurie Climer (Alternate: loch Dish;-oiv) BP Alaska - Well Integrity Coordinator Ghat Wells tri Organization WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com 1 SCMED OCT 3 0 2014, Injector NGI-04 (PTD #1750690) 90 day TIO Plot 2014 3.00 2.000 1,000 Wall: NGHM 3.60C 3.400 3.200 3.000 2.&10 2.600 2.40 2.20 u 2.00 1.60 1,40 7.200 1.00 80 60 40 20 0&02/14 0&09710 08116'14 08-23':. 0&'30;14 0906+14 09113114 0&M'14 0&27114 10.04%14 10'1U14 101&14 MON Injection Plot WWI: NGI-04 I 1 - I_ ^ARMA Itl1A1W1A nRl IA M011A -"IA1 M1 11 n©1'tllA nV IA n 7111 1lLY1 A'1nlllllA' MIR— IHSH ).000 )00 )000 ).00 October 28, Tbg -t IA -� OA OOA t OOOA On ),00 —NAW —PW ).000 —14 � —GI 00 On 00 o0 00 TRS = 6-318" CNV WELLHEAD = GRAY ACTUATOR = BAKER C KB. E -EV = 47.0' BF. ELEV = NAA KOP = 3200' Wx Angle = 54 @ 67W Datum MD = 3-3/8" Datum TVD 8800' SS 13-3/8' CSG, 72#, MN -80, D = 12.347" I 2711' Minimum ID = 5.50" @ 9603' 7" HES RN NIPPLE 7-5/8' TBG -IPC, 29.04#, L-80 STL, 9558' .0459 bpf, D = 6.690" I7" TBG, 26#, L-80 NSCC, .0383, D = 6.276" I 9619' SIZE 9-5/8" CSG, 47#, RS -95 /S00-95 / MN -80N BTRS, 1) = 8.681" 9941- SOZ PERFORATION SUMMARY RE= LOG- BRCS ON 06/17/77 A NGLE AT TOP PERF 44 @ 10216' Nate. Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 3-318' 4 10216 - 10268 O 06/29190 2573' 3-3/8' 4 10329 - 10354 O 06118f77 07/29/14 PJC PERFORATION RESEARCH 3-3/8" 4 10354 - 10373 O 02/28/87 3-3/8" 4 10373-10398 O n1(4 I fiV� 7 3-318" 4 10398 - 10406 O 02/27/87 3-318" 4 10410 - 10425 O 06/17/77 3-318" 4 10441 -10470 O 06/17/77 3-318" 6 10441 - 10501 O 09/06/14 3-318" 4 10470 - 10486 O 02/27/87 3-318" 4 10486 - i i i. O 06/17/77 3-3/8" 6 10501 - 10531 O 09/05/14 3-3/8" 4 10510 - 10535 O 02/27/87 3-318" 4 10535 - 10558 O 06/17/77 3-318" 6 10545 - 10575 O 09/05/14 3-318" 4 10574 - 10599 O 06/17/77 3-318" 4 10599 - 10630 O 02/27/87 3-318" 4 10639 - 10644 O 02/27/87 3-318" 4 10662 - 10673 O 06/17/77 3-3/8" 4 10673 - 10686 O 02/27/87 3-318' 4 10686 - 10697 O 06/17/77 3-3/8' 4 10697 - 10725 O 02/27/87 3-3/8" 4 10725 - 10750 O 06/17/77 3-3/8" 4 10750 - 10762 O 02/27/87 3-318' 4 10819- 10844 O 06/17/77 7" LNR, 29#, MN•80 BTRS, .0371 bpf, D = 6.184" 10982' NG I _0 4 SAFETY NOTES: WELL REQUIRES A SSSV '"• 25' 7" X 7-5l8" XO, D = 6.151' 220--17-5/8" X 7" XO, D = 6.151" 2209' 7" CAMCO BAL-O SSSV N, D = 5.937" 03111/01 N9ES RWO 2367' 9-518' HES FO CBVIENTER 2573' 9-518" HES FO CBVIENTER 9558' {7-5/8' X 7" XO, D = 6.151' 9579' 9-5/8" X 7" BKR SA BL -3 PKR, ID = 600- 9603- 1—� 7" HES RN NP, D = 5.50" 9623' I-19-5/8" X 7" BOT MC HGR W/ TEBK SLV, ID = ? 9626' 7" MULESHOE, D= 6.151" ELMD TT NOT LOGGED 11010' —1 FISH - PERF GUN LOST 06/18/77 11015' DATE REV BY CDANVIENTS DATE REV BY COKVAENTS 02/27/76 CHAL 51 ORIGINAL COMPLETION 09/09/14 TO/ PJC ADFERFS (09/05-09/06/14) 03111/01 N9ES RWO 01/07/02 CH/TLP CORRECTIONS 07/05107 DSWPJC TREE C/O 02J1 1/111 IVB/JKU I ADDED SSSV SAFETY NOTE 07/29/14 PJC PERFORATION RESEARCH PRUDHOE BAY U14T WELL NGI-04 PERIAT No: 1750690 API No: 50-020-20183-00 SEC 12, T11N, R14E 567' SNL 8 1064' EWL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SEF 2b �u14 1. Operations Abandon Li Repair Well Li Plug Perforations Lj Perforate J Other Li CC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well[] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Developmert❑ Stratigraphic❑ Exploratory ❑ Service [Z 175-069-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20183-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028302 PBU NGI-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11015 feet Plugs measured None feet true vertical 8556.13 feet Junk measured 11010 feet Effective Depth measured 10898 feet Packer measured 9579 feet true vertical 8474.51 feet true vertical 7542.75 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 28-108 35-110 1530 520 Surface 2680 13-3/8" 72# MN -80 31 -2711 33-8485.37 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1322 7" 29# MN -80 9586-10908 8352.11 - 8352.94 8160 7020 Perforation depth Measured depth See Attachment feet NOY 13 201 True Vertical depth See Attachment achment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 7" Baker SABL-3 Packer 9579 7542.75 Packer 7" Camco Bal -O SSSV 2209 2208.93 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 401 24765 1727 0 232 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil Gas WDSPLJ Daily Report of Well Operations X GSTOR ❑ WINJ ❑ WAG ❑ GINJ Q SUSP ❑ SPLUCF 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: N/A Contact Nita Summerhays Email Nita.Summerhays2bp.com Printed Name Nita Summerhays Title Petrotechnical Data Engineer igna Phone 564-4035 Date 9/25/2014 V1_ io/z3il¢ Form 10-404 Revised 10/2012 Submit Original Only FLUIDS PUMPED BELS 2 DIESEL 10 METH 1186 1% KCL 307 60/40 METH 1505 TOTAL Casing / Tubing Attachment ADLOO283O2 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 28 - 108 35 - 110 1530 520 INTERMEDIAT 2328 9-5/8" 47# R -S-95 27 - 2355 8063.48 - 8508.86 8150 5080 INTERMEDIAT 43 9-5/8" 47# SOO-95 2355 - 2398 8365.35 - 9114.64 8150 5080 INTERMEDIAT 165 9-5/8" 47# R -S-95 2398 - 2563 2087.91 - 2088.91 8150 5080 INTERMEDIAT 44 9-5/8" 47# SOO-95 2563 - 2607 8199.15 - 8199.99 8150 5080 INTERMEDIAT 317 9-5/8" 47# R -S-95 2607 - 2924 8236.98 - 8237.82 8150 5080 INTERMEDIAT 7026 9-5/8" 47# MN -80 2924 - 9950 8323.89 - 8324.72 6870 4760 LINER 1322 7" 29# MN -80 9586 - 10908 8352.11 - 8352.94 8160 7020 NIPPLE 2 7" RN Nipple 9603 - 9605 8370.3 - 8371.13 SURFACE 2680 13-3/8" 72# MN -80 31 - 2711 33 - 8485.37 5380 2670 TUBING 9535 7-5/8" 29.7# L-80 23 - 9558 34 - 2692.9 6890 4790 1 TUBING 71 7" 26# L-80 9558 - 9629 35 - 8379.381 7240 5410 f sr. full • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 02, 2013 TO: Jim Regg ' 7 e ; � J 1Z`I SUBJECT: Mechanical Integrity Tests P.I. Supervisor BP EXPLORATION (ALASKA) .J INC Y yy '' tt (' NGI -04 FROM: Jeff Jones tomo U I 0 8 2 O 13 PRUDHOE BAY UNIT NGI -04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry (J ' NON- CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI -04 API Well Number 50- 029 - 20183 -00 -00 Inspector Name: Jeff Jones Permit Number: 175 -069 -0 Inspection Date: 4/28/2013 Insp Num: mitJJ130430150159 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Iq . 7543 • 1 T e In T VD 1 3970 3930 - NGI -04 i — � -- —— IA I 250 i 4100 • , - — - - - -- - - - - � — - i - -- — — T e Test T es t s i: PTD YP J o o o o o 4020 I a Interval - -- - 3720 1450 — YP P g - 00 , � 175069 SOT ; I -- REQVAR P/F T u b in 1500 - 1500 1500 1500 - Notes: AA -4E -024: slow T X IA communication, 2 year MIT. 5.7 BBLS methanol pumped. 1 well inspected, no exceptions noted. J I Thursday, May 02, 2013 Page 1 of 1 STATE OF ALASKA ' ALOA OIL AND GAS CONSERVATION COMMI�N . REPORT OF SUNDRY WELL OPERATPONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other L J Water Wash Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. ShutdowrD Stimulate - Other ❑ Re -enter Suspended WeII 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ ••• 175 -069 -0 3. Address: P.O. Box 196612 StratigraphiJ Service 0 6. API Number. s Anchorage, AK 99519 -6612 50- 029 - 20183 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: v ADL0028302 PBU NGI -04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11015 feet Plugs measured None feet true vertical 8556.13 feet Junk measured 11010 feet Effective Depth measured 10898 feet Packer measured 9587 feet true vertical 8474.51 feet true vertical 7548.45 feet ' Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 84 20" 94# H-40 29 - 113 29 - 113 1530 520 Surface 2683 13 -3/8" 72# MN -80 28 - 2711 28 - 2710.93 5380 2670 Intermediate None None None None None None Production 9914 9 -5/8" 47# MN -80 27 - 9941 27 - 7807.04 6870 4760 Liner 1358 7" 29# MN -80 9624 - 10982 7574.89 - 8533.03 8160 7020 Perforation depth Measured depth See Attachment feet s p p �i 1 � �i JAN 2 �+�� RECEIVED True Vertical depth See Attachment feet W",w IJ OCT 1 2 2012 Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment AOG CC Packers and SSSV (type, measured and true vertical depth) 7" Baker SABL -3 Packer 9587 7548.45 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 190829 0 0 3261 Subsequent to operation: 0 155921 0 0 3235 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratoq❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas 0 WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ 151 — SUSP ❑ SPLUCO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -297 Contact Nita Summerhays Email Nita.Summerhaysc. bp.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Signatur. - _ Phone 564 -4035 Date 10/12/2012 RRDMS OCT 15 20 /U/3 W.' e g Form 10-404 Revised 10/2012 g445-/" Submit Original Only • • Daily Report of Well Operations ADL0028302 ACTIVITYDATE SUMMARY • = I • • .j. oven rea men pear in • g wi I • • s o 60/40 from CH2 tanker #39013 followed by 100 bbls of (50/50) diesel/xylene mix. Followed that with 185 bbls of fresh water with F103 (0.02 %) Continue 9/23/2012 job on next day Continued from previous day T /I /O = 1100/342/11 (Obj. Solvent Treatment) Pumped (185 prior to midnight) 633 bbls (818 bbls total) of fresh water with F103 (0.02 %) down Tbg followed by 20 bbls of 60/40 for FP, Turn well back to DSO to POI DSO notified at time of LRS departure. SV, WV, SSV, CV = closed MV, IA, OA = open FWHP = 9/24/2012 vac /300/12 FLUIDS PUMPED BBLS 30 60/40 METH 50 DIESEL 50 XYLENE 818 FRESH WATER W/ F103 (0.2 %) 948 TOTAL Perforation Attachment ADL0028302 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top ND Depth Base NGI -04 6/29/1990 APF 10216 10268 8010.22 8047.08 NGI -04 6/17/1977 PER 10329 10354 8089.39 8106.48 NGI -04 2/28/1987 APF 10354 10373 8106.48 8119.38 NGI -04 6/17/1977 PER 10373 10398 8119.38 8136.23 NGI -04 2/27/1987 APF 10398 10406 8136.23 8141.59 NGI -04 6/17/1977 PER 10410 10425 8144.27 8154.3 NGI -04 6/17/1977 PER 10441 10470 8164.98 8184.26 • NGI -04 2/27/1987 APF 10470 10486 8184.26 8194.87 NGI -04 6/17/1977 PER 10486 10510 8194.87 8210.74 NGI -04 2/27/1987 APF 10510 10535 8210.74 8227.31 NGI -04 6/17/1977 PER 10535 10558 8227.31 8242.6 NGI -04 6/17/1977 PER 10574 10599 8253.26 8269.98 NGI -04 2/27/1987 APF 10599 10630 8269.98 8290.8 NGI -04 2/27/1987 APF 10639 10644 8296.86 8300.24 NGI -04 6/17/1977 PER 10662 10673 8312.4 8319.86 NGI -04 2/27/1987 APF 10673 10686 8319.86 8328.69 NGI -04 6/17/1977 PER 10686 10697 8328.69 8336.18 NGI -04 2/27/1987 APF 10697 10725 8336.18 8355.28 NGI -04 6/17/1977 PER 10725 10750 8355.28 8372.39 NGI -04 2/27/1987 APF 10750 10762 8372.39 8380.62 NGI -04 6/17/1977 PER 10819 10844 8419.84 8437.1 • J I Casing / Tubing Attachment ADL0028302 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 20" 94# H-40 29 - 113 29 - 113 1530 520 LINER 1358 7" 29# MN -80 9624 - 10982 7574.89 - 8533.03 8160 7020 PRODUCTION 9914 9 -5/8" 47# MN -80 27 - 9941 27 - 7807.04 6870 4760 SURFACE 2683 13 -3/8" 72# MN -80 28 - 2711 28 - 2710.93 5380 2670 TUBING 9535 7 -5/8" 29.7# L -80 26 - 9561 26 - 7529.95 6890 4790 TUBING 68 7" 26# L -80 9561 - 9629 7529.95 - 7578.47 7240 5410 • • 1 1 TREE = 6 -3/8" CM/ WELLHEAD = GRAY Si. NOTES: WELL REQUIRES A SSSV. ACTUATOR= BAKER N G I -04 KB. ELEV = 47.0' BF. ELEV = NA KOP = 3200' I 25' H7" X 7 -5/8" XO, ID = 6.151" I Max Angle = 54 @ 6700' Datum MD = Datum TVD = 8800' SS I 2207' 1-17-5/8" X 7" XO, ID = 6.151" I I 2209' H 7" CAMCO BAL -O SSSVN, ID = 5.937" I 1 2213' I-17" X 7 -5/8" XO, ID = 6.151" I 113-3/8" CSG, 72 #, MN -80, ID = 12.347" H 2711' (-A 7 -5/8" TBG -IPC, 29.04 #, L -80, -1 9558' I I 9559' I-I . 7 -5/8" X 7" XO, ID = 6.151" I .0459 bpf, ID = 6.690" - I 9579' H 9 -5/8" X 7" BKR SABL -3 PKR, ID = 6.00" I Minimum ID = 5.50" @ 9603' 7" HES RN NIPPLE 1 I 9603' H7" HES RN NP, ID= 5.50" I 7" TBG, 26 #, L -80, .0383 bpf, ID = 6.276" H 9619' I 9623' 1-19-5/8" X 7" BOT MC HGR W/ TIEBACK SLV I 7 I 9626' 1-1r MULESHOE, ID = 6.151" I 19-5/8" CSG, 47 #, MN-80, ID = 8.681" H 9941' I • PERFORATION SUMMARY REF LOG: BHCS ON 06/17/77 ANGLE AT TOP PERF: 44 @ 10216' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 10216 - 10268 0 06/29/90 3 -3/8" 4 10329 - 10354 0 06/17/77 3 -3/8" 4 10354 - 10373 0 02/28/87 3 -3/8" 4 10373 - 10398 0 06/17/77 3 -3/8" 4 10398 - 10406 0 02/27/87 3 -3/8" 4 10470 - 10486 0 02/27/87 3 -3/8" 4 10510 - 10535 0 02/27/87 3 -3/8" 4 10599 - 10630 0 02/27/87 3 -3/8" 4 10639 - 10644 0 02/27/87 3 -3/8" 4 10673 - 10686 0 02/27/87 3 -3/8" 4 10697 - 10725 0 02/27/87 3 -3/8" 4 10750 - 10762 0 02/27/87 7" LNR, 29 #, MN-80, .0371 bpf, ID = 6.184" H 10982' I-4 11010' H FISH - PERF GUN LOST 06/18/77 I TD H 11015' I :V DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 02/27/76 ORIGINAL COMPLETION 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE WELL: NGI-04 12/04/00 SS -Isl CONVERTED TO CANVAS PERMIT No: '1750690 03/07/01 TWA FINAL COMPLETION API No: 50- 029- 20183 -00 03/11/01 RWO SEC 12, T11N, R14E 567' SNL & 1064' EWL 01/07/02 CH/TLP CORRECTIONS 07/05/07 DSM/PJC TREE C/O BP Exploration (Alaska) • • u nELASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Javier Farinez Petroleum Engineer - O V J BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI -04 Sundry Number: 312 -297 Dear Mr. Farinez: ,t„ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cat y P Foerster Chair DATED this day of August, 2012. Encl. '; RECEIVED 111 .: CE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG � Ste--/ Q APPLICATION FOR SUNDRY APPROVALS AOGCG 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ V y . Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Oth2�F: Water Wash IS 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development El Exploratory El 175 -069-0 • 3. Address: Stratigraphic ❑ Service 0 • 6. API Number: P.O. Box 196612, Anchorage, AK 99519 -6612 50 -029- 20183 -00 -00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El PBU NGI -04 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0028302 • PRUDHOE BAY, PRUDHOE OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11015 8556 • 10898 8475 None 11010 Casing Length Size MD TVD Burst Collapse Structural Conductor 84 20" 94# H-40 29 - 113 29 - 113 Surface 2683 13 -3/8" 72# MN -80 28 - 2711 28 - 2710.93 5380 2670 Intermediate None None None None None None Production 9914 9 -5/8" 47# MN -80 27 - 9941 27 - 7807.04 6870 4760 Liner 1358 7" 29# MN -80 9624 - 10982 7574.89 - 8533.03 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 7" Baker SABL -3 Packer Packers and SSSV MD (ft) and TVD (ft): 9587, 7548.45 No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal © 13. Well Class after proposed work: Detailed Operations Program 7 BOP Sketch fl Exploratory n Development n Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ p - WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Javier Farinez Prepared by Garry Catron 564 -4424 Printed Name -- F F. rinez Title Production Engineer Signature /� Phone Date 564 -5043 1 3 f i tt,t1, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 312..-2cr Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance El Other: Subsequent Form Required: ) -LID Li P APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: g - Z p . ; 1 i Form 10-403 evised 1/2010 o G�� ORIblINI.44:1 , MS AUG 0 3 7O1 i D plicate i ;•v • • Perforation Attachment ADL0028302 Well Date Perf Code MD Top _ MD Base TVD Top TVD Base NGI -04 6/29/90 APF 10216 10268 8010 8047 NGI -04 6/17/77 PER 10329 10354 8089 8106 NGI -04 2/28/87 APF 10354 10373 8106 8119 NGI -04 6/17/77 PER 10373 10398 8119 8136 NGI -04 2/27/87 APF 10398 10406 8136 8142 NGI -04 6/17/77 PER 10410 10425 8144 8154 NGI -04 6/17/77 PER 10441 10470 8165 8184 1 NGI -04 2/27/87 APF 10470 10486 8184 8195 NGI -04 6/17/77 PER 10486 10510 8195 8211 NGI -04 2/27/87 APF 10510 10535 8211 8227 NGI -04 6/17/77 PER 10535 10558 8227 8243 NGI -04 6/17/77 PER 10574 10599 8253 8270 NGI -04 2/27/87 APF 10599 10630 8270 8291 NGI -04 2/27/87 APF 10639 10644 8297 8300 NGI -04 6/17/77 PER 10662 10673 8312 8320 NGI -04 2/27/87 APF 10673 10686 8320 8329 NGI -04 6/17/77 PER 10686 10697 8329 8336 NGI -04 2/27/87 APF _ 10697 10725 8336 8355 NGI -04 6/17/77 PER 10725 10750 8355 8372 NGI -04 2/27/87 APF 10750 10762 8372 8381 NGI -04 6/17/77 PER 10819 10844 8420 8437 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing Summary ADL0028302 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 84 20" 94# H -40 29 113 29 113 1530 520 H -40 LINER 1358 7" 29# MN -80 9624 10982 7575 8533 8160 7020 MN -80 PRODUCTION 9914 9 -5/8" 47# MN -80 27 9941 27 7807 6870 4760 MN -80 SURFACE 2683 13 -3/8" 72# MN -80 28 2711 28 2711 5380 2670 MN -80 TUBING 68 7" 26# L -80 9561 9629 7530 7578 7240 5410 L -80 TUBING 9535 7 -5/8" 29.7# L -80 26 9561 26 7530 6890 4790 L -80 4111 III Fullbore Pumping Design Template Well Name NGI -04 Job Scope _ Solvent Treatment No Records H2S (ppm/date) WBL Cat IOR 500 Max Pumping Pressure (psi) Well Type _ GI AFE APBINJEC Main Fluid Type Date _ 7/30/2012 IOR 30 800 Main Fluid Volume (bbls) Engineer Javier Farinez Phone x5043 i Methanol (60/40) Freeze Protect Type 10 Freeze Protect Volume (bbls) Job Objective If Applicable Recent Tbg Fluid Level (ft) improve injectivity by dissolving salts and possibly asphaltenes in the If Applicable Recent IA Fluid Level (ft) tubing and formation. Diesel / Xylene washes have been used If Applicable Recent OA Fluid Level (ft) successfully in the past on the NGI /WGI /AGI gas injectors to improve If Applicable Expected Tbg Fill Up Volume (bbls) injectivity. If Applicable Expected IA Fill Up Volume (bbls) If Applicable Expected OA Fill Up Volume (bbls) 484 Welibore Volume to Peas (bbls) Fullbore Pumping Schedule 3300 Anticipated Bottom Hole Pressure (psi) Pump Volume Rate Max Select Tubing/Casing within Pressure Limits? Stage Fluid Type Into (bbls) (bpm) Pressure Size Burst/Collapse 80% Burst/Collapse Tubing Burst (psi) 7 8160 6528 I Pre-Rush I L Methanol (60/40) 11 Tbg I 101 [ 25001 Tubing Collapse (psi) 7 7030 5624 Casing Burst (psi) size See helpful tips tab , Solvent 1 I Select Fluid Type 11 Tbg ( 1001 I ( 25001 Casing Collapse (psi) size See helpful tips tab Load 11 Select Fluid Type I( Tbg 1 1 800 I I 5001 Select Input Depth Integrity Issues? TxIA unknown I Freeze Protect 1 ( Methanol (60/40) 11 Tbg 1 101 I I I 5001 No Input Depth ' Select Stage 1 ( Select Fluid Type I I Select I ( 1 1 I I f 1 Yes - Tbg cond good 1 Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition I Select 1 Production Packer within Pressure Limits? Detailed Pumping Procedure Rated Packer dp Max Anticipated dp at Packer 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene Not Necessary 1 Hold Pressure on Other Strings? 3 800 bbls of fresh water with 0.02% F -103 surfactant F (psi) 4 10 bbls 60/40 meoh ,A Insit 5 RDMO. Return well to gas injection 6 • • Fulibore Pumping Program for Field Well Name NGI -04 Job Scope Solvent Treatment Well TyPe GI AFE APBINJEC Date 7/30/2012 IOR 30 Engineer Javier Farinez Phone x5043 H2S Job Objective Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel / Xylene washes have been used successfully in the past on the NGI/WGI /AGI gas injectors to improve injectivity. Fulibore Pumping Schedule Stage Fluid Type Pump Into volume (bbls) Rate (bpm) Max Pressure 1 Pre -Flush 1 Methanol (60/40) Tbg 10 1 2500 2 Solvent Select Fluid Type I Tbg 100 1 2500 3 Load I Select Fluid Type Tbg 800 500 4 Freeze Protect' Methanol (60/40) 1 Tbg 10 500 5 Select Stage Select Fluid Type Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene 3 800 bbls of fresh water with 0.02% F -103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details If Applicable Recent Tbg Fluid Level (ft) Integrity Issues? TxIA unknown If Applicable Recent IA Fluid Level (ft) No Input Depth If Applicable Recent OA Fluid Level (ft) • Freeze Protection - see PE manual for additional information Freeze Protect to 2500' TVD in GPB. Use 60/40 Meth Water for Injectors Use 5 bbl 60/40 Meth Water spear followed by dead crude for Producers Pipe Data (L -80) dimensions mechanical inner capacity outer capacity size lb /ft od id drift id collapse burst bbls /ft ft/bbls bbls /ft ftibbis 2.375 4.60 2.38 2.00 1.90 11780.00 11200.00 0.00387 258.6 0.00548 182.5 2.875 1 6.50 2.88 2.44 2.35 11160 00 10570.00 0.00579 172.8 0.00803 124.5 3.188 6.40 3.19 2.81 2.68 1111100 11111.00 0.00769 130.1 0.00987 101.3 3.500 9 30 3.50 2 99 2 87 10530.00 10160.00 0.00870 115.0 0.01190 84.0 4.500 12.60 4.50 3 96 3 83 7500.00 8430.00 0.01522 65.7 0.01967 50.8 5 000 18.00 5 00 4.28 4.15 10490.00 9910.00 0.01776 56 3 0.02429 41.2 5.500 17 00 5.50 4.89 4.77 _ 6280.00 7740.00 0.02325 43.0 0.02939 34.0 7 000 26.00 7 00 6.28 6 15 5410.00 I 7240.00 0.03826 26.1 0.04760 21.0 7.000 29.00 7.00 618 6.06 7020.00 8160.00 0.03715 26.9 0.04760 21.0 7 625 29 70 7.63 6.88 6 75 4790.00 6890.00 0.04592 21.8 0.05648 17.7 9.625 47.00 9.63 8 68 8.53 4760.00 6870.00 0.07321 13.7 0.08999 11.1 13.375 72.00 13.38 12.35 12.19 i 2670,00 5380 00 0 14809 6.8 0.17378 5.8 custom 6.000 4.000 0.01561 641 0.03497 28.6 Bursts OD GRADE WT Burst 3 1/2" 80 9.3# 10160 41/2" 80 12.6# 7500 5 1/2" 80 15.5# 7000 80 17# 7740 7" 80 26# 7240 80 29# 8160 95 29# 9690 110 29# 11220 7 5/8" 80 29.7# 6890 80 33.7# 7900 95 29.7# 8180 9 5/8" 55 36# 3520 55 40# 3950 80 40# 5750 80 43.5# 6330 80 47# 6870 80 53.5# 7930 95 47# 8150 10 3/4" 55 45.5# 3580 80 45.5# 5190 80 55.5# 6450 11 3/4" 95 60# 6920 13 3/8" 55 54.5# 2730 55 61# 3090 55 68# 3450 80 68# 5020 80 72# 5380 95 72# 6390 16" 80 84# 4330 18 5/8" 55 96.5# 2510 55 109.3# 2910 20" 40 94# 1530 55 133# 3060 Brine Design Notes Revised: 5/1/00 NaCI KCI CaCI NaBr Design Notes: 8.5 29 8.4 31 8.5 30 8.5 30 8.6 27 8.5 30 9.0 22 9.0 25 Design for -50 degrees from surface to 100', 10 degrees through permafrost (approx. 2500'). 8.7 26 8.7 27 9.5 10 9.5 20 Be careful using McOH /H2H for freeze cap - McOH may mix with brine and dilute 8.8 24 8.9 23 10.0 -9 10.0 14 Don't use Ca based fluids that may come in contact with the formation, 8.9 22 9.1 19 10.5 -36 10.5 6 Be careful using CaCI in IA - may dump on formation 9.0 19 9.3 15 10.7 -51 11.0 -2 Corrosion Inhibitor: mix 25 gal of NEEC EC1124 per 100 bbls brine 9.1 17 9.5 15 10.8 -57 11.5 -11 Note: Inhibitor has a 1 day half -life 9.2 14 9.6 33 10.9 -35 11.7 -16 Be careful allowing very cold diesel to contact KCI - could form a slush 9.3 11 11.0 -19 11.8 -19 IIIII 9.4 9 11.5 36 11.9 -10 9.5 6 12.0 6 9.6 3 12.5 50 9.7 -1 12.7 63 9.8 -5 9.9 5 10.0 25 Crystallization Temperatures for Clear Brines 40 KCI A CaCI * NaCI 20 •'. ~ . :72 • o / o NaBr 1 ° 4•3' o / Y - N. N. i O 20 a / .. ♦ - NaCI -40 \ -N ! --M- CaCI \ • KCI so - - o NaBr - 8.5 9.5 ~ -_ Density, PPG 10 5 115 12.5 TREE = 6 -3/8" CM/ W • ELLHEAD = GRAY SAFETY NOTES: WELL REQUIRES A SSSV. ACTUATOR= BAKER NGI -04 KB. ELEV = 47.0' BF. ELEV = NA KOP = 3200' ) ( 25' I-I 7" X 7 -5/8" XO, ID = 6.151" I Max Angle = 54 @ 6700' Datum MD = Datum ND = 8800' SS 2207' H7-5/8" X 7" XO, ID = 6.151" I 2209' H7" CAMCO BAL -O SSSV N, ID = 5.937" I 2213' I -17" X 7 -5/8" XO, ID= 6.151" I 13 -3/8" CSG, 72 #, MN -80, ID = 12.347" H 2711' I- 7 -5/8" TBG -IPC, 29.04 #, L -80, -I 9558' I . . 9559' H7-5/8" X 7" XO, ID = 6.151" I .0459 bpf, ID = 6.690" E g 9579' H 9 -5/8" X 7" BKR SABL -3 PKR, ID = 6.00" I Minimum ID = 5.50" @ 9603' 7" HES RN NIPPLE 1 1 9603' I -17 " HES RN NIP, ID =5.50" I 7" TBG, 26 #, L -80, .0383 bpf, ID = 6.276" H 9619' I 9623' H 9 -5/8" X 7" BOT MC HGR W/ TIEBACK SLV I 7 9626' H7" MULESHOE, ID = 6.151" I 19 -5/8" CSG, 47 #, MN-80, ID = 8.681" I-I 9941' I 4 ■ PERFORATION SUMMARY REF LOG: BHCS ON 06/17/77 I ANGLE ATTOPPERF: 44 @ 10216' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE I 3 -3/8" 4 10216 - 10268 0 06/29/90 3 -3/8" 4 10329 - 10354 0 06/17/77 I 3 -3/8" 4 10354 - 10373 0 02/28/87 3 -3/8" 4 10373 - 10398 0 06/17/77 3 -3/8" 4 10398 - 10406 0 02/27/87 I 3 -3/8" 4 10470 - 10486 0 02/27/87 3 -3/8" 4 10510 - 10535 0 02/27/87 3 -3/8" 4 10599 - 10630 0 02/27/87 I 3 -3/8" 4 10639 - 10644 0 02/27/87 3 -3/8" 4 10673 - 10686 0 02/27/87 I 3 -3/8" 4 10697 - 10725 0 02/27/87 3 -3 /8" 4 10750 - 10762 0 02/27/87 17" LNR, 29 #, MN-80, .0371 bpf, ID = 6.184" I 10982' 1 ilk 11010' II FISH - PERF GUN LOST 06/18/77 I I TD H 11015' I i� i� : � : � i �i •∎� •1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/27/76 ORIGINAL COMPLETION 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE WELL: NGI-04 12/04/00 SS -Isl CONVERTED TO CANVAS PERMIT No: ° 1750690 03/07/01 TWA FINAL COMPLETION API No: 50- 029 - 20183 -00 03/11/01 RWO SEC 12, T11N, R14E 567' SNL & 1064' EWL 01/07/02 CH /TLP CORRECTIONS 07/05/07 DSM/PJC TREE C/O BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission _ DATE: Monday, May 09, 2011 TO: Jim Regg J P.I. Supervisor /lt ' 1 2 ` // SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI -04 FROM: Jeff Jones PRUDHOE BAY UNIT NGI -04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv\J -- NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI - 04 API Well Number: 50 029 - 20183 - 00 - 00 Inspector Name: Jeff Jones Insp Num: mitJJ110427122124 Permit Number: 175 - 069 - Inspection Date: 4/25/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NG] -04 'T Inj. 1 G 1 TVD 7543 • 1 IA r 1980 4540 • 4460 4420 - P. T.D 1750690 � f PT Test psis Ism ' OA 10 10 10 10 Interval RE QVAR P/F ? r Tubing 1 2260 2680 2680 2700 - Notes: 2.9 BBLS methanol pumped. 1 well inspected; no exceptions noted. AA for T X IA communication. A-.C; 4E.6Z4 ). 5) MA 5 2011 Monday, May 09, 2011 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, April 28, 2011 TO: Jim Regg P.I. Supervisor J r R" et 516(6 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI -04 FROM: Jeff Jones PRUDHOE BAY UNIT NG1 -04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI -04 API Well Number: 50- 029 - 20183 -00 -00 Inspector Name: Jeff Jones Insp Num: mitJJ110427122124 Permit Number: 175 -069 -0 Inspection Date: 4/25/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well [ NGI -04 ' Type Inj. W ' TVD 7543 - I IA 1980 1 4540 / 4460 4420 — P.T.DL'750690- ' TypeTest 5PT Test psi 1885 • OA 10 10 10 10 Interval REQVAR P/F P - Tubing 2260 2680 2680 2700 Notes: 2.9 BBLS methanol pumped. I well inspected; no exceptions noted. AA for T X IA communication. Aso 4&O z4 1(' x' Thursday, April 28, 2011 Page 1 of I Gas Injector Volume Calculation~Flow meters replaced • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~6~ ~ Sent: Wednesday, May 27, 2009 9:46 AM ~~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Engel, Harry R; Rossberg, R Steven; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; NSU, ADW Well Integrity Engineer; GPB, FS1 Fac Engr Subject: Gas Injector Volume Calculations -- Flow meters replaced Attachments: Gas Injector volume calculations.xis Jim, ~ / The flow meter on NGI-13 was blocked in on 03/29/09 and eturned to surface on 05/11/09; as this transmitter developed a small gas leak and was removed from service at that time. It wasn't until later that the lower design pressure was noticed on this and other transmitters, at which time the remainders were blocked in. The flow meters on NGI-01 03. 04, 05. 08 12 were blocked in on 04/23/09 a~nlac d back in service on 05/12/09. The pressure-rate data for operation before and after this time was extrapolated raphicall to determine the rates for the time the transmitters were blocked in. Ailowing them to operate or a short time after they were put back in service has been helpful in assuring the most accurate representation of the time they were out of service. I have attached a spreadsheet containing daily rates and pressures, as well as the graphicai analysis completed to obtain the data for the time the transmitters were out of service. «Gas injector volume calculations.xls» „/ Please call with any questions or concerns. Thank you, Andrea Hughes WeN Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 L~~u- ._--- ~~~ n3G~- ~ I ~"'' ~~~~~.' ~`!~ .! x. ~: ~~~~ (~l'~.~t ~1C~- 03 ~~ ~~. _~~, P~~,~T -~ 4 ~'~u- ~'G~'- oS ~~~ ~.~-v~ ~~u :~C~-~Z ~~ ~~ ~z- I 3 ~ i r ~-~ I 7~-D~ I~5-6L1 e~s-o~~ 1~1(~--C?(~ i~~ ~L S-z r7?-C~'~,I Z-~~- ~r~ 8/6/2009 i SUMMARY OF INJECTED VOLUMES DURING FLOW TRANSMITTER OUTAGE Volume Tubing Injected Pressure Date (MCFPD) (psi) NGI-01 05/12/09 119,210 3,165 05/11/09 117,670 3,148 05/10/09 136,884 3,360 05/09/09 144,134 3,440 05/08/09 143,228 , 3,430 05/07/09 145,131 3,451 05/06/09 143,681 3,435 05/05/09 140,146 3,396 05/04/09 140,509 3,400 05/03/09 142,865 3,426 05/OZ/09 141,868 3,495 05/01 /09 140, 871 3, 404 04/30/09 135,796 3,348 04/29/09 135,977 3,350 04/28/09 134,708 3,336 04/27/09 133,530 3,323 04/26/09 140,056 3,395 04/25/09 142,503 3,422 04/24/09 140,328 3,398 04/23/09 138,515 3,378 NGI-03 05/12/09 110,330 3,450 05/11/09 110,692 3,455 05/10/09 110,836 3,457 05/09/09 111,053 3,460 05/08/09 113,151 3,489 05/07/09 113,657 3,496 05/06/09 113,006 3,487 05/05/09 112,211 3,476 05/04/09 113,947 3,500 05/03/Q9 113,368 3,492 05/02/09 114,814 3,512 05/01 /09 114, 091 3, 502 04/30/09 113,874 3,499 04/29/09 112,934 3,486 04/28/09 112,138 3,475 04/27/09 111,487 3,466 04/26/09 113,802 3,498 04/25/09 113,947 3,500 04/24/09 114, 091 3, 502 04/23/09 114,742 3,511 ~ NGI Volume Calculations 1 ~ • NGI-04 05/12/09 112,110 3,070 05/11 /09 112,143 3, 050 05/10/09 111,633 3,356 05/09/09 111,437 3,474 05/08/09 114, 568 1, 595 05/07/09 113,765 2,077 05/06/09 111,428 3,479 05/05/09 111,498 3,437 05/04/09 111,488 3,443 05/03/09 111,445 3,469 05/02/09 111,460 3,460 05/01/09 111,488 3,443 04/30/09 111,587 3,384 04/29/09 111,575 3,391 04/28/09 111,603 3, 374 04/27/09 111,630 3, 358 04/26/09 111,493 3,440 04/25/09 111,450 3,466 04/24/09 111,490 3,442 04/23/09 111,410 3,490 NGI-OS 05/12/09 179,667 3,375 05/11/09 179,789 3,380 05/10/09 179,910 3,385 05/09/09 180,007 3,389 05/08/09 179,813 3,381 05/07/09 180,299 3,401 05/06/09 179,935 3,386 05/05/09 179,010 3,348 05/04/09 179,108 3, 352 05/03/09 179,667 3,375 05/02/09 179,472 3,367 05/01/09 179,156 3,354 04/30/09 177, 892 3, 302 04/29/09 178,062 3,309 04/28/09 177,721 3,295 04/27/09 177,405 3,282 04/26/09 179,108 3,352 04/25/09 179,667 3,375 04/24/09 179,156 3,354 04/23/09 180,178 3, 396 NGI-08 05/12/09 150,117 3,470 05/11/09 150,117 3,470 05/10/09 150,117 3,470 05/09/09 149, 821 3,467 05/08/09 148,833 3,457 05/07/09 151,599 3,485 05/06/09 150,117 3,470 05/05/09 145,869 3,427 05/04/09 146,067 3,429 05/03/09 148,438 3,453 NGI Volume Calculations 2 ~ 05/02/09 147, 351 3, 442 05/01 /09 145, 573 3,424 04/30/09 139,744 3,365 04/29/09 140,535 3,373 04/28/09 138,954 3,357 04/27/09 137,275 3,340 04/26/09 145,672 3,425 04/25/09 148,142 3,450 04/24/09 145,968 3,428 04/23/09 151,006 3,479 NGI-12 05/12/09 179,508 3,400 05/11/09 179,508 3,400 05/10/09 179,508 3,400 05/09/09 181,429 3,419 05/08/09 180,216 3,407 05/07/09 179,508 3,400 05/06/09 179,508 3,400 05/05/09 177,485 3,380 05/04/09 177,587 3,381 05/03/09 180,014 3,405 05/02/09 179,002 3,395 05/01/09 177,283 3,378 04/30/09 171,721 3,323 04/29/09 172,429 3,330 04/28/09 170,912 3,315 04/27/09 169,294 3,299 04/26/09 177,485 3,380 04/25/09 180,014 3,405 04/24/09 178,193 3,387 04/23/09 182,946 3,434 I-13 05/10/09 246,658 3,350 05/09/09 246,368 3,341 05/08/09 246,078 3,332 05/07/09 246,754 3,353 05/06/09 246,497 3,345 05/05/09 243,279 3,245 05/04/09 245,306 3,308 05/03/09 245,692 3,320 05/02/09 245,660 3,319 05/01/09 243,247 3,244 04/30/09 240,801 3,168 04/29/09 243,955 3,266 04/28/09 243,375 3,248 04/27/09 243,086 3,239 04/26/09 245,370 3,310 04/25/09 246,078 3,332 04/24/09 245,564 3,316 04/23/09 246,979 3,360 • NGI Volume Calculations 3 ~ ~ 04/22/09 247,494 3,376 04/21 /09 246, 979 3, 360 04/20/09 247,366 3,372 04/19/09 247,333 3,371 04/18/09 247,301 3,370 04/17/09 247,301 3,370 04/16/09 246,658 3,350 04/15/09 246,722 3,352 04/14/09 245,821 3,324 04/13/09 244,244 3,275 04/12/09 243,536 3,253 04/11 /09 239,160 3,117 04/10/09 243,729 3,259 04/09/09 244,051 3,269 04/08/09 244,823 3,293 04/07/09 246, 304 3, 339 04/06/09 247,816 3,386 04/05/09 247,591 3,379 04/04/09 247,816 3,386 04/03/09 248,234 3,399 04/02/09 248,363 3,403 04/01/09 245,692 3,320 03/31/09 243,987 3,267 03/30/09 246,175 3,335 03/29/09 247,237 3,368 03/28/09 249,103 3,426 03/27/09 248,588 3,410 03/26/09 245,757 3,322 03/25/09 245,049 3,300 03/24/09 245,049 3,300 NGI Volume Calculations 4 NGI-01 155,000 150,000 y = 90.632x - 167640 ~ 145, 000 0 140,000 ~ 135,000 130, 000 125,000 . 3,300 3,350 3,400 3,450 3,500 pressure 3,550 ~ ~ NGI-03 140,000 120,000 100,000 80, 000 w f- ~ 60, 000 40, 000 20,000 0 3, 350 3,400 3,450 3,500 3,550 3,600 ~ ~ ~ PRESSURE y = -1.6665x + 117226 160, 000 140,000 120,000 100,000 w ~ 80,000 ~ 60, 000 40, 000 NGI-04 ~ • 20, 000 3, 300 ~ ~ r --i i ~ _'~ 3,350 3,400 3,450 3,500 PRESSURE 3, 550 3,600 NGI-05 182, 000 181,500 181,000 180, 500 180,000 m r ~ ~ 179, 500 179,000 178,500 178,000 177 500 y = 24.302x + 97587 ~ • 3,300 3,320 3,340 3,360 3,380 3,400 3,420 3,440 3,460 3,480 Pressure NGI-08 160,000 155, 000 y = 98.79x - 192684 ~ 150, 000 d ~ 145,000 140, 000 135, 000 130,000 3,300 3,350 3,400 3,450 3,500 3,550 Pressure 3,600 I ~ NGI-12 rate = 101.13(pressure) - 164334 200,000 195,000 190,000 185, 000 d ~ 180,000 175,000 170,000 ~ ~J 165,000 160, 000 3,300 3,350 3,400 3,450 3,500 3,550 Pressure NGI-13A 260,000 255,000 250,000 245,000 w F- ~ 240,000 235,000 230,000 225,000 2,500 2,600 2,700 2,800 2,900 3,000 PRESSURE 3,100 3,200 3,300 3,400 3,500 ~ ~ UPDATE: NGI Flow Transmitte~ • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comJ Sent: Monday, May 04, 2009 2:11 PM ~c~~n t~'6 /~( To: Regg, James B(DOA) ~~ z~ ~ Cc: GPB, FS1 OTL; GPB, Area Mgr North (Gas Plants/GPMA); GPB, FS1 Fac Engr; Rossberg, R Steven; NSU, ADW Well Integrity Engineer; Daniel, Ryan; Bill, Michael L(Natchiq); Cahalane, Ted W; Dahlem, Jason E; Seymour, Len I; NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Engel, Harry R Subject: UPDATE: NGI Flow Transmitters Jim, After further evaluation, it has been decided to leave the underrated flow transmitters on the seven NGI wells isolated until the fullv rated transmitters are available for replacement. The fully rated transmitters are expected to arrive on the slope on May 13th and work to install them is planned to begin on May 15th. After the transmitters are replaced, calculations will be made to determine injection volumes and rates for the time the meters were out of service. We will also provide our calculation and the exact number of days the flow meters ~ were out of service. We will continue to update you on the status of the replacements. If you have any questions in the interim, please don't hesitate to contact me or Anna Dube. Thank you, Andrea Hughes Well integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Engel, Harry R Sent: Thursday, April 23, 2009 4:57 PM To: James Regg Cc: GPB, FSl OTL; GPB, Area Mgr North (Gas Plants/GPMA); GPB, FSl Fac Engr; Rossberg, R Steven; NSU, ADW Well Integrity Engineer; Daniel, Ryan; Bill, Michael L(Natchiq); Cahalane, Ted W; Dahlem, Jason E; Seymour, Len I; NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Engel, Harry R Subject: NGI Flow Transmitters Jim- This is a follow up to our telephone conversation this afternoon regarding flow transmitters at ~ NGI pad. The NGI 13 flow transmitter failed on March 29th. There was a minor gas release associated with the failure, far below 1 MMSCF. The flow transmitter was found to be underrated, yet the 8/6/2009 UPDATE: NGI Flow Transmitter~ ~ Page 2 of 2 body is fully rated. We discovered six additional underrated flow transmitters at NGI 1, 3, 4, 5, 8, 12. All seven flow transmitters have been tem~orarilv taken out of service. The wells remain on injection. No other gas injection well flow meters are affected. We have taken the following actions; a. Contacted the manufacturer and ordered metal backed Viton O rings which will increase transmitter operating pressure rating. These O rings will be installed in all seven wells within 1'~ week. Th+s is a temporary modification until new transmitters are installed. b. New fu11y rated transmitters have been identified and wi{{ be installed in all wel{s in / approximately 2-6 weeks. Flow rates will be calculated during the periods when the transmitters are out of service. ~ As you requested, we will send you the flow rate calculation method and the total number of ~ days the transmitters were out of service. I wiff be out of the office for a few days next week. 1f you have any questions, please contact Andrea Hughes at 659-5102. Regards, Harold R. Engel (Harry) Engineering Team Leader Integrity Management, Alaska Drilling & Wells 907-564-4194 office 907-564-5510 fax 8/6/2009 • Page 1 of 1 ~ Regg, James B (DOA) '~ ~ ~' - ~~ From: NSU, ADW Weli Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, May 08, 2009 8:25 PM ~~ ~/.~'~~ To: Regg, James B (DOA) ~l ~ ( Cc: NSU, ADW Well Integrity Engineer Subject: RE: NGI-04 (PTD 1750690) Attachments: NGI-04 TIO Plot.doc Hi Jim, ~ I've attached an updated plot for NGI-04 (PTD #1750690). The OA pressure did increase slightly during the end of April and was bled from 230 psi to 0 pis on 5/1/09. Since then the OA pressure has been stable. We wiil continue to monitor the pressure on the Monthly Injection Report. Please let me know if you have any other questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coerdinatar GPB Wells Group Phone: (907} 659-5102 Pager: (907~ 659-5100 x1154 ~ 70~~~ -•r `s'~~~"~.~~s ~,i i 4~ 6~ ~:~~~ F From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, May 08, 2009 4:04 PM To: NSU, ADW Well Integrity Engineer Subject: NGI-04 (PTD 1750690) MIT done 4/29 for PBU NGI-04 (PTD 1750690) showed increasing OA pressure during test; monthly TIO report indicates BP is investigating increasing OA pressure. Do you have any info/results to share? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 8/7/2009 PBU NGI-04 PTD 175-069 5/8/2009 TIO Plot I a.oot~? ........................................................................... . .. ..... 3,000 2.OC10 ~ ~~ ~ ~- ~ ~~ 1,000 ll_ 1 1_ L ~~>~Lj~~~~ L~ ~i ~L~~i~~ 1r~Yai1<~1~ -~ Tbg -~- IA -~- OA OOA --~- OOOA ~ On • • 02114l09 02I21109 02~'28109 03I07109 03f14l09 03121J09 03128I09 04I04I09 OA111109 04/18l09 04i25/03 05I02I~9 MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~~~ ~~~(~( FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, May 04, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-04 PRUDHOE BAY CJNIT NGI-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~J~- Comm Well Name: PRUDHOE BAY UNIT NGI-04 Insp Num: mitRCN090430141955 Rel Insp Num: API Well Number: 50-029-20183-00-00 Permit Number: 175-069-0 Inspector Name: Bob Noble Inspection Date: 4/29/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-04 Type Inj. CT TVD 7543 IA 540 4570 ~ 4570 4570 4570 '' P.T.D 1750690 TypeTest SPT Test psi as7o OA 70 320 370 3so aao Interval REQvAR P/F P Tubing 3370 3370 3370 3370 3370 NOtes• Took a 60 min reading becouse OA was increasing. g E h f;~ - `i >' nr Monday, May 04, 2009 Page 1 of 1 • __ -, _. J, - ~.. i G,. ~ / r, Ai.,~58A OITi A1~TD G~ CO1~T~ERQgTI011T COMI~IIS~IOIQ LJ SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ..«.- ADMINISTRATIVE APPROVAL 4E.024 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 995 1 9-66 1 2 c~a'~{~~ JAN ~ ~ 2008 RE: PBU NGI-04 (PTD 175-069) Request for Administrative Approval Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order ("AIO") 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or '`Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue gas injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU NGI-04. The Commission further finds that the well demonstrates IA repressurization up to 60 psi per day resulting from tubing by inner annulus communication. Inner annulus pressure can be safely managed with periodic pressure bleeds. Outer annulus pressures do not indicate anomalous conditions or loss of pressure integrity. The Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the constraints enumerated below. AOGCC's administrative approval to continue gas injection in PBU NGI-04 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall perform anMIT - IA every 2 years to the maximum anticipated injection pressure; 4. BPXA shall limit the well's IA operating pressure to 2500 psi; • Mr. Steve Rossberg July 20, 2007 Page 2 of 2 5. BPXA shall install, operate and maintain remote pressure monitoring equipment on the well's IA; an alarm set point of no higher than 2000 psi shall be maintained to allow for time to respond and bleed pressure from the IA; 6. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7. After well shut in due to a change in the well`s mechanical condition, AOGCC approval shall be required to restart injection; and 8. The MIT anniversary date is April 29, 2007. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date oerson letter, or the next working day if the 23rd day falls on a holiday or weekend. A p may not appeal a Commission decision to Superior Court unless rehearing has been requested. Done at Anchorage, Alaska and dated July 20, 2007. Dan T. Seamount Commissioner ~~~ ~~ -; Y~ x -_ ~-~ _ > ;" -- .h _ , ;~.~,,~~ Cathy . Foerster Co issioner MEMORANDUM e TO: Jim Regg P.I. Supervisor ":/ ", ( Ii> Ie í,1 I\lf'( J r\. , FRO"I: Jeff Jones Petroleum Inspector Well Name: PRUDHOE BAY UNIT NGI-04 Insp Num: mitJJ070502104114 ReI Insp N urn: Packer -- I -- ; 'I Well NGI-04 ,Type Inj. : N TVD ; P.T.D' 1750690 ¡TypeTest ! SPT! Test psi : ~y&~EQVAR ,__ P/F P Notes: 64 BBLS methanol pumped. --~,--- Thursday, May 03, 2007 State of Alaska Alaska Oil and Gas Conservation commie DATE: Thursday, May 03,2007 SUBJECT: MechanIcal Integrity Tests BP EXPLORA nON (ALASKA) INC NGI·04 PRLDHOE BAY L'-IIT i\:GI·04 Src: [nspector NON-CONFIDENTIAL API Well Number: 50-029-20183-00-00 Permit Number: 175-069-0 Depth </vCoq 4' '17 \.....-0 ~ V Reviewed By: P.I. Suprv ,)r5¡2:- Comm Inspector Name: Jeff Jones Inspection Date: 4/29/2007 7543 IA , OA Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. .~~.._.".-,--~___.._,--_n,_-,----_,--,-___ 440 4560 4550 4550 1885.75 50 I I i .~ I ~. : 60 50 50 I ---L__~ 2480 2420 2420 I ~_J -~ .../ Tubing I 2200 -------- ~CAliNED MAY 09 2007 Page I of I [Fwd: RE: NGI-04 (PTD #1750690) IA Repr.izatiOn] . Couple problems from my review... 1) We were notified of control/balance line issues on October 30, 2006¡ stated work plan seemed reasonable. I'm surprised it took until December to resolve that. Our records indicate this well has injected nearly continuous except for 10 days in November. Email notice October 30 said the well would not restart until communication issue resolved. 2) BP's actions in response to the current annulus pressure increase do not appear to be consistent with AIO 4E, Rule 7. Bleeding annulus pressure to keep below 2000psi (production well SCP criteria, not applicable to injection wells) is an indication of pressure communication that should have triggered notice to the Commission in February (certainly after the first bleed and respressure if not when pressure were increasing in early February), not April. Can we get an explanation? Jim Regg AOGCC SCANNED APR 3 0 2007 -------- Original Message -------- Subject: RE: NGI-04 (PTD #1750690) IA Repressurization Date: Tue, 10 Apr 2007 13:26:10 -0800 From: NSU, ADW Well Integrity Engineer <NSUADVJvJell Integri. tyEngineer@BF. com> To : J ame s Regg~:j~r~:r::i?gg(ij)?:c:l!T\~!l:~~?:~E":0!<::?t;?' " Enge I, Harry R" <Earry.Engel@bp.com>, "NSU, ADW Well Operations Supervisor" ~NsuADwï~eIIOpei:"a:tlorlsSupervisor@BF. com>, "Rossberg, R Steven" ::ª-1::_E""Yi?~~:Bgt;§;:'5":.:J:::g~~!?P:(:;?!T\?, "GPB, FSl OTL" .s9l??~~~~.Q::I'.I:,(fi)!?E:?Q!T\.?' "GPB, FSl DS Ops Lead" <GPBFSIDSOpsLead@BP.com>, "Senden, Leslie B" <Leslie.Senden@bp.com>, Thomas Maunder <tom maunder@admin.state.ak.us> CC ;-""NSU;""ADw·wellintegrIty Engineer <NSUADWWel1 Integ:ci t yEngineer@BP . com>, Winslow, Jack L .:::l.:'.Y,?J,:l§",(fi)?:?:S:?rrl?" NSU, ADW WI Tech <Nª-(!~I?W~:~"f"!i?"c:t:~ª--E.'":"s:_()S?. Hello Jim and Tom, Well NGI-04 (PTD #1750690) is exhibiting indications of pressure communication between the tubing and IA. The field Operators have been bleeding the IA with increasing frequency over the last two months to maintain a pressure below 2000 psi. The well was found to exhibit indications of TxIA communication in December, at which time GX sealant was pumped on the control and balance lines, mitigating the communication until the last two months. The current plan forward is to perform an MITIA and pursue a AA for TxIA communication. While we are pursuing the AA, we will leave the well on injection while monitoring the IA for repressurization. Attached is a TIO plot and wellbore schematic for reference. Please call with any questions. «NGI-04.pdf» «NGI-04 TIO plot. doc» Thank you - */Jack L. Winslow (for Anna Dube)/*// Well Integrity Engineer alternate: Paul Austin office - 659-5102 pager - 659-5100, 1242 1 of2 4/12/20075:44 PM [Fwd: RE: NGI·04 (PTD #1750690) IA ReP..izatiOn] . Content- Type: application/octet-stream Content-Encoding: base64 NGI-04 TIO Content-Type: application/msword Content-Encoding: base64 Content-Type: text/plain PBU _NGI-04_IA_repressnre_2006-1030.txt Content-Encoding: 7bit 20f2 4/12/20075:44 PM · TREE = 7-1/16" GRAY WELLHEAD = GRAY ACTIJATOR= AX8..SON KB. ELBI = 47.0' BF. ELBI = NA KOP- 3200' Max Angle = 54 @ 6700' Datum MD = Datum ND - 8800' SS 113-318" CSG. 72#, ~-80, ID - 12.347" I 2711' 7-518" TBG-IR::, 29.04#, L-80, .0459 bpf, ID = 6.690" 9558' Minimum ID = 5.50" @ 9603' 7" HES RN NIPPLE 7" 1BG, 26#, L-80, .0383 bpf, ID = 6276" 9619' 9-5I8"CSG,47#,MN-80,ID=8.681" , 9941' PffiFORA TION SUMMARY REF LOG: BHCS ON 06/17/77 ANGLEATTOP ÆRF: 44 @ 10216' I'bte: Refer to Production DB for historical rf data SIZE SPF NTffiVAL Opn/Sqz [)6.TE 3-3/8" 4 10216- 10268 0 06129/90 3-3/8" 4 10329 - 10354 0 06117/77 3-3/8" 4 10354 - 10373 0 02128/87 3-3/8" 4 10373 - 10398 0 06117/77 3-3/8" 4 10398 - 10406 0 02127/87 3-3/8" 4 10470 - 10486 0 02127/87 3-3/8" 4 10510- 10535 0 02127/87 3-3/8" 4 10599 - 10630 0 02127/87 3-3/8" 4 10639 - 10644 0 02127/87 3-3/8" 4 10673 - 10686 0 02127/87 3-3/8" 4 10697 - 10725 0 02127/87 3-3/8" 4 10750 - 10762 0 02127/87 NGI-04 7" LNR, 29#, ~-80, .0371 bpf, ID = 6.184" ~ 11015' DATE REV BY COMMENTS [)6. TE RBI BY 02/27/76 ORIGINAL COMPLErION 12/04/00 S&-Isl CONVERTED TO CANVAS 03/07/01 TWA RNAL COMFtETION 03/11/01 RNO 01/07/02 CHfTLP CORRECTIONS COMMENTS I SAFETY NOTES: 25' -17" X 7-5/8" XO, ID = 6.151" I 2207 -17-518" X 7" XO, ID = 6.151" I 2209' 7" C!\IIIK:;O BAL-O SSSVN, D = 5.937" 2213' 9559' 9579' 9603' 9623' 9626' 11010' 9-5/8" X 7" BKR SABL-3 PKR, ID= 6.00" 7" HES RN NIp, ID = 5.50" -19-518" X 7" BOTIIIK:; HGRWITIEBACKSLV 7" MULESHOE; ID= 6.151" FISH - PERF GUN LOST 06/18/77 FRUœOE BA Y UNrr WELL: NGI-04 ÆRMrrNo: 1750690 API No: 50-029-20183-00 SEe 12, T11 N. R14E 567' SNL & 1064' EWL BP EXploration (Alaska) NGI-04 (PTD #1750690) IA Repressurization . . Hello Jim and Winton, Well NGI-04 (PTO #1750690) is exhibiting indications of pressure communication between the tubing and IA. The field Operators bled the IA multiple times last night to maintain a pressure below 2000 psi. The well was shut-in this morning. The current plan forward is to troubleshoot the SSSV control and balance lines. Once complete we will put the well back on injection and monitor the IA for repressurization. Attached is a TIO plot and wellbore schematic for reference. Please call with any questions. «NGI-04.pdf» «NGI-04 TIO plot.doc» Thank you, Andrea Hughes Well Integrity Engineer Office: (907) 659-5766 Pager: (907) 659-5100 x1242 '·'1, . ^ :!\..H\rÞ,;~ ~, \J,*¡~2.1l '..''ò ;;1......'"'"",.; Content-Description: NGI-04.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: NGI-04 no plot.doc NGI-04 TIO plot.doc Content-Type: application/msword Content-Encoding: base64 1 of 1 10/30/2006 1 :31 PM · TREE: 7-1/16" GR.L\ Y WELLHEAO: GR.L\Y ACWATOR: AXB..SON KB. ELBI : 47.0' BF. ELBI - NA KOP: 3200' Max Angle - 54 @ 6700' Oatum MD: Oatum lVO: 8800' SS 113-318" CSG, 72#, MN-80, 10 - 12.347" I 2711' 7-5I8"TBG-IR::, 29.04#, L-80, .0459 bpf, 10: 6.690" 9558' Minimum ID = 5.50" @ 9603' 7" HES RN NIPPLE 7" TBG, 26#, L-80, .0383 bpf, 10: 6.276" 9619' 19-518" CSG, 47#, MN-80, 10: 8.681" I 9941' PffiFORATION SUMMARY REF LOG: BHCS ON 06/17m ANGLEATTOP ÆRF: 44 @ 10216' IIbte: Refer to Production OB for historical rf da1a SIZE SA" NTffiVAL Opn/Sqz 1)/\ TE 3-3/8" 4 10216- 10268 0 06129/90 3-3/8" 4 10329 - 10354 0 06117/77 3-3/8" 4 10354 - 10373 0 02128/87 3-3/8" 4 10373 - 10398 0 06117/77 3-3/8" 4 10398 - 10406 0 02127/87 3-3/8" 4 10470 - 10486 0 02127/87 3-3/8" 4 10510 - 10535 0 02127/87 3-3/8" 4 10599 - 10630 0 02127/87 3-3/8" 4 10639 - 10644 0 02127/87 3-3/8" 4 10673 - 10686 0 02127/87 3-3/8" 4 10697 - 10725 0 02127/87 3-3/8" 4 10750 - 10762 0 02127/87 NGI-04 17" LNR, 29#, MN-80, .0371 bpf, 10: 6.184" I 11015' OATE 02/27/76 12/04/00 03/07/01 03/11/01 01/07/02 RBI BY COMMENTS ORIGINAL COMPLErION S5-lsl CONVERTEOTOCANVAS TWA RNAL COMR.ETlON RlVO CHIfLP CORRECTIONS 1)/\ TE RBI BY COMMENTS I SAFETY NOTES: 25' 7" X 7-5/8" XO, 10: 6.151" 2207 -17-5I8"X7"XO,IO:6.151" 2209' 7" CAMeO BAL-O SSSVN, D = 5.937" 2213' -i7" X 7-5/8" XO, 10= 6.151" I 9559' 7 -518" X 7" XO, 10 = 6.151" 9579' -19.5/8" X T' BKR SA BL-3 PKR, 10 = 6.00" I 9603' 9623' 9626' 7" HES RN NIp' 10 = 5.50" -19-518" X T' BOT Me HGR W/ TlffiACK SL V 7" MULESHOE: 10 = 6.151" 11010' -I FISH - PERF GUN LOST 06/18m ffiUDHOE BAY UNIT WB..L: NGI-04 Æ~rr No: 1750690 A PI No: 50-029-20183-00 SS:; 12, T11 N, R14E 567' SNL & 1064' EWL BP Exploration (Alaska) MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor KG'11113/ð~ DATE: Tuesday, August 30, 2005 SUBJECT: Mechanical Integrity Tests SP EXPLORATION (ALASKA) INC NGI-04 PRUDHOE SAY UNIT NGI-04 f^C S "OW , \1 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv Sßf- Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT NGI-04 API Well Number 50-029-20183-00-00 Insp Num: mitJCr050825 I 12358 Permit Number: 175-069-0 Rei Insp Num Inspector Name: John Crisp Inspection Date: 8/23/2005 Packer Depth Well N~Ï=õ4- ITyp~-ïnj. ~_: TVD P.T. l~)~_~~OjTypeTest SPT t Test~~i _J!!!~rv!ll 4YRTST PIF P Notes 6.1 bbIs pumped for test Pretest Initial 15 Min. 370 2220 2200 90 90 110 3500 3500 3500 30 Min. 45 Min. 60 Min. --------1---'-- . ---------J------------ 120 I : ------- ..---------,----------j---- ------ 3500 I : _______---1.._____ __ 2240 ~ .-- (C" i - \,;.~~~iFl , 1~\;IJ~,r)\}, ,_il!"",¡ -- \. L\ (, ;) i:' (~ " , Tuesday, August 30, 2005 Page I of 1 TO: Jim Regg D I I P.I. Supervisor "'f[ 'ì ¡-gðS FROM: Jeff Jones Petroleum Inspector Well Name: PRUDHOE SAY UNIT NGI-04 Insp Num: mitJJ050810111950 Rei Insp N um: DATE: Monday, August 15,2005 SUBJECT: Mechanical Integrity Tests SP EXPLORATION (ALASKA) INC NGI-04 PRUDHOE SA Y UNIT NGI-04 (oC ~/O nJ Src: Inspector Reviewed By: P.I. Suprv .:.rg¡2... Comm NON-CONFIDENTIAL API Well Number: 50-029-20183-00-00 Permit Number: 175-069-0 Inspector Name: Jeff Jones Inspection Date: 8/6/2005 Packer Depth Pretest Initial W ~ii T -NGI-04 I Type Inj .___1,.__ G II TV_.D._..___ --;,--·-.-._7543----:-1' IA-- 480 ----T2õ5õ--- -P.T. !~750~~0 iTYp~_!~_st I SP~L!_~_~t psi i 1885.75 I OA -25Ö-j-----350 I _.Iµterval 4YRTS!____--.fLJl _ F__________ Tubing 3450 ---: 3450 --! Notes: 10,3 BSLS of diesel was pumped to pressure up the well to the required test pressure. The MIT failed because the fA was not tluid packed. () ,0 r(t<;jSi~ sa ~se f¿-Ii?;u+- o ~onday,August 15,2005 15 Min. 30 Min. 45 Min. 60 Min. ~_.._ ] m:-·t- :ì~- .~~ A/~, CJlz:.:IO')'- (.,,\Jj~1'\eSSe0.{ ~.?d- .:hJspecJor-,JCh~, CJ\Sp Jk'?( lit 310ç .'. . , ~ r",-IHi:r (' E \~J ~:jLÞt¡¡'\!~ìJt...-.L." ,,) _ ï" ~(i. G 2005 Page I of I "~ TREE = 7-1/16" GRA Y WELLHEAD = GRA Y Ä ëiùA l'ÖR ; ÄXELSON ks, ELEV = 47,0' 'SF~äE.V;"- NA Rop"'; 3200: ,~axÄrïg"I~:~·m "54"@ï3j~_?~ Datum I'vÐ = Datum TV D = 8800' SS 113-318" CSG, 72#, M'J-80, ID = 12.347" Ii 2711' ~ 7-5/8" TBG-IR::, 29.04#, L-80, -i 9558' ,0459 bpf, ID = 6,690" Minimum ID = 5.50" @ 9603' 7" HES RN NIPPLE IT' 1BG, 26#, L-80, ,0383 bpf, ID = 6.276" 1-1 9619' 19-5/8" CSG, 47#. MN-80, ID = 8.681" 1-1 9941' PffiFORA TION SUrvTVlARY REF LOG: BHCS ON 06/17/77 ANGLEATTOPÆRF: 44 @ 10216' I\bte: Refer to Production DB for historical perf data SIZE SA=' NTffiVAL Opn/Sqz DA 1E 3-3/8" 4 10216 - 10268 0 06/29/90 3-3/8" 4 10329 - 10354 0 06/17/77 3-3/8" 4 10354 - 10373 0 02128/87 3-3/8" 4 10373 - 10398 0 06/17/77 3-3/8" 4 10398 - 10406 0 02127/87 3-3/8" 4 10470 - 10486 0 02127/87 3-3/8" 4 10510 - 10535 0 02127/87 3-3/8" 4 10599 - 10630 0 02127/87 3-3/8" 4 10639 - 10644 0 02127/87 3-3/8" 4 10673 - 10686 0 02127/87 3-3/8" 4 10697 - 10725 0 02127/87 3-3/8" 4 10750 - 10762 0 02127/87 NGI-04 ) l a . I I >< ~ J I:I!::I -/ ... tiil \- ~ 10982' ~ TD l-f 11015' 1 IT' LNR, 29#, M'J-80, ,0371 bpf, ID = 6,184" H DATE 02/27/76 12/04/00 03/07/01 03/11/01 01/07/02 REV BY COMrvENTS ORIGINAL CONPLETION SS-lsl CONVERTED TO CANVAS TWA RNAL COMR...E110N RJVO CHfTLP CORRECfIONS I)c\ TE REV BY co rvTVIENTS ) "' I SAFETY NOTES: 25' 1-f7" X 7-5/8" XO, ID = 6.151" I 2207' 1-17-5/8" X 7" XO. ID= 6,151" 1 2209' 1-17" Cð..rvco BAL-O SSSVN, 0 = 5.937" 2213' 1-i7" x 7-5/8" XO, ID = 6.151" 1 ~ 9559' 1-17-5/8" X 7" XO, ID= 6.151" 1 9579' 1-19-5/8" x 7" BKR SABL-3 PKR, ID = 6,00" I L 9603' 1-17" HES RN NIp, ID = 5.50" 1 9623' 9626' 1-19-5/8" X 7" BOT rvc HGR W/TII33ACK SL V 1-17" MJLES HOE, ID = 6,151" 1 I 11010' l-f FISH - PERF GUN LOST 06/18/77 FRUDHOE SA Y UNIT W8.L: NGI-04 ÆRMIT No: 1750690 A PI No: 50-029-20183-00 SEC 12, T11 N, R14E 56T SNL & 1064' EWL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Per/orate _ Pull tubing _ Alter casing _ Repair well _ Other _X(RWO) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 47 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 567' FNL, 4216' FEL, Sec. 12, T11 N, R14E, UM (asp's 687266, 5971751) NGI-04 At top of productive interval 9. Permit number / approval number 3637' FNL, 4659' FEL, Sec. 6, T11 N, R15E, UM (asp's 691663, 5974071) 175-069 At effective depth 10. APl number 50-029-20183 At total depth 11. Field / Pool 3388' FNL, 4129' FEL, Sec. 6, T11 N, R15E, UM (asp's 692185, 5974333) Prudhoe Bay Oil Pool 12. Present well condition summary Totaldepth: measured 11015 feet Plugs(measured) Tagged PBTD @ 10814' on 4/3/2001. true vertical 8556 feet Effective depth: measured 10814 feet Junk (measured) true vertical 8416 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 1 03' 20" 240 Sx PF II 103' 103' Surface 2664' 13-3/8" 6400 sx PF II 2711' 2711' Production 9894' 9-5/8" 750 sx Class G & 125 Sx PF II 9942' 7808' Liner 1358' 7" 350 Sx Class G 1 0982' 8533' Perforation depth: measured 10216'- 10268'; 10329'- 10406'; 10410'- 10425'; 10441'- 10558'; 10574'- 10630'; 10639'- 10644'; 10662'- 10762'; 10819'- 10844'. true vertical 8010' - 8047'; 8089' - 8142'; 8144' - 8154'; 8165' - 8243'; 8253' - 8291" 8297' - 8300'; 8312'- 8381'; .... 8420' - 8437'.J~'~' ~, ~.,~ ~ I V.e,,,~ Tubing (size, grade, and measured depth) 7-5/8 29.04#, L-80 IPC Tubing @ 9558' MD; 7", 26#, L-SO Tubing @ 9626' MD. -- ~ ~ Packers & SSSV (type & measured depth) 7" x 9-5/8" Baker SABL-3 Packer @ 9579' MD. APR 2 0 2001 7,, camco BAL-0 SCSSSV @ 2209' MD. 13. Stimulation or cement squeeze summary Alaska Oil & (;as Cons. Commission Intervals treated (measured) (see attached) Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mc! Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut in f/AC Subsequent to operation 250000 3320 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended _ Service ~(Gas Inj).__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~.. ~ ~ Title: ~'I~, ~,~, ~J ~ ~,~-~ Date April 16. 2001 Prepared by Paul Rauf 564-5799 Form ,O-404Rev06/15/88o 0 R I 6 I i"~'?''',/*''\ L. SUBMITIN DUPLICATE '~ NGI-04 DESCRIPTION OF WORK COMPLETED PRE & POST RWO Date Event Summary 1/29/2001' 113112001' 2/02/2001: 2/04/2001: 2/09/2001 - 3/11/2001' 3/09/2001: 4/02/2001 - 4/03/2001' 4/14/2001' RIH & pulled IBP located @ 9221' SLM. Loaded tubing w/478 bbls of 2% KCL Water. Pumped salt pill. RIH & punched the 4-1/2" TT f/9411.5' - 9413.5' (4 SPF). RIH & set IBP @ 9628' CTM to cap salt pill & ensure well killed for upcoming RWO. RIH & punched tubing f/9338' - 9340'. Jet cut tubing @ 9305'. Performed RWO. RIH & pulled IBP. RIH & FCO'd salt pill to 10814'. Performed AOGCC witnessed MITIA to 2200 psi - passed. Placed well on Gas Injection & obtained representative injection data. Page 1 Legal Well Name: NGI-04 Common Well Name: NGI-04 Spud Date: 2/10/2001 Event Name: WORKOVER Start: 2/9/2001 End: 3/11/2001 Contractor Name: NABORS Rig Release: 3/11/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: 2/9/2001 12:00 - 00:00 12.00 MOB PRE RDMO S - 104i, Move onto NGI Pad with Camp, Work Shop, Pit Module and various loads of equipment. Rig Sub-base in transit. 2/10/2001 00:00 - 00:00 24.00 MOB PRE MIRU on NGI - 4. Rig on NGI Pad @ 1530 Hrs. Spot Rig over well, button up cellar, raise derrick, spot camp, workshop & pits. Hook up lines.to pumps & manifold. 2/11/2001 00:00 - 01:30 1.50 RIGU PRE Take on 8.8 ppg. brine. Rig accepted @ 00:01 Hrs. Cont. rigging up. Spud meeting with crew and svc. personnel. PJSM. 01:30 - 03:00 1.50 WHSUR DECOMP Rig up lines to Tree, choke and cuttings tank. Cont. taking on brine. Test all circ lines to 3500 psi. 03:00 - 04:00 1.00 WHSUR DECOMP R/U DSM, pull BPV, R/D DSM. NO press - tbg & ann. 04:00 - 10:30 6.50 CLEAN DECOMP Rev. circ diesel from tbg w/brine. Switch - pump dn. tbg. & circ diesel from annulus. Complete circ. w/8.8 brine. S/D pumps. Well Dead. 10:30 - 11:00 0.50 WHSUR DECOMP Install TWC. Test fr. below to 500 psi. 11:00 - 13:30 2.50 WHSUR ' DECOMP N/D Tree and adapter flange. 13:30 - 15:00 1.50 WHSUR DECOMP Clean and inspect tubing head. Check threads, LDS, Gland nuts, dart valve and all measurements. 15:00 - 19:30 4.50 BOPSUF DECOMP N/U BOP stack and rig to test. 19:30 - 20:30 1.00 BOPSUF DECOMP Spud metting with 2nd. crew. PJSM for BOP test. 20:30 - 00:00 3.50 BOPSUF DECOMP Testing BOPE 250 / 5000, APl, Jeff Jones, AOGCC witnessing. Jeff also testing rig PVT's, Epoch alarms, H2S and LEL sensors. Blind flange on mud cross -small leak - tighten - OK 2/12/2001 00:00 - 05:30 5.50 BOPSUF DECOMP Complete BOP test. APl. Lower top drive safety valve failed - replaced same - OK. All tests witnessed by Jeff Jones, AOGCC. 05:30 - 07:00 1.50 BOPSUF DECOMP P,/U DSM lubricator, Pull BPV, R/D Lub. 07:00 - 08:00 1.00 FISH DECOMP M/U Spear assy. RIH & engage 7" Tubing below Hanger 08:00 - 08:30 0.50 WHSUR DECOMP Back out Lock Down screws. 08:30 - 09:30 1.00 FISH DECOMP Work hanger off seat - pull tbg. free w/380K. Attempt to pull Hgr. to floor - NG. Hgr hitting wear plate in Hydril. Reseat Hgr. & release spear. 09:30 - 13:00 3.50 FISH THGR DECOMP Close blind rams. Remove drilling nipple. Grind I.D. of Hydril wear plate. Open blinds. Engage spear. Pull hgr. to floor. Reseat Hgr. & release spear. Close blind rams. reset drilling nipple. Engage spear & pull Hgr. to floor. 13:00 - 14:00 1.00 PULL DECOMP Break out Hanger and lay down. 14:00 - 15:30 1.50 CLEAN DECOMP Circ wellbore clean @ 8 bbls/min - 770 psi. Small amount of gas at btms. up. Observe wellbore after circ - dead and stable. 15:30 - 17:00 1.50 PULL DECOMP PJU equip to pull tubing and Camco equip to spool control lines. 17:00 - 23:00 6.00 PULL DECOMP PJSM POH & L/D 7" tbg. Pull 35th Jt - control lines missing. Line was extremely brittle. Continue pulling 34 more jts then SSSV. Drag 20 -40 K over String Wt. 38 SS straps and approximately 2100 fi. of control line left in wellbore. All connections very tight and difficult to break. Tubing, pins & collars in good condition. 23:00 - 00:00 1.00 PULL DECOMP R/D Camco spooler. C/O elevators. 2/13/2001 00:00 - 01:00 1.00 PULL DECOMP Continue POH w/7" Tubing. Observed balled control line in stack. 01:00 - 01:30 0.50 FISH JUNK DECOMP Fish contol line from stack - approx. 100 + fi recovered. - stack clear of control line, still balled at tbg. head. 01:30 - 11:00 9.50 PULL DECOMP Continue POH w/Completoin string. All connections very tight. Recovered 289 Jts 7" Tbg., 7"X 5.5" XO, 2 Jts 5.5" Tbg and cutoff- 16.96' 11:00 - 12:00 1.00 PULL DECOMP Rig down Tubing pulling equip. & clear floor PJSM on Fishing control line. 12:00 - 16:30 4.50 FISH JUNK DECOMP Make multiple runs with Baker Crankcase spear into wellhead to fish control line. Very brittle - retrieved approx. 1000 to 1200 fi. balled up & Printed: 4/12/2001 9:34:59AM 7::.'~:: ~:~;~' :: ~'~;:~:::::::~:~-. :::.::~,::~;~:~:.:: .~ Legal Well Name: NGI-04 Common Well Name: NGI-04 Spud Date: 2/10/2001 Event Name: WORKOVER Sta~: 2/9D001 End: 3/11/2001 Contractor Name: NABORS Rig Release: 3/11/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: ~:'~:~:~;.'~'~'~ ~:~::~:~':~'::: ~ ~:::::::.~ ~ ~.~:<'~.'.:~>~.:~.:.::.:~.:~::.~:;:.::'.:.~'::.~ ?.~- :.': 2/13/2001 12:00 - 16:30 4.50 FISH JUNK DECOMP broken control line with a number of pie~s of straping. Small pie~s of control line visable in stack and Tbg head. 16:30 - 20:00 3.50 FISH JUNK DECOMP Run Baker 9" fishing magnet in stack and tbg head. recovered multiple small pie~s of control line. Ran po~ed sub through BOP, pumping brine and rotating slowly to wash out stack. Re -run magnet, recovered mom pie~s line. 20:00 - 22:00 2.00 BOPSUF DECOMP Close blinds and C/O top rams to 3 1/2" X 6" variables. 22:00 - 00:00 2.00 FISH DECOMP P/U 4" DP. Standing back eve~ throe Jts. 2/14/2001 00:00 - 01:30 1.50 FISH DECOMP Cont. P/u 4" DP standing back in Derrick by stands. 01:30- 02:00 0.50 FISH DECOMP Se~i~ Top Drive. 02:00 - 03:00 1.00 FISH DECOMP M/U modified Tbg Hgr w/XO 1 it. 4" & TIW. RIH. RILDS, Test from above to 500psi. 03:00 - 04:00 1.00 BOPSUF DECOMP C/O boEom rams to 2 7/8" X 5". 04:00 - 05:30 1.50 BOPSUF DECOMP Pull Tbg. Hgr. Run test plug. Test both upper and lower rams to 250 / 5000 psi. 5/10 min. OK 05:30 - 16:00 10.50 FISH DECOMP M/U Baker Crankcase spear and BHA. Make runs to 1600' and 2648' recovering some control line and straps. ~D spear 16:00 - 19:00 3.00 FISH DECOMP M/U 5.5" Ovemhot BHA ( ~2 ). 19:00 - 20:30 1.50 FISH DECOMP RIH w/32 stands 4" DP. PJSM w/crew on P/U singles RIH and fishing. 20:30 - 00:00 3.50 FISH DECOMP RIH picking up 4" DP. 2/15/2001 00:00 - 03:00 3.00 FISH DECOMP Cont. P/U 4" DP.RIH to 9287'. Break cim - 3.5 bpm ~ 195 psi. Up ~- 195 K, Dn ~ 140 K, Rot. ~ 165K Torque - 6,000. Tag fish ~ 9297'. 03:00 - 04:00 1.00 FISH DECOMP Spa~ out to fish w/pup jts below BOP. Work over and engage fish. Pull 235 K to set grapple and bleed jars - Fish free. Pulled up to clear PBR 04:00 - 06:00 2.00 FISH DECOMP CBU ~ 5 bpm, 410 psi. LiEle gas and oil at bosoms up, cont. circ until clean. Monitor well;stable & dead. 06:00 - 13:00 7.00 FISH DECOMP POH - slowly. Recovered 50.08' of fish + seal assy. 13:00 - 17:30 4.50 FISH DECOMP C/O grapple to 6", Run same BHA. RIH to 5644'. Phase 3 Weather Conditions called. Shut down rig operations. 17:30 - 00:00 6.50 FISH ~HR DECOMP Phase 3. Shutdown Workover operations. Safety meeting with all pemonnel on rig. Review pm~dums. Monitor well and consewe as much fuel and water as possible. All hands to use" buddy system" AND hand held radios while checking rig equipment 2/16/2001 00:00 - 02:00 2.00 FISH DECOMP Phase 3 liEed. Cont. RIH to 9287' 02:00 - 03:00 1.00~ FISH DECOMP Spa~ out w/pup jt. Wash down and engage fish at 9347'. Jar up to loosen "K" latch. Pulled free on 2nd. jar at 275 K. Drag 120 initial down to 40 K. Fish appeam to be complete packer assembly, 03:00 - 08:00 5.00 FISH DECOMP Make complete cimulation through choke, 3,5 bpm ~ 430 psi, Small amt. of gas on btms up. Cim out. & monitor well - stable & dead. 08:00 - 15:30 7.50 FISH DECOMP POH w/fish. Had to Jar to initially sta~ moving aEer circulation, then 3ulled w/minimum drag. 15:30 - 17:00 1.50 FISH DECOMP Recovered PBR and "K" anchor Total mcove~ 33.61' Lay down fish 17:00 - 18:30 1.50 FISH DECOMP M/U Packer -Picker BHA. 18:30 - 20:00 1.50 FISH bECOMP RIH w/4" DP 20:00 - 20:30 0.50 FISH DECOMP Hold PJSM w/Lunda's crew -just arrived. 20:30 - 22:00 1.50 FISH DECOMP Cut and Slip drilling line 85'. Clean and inspe~ Draw works 22:00 - 00:00 2.00 FISH DECOMP Continue RIH w/fishing assembly on 4" DP, 2/17/2001 00:00 - 02:30 2.50 FISH DECOMP Continue TIH 8.5" Mill and Packer Picker assembly on 4" drill pipe to Printed: 4/12/2001 9:34:59AM :::::::::::::::::::::::::::::::::::::::::::::: Legal Well Name: NGI-04 Common Well Name: NGI-04 Spud Date: 2/10/2001 Event Name: WORKOVER Start: 2/9/2001 End: 3/11/2001 Contractor Name: N^BORS Rig Release: 3/11/2001 Group: RIG Rig Name: N^BORS 9ES Rig Number: ~';'~;:;;:~;~:::;~:;;:;:.;.~:;;:::~:~;.;:;;~;<~s:..: ..,,:~:...:..:.,~:~:~::~:.~:~:~.:~ ................. /:::::~:;Z;:'/:;'. ;;:;:::.,>"" .:; ?.... ~;;;: _. ,: .-.. ;. ,,~ - - X 2/17/2001 00:00 - 02:30 2.50 FISH DECOMP 928~'. Take SPR. 02:30 - 04:30 2.00 FISH DECOMP Circulate and work 8.5" miii down to top of packer at 9322'. ~ill top slips, rubber seals and botto~ slips. WOB 8k, RPM 130 w/8-13k lib Torque, 243 GPM w/520 psi. P/U 183k, S/O 145k, Rot Wt 165k. A~er milling bo~o~ slips on packer, took a 60k overpull to 225k to ensure that spear had engaged the fish-OK. 04:30 - 07:30 3.00 FISH DECOMP Circulate one complete circulation from 9322' w/243 GPM ~ 520 psi, 07:30 - 19:30 12.00 FISH DECOMP POOH slowly-16 'to 18' a ~inute. T~ing to swab. Pulling 40 K over 1st 6 stands. Hanging up occassionaly, having to work through. - Packer to ~oor.( finally ! ) 19:30 - 21:30 2.00 FISH DECOMP Lay Down Packer and tail pipe assy.- 138' ~sh. 21:30 - 22:30 1.00 FISH DECOMP Clean out boot baskets. Recovered about 2 gal of loose metal, Clear & clean rig ~oor. 22:30 - 00:00 1.50 FISH DECOMP P/U and ~/U RCJ~ and 9 5/8" Scraper BHA 2/18/2001 00:00 - 04:30 4.50 FISH DECOMP TIH with 8 1/8" RCJB and 9 5/8" ~sing scraper assembly on 4" DP to 9517'. Tag-up on obstruction. 04:30 - 09:30 ~.00 FISH DECOMP Establish circulation. Wash, Ream and work string down to th~ 7" liner top { 9623'. Pu~p Hi-vis sweep. Circulate hole clean from 9623' w/ 235 GPM ~ 1000 psi. 09:30 - 16:00 6.50 FISH DECOMP Flow check well-OK. POOH with 4" DP work string and ~HA. 16:00 - 17:00 1.00 FISH DECO~P Lay down RCJB and boot baskets. Recovered 5 gal. pail of jun~. clean & clear rig floor. 17:00 - 19:30 2.50 ~OPSU~ DECOMP Test BOPE to 2~0 / 5000 psi - APl. No Failures. Witness of test waived by Chuck Sheve, AOGCC. 19:30 - 20:30 1.00 CASE DECOMP PJSM - M/U HOWCO RBP, R~S, By Pass & Pup Jt. 20:30 - 00:00 3.50 CASE DECOMP RIH w/RBP & R~S on 4" DP. 2/19/2001 00:00 - 02:30 2.50 CASE DECOMP RIH w/RBP to 9515' 02:30 - 03:30 1.00 CASE BECOaP Set RBP ~ 9515'. Pull up to 9476' and set R~S. Test be~een RBP & R~S to 4000" Lost 150 psi - 15 min. -still dropping. 03:30 - 05;00 1.50 CASE DECOMP Check all suffae equip. Found leaking Hailibu~on Lo-Torque valve. Replae valve. Un-set R~S, circ, re-set R~S. 05:00 - 07:30 2.50 CASE DECOMP Pressure test be~een RBP ~ R~S to 4000 psi for 30 min. - OK. Pressure be~een R~S and pipe rams, testing 9 5/8 casing to 4000 ~si. Pressure bled off 1~ psi in 30 min. Release pressure. 07:30 - 08:00 0.50 CASE DECO~P Unset R~S. Circulate through Top-Drive. 08:00 - 13:30 5.50 CASE DECOMP Retrieve RBP ~ 9515'. Flow check well-OK. POOH to 2747'. 13:30 - 15:30 2.00 CASE DECOMP Set RBP ~ 2747', P/U and set R~S ~ 2712'. AEempt to test be~een packers. RSP leaking. Reset RBP { 2756' and R~S ~ 2743', Pressure up to 4000 psi bebeen packers. RBP still leaking off slowly. Bled off pressure. Line up to pump down Kill line. Pressure up above R~S to 4060 psi. Held test for 30 minutes with 4000 psi final pressure. Release packers. 15:30 - 17:30 2.00 CASE DECOMP POOH with R~S and RBP. ED same. 17:30- 18:00 0.50 CASE DECO~P Clean Rig Floor. 17:30 - 20:00 2.50 CASE PACK DECO~P ~/U HES Type" N "Quick RBP. TIH on 4" DP to 2785'. 20:00 - 21:00 1.00 CASE PACK DECOMP Set RPB ~ 2785'. Close Top DPR. Test 9 5/8" casing to 4000 psi. Lost 75 psi in 30 minutes ( Pressure ~atiine the last 15 ~inutes of test ). 9eld off pressure. Open well. 21:00- 23:00 2.00 CASE DECOMP POOH with 4" DP. 23:00 - 00:00 1.00 CASE DECOMP P/U one joint of 7 5/8" casing and set in rota~ table. Dump 21 cu~ ( 50' ) of OEawa sand on top of RBP, 2/20/2001 00:00 - 00:30 0.50 WHSUR DECOMP Held PJSM prior to N/D BOP's. Printed: 4/12/2001 9:34:59 AM Legal Well Name: NGI-04 Common Well Name: NGI-04 Spud Date: 2/10/2001 Event Name: WORKOVER Start: 2/9/2001 End: 3/11/2001 Contractor Name: NABORS Rig Release: 3/11/2001 Group: RIG Rig Name: N^BORS 9ES Rig Number: 2/20/2001 00:30 - 04:00 3.50 WHSUR DECOMP N/D BOP and secure, Change xo on Top-Drive to 4 1/2" IF, 04:00 - 06:30 2,50 WHSUR DECOMP N/D 7" Tubing spool, 06:30 - 08:00 1.50 WHSUR DECOMP M/U BOT 9 5/8" Spear assembly. 08:00 - 08:30 0.50 WHSUR DECOMP Held PJSM prior to spearing and pulling on casing, 08:30 - 12:00 3,50 WHSUR DECOMP Spear 9 5/8" casing at the wellhead, Pull 350k on the 9 5/8" casing with 8" of casing stretch, The old pack-off seals came up half way out of the wellhead, The Vetco Rep and Rig Crew were able to remove the complete pack-off assemble plus the top plate on the 9 5/8" casing slips, Three attempts were made to pull the casing slips free with no success. Maxium pull on the 9 5/8" casing was 400k with 12" of casing stretch,The old 9 5/8" casing slips were reset with 219k wt above the calculated casing string wt from 2367', The casing was centered up perfect in the wellhead at this point. The new 9 5/8" pack-off seal assembly with have to be machined down 3/8" on the bottom to make it fit correctly, 12:00 - 16:00 . 4.00 WHSUR DECOMP Machining new pack-off seal for installation, Release 9 5/8" spear, IJD spear assembly. Place new Vetco/Gray GEN II 13 5/8" 5M wellhead in cellar area. 16:00 - 22:00 6.00 WHSUR DECOMP Dress 9 5/8" casing stub. Install new pack-off seal assembly, Install the new Vetco/Gray 13 5/8" 5M GEN II Tubing spool, 22:00 - 22:30 0.50 WHSUR DECOMP Test pack-off to 3500 psi for 30 minutes with no leaks, Test was APl, 22:30 - 00:00 1,50 BOPSUR DECOMP N/U 13 5/8" 5M BOP's, 2/21/2001 00:00 - 01:30 1.50 BOPSUI~ DECOMP Finish N/U BOP. Clean up cellar area, 01:30 - 02:30 1,00 BOPSUR DECOMP Run test plug on 4" DP, Test BOP against new GEN II tubing spool to 5000 psi for 30 minutes with no leaks, 02:30 - 04:00 1.50 BOPSUR DECOMP R/D test joint and plug, Test 9 5/8" casing to 3000 psi for 30 minutes with no leaks, 04:00 - 05:00 1.00 wHSUR DECOMP Install wear bushing, 05:00 - 09:30 4.50 CLEAN DECOMP M/U 8 1/8" RCJB, TIH on 4" DP to 2727', Tag up on sand plug above RBP. Dry drill 2' to 2729', 09:30 - 11:30 2.00 CLEAN DECOMP POOH. L/D RCJB, No junk or debris found in RCJB, 11:30 - 13:00 1.50 CLEAN DECOMP M/U Halliburton RBP retrieving tool, TIH to 2727', 13:00 - 14:00 1,00 CLEAN DECOMP Break circulation, Close Hydril, Line up to reverse circulate, Wash out sand above RBP to 2785' @ 3 bpm w/210 psi, 14:00 - 15:30 1,50 CLEAN DECOMP Open well. Circulate direct, Pump Hi-vis sweep, Circulate hole clean @ 9.5 bpm w/310 psi, Latch onto RBP @ 2785' and release, CBU, Flow check well-OK, Pump slug, 15:30 - 17:30 2,00 CLEAN DECOMP POOH with 4" DP. L/D RBP, 17:30 - 18:00 0.50 CLEAN DECOMP Clean and clear Rig Floor, 18:00 - 20:30 2,50 CLEAN DECOMP M/U 5 3/4" RCJB and Boot basket assembly, TIH to 3800'. 20:30 - 21:30 1.00 CLEAN DECOMP Slip and cut 85' of Drill line, Reset and check C-O-M, 21:30 - 00:00 2,50 CLEAN DECOMP Continue TIH w/RCJB ( 7800' @ Midnight ). 2/22/2001 00:00 - 00:30 0,50 CLEAN DECOMP Finish TIH w/RCBJ assembly to 9191', Break circulation, Wash down to 9610', Tag-up on obstruction, 00:30 - 03:00 2.50 CLEAN DECOMP Circulate and work RCJB down to top of 7" liner @ 9623', Work Junk Baskets. Drop ball for RCJB. Wash down inside of 7" liner ( tagged sand plug @ 9628' ) to 9631'. Work RCJB and Junk Baskets, POOH above the 7" liner top @ 9623', 03:00 - 05:00 2.00 CLEAN DECOMP Pump a 25 bbl Hi-vis sweep. Circulate hole clean from 9623' w/334 GPM @ 935 psi. 05:00 - 05:30 0.50 CLEAN DECOMP Monitor well for 30 minutes, Held PJSM regarding L/D drill pipe. 05:30 - 17:30 12,00 CLEAN DECOMP Pump slug, POOH L/D all 4" DP and BHA, 17:30 - 18:30 1.00 CLEAN DECOMP Dump RCJB and Boot Baskets. Found one Jet Nozzel and small pieces Printed: 4112/2001 9:34:59AM Legal Well Name: NGI-04 Common Well Name: NGI-04 Spud Date: 2/10/2001 Event Name: WORKOVER Start: 2/9/2001 End: 3/11/2001 Contractor Name: NABORS Rig Release: 3/11/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: ~:~;~:~::~:.;~;:~/:.~;~:~:~:~::~:~:~:::~:;:::*;:~:~::~::::: :,:~>~?~,~:~s.,:-:?~::::~:::::~::::.:~:.::...: :*: ~":::: :":::: .<.c ........... · ,:. .~: ............. · - ~,- 2/22/2001 17:30 - 18:30 1.00 CLEAN DECOMP of metal debris. Clean Rig Floor. 18:30 - 19:00 0.50 BOPSUIq COMP Pull wear bushing. Run test plug. 19:00 - 20:30 1.50 BOPSU~ CO~P Install 7 ~/8" casing rams and test to 5000 psi. ED test plug. 20:30 - 21:30 1.00 CASE CO~P EU to run 5.5" Tail pipe assembly. 21:30 - 22:30 1.00 CASE COaP Held PJSM. Ran 5.5" Tail pipe assembly with WLIG, "XN" and "X" nipples + 5.5" x 9 5/8" ~OT "S-3" Packer and xo. 22:30 - 00:00 ~.50 CASE COMP ~U 7 5/8" 3~0 ton casing and Torque-Turn equipment. 2/23/2001 00:00 - 00:00 24.00 RUNCO~ COMP PJSM. Run 7 5/8", 29.0~, L-80, ST-L tubing completion, Ran w/ Torque-Turn. Used collar clamp on each it. PJSM, MU SSSV w/dual control lines. Continue RIH. Spill Drill: OS-1:45 rain; Fire Drill: OS-70 sec. 2/24/2001 00:00 - 04:30 4.50 RUNCOI CO~P Finish RIH w/tbg, Ran total of 229 its 7 5/8", 29,0~, L-S0, ST-L, IPC tbg. PUW: 284k; SOW: 194k. Ran total of 57 SS bands. PU hanger. 04:30 - 05:00 1.50' RUNCO~ COMP aU landing it. RD casing tools. 06:00 - 07;00 1.00 RUNCO~ COMP RU CL to hanger. Test to 5500 psi-OK. Bleed off. AEempt to land hanger. SeRing down 6" high. 07:00 - 09:00 2.00 RUNCO~ EHGR CO~P A~empted to land tbg hanger several times. Pulled hanger back to floor. Had cut upper seal from tbg hanger. Removed remainder of upper seal. 09:00 - 10:30 1.50 RUNCO~ ~ COaP Landed tbg. RILDS. BO landing it, Set ~C, 10:30 - 13:00 2.50 BOPSUF COMP ND & stand back BOP. 13:00 - 16:30 3.50 WHSUR CO~P Redress upper hanger seals. Install adapter flange and tree. Test hanger void, control lines, and tree to ~000 psi each-OK. 16;30 - 18:30 2.00 WHSUR CO~P Pull ~C w/lubricator. RU to reverse circulate. 18:30 - 22:30 4.00 RUNCO~I COMP PJSM Test lines to 4000 psi. Revere circ well w/500 bbls clean 8.8~ brine. Follow w/124 bbls inhibited brine, 3 bpm w/300 psi. 22:30 - 00:00 1,50 RUNCO~I COMP RU Li~le Red. Test lines to 4500 psi. Pu~p 80 deg diesel down annulus. 2/25/2001 00:00 - 01:00 1.00 RUNCO~I COMP Finish pumping diesel & U-Tube to tbg. 01:00 - 04:30 3.50 RUNCO~I COMP Drop rod/ball and wait. Pressure tbg to 4000 psi (900 annulus). Held for 30 min-OK (pressure down to 3890 psi). Bled pressure to 1500 psi (300 annulus). Pressure annulus to 3700 psi and communicated to tbg (2400 tbg). Bled off all pressure. Pu~p down annulus ~ 1100 psi w/returns f/ tbg. Bled off all pressure. 04:30 - 08:00 3.50 RUNCO~ACK COMP Discussed options w/Rig team, Anchorage team, Wells group, and se~i~ contractors, 08:00 - 12:00 4.00 RUNCOI ~ACK COMP Pressure tbg to 4500 psi (Ann 980). Bled tbg to 1500 psi. Pressure annulus to 4000 psi. Tbg looked like it would be steady ~ 2350, but within 10 minutes had equalized to 3375 on ann w/3000 on tbg, Bled off ann. Pressure tbg to 5000 psi (Ann 2300). Bled tbg to 1500 (Ann 1600). Pressure ann to 4000 psi (tbg 2450). Within 1 min ann ~ 3600 psi w/tbg ~ 2800. Bled off pressure. 12:00 - 19;30 7.50 PULL PACK DECOaP RU HES slickline unit. Made three slickline runs. Pull SSSV dum~y, Pull bail/rod. Pull RHC plug, RD HES. 19:30-20:00 0.50 PULL PACK DECOMP Set BPV. 20:00- 21:30 1.50 PULL PACK DECOMP ND tree. 21:30- 00:00 2.50 PULL PACK DECOMP NU BOPE. 2/26/2001 00:00 - 06:00 6.00 PULL PACK DECOMP RU test tools. Test BOPE to 250 / 5000 psi; annular to 250 / 3500 psi. Witnessing waived by John Crisp-AOGCC Field Inspector. Blow down lines & RD tools. 06:00 - 07:30 1.50 PULL PACK DECOMP Pull test da~. RU DSM w/lubricator, Pull BPV, RD DSM, 07;30 - 10;00 ~.50 PULL PACK DECOMP Change out elevator bales, Clear floor, PU landing it, MU XO's, HaS Drill; OS-2:50 min. Printed: 4/1212001 9:34:59AM ¢~irr~:~!~i:~¢~ ~ :i~ ::~ 5 i!.~i~: ;:~:::~ i.'~:~:~?~ ~::::~ :...:~: 2i~::.';.':::::~;.i~; .;.::.J: Legal Well Name: NGI-04 Common Well Name: NGI-04 Spud Date: 2/10/2001 Event Name: WORKOVER Start: 2/9/2001 End: 3/11/2001 Contractor Name: NABORS Rig Release: 3/11/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: ~i'iB~ :~...,..:Bescn, tlon;,o !;Operations , 2D6/2001 10:00 - 10:30 0.50 PULL PACK DECOMP PJSM w/SWS on rig up & cutting ops. 10:30 - 11:00 0.50 PULL PACK DECOMP Screw into hanger. BOLDS. Pulled to 355k ~i~. Unseated hanger & had tbg stretch. No packer movement. 11:00- 15:30 4.50 PULL PACK DECOMP RU SWS. RIHw/47/16"jetcu~er. Pull 50k over up weight. Tie-into jewelw. Cut 5.5" tbg pup ~ 9483'. Good indication of cut at su~ace. POH & RD SWS. 15:30 - 18:00 2.50 PULL PACK DECOMP RU to cim. Unseat hanger. Reveme diesel to outside tank. Swap sides. Circ till clean returns. Continue cim suCa~ to suCa~ to pits. Monitor well-OK. Spill Drill; OS-70 sec. 18:00 - 20:00 2.00 PULL PACK DECOMP RU ~sing tools & Camco spoolers. Pull hanger to floor & LD. PJSM. Employee pinched finger while blowing down top drive--see Remarks section. 20:00 - 00:00 4.00 PULL PACK DECOMP Sta~ LD 7 5/8" tbg w/nubbins & collar clamp. Control line snagging in stack. Having to watch closely to keep control line from bailing up. 2/2W2001 00:00 - 14:00 '14.00 PULL PACK DECOMP Continue POH w/tbg, spooling control line. Control line broken in pla~s and bands missing. CL sheared 3 its above SSSV. Lost 42 SS bands in hole. Rat's nest of control line ~ SSSV, LD SSSV. Remove slips and clean out CL as best as possible. Continue POH. D1 Drill-OS-1 min. Fire Drill-OS-1 min. 14:00- 16:00 2.00 PULL PACK DECOMP Onjt¢ll5, Iower shackle on singlejtelevatom failed, allowing elevatom & slings to fall to the top of the slips. Had stand down and held investigation. Changed out all shackles and slings in the assembly. See LCIR ~24209. 16:00-22:30 6.50 PULL PACK DECOMP LD remainder of tbg w/ 5.72'--5.5" tbg stub. 22:30 - 00:00 1.50 PULL PACK DECOMP Clear & clean rig floor. RD casing tools. Changing bails and elevatom. 2/28/2001 00:00 - 01:00 1.00 PULL PACK DECOMP Finish RU DP handling tools. 01:00 - 03:30 2.50 BOPSUF.PACK DECOMP Flushed stack w/po~ed sub while rotating & reciprocating. AEempted to fish SS control line out of stack. Recovered some, but most fell down hole. 03:30- 05:00 1.50 BOPSU~ PACK DECOMP Change rams to variables. 05:00 - 06:00 1.00 BOPSU~ PACK DECOMP Test pipe rams & doom to 350 / 5000 psi-OK. 06:00- 07:00 1.00 BOPSU~ PACK DECOMP Set wear ring & mousehole. 07:00- 07:30 0.50 BOPSUR PACK DECOMP Se~ice top drive. 07:30 - 12:00 4.50 FISH PACK DECOMP PU & MU packer milling BHA. PU 9-6.5" DC's & 21-5" HWDP. Change elevatom to 4". Fire Drill; OS-1:10 min. 12:00 - 19:30 7.50 FISH PACK DECOMP Single in 4" DP. Rabbit all pipe, D1 Drill; OS-1:30 min. 19:30- 00:00 4.50 FISH ' PACK DECOMP Tagged up on packer ~ 9474' (DPM). Began milling on tbg stub & packer. Milled to 9476'. 3/1/2001 00:00 - 03:30 3.50 FISH PACK DECOMP Milled packer to 9484'. Pushed down hole to 9~0' (WLEG ~ -9608'). 03:30 - 05:00 1.50 FISH PACK DECOMP Circ HiWis sweep around. 20 rpm; 465 gpm; 1500 psi. 05:00- 09:00 4.00 FISH PACK DECOMP Monitor well. Pull 1 std. Blow down. Pull 65 stds, D1 Drill; OS-2 min. 09:00 - 10:00 1.00 FISH DECOMP Held safety stand down w/all pemonnel. AEended by Jim Denney & Fri~ Gunkel. Covered incidents, accidents, & fatalities in BP operations. 10:00- 12:00 2.00 FISH PACK DECOMP POH to BHA. 12:00 - 14:00 2.00 FISH PACK DECOMP Stand back BHA. LD mill & boot baskets, Boot baskets full of-6 gals metal & rubber cuttings. Clear floor. Spill Drill; OS-1:45 min. 14:00- 15:30 1.50 FISH PACK DECOMP MU spear fishing assembly & BHA. 15:30 - 16:30 1.00 FISH DECOMP Held safety stand down w/all personnel. Covered incidents, accidents, & fatalities in BP operations. 16:30 - 18:00 1.50 FISH PACK DECOMP Cut & slip 79' drlg line. Sewi~ draw works. 18:00- 20:30 2.50 FISH PACK DECOMP RIH to top offish ~ 9540'. POW: 212k; SOW: 145k, 20:30 - 21:00 0.50 FISH PACK DECOMP Spear into packer. Push down 18' to 9557'. Stack 25k down. Pulled 30' Printed: 4/12/2001 9:34:59AM Legal Well Name: NGI-04 Common Well Name: NGI-04 Spud Date: 2/10/2001 Event Name: WORKOVER Start: 2/9/2001 End: 3/11/2001 Contractor Name: NABORS Rig Release: 3/11/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: 3/1/2001 20:30 - 21:00 0.50 FISH PACK DECOMP free. Tight spot. Bled off jars. Pulled 275k to free up. Continue up dragging 20k to 40k on occasion. 21:00- 00:00 3.00 FISH PACK DECOMP Start POH slowly. Hanging up occasionally. 3/2/2001 00:00 - 07:00 7.00 FISH PACK DECOMP Continue POH slowly. Fish dragging quite often. Hung up @ lower FO collar (2573'). Worked free w/100k over. Hung up @ upper FO collar ( 2542') Worked free w/100k over. Continue POH to BHA. 07:00 - 11:00 4.00~ FISH PACK DECOMP Monitor well. Change elevators. Stand back HWDP & DC's. LD fish. Broke tail pipe down w/iron roughneck ( Baker locked connections). Spill Drill; OS-1:40 min. 11:00 - 12:30 1.50 CLEAN DECOMP Clear floor. Replace driller side manrider cable. 12:30- 17:00 4.50 CLEAN PACK DECOMP MU 8.5" RCJB BHA. RIH w/DC's & HWDP. 17:00- 21:00 4.00 CLEAN PACK DECOMP RIH w/rig tongs while repair Iron Roughneck. Continue RIH w/ Roughneck to 9590'. 21:00 - 22:00 1.00 CLEAN PACK DECOMP Wash down. Tag up @ 9606'. Wash down to 9623'. 22:00 - 00:00 2.00 CLEAN PACK DECOMP Drop ball f/RCJB. Pump sweep around @ 6.5 bpm w/1500 psi. Circ clean. Monitor well-OK. Fire Drill; OS-2 min. POW: 210k; SOW:150k, Rot: 175k. 3/3/2001 00:00 - 04:00 4.00 CLEAN PACK DECOMP POH w/RCJB. Hit tight spot @ 6726'. Checked up & down, didn't see anything. POH to HWDP. 04:00- 07:30 3.50 CLEAN PACK DECOMP Monitor well. Change elevators. Stand back HWDP & DC's. LD RCJB & boot baskets. Recovered 2 1/2 slip segments, cone pieces, and assorted other large pieces, with numerous small pieces from RCJB. Boot baskets full of sand, metal cuttings, & small pieces. 07:30 - 09:00 1.50 CLEAN- PACK DECOMP Service blocks, crown, Iron Roughnech, and top drive. 09:00 - 10:30 1.50 CLEAN PACK DECOMP MU 9 5/8" RTTS & finger sub. RIH on BHA. 10:30- 12:30 2.00 CLEAN PACK DECOMP Change elevators. RIH to 3085'. D1 Drill; OS-2:55 min. 12:30 - 13:00 0.50 CLEAN PACK DECOMP Set RTTS. Test casing (FO collars) to 4000 psi f/15 min-OK. Release RTTS. 13:00- 15:30 2.50 CLEAN PACK DECOMP RIH to 9610'. PU & set R'IFS @ 9584'. 15:30 - 17:00 1.50 CLEAN PACK DECOMP Set RTTS. Test 9 5/8" casing to 4000 psi f/30 min-OK (lost 100 psi). Release RTTS. 17:00 - 20:30 3.50 CLEAN PACK DECOMP Monitor well-OK. POH w/4" DP. D1 Drill; OS-2:10 min. 20:30- 22:00 1.50 CLEAN PACK DECOMP Change elevators. Stand back HWDP. LD RTTS. Clear floor. 22:00 - 23:30 1.50 CLEAN DECOMP MU BHA-6" RCJB. RIH w/collars & HWDP. 23:30- 00:00 0.50 CLEAN DECOMP Change elevators. Start RIH. 3/4/2001 00:00 - 05:00 5.00 CLEAN PACK DECOMP RIH w/6" RCJB. 05:00 - 08:00 3.00 CLEAN PACK DECOMP Break circ. PU: 215k; SO: 154k; Rot: 180k. Circ 100 spin (245 gpm) w/ 585 psi. Tag up @ 9610'. Wash & rotate to 9615'. PU & drop ball. Wash & rotate to 9621'. Work into liner top & wash to 9627'. Rotary 60 rpm; Torque off: 6,000-8,000; Torque on: 10,000-13,000. Sticky f/9625' to 9627'. Hanging up on occassion. Jar free once. Unable to work deeper. PU out of liner. 08:00 - 10:00 2.00 CLEAN PACK DECOMP Circ Hi-Vis sweeps surface/surface. 340 gpm w/1500 psi. H2S Drill; OS-2:25 min. 10:00- 12:00 2.00 CLEAN PACK DECOMP Monitor well. Pump dry job. Blowdown. POH to 6000'. 12:00 - 13:30 1.50 CLEAN PACK DECOMP Cut & slip 95' drlg line. Service top drive & draw works. 13:30- 16:00 2.50 CLEAN PACK DECOMP POH to HWDP. 16:00- 17:30 1.50 CLEAN PACK DECOMP Change elevators. Stand back HWDP & DC's. LD RCJB & boot baskets. Some sand & metal in boot baskets. RCJB 3/4" full of metal. Included 1/2 slip segment & numerous fairly large pieces. Bottom was plugged w/what appears to be a complete slip cone. 17:30- 19:00 1.50 CLEAN PACK DECOMP MU new burn shoe and a circ sub. MU BHA. 19:00-22:30 3.50 CLEAN PACK DECOMP RIH to 9580'. Printed: 4/12/2001 9:34:59 AM Legal Well Name: NGI-04 Common Well Name: NGI-04 Spud Date: 2/1012001 [vent Name: WORKOVfR Start: 2/0/2001 find: 3/11/2001 Contractor Name: N^BORS Rig Release: 3/11/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: 3/4/2001 22:30 - 00:00 1.50 CLEAN PACK DECOMP Wash down to 9618' & tag up. Drop ball & activate RCJB. Wash & rotate to 9655' w/no problems. Bottom scraper out on liner top. Pump 2 Hi-Vis sweeps @ 140 spm while rotate & recip. PU:230k; SO: 153k; ROT: 180k. Tq off: 8,000 @ 60 rpm. H2S Drill; OS-2:20 min. 3/5/2001 00:00 - 00:30 0.50 CLEAN PACK DECOMP Finish pumping Hi-Vis sweep around. 00:30 - 02:00 1.50 CLEAN PACK DECOMP Drop dart. Pump down. Open circ sub. Increase rate to 485 gpm wi 1250 psi. Pull up out of liner. Pump Hi-Vis sweep. PU: 230k; SO: 153k; ROT: 180k; 35 rpm. 02:00 - 11:00 9.00 CLEAN PACK COMP Monitor well. Pump dry job. Blow down. LDDP. 11:00 - 14:30 3.50 CLEAN PACK COMP Change elevators. LD HWDP, DC's, & BHA. Empty baskets. Recovered 1 piece of control line & 1 medium size piece of metal. Clean & clear floor. Fire Drill; OS-2:00 min. 14:30 - 15:30 1.00 RUNCOI~ACK COMP Clear floor. Pull wear ring. Set test plug. 15:30 ~ 16:30 1.00 RUNCOI~ACK COMP Change top rams to 7 5/8". 16:30 - 17:30 1.00 RUNCOI~ ~ACK COMP Test 7 5/8" rams & door seals to 250 / 5000 psi-OK. 17:30- 18:00 0.50 RUNCOI~ACK COMP RU tubing tools. 18:00- 18:30 0.50 RUNCOI~ACK COMP PJSM w/all personnel. 18:30 - 19:00 0.50 RUNCOI~ACK COMP MU 7" tail pipe & packer assembly. 19:00 - 20:00 1.00 RUNCOI~PACK COMP Change over to 350T equipment w/single jt elevators. 20:00 - 00:00 4.00 RUNCOI~PACK COMP PU 7 5~8" ST-L completion string. Fire Drill; OS-1:35 min. 3/6/2001 00:00 - 04:30 4.50 RUNCOI~PACK COMP Run total 41 Jts. Tubing - Inspect lifting equip. 04:30 - 05:00 0.50 RUNCOI~13ACK COMP Fluid unbalanced - running over tubing - pump dry job 05:00 - 13:00 8.00 RUNCOI~PACK COMP - Continue running tubing, 179 Jts. run, Up and down weights within parameters, periodicly inspect lifting equipment 13:00 - 14:00 1.00 RUNCOI~PACK COMP Run Camco SCSSSV. PJU Camco to run control lines. Connect to SCSSSV and test to 5000 psi. 14:00 - 20:30 6.50 RUNCO~ PACK COMP Continue running Tubing with Dual control lines, banding every Jt. 20:30 - 23:00 2.50 RUNCO~ PACK COMP Tagged with Jt. # 232. Measurements indicate No-Go is on top of liner. PJU XO, and circ line to verify. Worked tubing while circulating, observed no pressure change into liner nor when No-Go on top of liner. Lay Dn. Tubing jt and PJU DP pup and top drive. Turned pipe at tag to re -confirm No-Go at liner top. 23:00 - 00:00 1.00 RUNCO~ACK COMP Rig down DP pup & XO. Blow dn. top drive. 3/7/2001 00:00 - 03:30 3.50 RUNCO~ACK COMP Finish space out. Change out elevators. MU hanger and landing jt. MU control line. Test to 5000 psi-OK. Land tbg and BO landing jt. 03:30 - 04:00 0.50 BOPSUF,PACK COMP Set BPV. Test f/below to 500 psi-OK. 04:00 - 05:30 1.50 BOPSUF~PACK COMP ND and set stack back. 05:30 - 07:00 1.50 WHSUR PACK COMP Install upper body seal on tbg hanger. Spill drill; OS-2:10 min. 07:00 - 08:00 1.00 WHSUR PACK COMP RU & test hanger void to 5000 psi-OK. 08:00 - 12:30 4.50 BOPSUi; PACK COMP NU stack. Change upper rams to variable. Install riser. 12:30 - 16:00 3.50 BOPSUI; PACK COMP Test BOPE to 250 / 5000 psi; annular to 250 / 3500 psi. Witnessing waived by Jeff Jones--AOGCC Field Inspector. 16:00 - 18:00 2.00 BOPSUI; PACK COMP Pull blanking plug w/T-bar. Pull BPV w/DSM lubricator. 18:00 - 20:00 2.00 RUNCOI~F~ACK COMP RU HES SL. RIH & retrieve SSSV dummy @ 2209'. Took two trips to retrieve. 20:00 - 00:00 4.00 RUNCOI~PACK COMP Make two attempts to pull RHC plug @ 9603' with no success. RIH f/ third attempt. H2S drill; OS-2:20 min. 3/8/2001 00:00 - 03:00 3.00 RUNCOI~F)ACK COMP Made 3rd SL run f/RHC plug w/no recovery. Recovered plug on 4th attempt. RD HES. 03:00 - 05:00 2.00 CLEAN PACK COMP Prep to PU BHA. Pull tools to floor. Change out elevators & handling tools. 05:00 - 08:00 3.00 CLEAN PACK COMP MU cleanout BHA. Circulate through BHA. Assembly will swallow fishing neck on IBP. Blow down top drive. Change out handling tools. Printed: 4/12/2001 9:34:59AM 'r Legal Well Name: NGI-04 Common Well Name: NGI-04 Spud Date: 2/10/2001 Event Name: WORKOVER Start: 2/9/2001 End: 3/11/2001 Contractor Name: NABORS Rig Release: 3/11/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: 3/8/2001 08:00 - 16:00 8.00~ CLEAN PACK COMP Single in 4" DP to Tag @ 9652'. PU. D1 Drill; OS-2:15 min. 16:00 - 00:00 8.00 CLEAN PACK COMP RU to reverse circ. Reverse to 9660'. CBU. Made.connection. Reverse to 9662' and plugged off. Circ & cleared up. Made three more attempts to reverse and either plugged off totally or partially. Attempted pump rates f/4.5 to 7 bpm. Circulate & wash down to 9665' pumping 9 bpm. Circ sweep around. Recovered sand & a couple of small pieces of · rubber. Reverse down to 9701'. Reverse sweep around @ 7.5 bpm w/ 1450 psi. D2 Drill; OS-1:25 min. 3/9/2001 00:00 - 03:30 ! 3.50 CLEAN PACK COMP Reverse circulate and wash down to IBP @ 9786. Reverse circ. Hi Vis sweep @ 320 GPM - 1400 psi. Returns clean. Monitor well Stable & dead 03:30- 10:30 7.00 CLEAN PACK COMP POH. L/D Baker tools. 10:30 - 00:00 13.50 CLEAN PACK COMP PJSM. PJU HES slickline. #1 'Run: Equalizing Latch tool, tag @ 9936.- unable to latch. POH #2 run: LIB - partial impression of fishing neck on Iow side. #3 run: Latch tool with oversized guide and centralizer - unable to latch. POH. #4 run: Latch tool with Knuckle joint - Latched IBP. Pull up slowly 100 ft. with 100 lbs. drag. Monitor well 15 minutes - stable. POH slowly while circulating through choke and constantly monitoring returns. No Losses - No Gains. Pull to surface with IBP complete. I./D same. 3/10/2001 00:00 - 01:30 1.50 RUNCOI~PACK !COMP RIH w/RHC plug- set in RN nipple @ 9603' POH. 01:30 - 02:30 1.00 RUNCOr PACK COMP RIH w/dummy valve and set in SSSV @ 2209'. Test Camco control lines to dummy to 5000 psi. 02:30 - 04:00 1.50 RUNCOr PACK COMP Rig Down HE$ slickline & Lubricator, clear floor. 04:00 - 17:30 13.50 CLEAN PACK COMP Lay down 2 3/8" tubing and 4" DP 20 stands at a time ( Had 103 stands of 4" DP total in derrick ). 17:30 - 18:30 1.00i RUNCOr PACK COMP Cut and slip drilling line 87'. 18:30 - 00:00 5.50 CHEM PACK COMP Rig up Circulating lines to Wellhead and Tubing & test. Reverse circ. clean 8.8 ppg brine @ 3 BPM - 200 psi. 3/11/2001 00:00 - 02:00 2.00 CHEM PACK COMP Complete reverse circulating 500 bbls. clean brine followed by 124 bbls. Corexit treated brine @ 3 BPM 200 psi. NO gains or losses. Shut down & blow down circ lines. 02:00 - 05:30 3.50 WHSUR COMP PJU Hot Oilers, test lines - Wing valve on tubing head leaking. Inject grease, still leaking. Install LO torque valve upstream & test to 4000 psi - OK. 05:30 - 08:30 3.00 RUNCOI~ACK COMP Reverse circulate 138 bbls. diesel Down 9 5/8" csg. X 7 5/8" tbg. annulus. Pumped at 2 BPM. Pressure From 175 psi pumping at start to 775 psi. diferential when hot oiler shut down. Allow to U - Tube; then 0 pressure ann./tbg. 08:30- 09:00 0.50 RUNCOI~I~ACK COMP Drop Ball/Rod. Hold PJSM. 09:00 - 12:30 3.50 RUNCOI~PACK COMP Pres. Tbg. to 3500 psi and hold for 10 minutes. Bleed off slowly to 0 psi. Repeat same 3 times to ensure packer set. On 3rd. time: hold 3500 psi on Tbg. for 30 min. then bleed to 1500 psi and lock in. Pressure 9 5/8" X 7 5/8" Annulus to 4000 psi and hold for 30 minutes. All tests APl. !Witnessed by Mr. Lou Grimaldi; AOGCC. 12:30 - 13:00 0.50 RUNCOI~ COMP Blow down & rig down all lines and valves. 13:00 - 13:30 0.50 WHSUR COMP Install BPV & Blank plug, test 1000 psi. 13:30 - 15:00 1.50 RIGD COMP N/D BOPE. 15:00 - 18:00 3.00 WHSUR COMP N/U adaptor flange and Tree. Test void and tree to 5000 psi. Install VR plug in Tubing head and pull blank plug from BPV. 18:00 - 20:00 2.00' RIGD COMP Secure tree. Blow down all pumps and lines, clean cellar, RIG RELEASED @ 20:00 HRS. Printed: 4112/2001 9:34:59AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~. \~\" DATE: April 14, 2001 CommissiOner t SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder /~r~~ BPX · P.I. Supervisor/~"' ~"- ' NGI Pad (~I~''~\ NGI-04 FROM: Jeff Jones PBU Petroleum Inspector PBF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. .. ,WellJ NGI.04 I Typelnj. J G I T.V.D. I '754~ JTubing 13350 13350 J 3350 I 3400 J ln[erValI O . p.T.D.I 175~069 ITypetesti P ITestpsiI 1886 I CaSingI 360 I 22251 2225 I 22201 P/F I P Notes: poSt casing hanger leak repair MIT WellI I Type,nj. I I T'V'D' I I Tubing I ' ' I I I I lntervall ..... P.T.D.I ITYpetestl' ' ITeStpsil 0 I Casing l I I I I P/F I Notes: WellI P..T.D.I Notes: WellI P.T.D.I Notes: WellI ' p.T.O.I Notes: Type testI I Test psiI0 I Casing I I I I I P/F I IType Inj. Type test Type Inj. Type test! Type INJ. Fluid Codes F = FRESH WATER IN J. 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 Saturday, April 14, 2001: I traveled to BPX's PBU well NGI-04 to witness an MIT following repair of a leaking production casing hanger. Joe Anders was the BPX representative in charge of testing. The pretest pressures were observed to be stable and the standard 30 minute pressure test was successfully performed. The test data above indicates this well is suitable for continued injection. Summary: I witnessed a successful MIT on BPX's PBU gas injector well NGI-04 in the Prudhoe Bay Field. M.I.T.'s performed: . 1_ Number of Failures: 0_ Total Time during tests: I hr. Attatchments: c.c: MIT report form 5/12/00 L.G. MIT PBU NGI-04 4-14-01 JJ 6/9/01 RE: NGI-04 Rig Workover Subject: RE: NGI-04 Rig Workover Date: Wed, 7 Feb 2001 18:50:06-0600 From: "PBU, Drlg Rig 9es" <PBUDdgRigges@BP.com> To: "Schmitz, Steve H (Fairweather)" <SchmitSH@BP.com>, '"tom_maunder@admin.state.ak. us'" <tom_maunder@admin.state.ak.us> Tom & Steve- 4" HT DP. Rams would be 3 1/2" x 6" variable & 2 7/8" x 5" variable. Tom .... Original Message--- From: Schmitz, Steve H (Fairweather) Sent: Wednesday, February 07, 2001 3:45 PM To: PBU, Drlg Rig 9es Subject: FW: NGI-04 Rig Workover Tom Anglen, Can you answer this question for Tom Maunder? Steve Schmitz ---Original Message--- From: Tom Maunder [mailto:tom maunder~.admin.state.ak, us] Sent: Wednesday, February 07, 2001 3:40 PM To: Schmitz, Steve H (Fairweather) Subject: Re: NGI-04 Rig Workover Steve, What drill pipe and ram combination(s) will be employed? Tom "Schmitz, Steve H (Fairweather)" wrote: > Tom Maunder, > I spoke to Tom Anglen concerning the ram configuration for the subject > workover. Anglen advises that Nabors 9ES will utilize dual 7" rams when > decompleting, dual g 5/6" rams when pulling/running the repair casing, and > 7 5/8" dual rams when running the new completion tubing. Steve Schmitz BP Alaska Drilling & Wells (907) 564-5773 Phone (907) 564.4040 Fax (907) 240-8094 Cell SchmitSH@bp. com I of 1 2/10/01 8:07 AM MEMORANDUM TO: THRU: FROM: Dan Seamo'unt'~'~ Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 23, 2000 SUBJECT: Mechanical Integrity Tests Blair Wondzell ~ Bpx P.I. SuperVisor ~/"z(c~ NGI John H. Spauldin,~r.~~ ,,~ 4 , Prudhoe Bay Unit Petroleum Inspect0t Prudhoe Bay Field NON-CONFIDENTIAL WellI NGI-04 P.T.D.I 175-069 Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: P.T.D.I Notes: WellI P.T.D.I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type lnj.I G I T.V.D. I 7417 I Tubing I 3450 I 3450 J 3450 I 3475 I lntervalJ 4 Type testI P I Testpsil !854 ICasingI 1200I 2300I 2300I 2325 I p/F I ~ IType Inj. Type test Type Inj. Type Type Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Excellent test!! Type Test M= AnnulUs Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) · I.T.'s performed: Attatchments: Number of Failures: 0 Total Time during tests: '1 hr, cc: none MIT report form 5/12/00 L.G. mit pbu ngi-6 7-23-00js.xls 8/7/00 .7 · .~ STATE OF ALASKA ~ ALASK~AND GAS CONSERVATION C('-'-'~SSION '~' REPORT, - SUNDRY WELL OPI:. ,ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging --- Perforate X Pull tubing , Alter casing ~ Repair well ~ Other ,, , 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 567' FNL & 1064' FWL, Sec., 12, T11N, R14E, UM At top of productive interval 1783' FSL & 232' FWL, Sec. 6, T11N, R15E, UM At effective depth 1930' FSL & 556' FWL, Sec. 6, T11 N, R15E, UM At total depth 1991' FSL& 693' FWL, Sec. 6, T11N, R15E, UM 5. Type of Well Development ---- Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 47 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-4(13-6-11-15) 9. Permit number/approval number 76-69/90-297 10. APl number 50 - 029-20183 11. Field/Pool Prudhoe Bay Oil Pool feet True vertical depth 113' 2711' 7786' 7555-8521' 390O 3900 Gas Injection Date //'O/,,~ ~"///~:) SUBMIT I1~ DUPLICATE' ~', 12. Present well condition summary Total depth: measured true vertical 11015 feet Plugs(measured) 8544 feet Effective depth: measured 10810 feet true vertical 8402 feet ~'±11~,measured) 10810 Casing Length Size Cemented Measured depth Conductor 113' 20" 240 sx Permafrost II 113' Sudace 2664' 13-3/8" 6000 sx Permafrost II 2711' Production 9894' 9_5/8,, ~ ,x ,o,r~f,o,t, 9941' 750 sx Class G Liner 1358' 7" 325 sx Class G 9624-10982' 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Perforation depth: measured 10216-10268'; 10329-10406'; 10410-10425'; 10441-10558'; 10574-10630'; 10639-10644'; 10662-10762'; 10819-10844' true vertical 7996-8033'; 8075-8130'; 8132-8143'; 8154-8233'; 8244-8281 '; 8287-8291 '; 8303-8370'; 8408-8426' Tubing (size, grade, and measured depth) 7", 29#, L-80, @ 9222' 5-1/2", 17#, L-80, @ 9222-9400' 4-1/2", 12.6#, N-80, @ 9400-9475' Packers and SSSV (type and measured depth) Baker SAS packer @ 9400'/Otis SSS~~ OCT 2 9 _ , nn~K~isSio~' Alaska 0il & BBs [;0ns Representatiye [)ally Averaoe Production or Injection Data ~.efet'ence OiI-Bbl Gas-Md Water-Bbl Casing Pressure ?ubia8 ?~:essure Prior to well operation Subsequent to operation 197M 210M 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X , 16. Status of well classification as: Oil Gas Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~(~ ~_ .~ Title SeniorAreaEngineer Form 1(~404 Rev 06/15/88 NGI-4 Work Summary On June 29, 1990 the following perforations were added in Well NGI-4. Interval, MD (BHCS 02/19/76) Interval Length Formation Name SPF 10216-10268' 52' Sag River 4 STATE OF ALASKA AL/~A OIL AND GAS CONSERVATION COM.,.,.~SION WELL COMPLETION OR RECOMPLETION REPORT AND REVISED* OIL r'~ GAS [--] SUSPENDED r~ ABANDONED [~ SERVICE ~'~ GAS INJECTION 2 Name of Operator ;7 Permit Number ARCO Alaska, Inc 75-69 3 Address i8 APl Number P.O. Box 100360~ Anchorage, AK 99510-0360 50-029-20183 4 Location of well at surface 9 Unit or Lease Name 567' FNL, 1084' FWL, SEC 12, T11 N, R14E UM *LOCATIONS CHANGED DUE TO PRUDHOE BAY UNIT At Top Producing Intewal GYRO SURVEYS BEING RERUN. 10 Well Number 1675' FSL, 307' FWL, SEC 6, T11N, R15E UM* NGI-4 At Total Depth 11 Field and Pool 1892'FSL, 766'FWL, SEC 6, T11N, R15E UM* PRUDHOE BAY FIELD , 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 47' .I ADL 34632 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 01/20/76. 02/19/76. 02/27/76**I N/A feet MSLI 1 11015' MD/8556' TVD 10898' MD/8475' TVD YES [~ NO r'"] 2207, feet MD 1900' (approx) 22 Type Electric or Other Logs Run DIL, BHCS/GR, CNL/CCL, GR/CCL, CBL,GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" · 94.0# H-40 SURF 103' 32" 240 SX PF II 13-3/8". 72.0# MN-80 SURF 2711' 17-1/2" 6000 SX PF II & TOP JOB W/400 SX PF II 9-5/8" 47.0# MN-80/S-95 SURF 9942' 12-1/4" 750 SX CLASS G &125 SX PF II 7" ' 29.0# MN-80 9624' 10982' 8-1/2" 350 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and BOttom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD} PACKER SET (MD) 10329'-10406'MD/8089'-814ZTVD W/4 SPF 7" / 5-1/2"/4-1/2" 9538' 9400' 10410'-10425'MD/8145'-8155q'VD W/4 SPF 10441'-10558'MD/8165'-8242q'VD W/4 SPF 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 10574'-10630'MD/8253'-8290q'VD W/4 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10639'-10844'MD/8297,-8300q'VD W/4 SPF N/A 10662'-10762'MD/8312'-8381"l'VD W/4 SPF 10819'-10844'MD/8420'-8437'TVD W/4 SPF 27 PRODUCTION TEST Date First ProdUction IMethod of Operation (Flowing, gas lift, etc.) 10/77. ~ INJECTION Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 03/02/87. 24 TESTPERIOD ~ 0 154,044 MCF 0 N/AI N/A Flow Tubing Casing Pressure CALCULATED' OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 3656 - 24-HOUR RATE ,~ 0 154,044 MCF 0 N/A 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED OCT O 91990 · *NOTE: PERFORATED WELL 6/19/77. ADDITIONAL PERFORATIONS 2/28/87. :~ ~';;:~ka .0i!.& Gas Cons. C0.mBlssj~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME ,,, Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SADLEROCHIT 10323' 8085' BASE SADLEROCHIT 10946' 8508' N/A · 31. LIST OF ATTACHMENTS REVISED GYROSCOPIC SURVEY (2 COPIES) :~2. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~//').~')qJ~.'/ ~ ~ Title DRILLING .~,,/~.LYST Date __f0'~-~O , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas:injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for,separate production from more than one interval (multiple completion), so state in item 16,. and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALA."i'KA: ]iNCh F'. 0 · BOX t ANC. HORAGE, ALASKA 995i 6, D A T E · '7 - '7.- 90 REF'ERE-NCFJ' ARCO CASED HOLE. FINALS N(;I--i 6- 28- 9,.':':, N(.;i .... 2 6 .... 28-96, N(.;I --Z 6- 29-- 9,.9 N(;I-4 6 .... 2 9-- 9,.9 NG 1-6 6-' ~':.)- 9 (') N. (; I - '7 7 - i '- 9 '::) N6;I-8 7-i -9'.9 NGI'-9 ?'-2-9':~' NE;I .... i(~ 7-4-9 F'L. IEASE SI(iN RECEIVED BY C 0 L t. A R / P E F;..' F' C 0 L L A R /F' E F,' F: C O I: L A R/' F:' E F;,' F' CC~LLAR/F'ERF COLLAR/F:'EF;.:F:' COI_LAR/F'EF(F C 0 L L A R / F' E R F C 0 L I_ A I".'../' F' Ii" F;,' I:: C:OLLAR/F'EF',',F HAVE A NICE DAY! SALI_Y HOFFECKER A T f'~ - 'i '~ '"' o OF' DATA. A 'f' L. A,:: ALLAY A 'f' I... A 2' ,'::, 'f' 1.. A £ r:~'f'l_A£ A 'i" L. A ,~.' A 'f L r:~ .? A 'f'L A :.; D!2TRIBUT]:ON '"' C F_' N T I;..'A i_ F: I I_IE'~'' · ,,-t:: H E V R 0 N · .IL · o · ,, E X'T E N ~';: l 0 N E: X P L 0 R A 1' I 0 N' · .- EXXON MARATHON · ., HO~L · ir °~, · ~ F'HILLIF'S F'B WELl.. F'ILE:S R & D ~ BPX .,- 2TATF OF ALA,'S'KA TEXACO STATE OF ALASKA ALAS!~"'~'~AND GAS CONSERVATION'"'-'~'~"tSSIOI~ ~ APPLIC i ON FOR SUNDRY APPROVALS 1. Type of Request: ~ Abandon :1 Operation shutdown -- Re-enter suspended well Alter casing Repair well Plugging -- Time extension Stimulate Change approved program Pull tubing Variance Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 567' FNL & 1064' FWL, Sec. 12, T11N, R14E, UM At top of productive interval 1783' FSL & 232' FWL, Sec. 6, T11N, R15E, UM At effective depth 1930' FSL & 556' FWL, Sec. 6, T11N, R15E, UM At total depth 1991' FSL & 693' FWL, Sec. 6, T11 N, R15E, UM 5. Type of Well Development -- Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 47 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-4 (13-6-11-15) 9. Permit number 75-69 10. APl number 50 - 029-20183 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 113' Surface 2664' Production 9894' Liner 1358' 11015 feet Plugs(measured) 8544 feet RECEIVE .? 10868 feet i~AY 0 3 ]gg~ 8442 feet Junk(measured) ~l~ska 0ii & Gas C0as, C0mmis$i Size Cemented Measured depth ~l~ilal'al~Elcal depth 20" 240 sx Permafrost II 113' 113' 13-3/8" 6000 sx Permafrost II 2711' 2711' 9-5/8" 125 sx Permafrost II + 750 sx Class G 9941' 7786' 7" 325 SX Class G 9624-10982' 7555-8521' Perforation depth: measured 10329-10406'; 10410-10425'; 10441-10558'; 10574-10630'; 10639-10644'; 10662-10762'; 10819-10844' true vertical 8075-8130'; 8132-8143'; 8154-8233'; 8244-8281'; 8287-8291 '; 8303-8370'; 8408-8426' Tubing (size, grade, and measured depth) 7", 29#, L-80 @ 9222' 5-1/2", 17#, L-80, 9222-9400' 4-1/2", 12.6#, N-80 @ 9400-9475' Packers and SSSV (type and measured depth)i~t<¢r ~AI5 p,¢~ ~ ~/~oo'/o~r.~ ~ v ~ .220"/' /~ t~ 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch x 14. Estimated date for commencing operation 15. Status of well classification as: May, 1990 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~'/~ ~~ Title Operations Engineering Manager FOR COMMISSION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~{~/ Gas Suspended gas injection well Date I Approval No. ~ ~ _ o~. P 7' Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston . ~q~,,missioner Approvt~Ct ~P~ Returnec~ SUBMIT IN TRIPLICATE NGI-4 Proposed Additional Perforations ARCO Alaska,/nc. ProPoses to add Perforations in Well NGI intervals are as follows: 4 The proposed er Interval, MD '' f, ~CS' /.~ ~,-,... Interv ~,,., P oration ~/76) ,.,.. al, ,,,u . ,uz~b. lO2~in) -- lnterval _ , __ - 1°2~h-' _Formation W°rk. A~I"~,~'~_~!reline lubri,.,~,,.... All Perf or ~?(~rn°sra~v?l~SbV~, llmb~ ;r~fe tewSittehdhtool lowwOrkc ? Perforating, g. pressure, will u with th .... ,,,_ arner type u ~ unnzec/ for '. e -,unoor In~,~.._, g ns at 4 ~,...- _ this gas injection will resume with the e --.~,,,~u with s,.-, .~,,,.,?s per toot. the wellbore formation. No flaring is anticipated, fluid ~o water. After Wellbore Icad being displaced into RECEIVEi? AJaska 0il & Gas Cons. Commission AnchoraFa ARCO Alaska, Inc. ~ Prudhoe Bay:~.,,gineering Post Office Box 100360 Anchorage, Alaska 99510'0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 31, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS NGI-4 Approval No. 8-217 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations formed on the above-referenced well. Very truly yours, D. F. S cheve DFS/JMV/jp At t a chment cc: Standard Alaska Production Company J. Gruber, ATO-1478 PI(DS NGI-4)W1-3 detailing work per- RECEIVED WELLS2/60 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASi'... ulL AND GAS CONSERVATION COMb, .~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown % Stimulate ~ Plugging ~ Perforate -- Pull tubing Alter Casing ~ Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AE 99510 Location of well at surface 567' FNL & 1064' FWL, Sec. 12, TllN, R14E, UM At top of productive interval 1783' FSL & 232' FWL, Sec. 6, TllN, R15E, UM At effective depth 1930' FSL & 556' FWL, Sec. 6, TllN, R15E, UM At total depth 1991' FSL & 693' FWL, Sec. 6, TllN, RI'5E, UM 5. Datum elevation (DF or KB) 47 ' RKB Feet 6. Unit or Property name Prudhoe Ba~z Unit 7. Well number NGI-4 (13-6-11-15) 8. Approval number 8-217 9. APl number 50-- 029-20183 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth' measured true vertical Effective depth: 11015 8544 Casing Conductor Surface Production measured 10868 true vertical 8442 Length Size 113' 20" 2664' 13-3/8" 9894' 9-5/8" Liner 1359' 7" feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth 240 sx Permafrost II 113' 6000 sx Permafrost II 2711' 125 sx Permafrost II 9941' + 750 sx Class G 325 sx Class G 10982' 113' 2711' 7786' 8521' Perforation depth: measured true vertical 10329-10406'; 10410-10425'; 10441-10558'; 10574-10630'; 10639-10644'; 10662-10762'; 10819-10844' 8075-8130'; 8132-8143'; 8154-8233'; 8244-8281'; 8287-8291'; 8303-8370'; 8408-8426' ~bing(size, gradeand measured depth) 7", 29#, L-80 @ 9222' 5½", 17#, L-80 @ 9414' Packers andSSSV(typeand measured depth) 4½", 12.6#, N-80 @ 9538' Baker SAB packer @ 9400' .MD/Otis SSSV @ 2207' MD 12. stimulation orcementsqueeze summary Intervals treated (measUred) See Attached 13. Treatment description including volumes used and final pressure Ri £ IVED Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operatiOn Oil-Bbl lv~l~ Water-Bbl Casing Pressure Tubing Pressure -- 178 .... 3900 ref. 200 .... 3900 ref. 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ;i; 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~~~,/~//~¢~ ~ Form 10-404 Rev. 12-1-85 Date~/'~~~/J~ Submit in Duplica~e~-~ NGI 4 12% HCI-3% HF MATRIX ACID STIMULATION ARCO Alaska Inc. performed the following mud acid matrix acid stimulation on Well NGI 4 on 5/6/88' 1. MIRU slickline unit. 2. GIH w/gauge ring and performed a tag run to PBTD to ensure all perforations were clear of fill. POH and RD. 3. MI and RU pump trucks, transports, and N2 unit. 4. Stimulated the well as follows: A. 800 gals of xylene nitrified w/1000 SCF N2/bbl B. 3000 gals of 12% HCl w/additives C,. 3000 gals of 12% HCl-3% HF w/additives D. 3000 gals of 2% NH4CI water E. 150 bbls of foam consisting of 55 bbls of 2% NH4Cl water gelled w/HEC polymer and 2500 SCF N2/bbl water F. 800 gals of xylene nitrified w/1000 SCF N2/bbl G 1500 gals of 12% HCl w/additives H. 3000 gals of 12% HCl-3% HF w/additives I. 3000 gals of 2% NH4CI water J. 150 bbls of foam consisting of 55 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 SCF N2/bbl water K. 1200 gals of xylene nitrified w/1000 SCF N2/bbl L. 2500 gals of 12% HCI w/additives M. 5000 gals of 12% HCl-3% HF w/additives N. 150 bbls of 50/50 methanol/water 5. RD and released equipment. Returned well to injection immediately. 6. Tested well for new injection capacity. ARCO Alaska, Inc. Prudhoe Bay =ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 23, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: NGI-4 and 5 Permit Nos. 75-69, 76-14 Dear Mr. Chatterton: Attached are the Application for Sundry Approvals detailing work to be performed on the above-referenced wells. Very truly yours, D. F. Scheve DFS/JMV/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-i478 P 1 (NGI-4) W1-3 P 1 (NOI-5) Wi-3 WELLS2/60 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ~'. STATE OF ALASKA ALAS .... OIL AND GAS CONSERVATION COM ...... SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate ~l~ Pull tubing [] Amend order [] Perforate [] Other [] f- 2. Name of Operator ARCO Alaska, Thc. 3. Address ?. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 567' FNL & 1064' FWL, Sec. 12, TllN, R14E, UM At top of productive interval 1783' FSL & 232' FWL, Sec. 6, TllN, R15E, UM At effective depth 1930' FSL & 556' FWL, Sec. 6, TllN, R15E, UM At total depth 1991' FSL & 693' FWL, Sec. 6, TllN, R15E, UM 5. Datum elevation (DF or KB) 47' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-4 (13-6-11-15) 8. Permit number , ,, 7,~-6~ 9. APl number 50-- 029-20183 10. Pool Sadlerochit feet 11. Present well condition summary Total depth: measured true vertical 11015 feet 8544 feet Plugs (measured) Effective depth: measured 10868 feet true vertical 8442 feet Casing Length Size Conductor 113 ' 20" Surface 2664 ' 13-3/8" Production 9894 ' 9-5/8" RECEIVED Junk (measured) ~J'~ 2 5 Nas~ 0il & Gas Cons. Commission Cemented Measured depth Anch0ra~ue Vertical depth 240 sx Permafrost II 113' 6000 sx Permafrost II 2711' 125 sx Permafrost II 9941' + 750 sx Class G Liner 1358' 7" 325 sx Class G 9624-10982' 7555-8521' 113' 2711' 7786' Perforation depth: measured 10329-10406'; 10410-10425'; 10441-10558'; 10574-10630'; 10639-10644'; 10662-10762'; 10819-10844' true vertical 8075-8130'; 8132-8143'; 8154-8233'; 8244-8281'; 8287-8291'; 8303-8370'; 8408-8426' Tubing(size, grade and measured depth) 7", 29#, L-80 @ 9222' 5½", 17#, L-80, 9222-9400' Packers andSSSV(typeand measured depth) 4½", 12.6#, N-80 @ 9400-9475' Baker SAB packer @ 9400' MD/Otis SSSV @ 2207' [vii) 12.Attachments Description summary of proposal [] Detailed operations program'~ BOP sketch [] f~ 13. Estimated date for commencing operation February 1988 14. If proposal was verbally'appro~_,d~eq~ ~, ~ Name of approver Date approved 15. I hereb~certify~t~ t~f~oing is true and correct to the best of my knowledge Signed ~,/'~~ ,,~~ Title Operations Engineering Manager Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Test [] Location clearanceI ORIGINAL SIGNED B~ ,pproved Copy Returnea -- ~ LONNIE C. SMITH c~// - / "- g ~ Approved by Commissioner Date by order of the commission Date 3'~ ~ '~" ~ ~//~' ~'n ~'ri (~f Form 10-403 Rev 12-1-85 WELLS2/60 J. M. Vitucci NGI 4 AND NG! 5 12% HCI-3% HF MATRIX ACID STIMULATION ARCO Alaska Inc. proposes to perform the following mud acid matrix acid stimulation on Wells NGI 4 and NGI 5: 1. MIRU slickline unit. . GIH w/gauge ring and perform a tag run to PBTD to ensure all perforations are clear of fill. POH and RD. 3. MI and RU pump trucks, transports, and N2 unit. 4. Stimulate the well as follows: A. 800 gals of xylene nitrified w/1000 SCF N2/bbl B. 3000 gals of 12% HCl w/additives C. 3000 gals of 12% HCI-3% HF w/additives D. 3000 gals of 2% NH4CI water E 150 bbls of foam consisting of 55 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 $CF N2/bbl water ' F. 800 gals of xylene nitrified w/1000 SCF N2/bbl G 1500 gals of 12% HCI w/additives H. 3000 gals of 12% HCl-3% HF w/additives I. 3000 gals of 2% NH4CI water J. 150 bbls of foam consisting of 55 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 $CF N2/bbl water K. 1200 gals of xylene nitrified w/1000 $CF N2/bbl L. 2500 gals of 12% HCl w/additives M. 5000 gals of 12% HCl-3% HF w/additives N. 150 bbls of 50/50 methanol/water 5. RD and release equipment. Return well to injection immediately. 6. Test well for new injection capacity. RECEIVED .Oil & Gas Cons. Comml~sJon "-'-.'-, Anchorage AtlanticRfchfieldCompany North American Producing Division North. Aiask,~*--%trict :Post Office ...... 360 Anchorage, Alaska 99510 Telephone 907 2775637 August 15, 1978 Mr. Hoyle H. Hamilton State of AlaSka Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subj ec t: NGI f/2 Permit No. 75-52 ~%~-~ Permit No. 75-69 "'~~~-~"'- Permit No 76-38 NGI f/9 Permit No. 76-68 NGI ~10 Permit No. 76-69 Dear Sir: Enclosed please find a Completion Report for the above- mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB:lr Attachments ~'~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CONfMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] GAS ~[' SUSPENDED [] ABANDONED [] SERVICE~ Gas Injection OIL 2. Name of Operator/ 7. Permit Number ARCO Alaska, Inc. 75-69 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20183' 4. Location of well at surface 9. Unit or Lease Name 567'FNL & 1064'FWL, Sec.12~ TllN, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1783'FSL & 232'FWL, Sec. 6, TllN~ R15E~ UM NGI-4 (13-6-11-15) At Total Depth 11. Field and Pool 1991'FSL & 693'FWL, Sec. 6, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool /+7 ' RKBI ADL 34632 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. [ 15. Water Depth, if offshore 116. No. of Completions 01/20/76 02/19/76 02/27/76 (Parred 6/18/77)I N/A feet MSL] Single 17. Total Depth (MO+TVO) 18. Plug Back Depth (MD+TVD) 19. DirectionaISurvey [ 20. Depth where SSSV set 121. Thickness of Permafrost llO15'MD 8544'TVD 10898'MD 8463'TVD YES ~X NO [] 2207 feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run DIL, BHCS/GR~ CNL/CCL~ GR/CCL~ and CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 9M~ H-40 Surf 84' 32" 2/+0 sx Permafrost II 13-3/8" 72# MN-80 Surf 2711' 17~." 6000 sx Permofrosg II 9-5/8" 474A MN-80 Surf 99/+1' 12k" 750 sx Class G Cmt & SOO-95 ..... ~.~.i & 125 sx Permafrost II Cmt 7" 294~ MN-80 9623' 10982' 325 sx 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10329-10406', 10410-10425', 10~41-10558', 7" q53~' 9~.~' 10574-10630' ~ 10639-10644', 10662-10672' ~ 10819-10844 ' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8075-8130', 8132-8143', 8154-8233', N/A 8244-8281', 8287-8291' , 8303-8370' ~ 8408-8426 'TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 10/77 Gas In.~ection Well Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS'OILRATIO 03/02/87 2/+* TEST PERIOD ~ -- 15/+.0/+/+ ...... Flow Tubing Casing Pressure CALCULATED ~, OIL-BBL GAS-~CF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 3656 __ 24-HOUR RATE __ 15/+ ~ 0/.+/+ .... 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVEI) AUG 2 6 198 Naska 011 & Gas Cons. Commlss~or~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. · ! : NAME Top Sadlerochit Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 10321' 10945' 'FORMATION TESTS TRUE VERT. DEPTH 8070' 8496' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and dorrect to the best of my knoWledge Signed,, ~. .- Title Oper. Engr. Mgr. Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-exPlain. Item 28' If no cores taken, indicate "none". Form 10-407 ~"~"'"' STATE OF ALASKA '-'~ AL/'._. .>IL AND GAS CONSERVATION COMN.. .SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO A1 aska_. Ipc. 3. Address Post Office Box 100360, Anchora.qe, AK 99510 4. Location of well at surface 567'FNL & 1064'FWL, Sec. 12 T11N R14E UM At top of productive interval ' ' 1783'FSL & 232'FWL, Sec. 6, T11N, R15E, UM At effective depth 1930'FSL & 556'FWL, Sec. 6, T11N, R15E, UM At total depth 1991'FSL & 693'FWL, Sec. 6, T11N, R15E, UM 5. Datum elevation (DF or KB) RI<R 47' Feet 6. Unit or Property name pr~dh0e Bay Unit 7. Well number NGI-4 (13-6-11-15) 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 95' Surface 2693' Intermediate 9923' 11015 feet 8544 feet 10808 feet 8401 feet Size 20" 240 sx Permafrost II 13-3/8" 6000 sx Permafrost II 9-5/8" 125 sx Permafrost II +750 sx Class G Plugs (measured) Junk (measured) 8. Approval number 667 9. APl number 50-- cI2q-?illR~ 10. Pool Sadl erochit None Cemented Measured depth 10808' - Fill 10875' - Perf Gun ~ue Vertical depth 113' 113' 2711' 2711' 9941' 7786' Liner 1358' 7" 325 sx Class G 9624-10982' 7555'-8521' Perforation depth: measured 10329-10406', 10410-10425', 10441-10558', 10574-10630', 10639-10644', 10662-10762', 10819-10844' true vertical 8075-8130', 8132-8143', 8154-8233', 8244-8281', 8287-8291', '8303-8370', 8408-8426' ~bing(size, grade and measured depth) 7", 29#, L-80, ABM, Brd @ 9222' 5½" 17#, L-80 8rd 9222'-9400' 4½" 12 6# N-80 BTC ~ 9400'-9475' Packers and SSSV(type and measured depth) ' ' ' ' valve @ 2207' 9-5/8" Baker SAB Pkr @ 9400'/Otis RB ball 12. Stimulation or cement squeeze sUmmary Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 2/23/87 -- 117,151 .... Subsequent to operation 3/2/87 -- 154,044 .... Tubing Pressure 3684 3656 13. 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 STAT17/NGI-4 M. R. Olson (265-6810) Date Submit in Duplicate ~r,~ NGI-4 Daily Report of Well Operations Add Perfs 2/27/87 PT equipment. OK. Pump in water/Surfactant, water, methanol/water. RIH w/3-3/8" dummy gun, CCL, GR. Tag bottom @ 10808'CLM. POH. PT. OK. RIH w/3-3/8" gun #1 (12', 8'), 4 SPF, 120° phasing. Shoot 10750' to 10762', 10398' to 10406'. POH - all shots fired. PT. OK. RIH w/3-3/8" gun #2 (22'), 4 SPF, 120° phasing. Shoot 10703' to 10725'. POH - all shots fired. PT. OK. RIH w/3-3/8" gun #3 (6', 13'), 4 SPF, 120° phasing. Shoot 10697' to 10703', 10673' to 10686'. POH - all shots fired. 2/28/87 PT. OK. RIH w/3-3/8" gun #4 (5', 11'), 4 SPF, 120° phasing. Shoot 10639' to 10644', 10619' to 10630'. POH - all shots fired. PT. OK. RIH w/3-3/8" gun #5 (20'), 4 SPF, 120° phasing. Shoot 10599' to 10619'. POH - all shots fired. PT. OK. RIH w/3-3/8" gun #6 (20'), 4 SPF, 120© phasing. Shoot 10515' to 10535'. POH - all shots fired. PT. OK. RIH w/3-3/8" gun #7 (5', 16'), 4 SPF, 120© phasing. Shoot 10510' to 10515', 10470' to 10486'. POH - all shots fired. PT. OK. RIH w/3-3/8" gun #8 (19'), 4 SPF, 120© phasing. Shoot 10354' to 10373'. POH - all shots fired. Anchorage, A[~.ska DATE: March 24, ~ 98';" REFrERENCE: t t- ,:."~ ""~ "~,'.. - 2 7 "' 8 '7 --~.~ Nt[.;I :~4 2----28-8'? N C; I~I: 92"" 2'? "" 87 '~'~', WGI :~t S .... ~i-87 WGI ..."z3- ,,.o t -87 ARco Cas'ed Hol. e F:'inaL C e m e n t.. l.'_:jv a L ts. a t.- i o n R u n 3, .5" PFC L. og Run t , .5" F:'F'C L. og R~n t, 5" F'FC Log Run ~i ,5" I::'I-':'C I..og Run t , 5" ~' c h Dr e.~.r~t' I)r em'.s' D~~ e..~ ~ I)r es's' F'l. ea::~e s'ign and re'turf: /lr~e ,.':~l't~py ~$,~:'r.-:ipt of data, I..I A V E A N I C E ~,~,.,,',~ q ':"t~ Cq 6 ~':~'.~ C!:'i')~, COP, I,:,~,',,,L': I:~.'. 0 J~.' & I'i n e ! ' (.? E. '~ ~/ ' "' :' '~ ' A'F 0 .... ~t 5 "2 9 'i" R A N.? :[: 8'? t El t ,49 A p p i" 0 V e d ..............................................................................'~. D I ,? 'r R I B IJ'r I 0 N :[: C:: e n t: r a L I::' i L e_s' :~: F:' h i I. L i p s' :,~:Chevron F'B We !. I. !:: i I.e.s' D & M R .~,.- D .IL .11. ""* · x on ?. ,s' t a't'e',i fiT 't'a ,,. H a r a t' h o n :.": T e x a c o :,",: H o b i L ., "'"~' STATE OF ALASKA ALAS~,, OIL AND GAS CONSERVATION COMb,..,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator ARC~3 Ala_~ka. Inc,. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 567' S & 1064' E of NW ct, Sec. 12, T11N, R14E, UM At top of productive interval At effective depth At total depth 1991' N & 693 E of SW ct, Sec. 6, T11N, R15E, UlVl 11. Present well condition summary Total depth: measured 11015 feet Plugs (measured) true vertical 8544 feet Effective depth: measured 10898 feet Junk (measured) true vertical 8462 feet 5. Datum elevation (DF or KB) RKB 47' 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-4 (13-6-11-15) feet 8. Permit number 75-69 9. APl number 50-- 029-20182 10. Pool Sadlerochit None Perforating gun. Top @ approx. 10875'MD Casing Length Size Conductor 95' 20" Sur~ac~ _ 2693' 13-3/8" Intermediate 9923' 9-5/8" Liner · 1358' 7" Cemented Measured depth 240 sx Permafrost II 6000 sx Permafrost II 125 sx Permafrost II +750 sx Class G 325 sx Class G True Vertical depth 113' 113' 2711' 2711' 9941' 7786' 9624-10982' 7555'-8521' Perforation depth: measured 10329-10354' 10373-10398' 10410-10425' 10441-10470' 10486- 10510', 10535-10558', 10574-10599', 10662-10673', 10686-10697', 10725-10750' ,10819-1084 true vertical 8075-8094', 8107-8125', 8133-8143', 8155-8174', 8185-8201', 8218-8233', 8244-8260', 8303-8310', 8319-8327', 8345-8361', 8408-8425' Tubing (size, grade and measured depth) 7", 29#, L-80, ABM, Brd @ 9222' 5½", 17#, L-80, 8rd, 9222'-9400' 4~'' 12.6# N-80~ BTC @ 9400'-9475' Packers and SSSV (type and measured depth) 9-5/8" Baker SAB Pkr 0 9400'/0ti.~ RB hall valv~ Fa ??n7' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 1.'.' ~..~ i ;~, i.' ~i ;,, il ,i , 13. Estimated date for commencing operation December 20, 1986 14. If proposal was verbally approved Name of approver 15. I hereb/y,)certify that/~he/,~ore~oing is true and correct to the best of my knowledge ~<~~¢~//. ~~ Title Operations Engineering Manaqer Signed Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI · :., ~ ~/-,~,~ B~~ ~r,,~;, ~;~ ~-~ /~'-~-~ by order of ['~;~' ~' ~'~'~ ~Com~F~ner ......... ' the commission Date Form 10-403 Rev 12-1-85 WJP (263-4511 ) Submit in triplicate NGI-4 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well NGI-4. The proposed perforatin intervals are as follows- Existing Perforations 10329-10354 (25') 10373-10398 (25') 10410-10425 (15') -10441-10470 (29') 10486-10510 (24') 10535-10558 (23') 10574-10599. (25') 10662-10673 (11') 10686-10697 (11') 10725-10750 (25') 10819-10844 (25') Proposed Perforations 10354-10373 (19') 10398-10406 (8') 10470-10486 ·(16') ~.05-~0-~0~35 - (25') -~0~99-~0~30 (3~') 10639-10644 (5') 10673-10686, (13') 10697-10725-~ (28') 10750-10762 (12') 10844-10895 (51') Reference BHCS of 2/19/76 TOTAL = 238' TOTAL- 208' A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. The well will be loaded with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the formation. No flaring is anticipated. 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF WIRELINE BOP EQUIPMENT : '~ SUBMIT IN DUi~ICATE* STATE OF ALASKA ':see other In- st ructions on OIL AND GAS CONSERVATION COMMITTEE reverse side! WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* iC ! I · . la. TYPE OF WELL: oil, [~ t;ts' WELL WELL DRY [---] Other Gas Insection b. TYPE OF COMPLETION: WrLr, ovrR rs n.~CK n£sva. Other Perforated 2. N&ME OF OPERATOII · Atlantic .Ridhfield. Comnanv · 3, *,DRzss or orZR,TOR 4. LocaT[0~0k WEL~-(-}~p~rt locati°n clearly aWd (n ~)~fi~ with any State requirements)* At su~ace 567~FNL & 1064~ Sec. 12, TllN-Ri4E, ~t top prod. interval ~eported below 1785~FSL & 234~F~ Sec. 6, TllN-R15E, ~t total deP~ 1991'FSL & 693'FWL Sec. 6, TllN-R15E, UM AP1 NLriVIEHICAL CODE 50-029-20183 6, LEASE DESIGNATION AND SERIAL NO. APL 34632 ~, IF INDIA_N, AJ.~O'FI'EE OR TRIBE NAMIg 8. UNIT,FA. IliVi OH LE, ASE NAME Pr,,dhom Rmv Unit 9. WELL NO. NGT No. 4 (13-6-11-15) 10. FIELD AlqD POOL, OR WlLDCkT Pr,,dhoo_ Bay Field/Prudhoe T., %o ff Pool OBJECTIVE) Sec. 6, TllN-R15E 12, PERMIT lq'O, 75-69 1/20/76 2/19/76 I 2/27/76(6/18/77) .. 47'RKB, 18.4' CRpad 11,015' & 8544' 0,8 ' & 8463', Single All None 22. PRODUCING INTERVAL(S), OF TI-lIS COMPI_,ETIO.AI--TOP, BOTTOM, NAME (MD AND TV'D)* 23. %VAS DIRECTIONAL ! SURVEY MADE Top Sadlerochit 10,321'MD 8070'TVD Base Sadlerochit 10,945'ND 8495'TVD i y...es 24. TYPE EI-2ECTRIC AND OTHEI~ LOGS RUN DIL,,,~ BHCS/GR, CNL/CqL, G,R/,CCL and CB..L . ~5. CASING RECORD (Report all strings set in well) 20" [ ~t4# ....... ! H-40 ] 84' 'i)gl 'pail 32" [ 240 sc' permafros, t""II cml:" ' 1..3-3/8" .. [ 72# ~N-80 [ 2711' i ' [ 17-1/2'l 6000 Sx permafrost II cmk . 9~5/S". _ [ 47#' '[~lqi80 ! 9941"_ I ~2.1/~',1.. 750 ax CalSs C. crat & I ...... !, aIsoo-ssl ' [ I 125 sx P, erma, frost II cmt , 21]. LiN~{ tqigC;R~ : ' '1 [ £?. TUBING REGOPt.D , ,' ..... ' t '5623' o.582' ..... . ,[ 94o0' 28. PERORATIONS OP~ TO PBODU~O~ (interval size and number} ~9. ACID, Si]OT, FiIACI'GRE, C~ENT $qU_EZ~, gTC. ~ 10,819'-10,844' v10,538'-10,561'. 10,331- /~10,728'-10,753' ~10,490'-10,520' .!.10,356' ~10,689'-10,700' ~10,4~4'-10,474' w/4 shots ~10,665'-10,676' ~10,414'-10,429' per ft. .~10~577'-10;602' ~10;376'-19~,404' ~"~'~':'~, ,~,, DF-~-~TIi IIN~TE~VA_L (MD) N/A 30. PRODUCTION DATE FIRST PI%ODUCTION J P1R. ODUCT1ON ME'IHOD (Flowii*g, gas lifi, pumping--size and type of pump) xJ'-~/)/ / ~ 7 7 j In~ection Oct. 1977~ 24 ~ N/A Inje~t Press lcA~m~ P~ssuamlcm~~ o~een. I l l 300 ~i ~ 0 al. ofseos~oN or oas (8ot'd5 u~ed for fuel vented, etc.) ReinSected LIST OF ~ATTACH M ENTS 33. I hereby certify that the forego[n- and attached information Is complete and correct aa determined from all-lva'l'lable records SI NE ITLE~~' ' o ' _ DATE __ , ii ii . i .Il ii iii I I II II I I I Ill *(See Inslmclion, ~nd Spaces [or Addition=l D~t= on Rever~e Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown1 for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc prcduction from more than one nterval zone (multiple completion), so state in item 20, and ir~ iteq~ 22 show the p~cducir~9 interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported ir~ item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produce,d, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to b.e separately produced. (See instruction for items 20 and 22 above). 34. SUMM'AT{¥ OF FORIV~ATION TF.~'~"S IN('LUI)iN(; INTERVAI. TF~STED, PHE~URE DATA ~'~OV~I~ OF OIL GAS, 35. G~GIC MARK~ WAT~ AND MUD MEAS. Top Sadlerochir 10,321' 8,0YO' Base SadlerochSt 10,9~5~ 8,~95~ ,1 ~1 i ' I I lilt I I I I I I ti - 3A. C~RE DATA. i i i i i i i ....... CONFIDENTIAL STAT~ O~ A~~ DIVISION OF O!~ ~ ~ AUG - 'z, 1977 ]~rolfl: DMsio~'l~t ~i ~l~O~hon/D~rvllm,',Jackson Well Name: NGI tt4. Transmitted here~vJ.th are the following for the subject ~:ell: l~un No. Scale Xerox Sepia BL Line .. BHC Sonic/Caliper Log BHC Sonic/Caliper - Ga]mrna Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL · Cement Bond Log/VDL Compensated Formation Dmtsity Log Compensated Neut]:on-Fo~nation Density Compensated Neutron Log Core Analysis - Inte]~ral Core No. Core D,~scription (SWC) - Intm'val Core Description (Conv.) - Core No, Directional Survey - Gyro Single Shot B{]ltishot Drill Stem Test - Test No, Dual Induction Laterolog Formation Density Log Formation Density Log/Galena Ray 'Ga]nm, a Ray/CCL Latm~olog Location Plat Microlaterolog Microlog Mudlog- Interval " Sample Log (A. R. Co~) - Inter~al Synergetic Log 'TFD-I)ZL TVD-Porosity Log' Casing Collar log and Perforating__ Record Receipt Ackno~v].edged Fo;' Date: P].ea,~e return receipt to: Atlan --'~R-i. dffield Con~panY North Alaska Engineering Manager P. O. Box 360 Anchorage, ~.aska 99510 #530 ~--Atlan~icRichfieldCompany ~ North A~n Producing Division North Ak ;istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 1, 1977 ' Mr. Hoyle B~milton State of Alaska Department of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #4 (13-06-11-15) Permit No. 75-69 ...... ~ ~Nd ~ J 3 GFOL I Enclosed please find our Sundry Notice of Subsequent Report detailing the %Drk done on the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure · Form 10-403 REV. 1-10~73 Submi t "1 ntentions" in Triplicate & "Subsequent Reports,' in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--~' for such proposals.) 5. APl NUMERICAL CODE 50-029-20183 6. LEASE DESIGNATION AND SERIAL NO. APL 28302 - Surface Location ADL 34632 - Bottom hole location 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. ~vlI=LLL[~]WELL,GAS ~] OTHER Gas Injection 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0.. BOx 360, Anchorage, Alaska 99510 NGI 4 (13-06-11-15) 12, TllN, R14E, UM 4. LOCATION OF WELL At surface 567'S & 1064'E of NW cr Sec. 13- ELEVATIONS (Show whether DF, RT, GR, etc.) l~' Gravel Pad 14, CheCk Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fie]d-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) ]99]'N & 693'E of SW cr. Sec. 6, TllN, R15E, UM 12. PERMIT NO. 75-69 )ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF J...__J PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Perforate (NOTE: Report results of multiple completion on Well Completion or'Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Began perf operations @ 0600 hrs 6/15/77. Tstd tree, csg,?lwireline BOP's Pulled dummy valve. Perf'd intervals 10,819' -'10'844", 10,725' 0,750', 10,686;'~- 10,697' 10,662' -~ 10,673", 10,574'~ 10,599', 10,535' ? 10,558', 10,501' - 10',510'~, 10,486' - 10,501', 10,455' -~}0,470', 10,441' - 10,455;, 10,410' - 10,425', 10,373' - 10,398', 10,329' - 10,354' w/4 shots/ft. Ran Amerada press bombs. Flowed well. Ran & set ball valve @ 2212'. Tstd balance & control lines to 5000 psi OK. Bled press above ball valve to 0 psi, held OK. Installed-& tstd tree cap to 5000 psi OK. Released well to Production Department @ 0900 hrs 6/18/77. JUL - 8 1977 16. I hereby certify that the foregoing is true and correct , TITLE District Drilling Engineer DATE ,~ ~/~2 (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side ~2-001B STATE of ALASKA TO: ~ FROM: O. K. Gi~, Jr. D~ DATE : July 7, 1977 SUBJECT: ~iday, . ~J=~.._.!7.__~7 - mm Davis, ~ for Arco (x~ N~I, picked ~t ~ 'site 9 ~ took m .to N~1%4 to wi~ surf~ o~trol subsm-fa~ A~t Satisfactory Type Inspection-_: . .... :: Satisfactory ~,, TYpe Inspection :Yes ' ~0:. Item (:_) kocat~on,General? ~es Ro ~Item'( ) BOP[ Tests ( )'..( ) '1. 'Well. Sign '-.>: ( ) ( )' .- 2: General Housekeeping' ( ) ( ) ...... 3. Reserve Pit-( )open('-)filled ( ) ( )~ 4. Rig' - '" (,~) Safety Val.ve T.ests .5. Surface-No. Wells / 6. Subsurface-No. Wells/ ( ) Well Test Data 7. Well Nos. , , , -. 8. Hrs... obser , , , __ __ __ 9. BS&~ , , , 10. Gr. Bbls. -'- ( ) Final Abandonment 11. P&A Marker ( ) ( ) 15. "Casing set @ ( ) ( )...16. lesC fluid-( )wtr.---~)"mud .( ) oil · ( ) ( )' 17. Master Hyd. Control SYs.- psig'" () () () () () () () ()' ( )/I ) (.> ). ..~:..-.(-') ( ) () () () () (): () 18. N2 btls. , . , , psig 19. Remote Controls 20. Drilling spool- "outlets 21. Kill Li.ne-( ) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifol'd No. valvs flas 24. Chokes-( )Remote( )Pos.(-~dj~.~ 25. Test Plug-( )Wellhd( )csg( )none · 26. Annular Preventer,_.___ps.ig 27. B1 ind Rams, ~'i-.~'i .."'"/.- ( ) ( I ~ 28. Pipe Rams ______lOs!q/ -. ( ) (, lZ. Water well-( )capped( )plugge~ (i) --( ) 29. Kelly & Kell.9-c~ck/ psig . ( ) ( ) 13. Clean-up (/) ~,{ ) 30. Lower Kelly valve psio ( ) ( ) 14. Pad leveled ~ "~ ..-(.) ~( ) ' 31. Safety Floor valve~BV '( )Dart ~~~ ta numb~ ~k/~a ~s ~'~~' Total inspection o~,~a~io%tzim /~yp-"' Remar~]~_~,~ ~., ~., ~.., ,__ ~: "".~ ~ .~ ~'~'~ /~ ~,% ~.- '~<- ~ /~/~o~i~/~ ~fai... ~.}r,~:-~,. ? , .,...,.., -_ days or whe'n ready AtlantiCRichfieldCompany North Ame..,,~n Producing Division North Ala"' /istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 5, 1977 Mr. Hoyl e Hami 1 ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subje~i~4~. -06-11-15) ~-(22-01-11-14) Permit No. 75-69 Permit No 76-69 Dear Mr. Hamilton' Enclosed please find a Sundry Notice outlining our plans for each above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer ·/vp Enclosure RECEIVED MAY -. g 1977 Division of Oil a~d G~s """~o,; .'~ "/% {...~ ,.,,,P./~tl3,1 (.. Form 1(~403 REV. ,1-10-73 Submit "i ntentlons- in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to clrlll or to deepen Use "APPLICATION FOR PERMIT--~' for such proposals.) WELLO'L [--1 WELLGAS n~l OT,ER gas injection NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 LOCATION OF WELL At surface 567'S & 1064'E of NW cr Sec. 12, T11N,R14E, UM 13. 'ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20183 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302- Surface location ADL 34632- Bottom hole location 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI-4 (13-06-11-15) 10. FIELD AND POOL, Ilar WILDCAT Prudh0e Bay - Sadler0chit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE)' 1991'N & 693'E of SW cr. - Sec. 6, T11N, R15E, UM 12. PERMIT NO. 75-69 )ort, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: FRACTURE TREAT MULTIPLE COMRLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) (Other) Perforate (NOTE.' Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 1.5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letail~, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals "within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. After setting and testing the downhole .safety valve, the well will · be blown down and flared to the pit for clean up only. A static bottom hole pressure survey will then be taken. Esti.mated start- June 5, 1977. RECEIVED MAY 1977 T,TLE District Drillinq ..E. nqineer_. DATE (This space for State office use) -?:~OVED BY .~,(~. ~:CONDITIONS OF APPROVAL, IF TITLE - / · , DATE ''IF 'l,~l'l ' See Instructions On Reverse Side North Alaska Distric,t' En, gineerin§ TRAN SM I-TT AL -From' J.A. Rochon/p. Hellstrom:' Date' April 12, 1977 Well Name' NGI # 4 ..Transmitted herewith are the following for the subject well' Run No. Scale Xerox Sepia BL Line BHC Sonic~Caliper L_.o~g · -' BHC Sonic/Caliper aroma Ray Log BHC Sonic/Gamma Ray Log __ .._ · .. Caliper/CCL _-~- ._ Cement Bond Log/VDL __ : .... : C°mP~ated Formation De .n~_i~tY~ Lgg 'Compensated Neutron-Formation Density _ .1 .. Compensated Neutron Log ' 5';" Core Analysis - Interval ._-, . ' Core No. Core Description .{~VC) - ~interval' .... "' ' ". .... Core Description [Cony.) - Core NO, · .- Directional Surcey- ~"' '-'---'- .- Single Shot~-~' '-:. ' ........ Multishot _ - ~.. · Drill Stem Test - Test No. . ...... _ -.. ~. . ,, . ;' ,,, Dual Induction Late~olog ___ ~~~ign D~e~i%y Log ........... :___: ........... ' "- ------ Foz~ztion :Density Log/~amma Ray -~~ '~' Gmmr, a Ray/CCL Laterolog. ~ ' ' Location Plat - . ~i~rolaterolog . . Micro.log . . 5~adlog- Interval sample Log [A.R.Co.)-Intervai) ' Synergetic Log TVD-DIL TVD-Porosity Log · Receipt Acknowledged For: Date - Please return receipt to: Atlantic Richfield Company North Alaska Engineering Manager P. O. Box 360 Anchorage, Alaska 99310 # 209 ~,~antic~lJ2'hfieldCo rnpany North A~e~ Producing Division North Alas! 'strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 3, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #4 (13-6-11-15) Permit No. 75-69 Dear S i r- J~C-~~ Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. DRAFT SEC ~CONFER; FILE: Very truly yours, C. R. Knowles District Drilling Engineer /jw Enclosure RECEIVED JAN - tl Form 10-403 ~ ~ Submit"lntentions" in Triplicate REV. 1-10-73 & "Subsequent Reports,' in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICAT ION FO R PERMIT---" for such proposals.) 5. APl NUMERICAL CODE 50-029-20183 6. LEASE DESIGNATION AND SERIAL NO. Surface' ADL 28302 Btm Hole' ADL 34632 :. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. OiL r-q GAS r~ WELLI I WELLIA~I OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay 3. ADDRESS OF OPERATOR 9.WELL NO. P. O. Box 360, Anchorage, Alaska 99510 NGI #4 (13-6-11-15) 4. LOCATION OF WELL At surface 567'S & 1064'E of NW cr Sec 12, TllN, R14E @ TD: 1991'N & 693'E of SW cr Sec 6, TllN, R15E 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 47' RKB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 6, TllN, R15E, UM 12. PERMIT NO. 75-69 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) SUBSEQUENT REPORT OF-' MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* CHANGE PLANS (Other) Recompl eti on (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. AcCepted rig @ 0300 hrs 12-3-76. NU & press tstd BOPE. PU 6" bit & csg scraper. RIH. Circ & cond mud @ intervals. Located fill in 7" liner @ 10,650'. CO to btm @ 10,898'. Displ mud w/lO.8 ppg CaCI~. Circ & cond CaCI~ wtr' Pulled & LD 5" DP. Chgd & press tstd pipe ~ams. RIH & set retrffevabl_e BP @ 1000'. ND BOPE. Installed & tstd new 9-5/8" pkoff to 5000 psi OK. NU BOPE. Retrieved BP @ 1000' LD 5" DP. Press tstd 9- 5/8" x 13-3/8" csg pkoff to 5000 psi OK. Chg~ & press tstd 7" pipe rams. Ran wireline junk basket & gauge ring. Ran 289 jts 7" tbg w/shear sub @ 9538' packer @ 9400' XN @ 9317' XA @ 9253' RB @ 2212' NU & tstd tree to 5000 psi OK. NU riser & lubricator & tstd OK. Pulled dummy valve. Set pkr & conducted short term tbg & csg tst OK. Opened sliding sleeve & displ CaCl~ to sleeve w/diesel. Pumped 20 bbls of diesel down 9-5/8" x 7" anul. CloSed sliding sleeve. Tstd tbg to 3000 psi OK. Reran dummy & left rng tools in hole. Fished out same. Ran GR/CNL/CCL logs & dummy gun. NU xmas tree. Press tstd tbg & tbg anul. Released rig@ 0600 hms 12-14-76~,~,~,,~ KI:LI: IVI: U JAN 1977 SIGNED. ~.~ _/~5;'~- ~ .... TITLE (This space for State office use) Dlvlllat el 011 incl Gas ..,,.., ~.~.~io~ · DATE 1--~'-7'7 APPROVED BY , CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Norlh Alas~islrici Post office. ~ 360 Anchor.age; Alaska 99510 Telephone 907 277 5637 July 14, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural ResourCes Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI No. 1 (33-12-11-14) NGI No. 2 (11-07-11-15) NGI No. 3 (32-11-11-14) ~ (13-06-11-15) --NGI No. 5 (33-01-11-14) Dear Sir: Enclosed are our Sundry Notices outlining recompletion plans for the above-mentioned wells. Very truly yours, C. R. Knowles District Drilling-Engineer CRl/cs Enclosures F~rrn 1~-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use ,,APPLICATION FOR PERMIT--" for such proposals.) O,L I'--I GAS WELLI I WELL [X_AJ OTHER NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska, 99510 4. LOCATION OF WELL Atsurface 567'S & 1064'E of NW cr of Sec 12, TllN.' @ TD 1991'N & 693'E of SW cr Sec 6, TllR,RKIbE 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 47' RKB Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20183 6, LEASE DESIGNATION AND SERIAL NO. Surface: ADL 28302 Btm Hole: ADL 34632 7. IF INDIAN, ALLO1 II'ER OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI #4 (13-6-11-15) 10. FIELD AND POOL, OR WILDCAT PrljdhnP~ R~v - .~dl~rnrh~ Pnnl_ 11. SEC., T., R., M.~ (BOTT(~M HOL-E-OB'JI~CTI~V]~ Sec 6, TllN, R15E, UM 12. PERMIT NO. 75-69 )orr, or Other Data NOTICE'OF tNTENT4ON TO: TEST WATER SHUT-OFF ~ FRACTU RE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) COMPLETI ON SUBSE!~UENT REPORT OF: MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* CHANGE PLANS (Other) . (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ;15. DESCRIBEPROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to complete .this gas injection well in Oct. 1976. A rig utilizing 13-5/8" 5000 psi Shaffer LWS BOP's (one double "plus one single) and a sph. erical BOP will be used The mud presently in the well will be displaced with CaC12. "SAB" wazer. A completi.on strin~ comprised.of a Baker 0il Tool Model Production Packer, PBR mandrel and Otis "RQ" landing nipple with dummy valve in place will be run with 7" 29# L-80 LT&C 8rd A-B modified tubing. A 6" 5000 psi tree will be installed and the completed well left unperforated with diesel in the tubing down to the PBR. Prior to setting the paCker and nippling up the Xmas tree, all work will be done in a calcium chloride brine with a 300 psi over balance. 16. SIGNEDI hereby certify that the~e~g i~g tms~n ~d c°rrect 0~ .... ' _ . __TITLE District Drilling Engeneer_ DATE L July 15.. 1976 AppROvEDBY ~~ ~.TITLE .-~"~ ~' CONDITIONS OF~"~ROVAL, IF ANY.' See Instructions On Reverse Side ~' ¢~ AtlaP,.:;~;'{ichfieldCompany North Ameri~ Producing Division ~ North Alast~ strict Post Office oox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 14, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001.Porcupine Drive Anchorage, AK 99504 Subject: NGI No. 4 (13-6-11-15) NGI No. 5 (33-1-11-14) Dear Mr. Gilbreth: Enclosed are Our Sundry Notices outlining recompletion plans for the above-mentioned wells. Very truly yours, C. R. Knowles District Drilling Engineer /CS Enclosures r'~,~m 10-403 REV. 1-10.73 Submit "1 ntentlons" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OiL D GAS E] WELL WELL OTHER NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P. 0. 'Box 360, Anchorage, Alaska, 99510 LOCATION OF WELL Atmdace 567'S & 1064'E of NW cr of Sec 12, TllN, R14E @ TD 1991'N & 693'E of SW cr Sec 6, TllN, R15E 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 47' ~.'.B 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAl- CODE 50--029--2018:~ 6. LEASE DESIGNATION ANO SERIAL NO. Surface: 'APL 28302 Btm Hole: ADL 34632 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI #4 (13-6-11-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 6~ TllN~ R15E, UM 12. PERMIT NO. 75-69 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER 5HUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE Pt-~NS (Other) Completion SUBSEQUENT REPORT OF t · WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. ._ Atlantic Richfield Company proposes to complete this gas injection well in August 1976. A rig utilizing 13-5/8" 5000 psi Shaffer LWS BOP's (one double plus one single)and a spheri, cal BOP will be used. The mud presently in the well will be displaced with an oil fluid.1~ A completion string comprised of a Baker Oil Tool Model "SAB" Production Packer, PBR mandrel and Otis "RQ" landing nipple with dummy valve in place will be run with 7" 29# L-80 LT&C 8rd A-B modified tubing. The oil fluid will be left in the 9-5/8" x 7" annulus and in the tubing. A 6" 5000 psi tree will 'be installed and the completed well left unperforated. 16. I hereby certify that the foregoing is true and correct TITLE District Drilling Engineer DATE June 14,1976 APP VED BY CONDITIONS OF/~PPROVAL, IF ti[Any "fluid" utilized mu.s.t be of sufficient weight to-control the reservoir pressure until the tubing is landed. See Instructions On Reverse Side ~ 'A'I'I,AN FI (j I~ICiI[;II'.iLD C031PANY ' 'Fo' I~IST!IlBUTI':D TO:T I( A N S ~'.I ] T T A I, ,~T,\'i'E ()F AI,ASKA DIVISION OF OIL & GAS From: J.A. Rochon/W. To!ivor Date' March 16, 1976 I~rell N~ne :NGI tt 4 (6-ll- 15) '. . Transmitted herewith are the following for the subject well' Run No. Scale Xerox Sepia BL Line : :' ~!~dlog.- Interval ~:' ': ~ ~S.amole Log (A. R. Co.) o, BttC Sonic/Caliper Log Bt-tC Sonic/Caliper - Gan~na Ray Log 1 BHC Sonic - Gmnma Ray Log ~l'&5" I Cement Bond Log /d/?~_ . ..%," 1 Compensated Formation Density Log 5" 1 Conpensated Neutron-Formation Density S" Core Analysis - Interval Core No. Core Description (~7C) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot ~ltiShot Drill Stem Test - Test No. 1 Dual Induction Laterolog Formation Density Log' Formation Density Log - Gan~a Ray _ Ganm]a Ray - Neutron Log Laterolog Location Plat 'iM$crolaterolog - Interval · :-..,.. :~ ...'?-';'~'?.., '" '"'" ~ /~'~7 ,~ c;. ~'- 2"&5" Receipt Acknow:l edged Date' Pilease return receipt to' At'tant:.ic Rich'f:i. eld. Company North AJ. ask~[ ])ist'ri'ct Engineer P,O, Box 360 Anchorage, Alaska 99510 M^it 19 19'/'6 DIVISION 0I~ 01~ AND OAS AN~.i.tF)~ At~d AtlanticRichfieldCompany North ~--~'~ Producing Division North Alask~ Strict Post Office Box 360 Anchor,age, Alaska 99510 Telephone 907 277 5637 March 4, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Permit No. 75-69 Dear Sir' We are enclosing the Well Completion Report along with the Well History and Directional Survey for the above mentioned well. Very truly yours C. R./Knowles District Drilling Engineer CRK:jl Enclosures For.-:,: P--- 7 SUBMIT IN D~,~¢ATE* STATE OF ALASKA (soo ()thor st ructiofls on reverse side; OILAND GAS CONSERVATION COMMITTEE i WELL cOMpLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: 0n,W~.LL [~] aASWF. LL [] DRY [-~ other Gas Injection. b. TYPE OF COMPLETION: .~.w [~ w o,:,[-] .=~-[] ~:-~. [-] ~,~. [-] ~ Suspended WELI, OVER ES BACK RESVR. ot er NAME OF OPERATOR ATLANTIC RICHFIELD C(~PA~ 3. AODgZSs oF org~aTOa ............ 4. :.od~::b~ :r WsU:' (Rl~orV~dti~-~r~F and in accoraanse ~ith anF ~tate requirements) ~7~ ~ 1064' ~ Sec 12, TllN--~4E, ~ It top ~rod. Interval ~e~orted below 1991' FSL ~ 695' ~ Sec 6, TllN-R!5E, ~ $. API NU1VIF_,RICAL CODE 50-029-20183 6. LEASE DESIGNATION A-ND SERIAL NO. ADL 34632 9. IF INDIA-N, ALLOTTEE OR TRIBE NA/VIE 8. UNIT,FA.R~ OR LEASE NAME Prudhoe Bay x~NGI N0'["4 ,~13-6-11-15) I0. FIEL~iKAJ~t~/:)OL, OR WILDCAT Prudhoe Bay- Sadlerochit 'n. s~.c., T., R., m., (SOTTO~ HOL~. POOl OIBJECTIVE) Sec 6~ TllN-R15E 12. PE1R~IT 1~O. 75-69 13. DAITE SPUDDED [14. DATE T.D. RF~CI-II~-D [15. EYA:T~ CO'MP ~$USP OR ABAN-D. ONS ~DF, RKB, RT, GR, ~I~)* 17. ~V. CASINGtiEAD 1/20/76 ] 2/19/76 . ~ 2/27/76 ~47~, 18.4' G~ pad ~ 18. TOTAL DE~H NE & TVD~9 PLUG, ~CK MD & ~D~. ~ ~LT~LE CO~L., [ 21. INTERVALS DR[I.L~D' BY ' I ' [ I HO%V~Y* ~ ROTARY TOOLS '{ CAB[,S TOOI,S 11,015 ~ 8544' / 10,8-98' 6 8465' ,l N/A I ml [ None , ~. PRODUCING XN~VAL(S), OF ~IS ~OMP~TION--~P, BOSOM, NAMg (~ AND ~)' [33. WAS DIR~CTION~ ~ SURVEY MADE None ~ Yes i 24. TY'PE ELECTRIC AND OTHER LOGS RUN DIL, BHCS/GR, CN~,/CCL, GR/CCL and CBL ! 25. CASING RECORD (Report all strings set in well) o~s~,~, si= l lbjft.thd~ ~ O~D~. I-~P~ s~¢ <~, IHOLE SIZE ! CI'~5ILNTING RECORD ] A~WIOU'~ PULLED" 20" 19d~-Vel~Co I H-40 [84'be14w p_~._. 32" ]240 sx Permafrost II cmtl 13-3/8" 72#-Butt: MN-80 2711' ' 17-1/2" 6000 sx Permafrost I1 cm ' . s -951 I ~ 12S~ sx Pemfrost II mtI ..... gO ~INE~ ~CO~ ~ ~ ~7. TUB~G - ]' [ Il' I [ I w~ [ II 28. PERFORATIONS OP~ TO PRODU~ON (Interval, size and number) 29. -ACID, Sl!OT, Fi1~CTURE, C~,IENT SQU__Z~, ~C. D~i 1NT~V~ (MD) [ AMOUNt r~D I,[!ND OF M~'i'EP~AL US~ , N/A , N/A 30. PRODUCTION DATE FIRST PRODUCTION CI-t O -%:E SIZE [PROD'N TES' FLOW, TUBING ICA$iNG PRES~.LrR~. ~CALC%J-Lak~ OIL--BBL. PT{ESS. ] J24-HOUR RATE 31..OlSP0SlTiON OF~AS (Sold, used for fuel, vented, etc.) PRODUCTION MEIIiO~D (Flow-ii, g, gas lif~, pumping--size and type of pump) OIL--BDL. G.a~S---Ar~CF. I I VcELL ~'FATUS (Producing or ~nui-in) Suspended ITEST ',VITNES//ED BY 32. LIST OF ATTACHMENTS Drilling Hist°~ry and Directional Survey .33. I hereby- certify that the fpregoing and attached information is complete and correct as determined from alUavatlab]e records ,, ' il' : m~ I [ :: *(See Instructions and Spaces For Additional Da~n ReverS~ Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well complet,on reloor~ and log on all types of lanJs and leases in Alaska. Item: 16,: Indicate which elevation is used as reference (where not otherwise sho.,,vn) for depth measure- ments given in other spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc- production from more than one ~nterval zone (multiple completion), so state ,n item 20, and in iteq~ 22 show the prcJuci~.g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shouIJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAHY OF' I~ORMATION TES'I':S INCLUDIN(; INTERVAL, T~STED. PROCURE DAT~ ~ ~OVERI~ OF OIL GAS. 35. G~GIC MARK~ WAT~ AND MUD ,,, ~ , Top SadlerochSt 10,521 ' 8,070 ~ . Base SadlerochSt 10,945 ~ 8,49S i 3~. COh. E DATA, Aq'I'ACI[' B'~IE~"D~,~'O~S O~:.'UIT[[O~GY', POHO'~I~Y, FI~C:~R~, AP~Y."~)': , A~'D,'I~I'~'ED SlrO~S OF O'IL, G~S'OR W~. i i i Atlantic Richfield Company NGI No. 4 (13-6-11-15) AP1 50-029-20183, ADL 34632, Permit No. 75-69 Drilling History Spud @ 0605 1-20-76. Drilled 17-1/2" hole to 2713', dropped multishot, POH. Ran 13-3/8", 72'# MN-80 Buttress csg w/shoe @ 2711' and FC @ 2629'. Cemented w/6000 sx Permafrost II cmt. Recemented 20" X 13-3/8" annulus thru 2-3/8" risers w/400 sx Permafrost II cmt. NU and tested BOPE. Made up 12-1/4" BHA, tested 13-3/8" csg @ 1500 psi, drilled FC and shoe. Tested formation to .65 psi/ft. Directionallydrill~12-1/4'' hole to 9980'. POH. Ran DIL. RIH and drilled to 10,000' Ran 9-5/8" 47# MN-80 and SO0-95 Buttress casing w/shoe @ 9941', FC @ 9~59', lower FO @ 2573! andupp~r FO'@ 2367. Cemented w/750 sx Class G cmt. ND BOPE, landed 9-5/8'' csg, installed and tested packoff. NUand tested BOPE. RIHw/RTTS and shifting tool, opened lower FO @ 2573, cemented w/125 sx Permafrost II cmt. Closed and tested FO. Opened upper FO @ 2367', pumped 341 bblsArctic Pack into 9-5/8" X 13-3/8" annulus. Final returns less than 1% water. Closed and tested FO. RIHw/8-1/2" bit, top of cmt @ 9658'. Drilled cement, FC and shoe. Tested formation to equi- valent .62 gradieht. Drilled 8,1/2" hole 11,015', ran multi-shot on trip out. Ran DIL, BHCS/GRand CNL/CCL logs. Ran 7" 29# MN-80 Buttress liner w/shoe @ 10,982' and top @ 9623'. Cemented w/325 sx Class G cmt. RIH w/8-1/2" bit'and csg scraper, drilled firm cement 9308'-9623'. POH. RIH w/6" bit, drilled 9623'-9693' and cleaned out to 10,898'. POH. RIHw/DST tool, set packer @ 9576'. Open tool for 1 hr test, had weak blow for 18 min, then dead. Took 1 hr SI, test okay. POH. Ran GR/CCL, Gyro survey and CBL. LDDP RIHw/OBDP .to 2530', changed mud to water to diesel. ND BOPE, NU and test tree. Released rig @ 1200 hrs. 2-27-76. SUB. SURFACE DIRECTIONAL SURVEY ~UIDANCE [~]ONTINUOUS Fflo L Company ARCO ALASKA~ INC. , Wetl Nam® NGI-4 I567' FNL,1064' FWL,~SEC 12zTllN~R14E,U,M) Field/Location PRUDHOE BAY~ NORTH SLOPE,,., ALASKA , Job Reference No. 73685 Logged By; PORTER/WEST/HUSBAND (~C'~ 0 r.) ~D,~ 9-0CT-89 (RUN 3) SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKAt INC. NGI-4 PRUDHOE BAY NORTH SLOPE~ ALASKA SURVEY DATE: 9-aCT-1989 CRUN J3) ENGINEER: PORTER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND aZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTEO ONTO A TARGET AZIMUTH OF NORTH 6~ DEG ~ MIN EAST DATA FROM SURFACE TO 10749.5m ACQUIRED WITH TANGENTIAL METHOD FROM SCHLUMBERGER GCT TOOL. DATA AT 11015' ACQUIRED WITH RADIUS OF CURVATURE METHOD FROM MEASURED WHILE DRILLING SURVEY. MWD DATA TIED TO GCT DATA AT DEPTH 107~9.5e. COMPUTA'TION DATE: 02-MAR-90 PAGE · I ARCO ALASKA~ INC. PRUOHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 9-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN 0.00 0.00 -47.00 0 0 N 0 0 100.00 100.00 53.00 0 23 S 32 48 200.00 200.'00 153.00 0 17 S 27 53 300.00 300.00 253.00 0 20 S 25 51 400.00 399.99 352.99 0 30 S 13 56 500.00 499.99 452.99 0 49 S 8 2 600.00 599.98 552.98 0 49 S 0 34 700.00 699.97 652.97 0 35 S 5 45 800.00 799.96 752.96 0 37 S 3 36 900.00 899.96 852.96 0 27 S 31 58 1000.00 999.96 952.96 1100.00 1099.95 1052.95 1200.00 1199.95. 1152.95 1300.00 1299.95 1252.95 1400.00 1399.95 1352.95 1500.00 1499.94 1452.94 1600.00 1599.94 1552.94 1700.00 1699.94 1652.94 1800.00 1799.94 1752.94 1900.00 1899.93 1852.93 0 22 S 34 4'3 E 0 17 S 41 16 E 0 23 N 86 43 E 0 33 N 66 32 E 0 23 N 60 44 E 0 25 N 63 9 F_ 0 29 N 36 29 E 0 22 N 14 16 E 0 20 N 88 49 E 0 51 S 72 32 E 2000.00 1999.92 1952.92 2100.00 2099.91 2052.91 2200.00 2199.91 2152.91 2300.00 2299.91 2252.91 2400.00 2399.91 2352.91 2500.00 2499.91 2452.91 2600.00 2599.91 2552.9! 2700.00 2699.91 2652.91 2800.00 2799.90 2752.90 2900.00 2899.83 2852.83 0 51 S 70 47 E 0 22 $ 76 50 E 0 17 N 75 40 E 0 16 N 31 16 E 0 16 N 10 39 E 0 2 N 73 20 E 0 2 S 81 10 E 023 S 10 19 E 0 32 S 50 27 E 3 37 N 43 44 E 3000.00 2999.43 2952.43 6 34 3100.00 3098.49 3051.49 8 37 3200.00 3197.23 3150.23 9 36 3300.00 3295.50 3248.50 11 40 3400°00 3393.09 3346.09 13 23 3500.00 3489.88 3442.88 15 47 3600.00 3585.26 3538.26 18 58 ~700.00 3679.12 3632.12 21 17 3800.00 3771.86 3724.96 22 19 3900.00 3863.74 3816.74 24 30 ENGINEER: PORTER VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG 0.00 0.00 0.00 N 0.00 E -0.13 0.02 0.13 S 0.08 W -0.60 0-00 0.60 S 0.38 W -1.04 0.01 1.07 S 0.64 W -1.52 0.22 1.72 S 0.87 W -Z.Z3 0.09 2.89 S 1.11 N -2.96 0.43 4.37 $' 1.21 W -3.53 0.90 5.58 S 1.27 W -4.02 0.48 6.56 S 1.35 W -4.14 0.14 7.44 S 1.06 W -4.03 0.26 8.08 S 0.64 W -3.93 0.18 8.61 S 0.29 W -3.62 0.38 8.75 S 0.13 E -2.75 0.18 8.57 S 1.01 E -1.95 0o00 8.21 S 1.72 E -1.33 0.00 7.91 S 2.27 E -0.62 0.39 7.44 S 2.82 E 0.01 0.18 6.71 S 3.18 E 0.38 0.54 6.44 S 3.46 E 1.27 0.41 6.66 S 4.55 E 0.00 N 0 0 E 0.15 S 30 41 W 0.71 S 32 8 W 1.25 S 30 57 W 1.93 S 26 46 W 3.09 S 20 59 N 4.53 S 15 30 W 5.72 S 12 50 ~ 6.69 S 11 39 W 7.51 S 8 9 W 2.39 0.31 7.17 S 6.03 E 3.21 0.51 7.49 S 7.08 E 3.62 0.00 7.48 S 7.54 E 4.06 0.'15 7.19 S 7.88 E 4.42 0.17 6.68 S 8.04 E 4.60 0.00 6.44 S 8.12 E 4.61 0.36 6.48 S 8.15 E 4.62 0.57 6.65 S 8.25 E 4.51 2.07 7.50 S 8.52 E 7.61 3.20 5.68 S 11.09 E 8.11 S '4 30 W 8.61 S I 54 W 8.76 S 0 52 E 8.63 S 6 42 E 8.39 S 11 51 E 8.23 S 16 0 E 7.96 S 20 47 E 7.43 S 25 21 E 7.31 S 28 14 E 8.06 S 34 21 E N 51 31 E 16.03 2.86 N 55 19 E 29.44 0.62 N 56 35 E 45.04 1.90 N 58 55 E 63.39 2.28 N 62 9 E 85.17 2.78 N 63 56 E 110.26 3.59 N 64 41 E 140.23 2.85 N 65 53 E 174.73 2.02 N 61 Z E 212.10 1.63 N 60 32 E 251.45 2.84 9.37 S 40 4 E 10.31 S 43 24 E 10.62 S 45 13 E '~ 10.67 S 47 37 E 10.4.6 S 50 16 E 10.37 S 51 35 E 10.41 S 51 32 E 10.60 S 51 8 E 11.35 S 48 40 E 1Z.46 S 6Z 53 E 0.44, N 17.52 E 17.53 N 88 33 E 8.42 N 28.59 E 29.80 N 73 36 E 17.18 N 41.70 E 45.10 N 67 36 E 27.09 N 57.31 E 63.39 N 64 42 E 37.76 N 76.36 E 85.18 N 63 4.1 E 49.01 N 98.79 E 110.28 N 63 37 E 62.06 N 125..78 E 140.25 N 63 44 E 76.39 N 157.16 E 174.74 N 64 5 E 93.10 N 190.59 E 212.11 N 63 58 E 112.50 N 224.96 E 251.52 N 63 26 E COMPUTATION DATE: O2-MAR-90 PAGE g ARCO aLASKA, INC. NGI-4 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 9-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF HEASURED DEPTH ENGINEER: PORTER VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG N 61 16 E 295.31 N 61 37 5 344.26 N 61 32 E 398.56 N 62 17 E ¢58.25 N 63 13 E 522.86 N 64 12 ~ 591.53 N 64 S E 66~.28 N 63 56 E 741.64 N 63 55 E 821.7! N 63 5~ E 902.04 N 63 53 E 982.12 N 63 52 E 1062.04 N 63 55 E 1141.89 N 63 51 E 1121.&8 N 63 45 E 1301.01 N 63 44 E 1380.26 N 63 35 E 1459.27 N 63 23 E 1537.91 N 63 42 E 1616.11 N 63 54 ~ 1694.53 N 63 51 E 1772.79 N 63 47 E 1851.50 N 63 39 E 1930.63 N 63 39 E 2010.05 N 63 45 E 2090.28 N 63 48 E 2170.67 hi 63 52 E 2251.25 N 63 56 E 2331.92 N 63 58 E 2412.38 N 63 51 E 2492.55 TRUE SUB-SEa COURSE MEASURED VERTICAL VERT[CAL DEVIATION AZIMUTH DEPTH. DEPTH DEPTH DEG MIN DEG 4000.00 3953.54 3906.54 Z7 4100.00 4040.68 3993.68 31 5 4200.00 4124.57 4077.$7 34 56 4300.00 4204.73 4157.73 38 31 4400.00 4281.00 4234.00 41 54 4500.00 4353.66 4306.66 44 51 4600.00 4422.24 4375.24 48 42 4700.00 4485.55 4438.55 52. 26 4800.00 4545.45 4498.45 53 41 4900.00 4604.99 4557.99 53 14 5000.00 4664.88 461T.88 53 6 5100.00 4724.97'4677.97 52 58 5200.00 4785.16 4738.16 52 54 5300.00 4845.70 4798.70 52 34 5400.00 4906.30 4859.30 52 34 5500o00 4967.28 4920.Z8 52 24 5600.00 5028.55 4981.55 52 1 5700.00 5090.30 5043.30 51 38 5800.00 5152.47 5105.47 51 32 5900.00 5214.65 5167.65 51 31 6000.00 5276.88 5229.88 51 42 6100.00 5338.56 5291.56 52 8 6200.00 5399.68 5351.68 52 26 6300.00 5460.43 5413.43 52 52 6400.00 5520.10 5473.10 53 36 6500.00 5579.57 5531.57 53 37 6600.00 5638.77 5591.77 53 41 6700.00 5697.84 5650.84 53 46 6800.00 5757.23 5710.23 53 20 6900.00 5816.98 5769.98 53 16 7000.00 5876.89 5829.89 53 6 7100.00 5937.Z6 5890.26 52 40 7200.00 5998.18 5951.18 52 12 7300.00 6059.69 6012.69 51 58 7400.00 6121.51 6074.51 51 44 7500.00 6183.64 6136.64 51 32 7600.00 6245.96 6198.96 51 13 7700.00 6308°63 6261.63 50 57 7800.00 6371.79 6324.79 50 48 7900.00 6435.27 6388.27 50 25 N 63 48 E 2572.61 N 63 47 E 2652.32 N 63 46 E 2731.61 N 63 42 E 2810.45 N 63 40 E 2889.03 N 63 42 E 2967.38 N 63 37 E 3045.57 N 63 37 E 3123.48 N 63 34 E 3200.99 N 63 31 E 3278.25 3.24 3.95 3.61 3.83 3.33 2.91 4.35 2.62 0 0.98 133.90 N 263.35 E 295.44 N 63 3 6 157.23 N 306.47 E 344.44 N 62 50 E 183.17 N 354.26 E 398.82 N 62 40 E ~ 2tl.32 N 406.98 E 458.58 N 62 34 E 2~0.97 N 464.44 E 523.23 N 62 35 E Z71.34 N 526.03 E 591.89 N 62 43 E 302.91 N 591.58 E 664.62 N 62 53 E 336.88 N 661.10 E 741.98 N 63 0 E 372.00 N 733.06 ~ 822.04 N 63 6 E 407.33 N 805.22 E 902.38 N 63 10 E 0.03 0.08 1.30 2.40 0.90 0.37 0.39 1.28 0.86 0.34 4.42.56 N 877.13 E 982.46 N 63 14 E 477.76 N 948.90 E 1062.38 N 63 17 E 512.89 N 10Z0.61 E 1142.23 N 63 19 E 547.89 N 1092.10 E 1221.83 N 63 21 E 583.05 N 1163.45 E 1301.37 N 63 23 E 618.10 N 1234.54 E 1380.63 N 63 24 E 653.20 N 1305.34 E 1459.65 N 63 2:5 E 688.30 N 13T5.73 E 1538.31 N 63 25 E T23.24 N 1445.83 E 1616.63 N 63 25 E 757.80 N 1516.1Z E 1694.95 N 63 27 E 0.46 0.62 0.52 0.77 0.49 0.85 0.29 0.46 0.27 0.32 792.27 N 1586.40 E 1773.23 N 63 28 E 826.99 N 1657.04 E 1851.94 N 63 29 E 862.03 N 1728.00 E 1931.08 N 63 Z9 E ~ 897.30 N 1799.17 E 2010.51 N 63 30 E 932.86 N 1871.11 E 2090.76 N 63 30 E ' 968.38 N 1943.~3 E 1171.16 N 63 31 E 1003.91 N 2015.57 E 2251.75 N 63 31 E 1039.42 N 2088.02 E 2332.43 N 63 32 E 1074.71 N 2160.33 E 2412.89 N 63 33 E 1109.98 N Z232.34 E Z493.07 N 63 34 E 0.72 0.46 0.57 0.26 0.43 0.24 0.32 0.59 1.13 0.76 1145.26 N 2304.Z1 E Z573.13 N 63 34 E 1180.47 N 2375.74 E 2652.85 N 63 35 E 1215.52 N 2446.87 E 2732.16 N 63 35 E 1250.43 N 2517.57 E 2811.00 N 63 35 E 1285.29 N 2588.02 E 2889.60 N 63 35 E 1320.04 N Z658.25 E 2967.97 N 63 36 E 1354.73 N 2728.34 E 3046.17 N 63 36 E 1389.35 N 2798.16 E 3124.10 N 63 36 E 1423.8a N 2867.59 E 3201.62 N 63 36 E 1458.27 N 2936.77 E 3278.90 N 63 36 E COMPUTATION DATE: O2-MAR-90 PAGE 3 ARCO ALASKAt INC. NGI-4 PRUDHOE BAY NORTH SLOPEs ALASKA DATE OF SURVEY: 9-0CT-1989 KELLY BUSHING ELEVATION: 4?.00 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASUREO DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 8000.00 6499.36 6452.36 49 56 8100.00 6563.91 6516.91 49 46 8200.00 6628.34 6581034 50 1 8300.00 6692.33 6665.33 50 18 8600.00 6756.07 6709.07 50 32 8500.00 6819.62 6772.62 50 36 8600.00 6883.07 6836.07 50 35 8700.00 6946.90 6899090 50 3 8800.00 7011.43 6966.43 49 30 8900.00 7076.77 7029.77 68 52 9000.00 7143.12 7096.12 48 6 9100.00 7210.30 7163.30 47 36 9200.00 7278.26 7231.Z6 47 3 9300.00 7346.98 7299.98 66 19 9400.00 7416.0Z 7369.02 66 3 9500.00 7485.96 7438.96 45 16 9600.00 7556.90 7509.90 44 27 9700.00 7628.82 7581.82 43 36 9800.00 7701.89 7656.89 62 46 9900.00 7775.87' 7728.87 41 57 10000.00 7851.10 7806.10 41 19 10100.00 7925.57 7878.57 42 19 10200.00 7998053 7951.53 63 56 10300.00 8069.37 8022.37 46 10400.00 8137.52 8090.52 47 53 10500.00 ~203.78 8156.78 48 40 10600.00 8270.31 8223.31 47 57 -10700.00 8337.95 8290.95 47 2 10800.00 8406.79 8359.79 46 28 10900.00 8476.12 8629.12 46 1 11000.00 8545.66 8498. ~,6 45 34 VERTICAL DOGLEG REC'TANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OISTo AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN N 63 22 E 3356.99 N 63 20- E 3431.34 N 63 28 E 3507.80 N 63 44 E 35.84.63 N 64. 3 E 3661.67 N 64 17 E 3738.88 N 64 26 E 3816.17 N 64 5 E 3893.14 N 63 51 E 3969.53 N 63 37 E 4045.22 0.38 .60 .20 .28 .89 2.30 1.63 2.55 .,85 .07 1692.60 N 3005.42 E 3355.66 N 63 35 E 1526.90 N 3073.66 E 3632.03 N 63 35 E 1561.12 N 3162.05 E 3508.50 N 63 35 E 1595034 N 3210.87 E 3585.35 N 63 35 E 1629.25 N 3280.05 E 3662.60 N 63 35 E 1662.9! N 3369.56 E 3739.61 N 63 36 E 1696.29 N 3419.25 E 3816.90 N 63 37 E 1729.T6 N 3488.58 E 3893.87 N 63 38 E 1763.30 N 3557.2! E 3970.26 N 63 38 E 1796.82 N 3625.08 E 6065.96 N 63 38 E N 63 2~ E 4120.02 N 63 10 E 4196.07 N 63 1 E 4267.60 N 62 58 E 4340.01 N 62 45 E 4412.32 N 62 57 E 4483.75 N 63 10 E 4556.20 N 63 19 E 4623.66 N 63 38 E 4691.91 N 63 45 E 4759.18 3.65 1830.18 N 3692.06 E 6120.78 N 63 38 E 1.13 1863.40 N 3758.26 E 6194.85 N 63 38 E 1.79 1896.61 N 3823.66 E 6268.20 N 63 37 E 3.00 1929.62 N 3888.38 E 6340.84 N 63 36 E 1.85 1962.61 N 3952.76 E 4413.18 N 63 36 E 0.59 1995.21 N 6016.37 E 6484.65 N 63 35 E 1.10 202T.16 N 6079.19 E 6555.13 N 63 34 E 0.93' 2058.39 N 6161.25 E 4626.60 N 63 36 E 0.81 2088.86 N 6202.36 E 4692.87 N 63 34 E 0.98 2118.69 N 6262.65 E 6760.15 N 63 :36 E N 64 6 5 4825.05 N 64 48 E 4891.79 N 65 1 E 4960.17 N 65 9 E 5030.74 N 65 13 E 5103.91 N 65 15 E 5178.81 N 65 11 E 5253.66 N 65 13 E 5327.11 N 64 37 E 5399.63 N 63 52 E 5471.68 N 63 7 E 5543.72 1.65 0.49 0.92 2.35 2.36 0.81 0.72 0.79 0.54 0.47 0.39 2147.77 N 6321.76 E 6826.03 N 63 36 E 2176.46 N ¢382.02 E 6892.76 N 63 35 E 2205.&1 N &443.97 E 4961.12 N 63 36 F 2235.15 N 4507.97 E 5031.67 N 63 38 ' ) 2265.86 N 4574.60 E 5106.8! N 63 39 E .... / 2297.25 N 6642.39 E 5179.69 N 63 60 E 2328.56 N 4710.17 E 5256.31 N 63 62 E 2359.50 N 6777.00 E 5327.95 N 63 63 E 2390.67 N 48~2.69 E 5400.46 N 63 66 E 2622.26 N 6907.25 E 5472.51 N 63 44 E 2453.82 N 6972.0! E 5564.56 N 63 46 E 10769.5 *** TIE-IN POINT GOING FROM GCT TO MWO DATA (SEE INTERPOLATED VALUES FOR CHOSEN HORIZONS). *** 11015.00 8555.86 8508.86 45 30 N 63 0 E 5554.52 0.00 2458.56 N 4981.73 E 5555.37 N 63 46 E COMPUTATION OATE: 02-MAR-90 PAGE ARCO ALASKAt INC. NGI-4 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 9-0CT-1999 KELLY BUSHING ELEVATION: 47.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIN DEG MZN 0.00 0-00 -47.00 0 0 1000.00 999.96 952.96 0 22 2000.00 1999-92 1952.92 0 51 3000.00 2999.43 2952.¢3 6 34 4000.00 3953.54 3906.54 27 41 5000.00 4664.8B 461..7.88 53 6 6000,,00 527'6.88 5229.88 51 42 7000.00 5876.89 5829.89 53 6 8000.00 6499.36 6452.36 49 56 9000.00 7143.12 7096.12 48 ENGINEER: PORTER 10000.00 7851.10 7804.10 41 19 11000.00 8545.46 8498.46 45 34 VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 'FEET FEET FEET DEG N 0 0 E 0.00 S 34 43 E -4.03 S 70 47 E Z.39 N 51 31 E 16.03 N 61 16 E Z95.31 N 63 53 E 982.12 N 63 51 E 1772.79 N 63 48 E 2572.61 N 63 22 E 3354.99 N 63 24 E 4120.02 N 64 6 E 4825.05 N 63 7 E 5543.72 0.00 0.26 0.31 2.86 3.24 0.03 0.46 0 ,,72 0.3 8 3.65 0.00 N 0.00 E 0.00 N 0 0 E 8.08 S 0.64 W 8.11 S 4 30 W 7.17 S 6.03 E 9.37 S 40 4 E 0.44 N 17.52 E .17.53 N 88 33 E 133.90 N 263.35 E 295.44 N 63 3 E 442.56 N 8'77.13 E 982.46 N 63 14 E 792.27 N 1586.40 E 1773.23 N 63 28 E 1145.26 N 2304.21 E 2573.13 N 63 34 E 1492.60 N 3005.42 E 3355.66 N 63 35 E 1830.18 N 3692.06 E 41Z0.78 N 63 38 E I .65 0.39 2147.77 N 4321.76 E 4826.03 N 63 34 E 2453.82 N 4972.01 E 5544.56 N 63 44 E 10749.5 ~ TIE-IN POINT GOING FROM GCT TO MWD DATA (SEE INTERPOLATED VALUES FOR CHOSEN HORIZONS). ~ 11015.00 8555.86 8508.86 45 30 N 63 0 ~ 555~.52 0.00 2458.56 N 4981.73 E 5555.37 N 63 44 E COMPUTATION DATE: OZ-MAR-gO PAGE 5 ARCO ALASKA, INC. NGI-¢ PRUOHOE BAY NORTH SLOPEr ALASKA OATE OF SURVEY: 9-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N 0.00 0.00 -47°00 0 0 N 0 0 E 47,00 47.00 0.00 0 0 N 0 0 E 147.00 147.00 100.00 0 18 S 34 1 W 247.00 247.00 200.00 0 18 S 30 56 W 347.00 347.00 300.00 0 23 S 18 42 W 447.01 447.00 400.00 0 41 S 12 17 W 547.02 547.00 500.00 0 53 S 5 15 W 647.03 647.00 600.00 0 42 S 2 57 W 747.03 747.00 700.00 0 34 S 8 4 W 847.04 847.00 800.00 0 34 S 16 42 E 947.04 947.00 900.00 104'7.05 1047.00 1000.00 1147.05 1147.00 1100.00 1247.05 -1247.00 1200.00 1347.05 1347.00 1300.00 1447.05 1447.00 1400.00 1547.06 1547.00 1500.00 1647.06 1647.00 1600.00 1747.06 1747.00 1700.00 1847.06 1847.00 1800.00 0 28 S 32 4, E 0 22 S 31 28 E 0 14 S 68 13 E 0 32 N 79 58 E 0 26 N 62 51 E 0 19 N 61 38 E 0 25 N 53 0 E 0 29 , N 26 7 E 0 12 N 43 12 E 0 40 S 80 44 E 1947.07 1947.00 1900.00 2047.09 2047.00 ZO00.O0 2147.09 2147.00 ZIO0.O0 2247.0g 2247.00 2200.00 2347.09 2347.00 2300.00 2447.09 2447.00 2400.00 2547.09 2547.00 2500.00 ' 2647.09 2647.00 2600.00 2747.09 2747.00 2700.00 2847.10 2847.00 2800.00 0 54 S 70 22 E 0 40 S 73 51 E 0 15 N 86 7 E 0 14 N 43 57 E 0 ZO N 19 0 E 0 10 N 21 10 E 0 2 S 22 lg E 0 4 S 66 57 E 0 32 S 13 49 E I 40 N 59 30 E 2947.30 2947.00 ZgO0.O0 5 1 3047.96 3047.00 3000.00 7 58 3149.10 3147.00 3100.00 9 5 3250.56 3247.00 3200.00 10 41 3352.70 3347.00 3300.00 12 46 3455.57 3447.00 3400.00 14 37 3559.67 3547.00 3500.00 17 45 3665.62 3647.00 3600.00 20 36 3773.14 3747.00 3700.00 22 9 3881.64 3847.00 3800.00 24 0 ENGINEER: PORTER VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E -0.38 0.30 0.38 S 0.24 W -0.79 0.00 0.80 S O.$O W -1.25 0.08 1.34 S 0.75 W -1.83 0.46' 2.19 S 0.98 W -2.61 0.26 3.58 S 1.19 W -3.23 0.25 4.98 S' 1.22 W -3.77 0.,12 6.02 S 1.33 W -4.14 0.28 7.02 S 1.26 W -4.08 0.04 7.76 S 0.85 W -3.98 0.83 8.35 S 0.46 W -3.84 O.Zg 8.73 S 0.12 W -3.25 0.12 8.70 S 0.51 E -2.32 0.52 8.38 S 1.40 E -1.66 0.00 8.07 S 1.97 E -1.00 0.49 7.74 S 2.55 E -0.27 0.45 7.08 S 3.05 E 0.17 0.24 6.51 S 3.26 E 0.71 0.68 6.50 S 3.85 E 0.00 N 0 0 E 0.00 N 0 0 E 0.45~ S 32 15 W ~J 0.9¢ S 31 59 W 1.53 .S 29 21 W 2.40 S 24 12 W 3.78 S 18 26 W 5.13 S 13 47 W 6.17 S 12 2.7 W 7.14 S 10 12 W 1.80 0.05 6.89 S 5.24 E 2.84 0.66 7.37 S 6.62 E 3.40 0.00 7.51 S 7.31 E 3.84 0.00 7.38 S 7.7'3 E 4.24 0.13 6.96 S 7.98 E 4.53 0.08 6.51 S 8.09 E 4.60 0.00 6.45 S 8.13 E 4.64 0.22 6.48 S 8.18 E 4.52 0.01 7.04 S 8.32 E 5.22 4.67 7.33 S 9.23 E 7.80 S 6 17 W 8.37 S 3 10 W 8.73 S 0 49 W 8.72 S 3 22 E 8.50 S 9 27 E 8.30 S 13 4.5 E 8.15 S 18 1,~ E 7.71 S 23 16 E 7.28 $ 26 37 E 7.55 S 30 40 E N 44 59 E 10.94 2.92 N 54 14 E 21.96 3.02 N 56 34 E 36.90 0.94 N 57 27 E 53.87 2.21 N 61 I E 74.53 1.49 N 63 29 i 98.62 2.23 N 64 12 E 127.50 3.31 N 65 48 E 162.46 2.22 N 62 11 ~ 201.95 2.25 N 60 29 E 243.94 2.56 8.66 S 37 17 E 9.91 S 41 56 E 10.48 S 44 13 E 10.69 S 46 20 E J 10.59 S 48 53 E ' 10.38 S 51 10 E 10.38 S 51 36 E 10.44 S 51 39 E 10.90 S 49 47 E 11.79 S 51 34 E 3.12 S 13.57 E 13.92 S 77 4 E 4.05 N 22.37 E 22.73 N 79 44 E 12.65 N 34.83 E 37.06 N 70 3 E 22.04 N 49.17 E 53.88 N 65 51 E 32.67 N 66.99 E 74.53 N 64 0 E 43.87 N 88.34 E 98.66 N 63 35 E 56.56 N 114.29 E 127.52 N 63 40 E 71.36 N 145.96 E 162.48 N 63 57 E 88.27 N 181.65 E 201.96 N 64 5 E 108.79 N 218.40 E 243.99 N 63 31 E COMPUTATION DATE: 02-MAR-g0 PAGE 6 ARCO ALASKA, INC. NGI-4 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 9-0CT-1989 KELLY BUSHING ELEVATION: ,7.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SER DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN 3992.60 3947.00 3900.00 27 26 4107.4! 4047.00 4000.00 31 21 4227.55 4147.00~ 4100.00 35 53 4354.82 4247.00 4200.00 40 32 4490.64 4347.00 4300.00 44 4638.15 4447.00 4400.00 50 20 4802.61 4547.00 4500.00 53 4970.I9 ,647.00 4600.00 53 11 5136.58 4747.00 4700.00 52 59 5302.1, 4847.00 ,800.00 52 34 5466.77 4947.00 4900.00. 52 24 5629.95 5047.00 5000.00 51 55 5791.20 5147.00 5100.00 51 31 5951.94 5247.00 5200.00 51 28 6113.76 5347.00 5300.00 52 10 6277.80 5447.00 5400.00 52 42 6445.26 5547.00 5500.00 53 26 6613.91 5647.00 5600.00 53 6782.86 5747.00 5700.00 53 23 6950.15 58,7.00 5800.00 53 11 7116.05 5947.00 5900.00 52 36 7279.40 6047.00 6000.00 51 59 7441.09 6147.00 6100.00 51 35 7601.67 6247.00 6200.00 51 12 7760.78 6347.00 6300.00 50 46 7918.40 6467.00 6400.00 50 19 8073.84 6547.00 6500.00 49 44 8229.10 6647.00 6600.00 50 13 8385.73 6747.00 6700.00 50 30 8543.14 6847.00 6800.00 50 37 ENGINEER: PORTER 8700.15 69,7.00 6900.00 50 3 885,.61 7047.00 7000.00 49 12 9005.81 7147.00 7100.00 47 59 9154.15 7247.00 7200.00 47 15 9300°03 7347.00 7300.00 46 19 9444.45 7447.00 7400.00 45 43 9586.12 7547.00 7500°00 44 32 9725.02 7647.00 7600.00 43 12 9861.13 7747.00 7700.00 42 8 9994.55 7847.00 7800.00 41 17 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EaST/WEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET~ DEG. MIN N 61 10 E N 61 36 E N 61 43 E N 62 43 E N 64 7 E N 63 57 E N 63 55 E N 63 53 E 291.85 3.09 348.13 3.78 414.54 3.29 493.12 3.39 584.95 2.87 693.29 4.01 823.81 0.31 958.27 0.52 0.22 2.38 N 63 53 E 1091.24 N 63 51 E 1223.18 132.2, N 260.31 E 291.98 N 63 4 E 159.08 N 309.88 E 3'8.32 N 62 50 E 190.77 N 368.35 E 414.82 N 62 37 E 227.44 N 437.94 E 493.48 N 62 33 E 268.47 N 520.12 E 585.32 N 62 42 E 315.61 N 617.67 E 693.63 N 62 56 E 372.92 N 734.94 E 824.14 N 63 6 E 432.06 N 855.72 E 958.61 N 63 13 E ,90.62 N 975.12 E 1091.59 N 63 17 E 548.64 N 1093.63 E 1223.53 N 63 22 E N 63 46 E 1353.93 N 63 33 E 1482.86 N 63 40 E 1609.32 N 63 53 E 1735.16 N 63 47 E 1862.36 N 63 3~ E 1992.37 N 63 47 E 2126.67 N 63 52 E 2262.45 N 63 59 E 2398.62 N 63 52 E 2532.72 0.03 0.27 0.98 0.56 0.88 0.71 0.37 0.39 0.67 0.39 606.,6 N 1210.93 E 1354.30 N 63 24 E 663.70 N 1326.47 E 1483.2' N 63 25 E 720.19 N 1439.65 E 1609.74 N 63 25 E 775.68 N 1552.61 E 1735.59 N 63 27 E 831.79 N 1666.78 E 1862.80 N 63 29 E 889.46 N 1783.33 E 1992.84 N 63 30 E 948.96 N 1903.75 E 2127.16 N 63 30 E 1008.8, N 2025.63 E 2262.95 N 63 31 E 1068.67 N 21'7.97 E 2399.13 N 63 33 E 1127.68 N 2268.40 E 2533.2' N 63 34 E N 63 45 E 2665.08 N 63 42 E 2794.22 N 63 39 E 2921.26 N 63 37 E 3046.87 N 63 34 E 3170.60 N 63 28 E 3292.,1 N 63 18 E 3,11.38 N 63 28 E 3530.12 N 64 I E 3650.66 N 64 25 E 3772.22 0.22 0.09 0.39 0.'29 0.66 0.51 0.31 0.24 1.76 2.07 1186.11N 2387.18 E 2665.61 N 63 35 E 1243.2, N 2503.03 E 2794.78 N 63 35 E 1299.59 N 2616.91 E 2921.84 N 63 35 E ~\ 1355.31N 2729.51E 30,7.47 N 63 36 E 1,10.30 N 2840.37 E 3171.23 N 63 36 E~ 1464.60 N 2949.44 E 3293.06 N 63 36 E N 64 5 E 3893.26 N 63 41 E 4010.95 N 63 26 E 4124.34 N 63 4 E 4233.87 N 62 5~ E 4340.03 N 62 52 E 4~44.17 N 63 6 E 4544.48 N 63 28 E 4640.84 N 63 40 E 4733.15 N 64 I E 4821.45 2.55 3.00 3.08 4.12 3.00 1.07 0 2.21 0.95 1.51 1729.79 N 3488.69 E 3893.98 N 63 38 E 1781.61 N 3594.37 E ,011.69 N 63 38 E 1832.11 N 3695.92 E ,1Z5.10 N 63 38 E 1881.,1 N 3793.77 E ,234.66 N 63 37 E 1929.63 N 3888.39 E 4340.86 N 63 36 E 1977.20 N 3981.11 E 4445.06 N 63 35 E 2022.76 N 4070.52 E 4545.40 N 63 35 E 2066.09 N '156.63 E 4641.79 N 63 34 E 2107.15 N ,239.32 E ,734.12 N 63 34 E 2146.19 N ,318.53 E 4822.,3 N 63 34 E COMPUTATION DATE: OZ-MAR-90 PAGE 7 ARCO ALASKA, INC. NGI-4 PRUOHOE BAY NORTH SLOPE, ALASKA DATE DF SURVEY: 9-0CT-1989 KELLY BUSHING ELEVATTON: 47.00 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUS-SE~ DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 10129.07 7947.00 7900.00 42 43 10267.96 8047.00 8000.00 45 16 10414.18 8147.00 8100.00 48 11 10565oll 8247.00 8200.00 48 11 10713.28 8347.00 8300°00 47 0 10858°00 8447.00 8400.00 46 13 11002.22 8547°00 8500.00 45 33 11015.00 8555.86 8508.86 45 30 DEG MIN FEET N 64 55 E &g11.42 N 65 6 E 5007.80 N 65 12 E 5114.46 N 65 12 E 5227.50 N 65 12 E 5336.82 N 64 11 E 5441.41 N 63 6 E 5545.32 N 63 0 E 5554.52 OEG/IO0 2.13 3.08 1.89 0.58 0.82 0.50 0.39 0.00 FEET FEET FEET DEG 2184.80 N 4399.80 E 4912.39 N 63 36 E 2225.51 N 4487.16 E $008.74 N 63 37 E 2270.26 N 4583.98 E 5115.36 N 63 39 E 2317.65 N 4686.60 E 5228.36 N 63 41 E 2363.58 N 4785.82 E 5337.66 N 63 43 E 2408.98 N 4880.05 E 5442.25 N 63 44 E 2454.52 N 4973.45 E 5546.16 N 63 44 E 2458.56 N 4981.73 E 5555.37 N 63 44 E ARCO ALASKA~ PRUDHOE BAY NORTH SLOPEr INC. ALASKA MARKER SAG SHUBLIK TOP ZONE ZONE ZONE GCT ZONE PBTD BASE SADLEROCHIT 4 3 2 LAS'T READING lB SAOLEROCHIT TD COMPUTATION INTERPOLATED VALUES DATE: OZ-MAR-90 PAGE 8 DATE OF SURVEY: 9-0CT-1989 KELLY B'USHING ELEVATION.' 47°00 FT ENGINEER: PORTER FOR CHOSEN HORIZONS SURFACE LOCATION = 567e FNL & 1064e FWL, SEC12 T11N R14E MEASURED DEPTH BELON KB 10216°00 10273°00 103Z3.00 ~0323.00 10436°00 10749°50 10898.00 10946°00 11015.00 TVD FROM KB SUB-SEA RECTANGULAR COORDZNATES NORTH/SOUTH EAST/NEST 8010.OZ 7963.0Z ZZlO.11 N 4454.07 E 8050.52 8003.5Z 2227.0Z N 4490.43 E 8085.ZZ 8038.2Z 2Z4Z.15 N 4523.09 E 8085.Z2 8038.Z2 224Z.15 N 4523.09 E 8161.51 8114.51 Z277.10 N 4598°77 E 8229.62 81'82.6Z 2309.48 N 4668.92 E 8371°77 8324.77 2374'72 N 4809.78 E 838Z.52 , 8335°52 Z379.62 N 4819.82 E 8474.74 8427.74 2421.61 N 4905.96 E 8508'02 8~61o02 2436.77 N 4937.04 E 8555.86 8508.86 2458.56 N 4981.73 E COMPUTAT[SN DATE: O2-HAR-90 PAGE 9 ARCO ALASKA, INC. NGI-4 PRUDHOE BAY NORTH SLOPEt ALASKA MARKER SAG SHUBLIK TOP SADLEROCHIT ZONE 4 ZONE 3 ZONE 2 ZONE lB PBTD BASE SAOLEROCHIT TO DATE OF SURVEY: 9-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT ENGINEER: PORTER ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 567' FNL & 1064' FWL~ SEC12 TllN R14E MEASURED DEPTH BELald KB TVD FROM KB SUB-SEA RECTANGULAR COORDI:NATES NORTH/SOUTH EAST/I, IEST 10216°00 8010.02 7963.02 10273.00 8050.52 8003.52 10323.00 8085.22 8038.22 10323.00 '8085.22 8038.22 10436.00 8161.51 8114.51 10539.00 8229.62 8182.62 10765.00 8382.52 8335.52 10898.00 8474.74 , 8427.76 10946.00 8508.02 8461.02 11015.00 8555.86 8508.86 2210.11N 2227.02 N 2242.15 N 2242.15 N 2277.10 N 2309.48 N 2.379.62 N 2421.61N 2436.77 N 2458.56 N 4454.07 E 4490.43 E 4523.09 E 4523.09 E 4598.77 E 4668.92 E 4819.82 E 4905.96 E 4937.04 E 4981.73 E FINAL ~/ELL LOCATTON AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11015.00 8555.86 8508.86 HORIZONTAL DEPARTURE OISTANCE aZIMUTH FEET DEG 5555°37 N 63 44 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL NO1-4 FI ELD PRUOHOE BAY COUNTRY USA RUN THREE DATE LOOOED 09 - OCT - 89 REFERENCE 7968S WELL · (567' NGI -4 FNL, 1064' 'FWL, Sku 12, TllN, R14E, UM) ?-%HORIZONTAL PROJECTION NORTH 5O00 4000 ~000 ~>000 lO00 - ! 000 -~000 SOUTH -~000 -~000 WEST REF ?3685 SCALE = l/lO00 IN/FT "T'-,'"T'T" ~T'T*T-F- "?'*'t"T*T" "T";"T'*?*-"T'±'~*'T" '*T-?T'+'--'?'4.'-:'"4."~*'+'+'-~**' ~'--+-+-+-H-*-+-+*-.~*-+.-*-+.-;**-?..+.. '*t'+'+'"i ...... F.-?.-i..+.- ~..~...~..4..-~ ....... ½....?.*~..-~ ....... !..+..~*-4- '*+'-hi"i"-m'"i'-i"~ ...... i"+'+-+-- .-+-+.-74 ....... ~*.+.+-+-...+-' .+-4 ...... ~..4.--i--4---..-i..¥.+--?--~.-i -4.- '*.4 ....... ~-.-~.--~..-~ ...... L.4..;.4 ...... .....~...;....; ....... ~..-~..-;..4... ~...~...;....~...~ ........ ;--~-4-4 ....... ;-; ...... -+-~-,-~.--¢.,+~-i---?- ~--+--F~ ...... 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SCALEO IN VERTICAL OEPTHS HORIZ SCALE = 1/1000 IN/FT Eastm n / A PETROLANE COMPANY D#~EC T#©~A L SURVEY Atlantic Richfield COMPANY WELL NAME prudhoe Bay LOCATION JOB NUMBER A276 G0071 TYPE OF SURVEY Gyro-scopic DATE 2--2'7-'76 SURVEY BY Jay Martin OFFICE Alaska COMPLET!ON.REPORT.,. .......... ATLANTIC RICHFIFLD CO. · WELL NGI.NO. __RAD_LU_S _OF .'CURVATURE NETHOD. OF _COMPUTATION KB EL~V, 47 FT, _.G.Y~R~;LSX~QI~_kC,_&UAVEY .' . COMPUTFf~ FOR FASTMAN WHIPSTOCK IN.C-. BY F. M. LINDSFY ANB AS_qC~CIATF& ............... . . . .-'.. . RECO.RB OF ~URVFY ' ALE CA:LCULAT!ONS~~~ _I B M ELF~T~ON!C C0~PUTE~ I'vIEAS. BI~ I FT ~ ANGLE D M, 0 0 100 O 26)0 300 _ 4.O0 _ 500 __ &oo _ 700 0 ' 80O o _ 900 . 0 1000 o ~100 0 1200 _ 13OO 1_400 . 1500 0 !500 0 1700 0 1800 0 ~~OQ . 0. 2000 ... ! ___2ZQo 0 2200 2300 _0 2400 0 0 50..' 35. 25 .35 O , lO 55 3O 30 40 3O .0 !J:iiLE DOG LE6 . - VERTICA'L SUB DRIF% TOTAL COORBINATF'S C 'L o .$ U R. F S .SEVEP.~TY DEPTH SEA ~JREC . 'D~ STANCE ANGLE .DEG, . _ ~ D N .$ ............. ,. ' .... ,, po z -,2 o, :o o .. s z _ ",, 3 6 o ..8_7 ,N z 1 w 99,99 ..... 5_2~9 S6~,_OOE ~52,fi~-N. 7~,5~ W 360,2S..N iZ 56 ~8 .W O,S&O___ 199..,.:.9. R Z52,98 S40~OOE SSl,~9 N _ 7S,70 W SS~!_~ N..._ZZ 50 S5 W . 0,259 ' ~e.,20 29~~,~ 536~_~_E . 350,~ N 73,16 W 35~ N_ll 46 ~.9 ;~ 9_9_, .98 '3 52 ,_9_8.__.SZg_,_O_Q_E: 3_~_D_, 04 N 72,68 W . 499.,97 ' 452,~_9_.7__~..'LO_,OOE 34,8,_74 N 72,22 W · W 59...9 · '95 5,5.Z_,.9~ _ 5.~_ _ODi~ 3 ~_fz., 86 N 72__23. W 69-9,93 6'52,93 5_%_O_,_QOW 345,06 N ...... 72,63 W 7,99.92 752,92 S Q_,OOW .... 34.3.82 N 72,74. W 89_9,92 852.3.2 S_]._O_,_OOW 34.2.95 N 72,32 w 999 · 9 '1 9_52J_9_l____&2 9,0_O_W____..~._~ 00 N 73 · ! 6 W '109c).~. 1052.91 S3~,OOW 341.15 .N 73.~72 w ~,57,.~.,1 N 11 4~ z~8,,w, o,i6o- i18__._.52_ 356,.I.4 N il 42 O_ W. 0.~10 , 118,06 3_53_,31 N__ll ~6 lO_W 0~ .... , 11!,~ ~,5z.63 N.~,i ~3 ~3 w O.z~o _. i~~ ~Z,~3 N l~ ~6 ~6 W 0,~30 350.60 N.~ 53 15. W. 0.087 543,73 N 12 4 28 W 0,170 3~9.02 N 12 11 39 W 0,170 199,90 1152,_9_0 54__2300W 340,14 N . 7.4,56 W 348,22 N 12 21 51 W 0,50.0 0 ~5 5O 5O 50 50 0 3O 50 35 5O ~ 299.81B !252.88 S69., OOW 339_,,16 N 1399,37 1352,87 S 81 ,..Q...OW .... 338,71 N 1499,86 1452~_B6~,00E_ 33"/_.551N ~ 5:99 · 85 i 552 ,_3_5__~_,_Q_Q.E___JLk6_. 49 N 1699,84 1.6.5..2 · 84 51_4, OOW ~35,18 N 1799,8~ ! 7_9_2_,_8~ $_~2 · O.OW ' 333,90 N 1'899,62 1S 5__2_,_8_2 S ~ O_,_O OW 3~3,20 N 1999.,80 1952,80 S29.00W 332,~0 N 2099,79 _20__~..2,79 S2O.OOE 331,Q.3... N 2199,79 12152,79 $ O,OOE 329,89 N 229.9,78 2252,7_8 $28,00W 328.69 N 2399,77 2352~_77 S29_,00W . 327,59 N 75.g8 W 347,5_7 I'4 12 37 ~+2 .W _ 77,67 W 34.7..,..50 N 12 54 55 W 78,27 W. 346,50 N 13 3 22 W 77,40 W 345,27 N 12 ,57 16 W. 76,94 W 343,.90 N 12 9~ 42 W. 77,6.2 W 342,8.0 N 13, ~ 14 W 78,88 W : 342,41 N 13 19 '8 W 8Q...,14 W 34!.83 N 13 33 35 W 80,24 W 340,62 h 13 37 34 W 80..,04 W' 339,.46 N ],.~.~8 18 W 80,.34 W ~_~8.~7 ~_13 44 5 W go,9~ W 337,44 N 13 52 4$ w' 1_15.07' i 13, .7 7 112.85 0,467 lO O, 209 1_08_. 2'2 O.ZSi i07 0 · o.9 o 1:0!_,..%0_. 0.927 . 107..02 o. 5~7 i.0~.Di O, 161 ' 102_:79_ o · .5 o o _, o ._~4.0' ,, Q. 2_5 o _1 0.250 99 e68. RECORD....OF SURVEY. ALL. CALCULAT.IOP~_S_P~~!qED BY ! ~ ~ ELECTRONIC COkiPUTER S_U_B $ E_A _ D I.P~¢ T_O_T_A_L__C_O_QRD INATES C L_O___S___Li_~ &EVERI TY SEC_T_LON =_ m ,D I S T A~C E .. AN_~l,. E D E GY_LO_O_FT DI ~_T_A~f._~ D m m~ um I $ ,mm ~&OO O ~O 25g9.75 2552.75 S16~W B24~4 ,N 81.~6 W 335..00 N 14 ~OO_~O 55 2799.7~ 2752.73 2900 3 65 2899 62 2852.~~ OE 328.41 N 81.90 W 338.47 ~ 14 0 15 W 3,000~ 9~~ 62 ,_B_O W. ~7...76 w 3_Q_,3. 3 W 11 · .~k,5 W 9,70 E 35_~ 13 E ~4,1~ .... E 9~00 22 1 0 39/)0.24 30 4000 27 30 4100 3O 45 . ~.300 ~ !5 ~400 42 o .... 4500 45 5 ~700 52 90 9800 5~ 0 ~900 53 30 5000 53 35 51QO 53 90 5300 52 10 ~281.95. 429~,95 N61,50E 571.50 N 370.23 E 680,94 N 32 56 10 E 6,354.42 4307_,_~.0_,50E 609_,_~[9 .... N 430.48 E 742,43. N 35 26 16 E ~422.71 ~B75~~6~E &AO,5R N 494,19 E 809.05 N B7...3B 5B .... E ~86.1~ 44.~9.1~ N6I~OE 678.05 N 561.79 E 880.54 N 39_38 35 E 4545.97 4~i~ .... N~,OOE 716,28 N 632.20 E 955.37 N 41 25 56 E 4605.10 ~558,1.~,~Q~ 75~-!g N 703.41 E 103~~__~. 0~_~ . 9664.52 9617,52 N62.0Q5 7_91.90 N 77.~.42 ~ 110..7.,63 N_4~.21 ~_9..~E ~4 ~_467~,~~~505 82~.35 N 8~61 E 118~3 N ~5 33 22 E 47R3.66 4~_66 N62~OOE _ _8~_~,30 N ~8~4.2~ ~797.29 N62.00~ 90~.03 N 1 .1R8 302,1~. 2 .~44 3.00 8 .. 3,253 3 · 7_57 6i 2 ;_Q.%. 3,1 ~ 0 6 ~,671 753_,_8~ 3,750 831 ,_0_7_ 1,637 911 ,_!2.. 0 · 5 0 0 9_91,_65. 0 ,_0_9_0 1 ~71 0_._3 3 5 1152_,_2_6. 916.59 E 1261._~7 N 986.8.0 E 1338,30 N 47 30 23 E 1.CO0 1311.74 A L L ' C A.tl C U. LA_T_LQEI~Qj~_,PJ3__5~ I B H E L E C T R 0 N I C C O.aBLLIEP,_ DOG.-LEG C__L_.,O,~._U._R_E__,5-- .~E-V~T,_Y 5 E C-T-i-ON-- _D I 5 T_AN.CE_ ............. __AN GL. "}Z_ .DLF_Ca/_ 100 F-T-----.-~T- .~.~g D .~vt .'% __.~g.aO_5~.O 5~-~A---5~52-.-QL~N 6.9,_0_0.E !.2~_~ 6 a ~6! 0 · 5 7 E. 2 o.3~_i~_ ~--5~. ~E . ~.0 5 .. 6 ~ 00 5 ~ . 0 ~, 30 .5_~1.Z,3_0.~ ~6.0.,.&~7_9~. 9 ~ N ! 679 · 83 6aO0 5a 0 55!a,78 5~7~8 -N~.~.c)F ~3!9_.8~ N ~7~,62 ~_66~_& 0 563'6.69 ....55_ag_.tf~_~i..60_.,_5_O..K~.9_gJ_69 a g7~0 %4 0 .-5609,z~7 %648~~.6~,~QE la39,22 N 1960,&3 _69~&.~~.6~,A3.., .N6i~.SQL~_.._R3 N ~10~.72 [~ 2~9.Z..J~ .~ ~ E 0,657 _7~O_52A 5 59-~.. 69 59.~_~9 N62_.Q 0S L~:_,i9 N 73!3.&2 2300 5~ 30 6053.39 6~,~9_ 5!~~_,~1 N 7383.62 a 291Q_t~54__59__~ _E O,.~O2 _7.~0~ 52_15 6!!k--~4 k06.7_,_~ N62.,_0_0_~7_0_6_,_7~ a P~_~9 _ ' ,I ~ 7~00 51 30 a237_,40 619 ' ~, ~ 06 N 5 Q_,~~6~._~ 1782, 2 92,_Q1 E .~i~,51. N 55 29 .... 26 ~ 0,810 ~_~0 51 30 8299,65 .... 6Z~,.6~ _a.6.Z,_O~a 1.alg_,~o N 2aa~38 ~.~ _9_0 lO 6615.19 656~,19 ~,~~~_73_~ N 3005,10 E 36~,63 N 56 22 ~.;..E 211!__.90 FL52__A..l 39 E 0.~_5_7 2192L_,6~- N_5.g--.SB 14 E ]-052 Z~..5_1.~,_9_0 _ a_. 5i__Z~_~0_.E 0_. 2 _~ 0 2q._~lj_l_7 N 53 43 8 F. 0,405 2!79-73__ 2260,a8_ . 2 258:_'~. 5n 2663,3_3_ ? 7_t,. ,.._~ 2823 2903.1S 29 3211,_9_9_ s 3 724_,3..6_ ~ 62_8_ ,_ .~_ _RECORD QF ALL ,_CAL, CULAT~ION-S P-,-~?~M~Y---I fl~F~ ELECTRONIC CONP_WTER ' T~LJF _J)EP_TH _A N.G LL D.~_ T H .... S E A D M D ~'G.. T_O_T_AL_CQORD_I N A T F & __ C LQ_~_U,__R_E_6_ D ! £ T_ANC E .... _~NGLE . D M S £EVERI T-Y ,%ECI_i_ON-- D. EG/_!0_0_F_T - - _D.LS.TAN~ __-82~O.0--50 _0 667-9_-35 6632.,_35 t,,16.~_,_5_OE 2037,,00 .N 3073-29 .E :;~6.~_.4.._,86 N 56 30 54 E 0,89.'7 84,-00-50 1-5 67z+.9_-.a6 . 6696-~.~6 .-N6?~_~0E 2_058-,3ZJ-.~._.N 3!~,!,._5! E . %76!_-!6 N fi5 38 3.1 F -0_-92.! F - " " ..~ ,. _ ...... 8-50~ .... 5-0--5-5 ~_9-5----&T-5-g-,-95--.-N 62,.-..5.QF_---Z~.C~. 11 N 32-0g-~ $ 9 -g-- 3 ~ 3.~J~-0-,~-N-5-&-~-5--~7--g - 8-6-00 -5 L .0 5-859.-- 93 .&8.22...9.&__~,~&.l.~.CLOE----2.Z-4.-0-, 88 N 3278,31 -E .39_!.5.,A.4~_N_-5-5--S&---Z~--F-. 0-.:909--- ,8700 60 30 693~.2_d ~;,886;20 ~,.L~...~0F 2!7_7._-.8.~ .N ?.'5~A:'~.~, F %9.97;aq N 5~ '~6 37 .E , .0 778 ...--..9~,:- ' : - -, - -_6.-_86- 7.C~2_9~.I.,_ '-0.D.E~~-?.A...F z-22/'3,83 N 57 %.3 3~ ..E . !,50q _91.&O__a_8 .0_--2-Lg&.,-Z9 ...... 2_L~6_,29 .......... N62..5_OE 2.52.G~-i3--N .3..6G._4._._SD. c~____~Lg_5~..%5__~_53__l-g--L9 E ,. 1, ! ! 7 · _ .7.2!3L,_8-:~ _u~63._,._0_LtE___2-.~5.5 _,~. - - ----.9~~3 0 7260.85 ; ' : '-~ '..,~3 N, 362..9_._7_5 E 4'568.~8.5_L~L~..7__2.2~9 _E 9~00 a6 55 't~.~9_,,09 7282,...0_9 N62.00E 2;~a9.94..N q74_.';~.,98 .E -9 a00 ~. 6 0 _ ?.2L92..~_93 .7..35.0.._9:L__J~62....04~--2A2-3-,9 8 N ?~02...-9-9- E ' 9600 44 30 7538.;15 7a9!;!5 N63:O. OE 2~8-9_,30 N .... 393~_-80 E _--9.~0.-~ ~ 5 7-6-0-9; 93- ?_562~.93_._.1~63_,.. ~O.O_E_ 2 5_2 0 -_ 90 N 3996 _- 83 E - 980 0_.A~_~-6-82--, 6 _2 '7_65.5_,_62__N.6~-,._O-O.F.- _25_53~5 _5 N ~ 05 b; 29 E R251,21 ~327,8& ~395.45 8~79,.71 0-5a5 1 !-!60 · 4.927.!5 N__~a O._.~.l__E - 5058..92..N Sa. 9 55 F · 5267.90 N 5.8.__~6 29 E 1.'t71 5~41.3_! ~ 5~15,65 N 58 38 42_E . 0,570 54S~4 N 5~ 44 37 E 0.930 552 k, 87~5. s ~~ E 1 HOLE CLOSURE _.. CODE T o.9.UF .Y~A&LLR~.ER.I I_C AL___ .... T 0_T_AL__CQDJ~T_E S · ~T H _C___L_O___S_~k,L_[q E .... _____~WB D I 5_T_A_N.C~ ANGLE SEA D .... M, $ 10217 "7,99..3.,~_'.3.B-2¢..,73,,2~ N _ z.,.~08,27.._.F 507.0,25. N 5.8__~._Q..._~)._F'_ _L02_7_0 8.0.32.,..40 ......... 26_~.&,.A 0__J".J_ ....... A~(~_GL~ 8 E ~.1D.~_,_8_7 _%5 5__.13_A2_~ 7~)_8.5_,~40 ! d3Z9 8_0_7_5.,3D__ 2._7_D...5_,_5_l_,N .... z,.33_?_,_6 ~E 1. ~ z,. 3 ~ 81 &.9_.,.2.Z_____.~LT_,_O.2 N . 44 ~ 5.,_0.& F 5.2..2,0_,_].J. N 5 fl _ 22 _3.9 F S 'L 0 ? - ~ 2 ~ 05_0_9 820D_._3__? ..... 2_7._.5.9.,_9.1_N ...... .z],X+_9_4J_9.0 g 522~+_,j_9 .... .N_5_8 .... 2_6 ....... 5-8.-.E---.A! 5 ! 0_8...1_~. _£~_0_5._,Zll. .2~B.SZ..,_Og_~__~7.gLl_,_.Al_E __5A_9£_,_8_8 ~ N~.._5.8---4-5-,-2_5 .... E- - 8 35 8-_- 0-1 · ~ n 8.98 ..... fl..A.A2_,~2_f,_8_%2N _ ,',.Z52_~03 m fi _5 5.9_,. 3 ~_ N_..:z.8 = 0_ 1.0.9.0.8.__ 8._~.69.,.~.6 ............. 282.9..,2,..0_...N ............ .~4_7..6.3_,_~ _.5 ..5. &6_,...._4.9___N ..... 5.3 ...... SD_ 11015 ' , .L~_4_~,.~.2 2911,_~2 N. _ 4.833,_7.7 F ~6_42.64 N 58 5~..6_~_3__.E____~7,,~2 ,i _ ....l¢~ u_ R'E D .._DEPTH ..... : _.._V_~ L 0 0 0 _8-4,-7 8A.7-, .... SO8 .......... 9~ 7 9-8-.7-., .. r"20-0~--O lng, 7 __l_o,,s_7_.,. _ ]o~o ..... o __ l~&Y Ll.~,.2.-. ...... i..10.0 0. ! 2.m7- ! 2 ~7''~ L .120_0 0 , -~ 3~_.7. _: 3/~_7..~_---13-~ ......... 0 l~,&_7 .... l_&.~ .7. ..... !AO 0 ............. -:3. 1_5_4_7 ! 5.~7_,_ ! 17_&_7 : 17 &_ 7_,__.1..7.Q O ............... O- LB._&7 : 8 &_7_.____i~iO_O ........ 19&7 ! ~ &_7~ZIO. ZOZ~7 20-~7-' . 2.OQO ............. 0 2-1.&7. 2 1 ~_7_.___- 2.LgO ........... O 22~L7 22/.~1., . 2200 _ .0 ? 3-~7 - 2_3_m7_,_ - 23.0.0 ._0 2t~,._.'7 2 a t.,,,_7_, ....... 2 ~.0-0- 0 25&7 254.7,, 2500 _ . 2.6z~ 26 a 7 ,_----Z6O. O .... 0 27~7 27&-L, 2 7-0-0 0 gOa8 '~ 0 & 7_L.__~~ 1 ~149 3147- .3!00 . 2 _ ~k2&l 3 2 ~ 7: 3.2~3:J 33 5..3 3 '3~.7 ~-~60 &-5~-7-.-- 3-500 ..... ~..2. 0 0 0 0 .0 0 0 0 0 0 0 2 ~ 24 ._ 3 ~ N 52._._0_7__~t 3 23; 7-L--N 83_,-3! %25.72 N 9,2.99 33!.63 N '7_9-,92 33~_~_ 69,_90 3~+2.~ '~' 55~55 /-- 1....-2 ~ ........ 3 a_a, 31 a ...... F Li../ ' %.~F 8 EASLXR F B V E R T I_CAL_ALJ~ ,/' - V D .... if,D.,_I_J V E R_'[J...CA L DEPTH. . D E P_T_kL__SE~ D i E.E~P..LL%,C E COR R E C._T_LO N TOTAL C ~ILIRtllN.A_T E 5 3313 3_88 ~- - 4...8.0 '1_ EgY o 5_!38 5~A_7 ~, 630_ ~'791 5_95 2 20 2.7. ___6.3 63 61 61 , 62,7~ , 6_61_7 67.87 .6_95 6 7289 7A53. . 7776 , ~Oe3 8721 8 ~7 7 5447,, 5_n_0D _ 832 _.5f.~_1, 5_500.___9.0.] 56 ~7_, 5 600 .....91C) 59_~_7_. 590 O__LLT_7 60a7_, ~OOO 1242 61 a_7_, 5!DO _13.06 6 2 q_7_, a20CL .... 6 a 4_!_,~0_o 1_.42.9 6!.,,._&7_, .... 6.4_0.0 ....... 65 4 7_. 65D_0___LS.~ § _6.~, 6.600 1602 . 67_~7_,.. 61DD___L63_ 8 6.8..~+_7_,_ 6~O.G 6 9 E2_, 6 ~0__L72_6 . 7 o~Lv_, 7_ODO _LE3_O 65 6_~ 70 69 62 61 i9 56 5.6 1:271.87 N 166~_._13 E 13_k9_,2 1 ~ . _1._7_~3_,1._7 _F, i ~_Q.~_,2~.__N 1_9__0.L,_.9_7_ E 1%73_,7B. N 2.Q.21_,..7 E ! 5_3C3_L71 N 2iAi. 1 2 ~ 1603_, 23 N 2260.,..0_9 ~ _ Q 16'65,39 N 237_~_,R1 E 1;Z2._~_,_6_6 N 2_.q_9_O_,~O F... 172~3_,J3_N .... 2.6_G 2.., 18,~7,25 ~: 2713,~16 E 1960,5_9 ,N__29_31_,_8~.~._I_ 20 69_,_94 N __.~_LA_4_,j91 E 2185 ,_4_f; N 3~_~6Q_,_(z6 E 22 a~L,2 2 N .... 34J.~-'_6 4 TRUE _h~OTH ,- ~EP.TH ..SEA :. _fl_I_ ~ ~6R.ENCF C©F~PFCT!C)N TOTAL CF~F)R f5 I,~A T F. $ . . . . CO30 .' 7'fa?. '7"lOO !883... 9123__ -: 7__2_,~_7__,, 7___ Z.20:0_,~9_~ .. 9~ 2:5 7 ~_3__4_7_, 730 O 19_70_9____ 96!2 75~.. __ 35.~~ ....... 0 ! 5 ! 76 a T, 7_~~~0_4 9~7 7,7a7- ~ 7700 ~2l_a~ 1~02 ! 7i~ .1~00 ~7A 1O?gfl . RNa'/..,. ROOD 2?42 lQ4 3 ! 8 ! a 7, - $ LO.O 22.83 L0-.5_7£ 83_k7_,__ S2.0a___-l.33 ! (18.7 5 8 ~&_l_, 8_~DD___2_&Z 8 B5 ! 000 9_9_9..,.. 95_2_, 3 4 ~ ,-00 _ N . .73 · 1. 5 W ~ OD fl 19 9_9._,____~9_5_2_, _ ~ _% 2,2.3_0 N - 80 ,_%4 -w .7-O00 laO.~ ........... ! ' · ~ -~ ............... 2800- .......... i ........... 3200, . - i ....... ' ~TL .... ! ' L~- Z_L .... :-3 ............. ] '-~_Z- ....... ~ ........... k/ER3'JCAEL SECTION. j.~_L_~.~.'"':r__~__J__ZLL~[ :-~-':-"'-'~ZZ~ ........ .............. -t--l':.-..-'--_'i, ....... ,_ ............ . ......... ........... .......... ,.=,ooo.: ..... ...... ........... t ............ t .... ....... ........ i ...... : e°°-I- ..... i ....... 4. ......... ,~ ....... t : ......... ~ .............. ATLANTIC RICHFIELD COMPANY ~- --: ...... '-{ ........ ~t ...... : .... :- ._ ! .... = -_J._.'L: :~' ' ~ _.,, '- -'iZZ_ - ~ _ ! _W.E_L_L. N:~..~....4._Z ...... ,_. ~ _-1-- -: j .-~ ...... '-~i ............~ .... - ...... ! i .~_.¥_._~....J .............. J ............. ~._L~.~'._J ......... ;:-- ~_.: ........... J- ....... RADIUS ~OF CURVATURE iMETHOD .~_ ...... ~ ..-I .j._~._?_.z~ ...... .~_:_. ! .... I..~-.~ ....... ~.. ,~oo ...... ~ .... ~ ....... i .............. ! .......... ~--i .......... F-~--:'-'~"-t ....... ~¥RoscoP~c suRvEY ........ t ............ ~--- ~-~ 't~'--~?f-I-~-~'.--~ '~ ..... I-" ....... i ....... i ....... i :- .... i ~ ........... !' ........... --i ..... :--~ ~--f-' l--?~ -~ .... ~ ................. i ......... ~-I ...... i .... ::1'~-~. ..... Z._._;'i~...ZJL-ZZ'L:E.._S_Z.__I. ........... .! ............... ~ ..... . -- ~ ..... t .......... ? ........... : ....... ~ ..... ~ ......r ' ........ i -- '- ............................................................................................. .......... ..--:: ......... ~ .......... I .............. ~ ............. i ............ ~ .... ..... "~ : '- ~'.j ' '~' .i .~ ~ ..__"i iL .... '~ Z. I 7.';_ ~..~: __./..;. i_~ ...... ~ (-i .... i- i- -/ ._ 'I ' "- '-:-- ~'- ........ '- '- ' ' - --: ..... i ....-~.:--':-i.- :: ........ - .... ~ . ~ . I .............. , ......... ~. ......... ~ ....... ~ ..... -~ i ~ · J ' ' 1 - ...... ~i -_:--L.'_' ."_ '.'-' ........... ~ ........ ~ ................... ~ j."...-: ..... : ..... i:". ::': .- ':--:":.:-:--I .... :: ...... ......... i ............ ~, .......... ~ ..................... ' ................ ' '~ - i : ~ - ' -Ti ...........~ ....... , ......~ ....... ...... i ......... ~ ................. i ........... i '-- - ~ "--- : i-.-" ~' ! - _ .... ~ YL:.:"_-~'_._i.' 7' _i--- -' 'i:-;.; ..... : -'. '!'-7_- '.. '~-' -' --_i- , t . . .' ....... : ..... ! ...... i ' . i , I ................. I -'--'n---., -' i ..... .'----~..: ' . " i ........... L~. ..... _!'-L'_~: ............. : ....... ' ............... ~ .......... ,-"~ 'sl ~]i .. i! i!!~!.~!!~ ~_I ................... ~ .................. i ...................... ~ .......... _ ~LL DE H$ OW .~. .... ............ ' ' ' ' t - -_' -7.-!- t ............... i ............................ i ................ ARE TVO, --'- }-' - ~ i' .............. -r ................ ~ ....... "' , - --j ..... ,-~ i!.TZ.UZL-.i_-- -' ' ' . ..................... ~ .............. ~ ........... i ....... ~ ......... i ........ : ......~! ......................... ............ ~,! ......... ........ .~* ....... ......... l. : : , i I HO Ri ZO N TA L_.:,V I EW..~x . ~ . SCALE 1".=500': ' ' ' ' · · - ATLANTIC RICHFIELD COMPANY( - WELL N.G.I. 4 ~ ......................~ RADIUS :0F 'CURVATURE 'METHOD AtlanticRichfieldCompany North Ame~ h Producing Division North Alask, . .~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 9, 1976 Hr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 RE: NGI No. 4 Permit No. 75.-69 Dear Sir: Enclosed please find the MonthlyReport of Operations for the above mentioned well. Yours very truly, C. R. Knowles District Drilling Engineer C~:j 1 Enclosure Form No. 1:.--4 l'~-q'. 3- I-?0 STATE OF ALA, SKA OIL AND GAS CONSERVATION COMMII-rEE SUBMIT IN ULTPLICATJ: MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS APl NUMERICAL CODE 50-029-20183 6 LEASE DESIGNATION AND SERIAL NO. ADL 34632 1. T. IF INDIA~, ALO'/ IE~- OR TRIBE NAME O,L [] ~,8 ~ OT.~ Gas Injection WELL 2. N~E OF OP~TOR 8. L~IT. F~ OR LEASE Atl~tic ~chfield P~oe Bay z. ~DD~ZSS OF 4. LOCATiON OF WELL P.O. Box 360, Anchorage, Alaska 99510 567t'FNL & 1064'FWL of Sec 12, TllN-R14F. 9. WELL NO NGI No. 4 (13-6-11-15) 10, Ft~.I.r~ AND POOL, OR WILDCAT ?rudhoe Bay - Sadlerochit Pool "' ii. s~.c.. T., R., M.. mo~ro~, HOU~ ' Sec 6, TllN-R15F, ' ~2. PJ~/IIT 1~O. 75-69 13. REPORT TOTAL DEPTH AT END OF MONTH, CH2~NGES IN HOLE SIZE, CASING A/FD CEMENTING JOBS INCLUDING DEPTH SET AND VOLLrlVIES USED. PERFOHATIONS, TESTS ANT) HESULTS. FISHING JOBS. JLrNK IAI HOLE AND SIDE-TRACKED HOLE A~D A/~Y OTHER SIGNIFICANT CHANGES IN HOL~ COBrDITIONS. RepoFt on operations for the month of January. Spud @ 0605 1-20-76. Drilled 17-1/2" hole to 2713', dropped multishot, POH. Ran 13~3/8", 72# MN-80 Buttress csg w/shoe @ 2711' and FC @ 2629'. Cemented w/6000 sx Permafrost I1 cmt. Recemented 20" x 13-3/8" annulus thru 2-3/8" risers w/400 sx Permafrsot I1 cmt. NU and tested BOPE. Maded up 12-1/4" BHA, tested 13-3/8" csg @ 1500 psi, drilled FC and shoe. Tested formation to .65 psi/ft. Directionally drilling 12-1/4"hole @ 6809' on February 1. __. __ ,,/ ,~/ , blOT[---Rjport on tl~i~ lorm iJ required fo~ ea¢l~ caltndar montini rtgerdlfl$ o! ll~'jtatu$ o! opotations, and must I~ tilod jn dupli~alt ~ltl~ tl~J oil o~d gos coflservat/on committee by the 15th of the succee4ing month, unle~ otherwise directed. ~T~TE of ~ALASKA DEPARTMENT OF fIATURAL RESOURCES Division of Oil and Gas __ODi K. G~lbreth, Jr. rector Thru: Hoyle !t. Hamilton Chief Petroleum Engineer ~,oM: Ben Le Norman Petroleum Inspector gATE .' February 9, 1976 .January 23, 1976 - Departed h~)me .at 7:30 AM for 8 o'clock show up at International ~)k-i~Port 'for 9:00-AM, BP charten to Deadhorse. Arrived at Deadhorse at 10:45 AM where '.we were met by BP representat.ive and driven to BP operations..Brian Rose, BP drilling.. ~foreman, called shortly after our arri.val to advise tests would be delayed due ~to poor cement job. We called Bill Congdon with ARCO regarding tests at their NGI-4'and were advised that tentative plans were for late Saturday. night or early Sunday. morning. January 24, 1976 - Arrived ~t Nabors 18-E .at 7:15 AM and Inet Bob Pomeroy, toolpusher, who advised tests would probably begin about noon. k~e toured the location and found it well organized, reserve pit .well built, steel welded fuel tanks not bermed and~ .~ well sign in place ............ - Tests began at 12:15 PM. PiPe and blind rams closed in fiv.e seconds, hydril in eleven seconds. The accumulator tested to 3000 psig.. N2 bottles tested to 2200, 2200, 2100 and 2100 psig. Rams were actuated by both primary and remote controls. Dart type and ball type valves were on the floor. Both sets pipe rams and 'blindrams tested ..to 3000 psig.. Hydril tested to 1500 psig. Both wing valves and HCR valve-on the choke Side.tested to 3000 psig. Both wing valves on the kill line tested to~.~3000 psig. The steam heater in the choke, man,ifold house blew up. earlier in the day and temperature inside the house was estimated at below zero. Since tests were being made with mud, we decided to forego testing the manifold until the heater could, be repaired. A new Koomey pump has been received on location and will be .installed on this location. All future tests will be made with this pump using diesel. Tests were completed at 5-15 .PM. A field inspection report was prepared, the original given to Brian Rose, a copy mailed to Swede Swenson and a copy attached to this report. We called Challenger Rig #51 and ,they advised us that we would be picked up, shortly. As. it turned out, they arrived at 10:45 PM-and vie departed for Arco's NGI-4 on the gas injection pad. b~e arrived at the location at ll:15 PM. Nippling up was still .in progress. Arco drilling foreman'was Joe Mann. Challenger toolpusher was Carl Lee, Ben Le Norman Field Trip Report' February 9, 1976 January 25, 1976- Tests began at 1:20 PM. Top pipe rams tested to 5000 psig. A flange i'eak-(16Wloped so we toured the location. The reserve pit was well built, the location well organized, steel fuel tanks not bermed and the v;ell sign not on location. AcCumulator was tested to 3000 psig. All rams and hydril were actuated by both primary and remote controls. There were six N2 bottles manifolded into the accumu- lator, but there was no gauge and bleed off valve incorporated in the manifold to test them. Two of the bottles had individual gauges which read 2000 and 1850 psig respectively. We recommended to Joe Mann that a gauge be utilized in the hookup for future testing and he agreed. Tests resumed at 3:45 PM and the hydril tested to 3000 pstg. Both wing valves and HCR valve on the choke side and both wing valves and the check valve on the kill line tested to 5000 psig. At this point the Sprague pump failed and repairs were begun. Testing resumed at 9:10 PR. Twenty valves and 66 flanges were successfully tested to 5000 psig in the choke manifold. Both manual adjustable chokes were free turning and tile Swaco super choke actuated. The Sprague pump failed again and repairs were initiated. January 26, 1976 - Tests resumed at 12:15 AM and lower pipe rams were tested to 5006~i'g-j ...... Bith2 rams were tested to 5000 psig. Sprague pump failed again a))d Joe Mann drove to Gull Island to 'pick up a new pump. Temperature -44°F. Wind nil. Tests resumed at 2:30 AM, but new pump would not work. Repairs were made and kelly cock a~d lower kelly valve tested to 5000 psig. Ball and dart type valves were on the floor. Tests were conCluded at 3:45 AM. A field inspection report was prepared, the original given to Joe Mann, a copy mailed to Benny Loudermilk and a copy attached to this report. Departed Deadhorse at 1:30 PM via btien flight 24 arriving in Anchorage via Fairbanks at 4:05 PM and at my home at 4:35 PM. In summary, vle witnessed BOPE.testing at BP's GC-1B and Arco's NGI-4. .'SatisfaCtory ' )ype..Inspect~on <-." }-(.' ":. SatisfaCtory ~p~pec't~on 'Yes'- NO:-~. Item' '( ~Loca~i on, Generai'-/;~'-' 'Yes No . Item (~BOPE Tests (')< (~.: ~i ~~ ~ ~~.... - '(~ (): ~]'/~Casing set (~)~ ( ) .2. General Housekeeping . ' (l~" ( ) 16. TeSt fluid-( )wtr.---]--C )mud (~oii ~ (~-(). (~,. (') () () () - () () () () 3.: Reserve Pit-( )oPen( )filled' 4.-Rigl '. · ' ( ).Safety Valve TeSts 5. 'Surface-No. Wells ' ' .6. SubsUrface-No Wells .( ) W~.ll Test Data 7. Well Nos. , , , 8.. Hrs. obser , , , ( ) ( )::_ 9. 'BS&W ,--, ,-- ( ) ( ) 10. Gr. Bb'ls. ( ) Final Abandonment (') ( ) 11-. P&A Marker () () () (} () () (~-- ( ) (~() () () (~() (,~r- ( ) 12. Water well-( )capped( )plugged (~() 1 3; Clean-up (1~)~ ( ) 14. Pad' leveled (~-- ( ) 17. Master Hvd. Control.Sys.-~sig 18 N? btls~_~_~,~,~,.. ~ psig 19 REmote' Controls 20. Dri 11 ing spool -__~___"outl ets 21. Kill Line-(j~)~Check valve 22. Choke Flowline (~)~CR valve 23. Choke Manifold No. valvs~_flgs~' 24 Chokes-( )Remote(~os.(~kdj. 25-Test Plug-( )Wellhd(~)~6's.o( )none 26,. Annular Preventer~_~xL~psig 27. Blind Rams,~sig 28. Pipe Rams ..~.~~sig 29. Kelly & Kelly-cock,,~psig 30. Lower Kelly valve~sig 31 Safety Floor valves-(~'BV Total inspection obs. ervation time ~ hrs/(ta~..Total number leaks and/or equip, failures RemarkS ~z~. .~'~ ?-~:.~ ~-,~.~ ~.~~~z~ ~ ~.~: ,.:,., .:,,~ .. cc' '~- .... ; / !,;~.~,~._ Date/-.~.~- <-,~;:, ~... ~,.,-~< Notify in days or when ready Inspected by ~,' ~ ......... .. . }.,'_; .?.., .' ... . ...... -. :.: ..;.,._... :;......: ..... . .... -...< .... :..- ........ . . , · .... ... _ -:.f ..... :.. .............. -.,,:-;~,. :< ....... .. ~!?,tlanticRi~;hfieldCompany North Americ~e,~Producing Division Alaska Reg[ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 7, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 ,- .... - 8 I976 RE' NGI No. 4 (21-11-11-14) Sec 11, T 11 N, R 14 E, UM Dear Sir: Enclosed please find a Sundry Notice for the above mentioned well. This change in plans was discussed in Mr. Schmidt' s call to Mr. Hamilton today. Very truly yours, C. R. Knowles District Drilling Engineer Enclosure CRK: cs Form R_EV. 9-30~ 9 Submit "Intentions" in Triplicate & "Subsequent P~ports" i~ Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMII-[EE SUNDRY NOTiC'ES AND REPORTS ON WELLS /Do not use this form for proposals to drill or Io deepen Use "APPLICATION 'FOR f~'Et~,iI'/'-L" '/or such'proPosals.) OIL ~ GAS ~EL: --~ wE,L OT,E~ Gas Injection 2. NAME OF OPERATOR Atlantic Richfield ,Company 3. ADDRES£ Ok" OPERATOR P. O. Box 360, Anchorage, AK, 99510 4. LOCA, TtON OF WELL At surface 567' FNL & 1064' FWL of Sec 12, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, OR, etc. 18' Gravel Pad 14. 5. AP1 NUI~LEHICA.L, CODE 50-029-20183 6. LEASE DESIGNATION A. ND SEI;:IAL NO. Surface ADL 28302 Btm Hole ADL 34632 7. IF INDIA.N, ALLO'I-rEE OR TRIBE NAALE s. UNIT, FAttN[ dR LEAS~. NaM~- Prudhoe Bay' 9. W'ELL NO. NG1 No. 4 (13-6-11-15) 10, FIELD AND POOL, OR WILDCAT Prudhoe Bay Sadlerochit 11. SEC., T., R., M., (BOTTOM HOI~' OBJECTIVE) Sec ,6~ Ti IN~ R1 SE~ UM , 12. PEH~%IIT 75-69 Check Appropriate Box To Indicate Nature c~ 'Notice, Re tort, or Other Data ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI.ETE REPAIR %VELL CHANG~ PLANB O:her) fRACTURE TREATMEST *LTZRI,~O CASINO (Other) . (NOTE: Report result~ of multiple completion on Well Completion or Reeompletton Report and Log form.) 15. DESCRIBE PROPOSED OR C0.MPLETED OPERATIONS. (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, Atlantic Richfield Company proposes to change the bottom hole location of this gas injection well from Section 11, TllN, R14E, UM to a 8300' ss Target location 1800' North and 800' East of the SW corner of Section 6, TllN, R15E, UM. The dfstance from this target loca~n to the. nearest well' is' 2880' ~--d--fo ~ nearest lease line is 800'. Proposed TD for this well is 11,500' ~ (8554' TVD). The proposed 9-5/8" casing depth is 9700' MD. Ail other data specified in the Application for Permit to Drill will remain the same. The estimated spud date is January 13, 1'976. Note the change in well number from NG1 No. 4 (21-11-11-14) to NG1 No. 4 (13-6-11-15). 1~. ~ hereb7 certify thatf~/foregoin~l true' and correct T~TLEDistrict Drilling Engineer DATE .Tan: 7~ !976 · · (This space for StarRed. APPROVED By ~ CO.NDITIONI OF,~PPROVAL, See Instructions On Reverse Side ~hoe ~ NG! State Pe~ Ne. 75-69. Enclosed ts the appreved appl.t~tton for permlt to drill the above referenced ~ell at a locatton I~ Sectlo, 111, Tokmshtp 11g, Range 14E, t~e11 samples, core chtps, and .a mud log are not r~.utred. A directional sur- ~ve.y Js required, Hany rtve~s tn Alaska ami' ~tr drainage systems have been classified as -!epor~ fo~ tl~ spa~mJng or migration of anadromous fish. Operations tn these areas are sub,~ect to ~ 1§.~.870 and the eegutatlons promulgated there- under (Title 5, Alaska Adm~JnJstra.~:tve Code). Prtor to commencing operetlons you may. be contacted by the ~t~bJtat ~tnator's office, Oepartment of Ftsh and ~me. Pollut!on of any ~aters of the State ts .prohtblted by AS 46, Chapter 03, Rrttcte 7 and ~ regulations _promul~d thereunder (Tttle 18, Alaska Administrate. ye ~, Cha~Pter 70) and by the .Federal Hater Pollutlon Contro.1 Act, as ~.. Prior to c~tng operations you may be contacted by a representative of the Oepar. tment of £nvtrmamntal Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alas.ka Department of Labor is being notJfted of t. he issuance o.f thts permtt to dr111. To atd us In scheduling fteld_ work, ~e would appreciate your notify.lng thls offlce wlthin 48 hours after the: ~ell ts spudded, t~e would al. so l~ke to be nottfJed so that a representative .of~ the Ot.vtston may be present to wttness testing of blowout preventer .equJ~t before surface castng shoe ts drtlled. ]~n the event, of suspension or abandonam~t please gtve thts offtce adequate advance notification so that we- may have a witness Present. Thomas R. l~arsha11, ,Tr. Executive SecreCy Alaska 0~1 and Gas Conservation Cem. tt~ C. R. rmowles No~ gl. 1~75 ~:bjm Encles~e cc: Oepar~t ef Fish and ~,, Habttat Sectton w/o eric1. ~rtment of Eavj~tal Conservation w/o encl. Oepartz,e~t ef -Labor, 'Supervisor. Laber Law Compliance O~vtstm ~/o encl. Submit "Intentions" in Tripliuate & "Subsequent 1-leports" in Duplicate Form ~--3 t,Y-LE V. 9-30-6 9 STATE OF ALASKA OIL AND GAS CONSERVATION ,COMM! .'UEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to decpefl Use "APP~,ICATION 'FOR P'Et~iI'i'---'" '/or such ":~ ' ~ °"' I-X'i,' Gas Injection %V£LL WELL OTHER NAME OF oPERA~OI~ Atlantic Richfield Company 3 ADDRESS OF OPERATOR P. O. Box 360,. Anchorage, Alaska 99510 4. LOCATION OF ~VELL 2kt surface 567'FNL fi 10.64'~VL of Sec 12, TllN, R14E, [gl 13. ELEVATIONS (Show whether DF, RT. ~l; e~c. '" 18' Gravel Pad 14. Check Appropriate Box To Indk~te Nature of Notice, Re NOTICE OF INTENTION TO: FRACTURE TREAT ~1 MULTIPLE COMPLETE SHOOT 01~ ACIDIZ~ ABANDONe REPAIR WELL CHANGE PLAN8 .__ , Other) 5. AP/ NLrl~ I~I{ICAL CODE' 50-029-20183 6'/LE~$I~. DE:SIGNATION A~ND SER[~.L NO. ADL 28302 7. IF INDI.a~N, A_LLOI"YEE OR TI{IBE NA!~I.E 8. UNITa FAf~,Y~ OR LEASE NAME Prudhoe Bay 9. WI:,X,L NO. #4 10, FIELD A2gD ]POOL, OR WII~DCAT Prudhoe Bay-Sadlerochit lt. SEC., T., R., 1~I., (BOTTO~I HOLE OBJECTIVE) Sec 11,.. TllN, R14E, UM t2. P~'t:~UT 75-69 ~ort, or Other Dnt',~ WATER SHUT-Orr [ ' REPIIRtN0 WgLL [ ' i FRACTURE TREATMENT . ALTERING CASING, SHOOTING OR ACIDIZING , . ABANDONME~T~ I [ (Other) (NOTZ: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) 15 DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated dat~ of starting any proposed work. The Atlantic-Richfield Company proposes to change the bottom hole location of this gas injection well from 1000'FNL fi 2200'B~L of Sec 11, TllN, R14E, UM to 270' FNL ~ i$00'B~L of Sec 11, TILN, R14E, OM. The distance from the proposed location to the nearest lease line is 1500'. The distance from the proposed location to the nearest well is 3000'. The proposed 9-5/8" casing point is 9300'MD. The proposed TD is ll,100'MD, 8900'TVD. All other data specified· in the Application for Permit to Drill will remain the same. The estimated spud date is December 25, 1975. ' 16. I hereby certlg he reg01ng SIGNED See Instructions On Reverse Side. Approved ~opy Returned AtlanticRichfieldCompany North Ame~~''~ ProduCing Division North Alask~ ~trict Post Office' bvx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 13, 1975 Mr. O~ K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 RE' NGI #4 (21-11-11-14) Sec 11, TllN, R14E, UM Dear Sir' Enclosed is our Application for Permit to Drill the Subject Well, together with the $100 Application Fee and required survey plat. This well will be directionally drilled. The surface location and target location are both on ADL 28302. This lease has an effective date of 10-1-65 and termination date of 3-27-84. ~ The information in the above paragraph will be helpful to the State Department of Labor. Very truly yours, C. R. Knowles District Drilling Engineer CRK:alh Enclosures Form P 1: ~ ' /, , , (O~her instruction~ REV. 0.~~'l'. ?"J' : //-'- ii: i:~_ ! ~ reverse side) ~ . '" ~A~E OF ALASKA ~ OI g>ANDC~AS'~' CO NSERVAT ION COMMITTEE "" A~PLI 'FOR~aMIT-~T_O DRILL DEEPEN, OR PLUG BACK DRILL ~ DEEPEN ~ PLUG BACK OIL ~ OA~ ~,~ w,~ ~ .. o~.~. ~as Injection ~o.."~' ~ ~""~'~"~~o~ 2. NAME OF ., Atlatic Richfield Comply P. 0. Box 360, ~chorage, ~ka 99510 4. LOCATION OF WEL~ At surface 567'~L & 1064'~ of Sec 12, Ti~, ~4E, ~ At ~ro~sed prod. zone 1000'~ & 2200'B~ of Sec 11, TllN, R14E, ~{ 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 8 miles Northwest of Deadhorse 14, BOND INFOP,~[ATION: TYPE Statewide surety ~nd/o~ No. Federal Insurance Co. # 80113840 S. 50-029-20183 · 6. I~SE DI/ISIGNATION A_NrD S~IAJ~ NO. ADL 28302 1F INDIAN, AJ.,LOTTEE OR TRIBE NA.M~E 8. UNIT, FARM OR LEASE NA~ME Prudhoe Bay 9. WELL NO. NGI #4 (21-11-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit 11 SEC., T., R., M,, (BOTTOM HOLE OBJECTIVE) Sec 11, TllN, R14E, UM 12. ~o.,-, $100,000 15, DISTANCE FROM PROPOSED* 16. LOCATION TO NEAREST PROPERTY OR LEASE LINE. F`T. 2200 ! {Al~o to nearest drig, unit, ii any) -~8. D~ANCE FROM PROPOSED LOCATION* ' ........ 119. I OR APPLIED FOR, FT. 3500' ELEVATIONS (Show whether DF, RT, C-H. etc.~ 18' Gr~vel Pad NO. OF ACRES IN LEASE 2560 PROPOSED DEPTH 10,600' , 17. NO. ACRES ASSIGNED TO THiS WELL 320 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* December 10, 1975 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE ,..SIZE OF CASING WEIGHT P~ FOOT L G~ s~G DEPTH QUANTIT! OF C[MZN: 32" .... 20" 94# '.~H-40 .... 100' c'i~c t6 surface -+500 sx PF II' 17~1/,2" ' i13_3/8,,, ' 72#'' ''~ MN;80 2700"" Circ t---~ surface +4000 s× ,, .... " ", " , ' _ 9-5/8 . 47# l~q, 80 .. 89.0.0 ,1500 -+ .C~lt. CO!..tmm ls~ Stg - +1.000 8~1/2i''' ....... 7'"Liner '29'#, '" i,S~D,-,95 , ,~ 300'-+ cmt column 2nd st~ -,-+125 s: · . ............ ' ~MN-80' "'..'TD . 125.0'i cmt col .um.- -+'25~ sx sx The Atlantic Richfield Company proposes to directionally drill this well to +10,600'~fl), 8900' TVD, for future use a gas injection well in the Sadlerochit gas cap. Logs will be run over. selected intervals. A 20-3/4'.' 2000 psi Hydril will be used on the 20" conductor. A 13-5/8" 5000 psi Hydril and 13-5/8, 5000 psi pipe and blind rams will be used on the 13-3/8" casing. The BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. 7" 29# ~q-80 Hydril SEU tubing with BOT Arctic Husky RH-1~ packer assembly, and a 7" safety valve landing nipple will be run as a completion asSembly. The well will be shut in pending perforating. YI~ ABOVE SPACE T)IESCHIBE I~ROPOS~ED PROGRAM: If ~I is ~ dee~n or plug ~, give &~ on p~ent p~u~ive zo~ ~d pro~ new produ~ive ~e. If p~l ~ ~ drill or ~n d~e~ ~o~lly,. give pe~ent ~ on ~bsu~a~ ~t~ ~d m~s~ ~d ~ue ve~ical dept. Give bio--ut preventer p~gram. 24, I he~by ce~if~~~e~ ~ S!GN~'.J- ,...~':~~' I~ . ~ ~ ~ jSXI~IPLF.,S AND CORE CHIPS S ~m ~ NO Correct CONDITIONS OF .APPROVAL, iF' ANY: A.P.I. ~CAL CODE 50-029-20183 'Exec. Secretary 0 .... : .... TI~, , 11-21-75 DA"fl: secfion line 96.5' 989' 1014.' 1064' 1089' 1114' 1139' CERTIFICAT~ ' OF SURVEY.OR I HEREBY CERTIFY THAT ! AM PROPERLY R~GISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE .~Y ME OR UNDER MY SUPERVISION, 'AND ALL DIMENSIONS AND O~HER DETAILS ARE CORRECT. OCT 4, 1975 AS - BUILT WELL NO. I LAT. 70°19'36.12~9'' LONG, 148°28'50,016" Y 5 971 400.07 X 687 350.54 WELL NO. 2 °!' ' 4" .LAT 70 9,37.28 ,, LONG. 148°28 50.762 Y 5 971 516.90 'X 687 322.06 WELL NO. 3 LAT. 70° 19'38.441" LONG. 148°28'51.493'' ,Y 5 971 633.76 X 687 294.09 WELL NO. 4 LAT 70° 19'59.596" LONG. 148°28'52.223'' Y 5 971 750.62 X 687 266.18 WELL NO. 5 LAT. 70° 19' 40.749" LONG. 148 °28'52.947'' Y 5 971 867.11 X 687 258.47 WELL NO. 6 LAT. 70° 19' 41. 908" LONG. 148° 28' 53.682" Y 5 971 984.28 X 687 210.34 WELL I~10. 7 0 ' 4 ~1 LAT. 70 19, 3,052.. LONG. 148028 54,412 Y 5 972 099.94 X 687 182.47 WgLL NO. 8 LAT. 70° 19'44,210" LONG. 148°28'55.126'' Y 5 972 217.07 X 687 ~55.06 WELL NO. 9 LAT. 70° 19' 45.370" LONG. 148° 28'55.850" , WELL NO. I0 LA'/'. 70° 19'46.519" LONG. 148°28'56.589'' Y 5 972 334.31 X 687 127.31 f 5 972 450.53 X 687 099.14 EXISTING WELL OR CONDUCTOR' PIPE WELL NO; I TOP PAD ELEV. = 18.4 FT. MLLW ""'VL # ....... L ATLANTIC RICHFIELD CO. -- AS-BUILT 'WELL I THUR I0 NORTH INdECTION SITE LOCATED IN PROTRACTED SECTIONS I ~.I2,.T_IIN, RI4E, U.M. PREPARED B Y HEWITT V. LOU. NSBUR¥ B A$SOC 723 W. 6 TH. AVE., .ANCHORAGE., ALASKA i , _, iL v ~t ' ' ,, ,1 i. il i , i . i,1 i' DATE OCT 9, 1975 SCALE., 1"=.3...00' LOOSE CHKD. BY G. D. FIELD BK LEAF- 965' 989' i014' 1039° · _ _ sE C fiOk ...... 1064' !089' 1114' SECTION CERTIFICATE OF .SURVEYOR ! HEREBYCERTtFY THAT ! AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT T~.H"/$ P.LAT; REPRESENTS A LOCATION SURVEY. MADE ,.~, Y ~M~_ .. OR UNDER MY SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT.. OCT 4 , 1975 12 A. - BUILT WELL NO. I LAT. 70°19'36.129'' Y 5 971 400.07 LONG. 148°28'50.016" X 687 350.54 WELL NO. 2_ .LAT. 70°1 ,57.284, Y 5 971 516.90 LONG. 148° 28 50.762' 'X 687 5,22.06 WELL NO. ,3 LAT. 70° '19'38.441" 'Y 5 971 633.76 LONG. 148°28'51.493" .X 687 2.94.09 WELL NO. 4 LAT. 70° 19'39,596" Y 5 971 750.62 LONG. 148°28'52.225" X 687 266.18 WELL NO. 5 LAT. 70° 19' 40.749" LONG. 148 °28'5~..947" Y 5 971 867.11 X 687 238..47 WELL NO.. 6 LAT. 70°19' 41.908" LONG. 148° 28'53.682~' WELL /~/0. 7 AT. LONG. 148 °28 54.412 WgLL NO. 8 LAT. 70° 19' 44.210" LONG. 148°28'55.126" Y 5 971 98~.28 X 687 210.54 Y 5 972 099.94 X 687 182.47 Y 5 972 217.07· X 687 155.06 WELL NO. 9 LAT, 70° 19' 45.370" LONG. 148° 28'55.850" · WELL NO. I0 LAT. 70° 19'46.519" LONG. 148028'56.589..` Y 5 972 334.31 X 687 127.51 Y 5 972. 450.55 X 687 099.14 EXISTING WELL OR CONDUCTORr PiPE WELL NO. ! TOP PAD ELEV. = 18.4 FT, MLLW ARCO~ AFE 292265 HVL# ATLANTIC RICHFIELD AS -BUILT 'WELL I THUR I0 NORTH INJECTION SITE LOCATED IN PROTRACTED SECTIONS I &I2, TIIN.,__~_I..4E_,=U.M.- .... ___-. PREPARED 8 Y . H.EWlTT V. LOU. NSBUR¥ 8 ASSOC. . 723 W. 6TH. AVE.., ANCHORAGE, ALASKA DATE OCT 9, 1975 SCALE _1__= 30O, LOOSE CHECK LIST FOR NEW ~,~ELL PERMITS ..... -"' Company Yes No Remarks 1. Is the permit fee attached ................ - ..... ~Lease & Well No. 2. Is well to be located in a defined pool ............. ~ 3. Is a registered survey plat attached ................ 4. Is v~ell located proper distance from property line ......... 5. Is well located proper distance from other wells .......... /F~/- 6. Is sufficient undedicated acreage available in this pool ..... /F~a~ 7.' Is well to be deviated ....................... AK-~PF-- ,~.~",'~ _s~ operator the only affected party ............... X/~g~ 9. Can permit be approved before ten-day wait ............. ~< I0. Does operator have a bond in force ................ ~ il. Is a conservation order needed ................... 12. Is administrative approval needed ................. 13. Is conductor string provided .................... Im. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings 16<,,i~''' ~11 cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ........... i8. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating ...... Additional Requirements' Approval Recommended' Geology Engineering: TRM~c HI;IK~/-~g ~W' OKG HHH Revised 1/15/75