Learn about The PHMSA Hazardous Liquid Pipelines Mega Rule Part (1) revisions and new requirements. Discover what the new rule means for pipeline operators.
The new section 192.607 defines requirements for verifying material properties and attributes of onshore steel transmission pipelines. Operators must maintain traceable, verifiable, and complete records for the life of the pipeline. The rule requires developing procedures to verify unverified material information through destructive or non-destructive testing. It also establishes sampling programs for pipelines with incomplete data to test for properties like minimum yield strength. The impacts are moderate, as operators will need to update practices to comply with the new verification and record keeping standards.
The document summarizes key aspects of PHMSA's final rule for gas transmission pipelines, including:
- Several new definitions are added around engineering critical assessments and moderate consequence areas.
- Requirements are added around material records retention, pipe design records, and component records that must now be kept for the life of the pipeline.
- MAOP establishment and reconfirmation has new requirements, including increasing the Class 1 safety factor from 1.1 to 1.25 and developing procedures to reconfirm MAOP for pipelines lacking complete records or in high consequence areas. Pipelines must complete 50% of reconfirmations by 2028 and 100% by 2035.
Learn about The PHMSA Hazardous Liquid Pipelines Mega Rule Part (1) revisions and new requirements. Discover what the new rule means for pipeline operators.
The document summarizes the final rule on gas gathering line regulation from PHMSA. It provides an overview of gas gathering and the types of gathering lines (Type A, B, C). The rule is effective May 16, 2022 with some exceptions. It clarifies definitions, requires reporting and mapping for Type R lines, and regulates Type C lines 8.625 inches or larger based on pressure and location near buildings. Operators have one year to comply with requirements for Type C lines. The rule also addresses incidental gathering lines, documentation of gathering points, and allows composite materials for Type C lines with notification to PHMSA.
This document provides an overview of corrosion monitoring and assessment requirements for pipelines. It discusses regulatory requirements for external, internal, and atmospheric corrosion control. The document reviews various assessment methods including test point assessments, rectifier assessments, close interval surveys, direct current voltage gradients, bond assessments, isolation assessments, alternating current assessments, and visual inspections. It also discusses data collection and record keeping requirements. The presentation aims to help identify gaps in corrosion control programs and plan future assessments to achieve regulatory compliance.
The document provides an overview of external corrosion direct assessment (ECDA). It summarizes the four phases of ECDA: pre-assessment, indirect inspection, direct examination, and post-assessment. The pre-assessment phase involves collecting pipeline data and selecting indirect inspection tools. Indirect inspections are then performed to identify corrosion indications, followed by direct excavations to validate findings. Finally, the post-assessment phase includes calculations, defining reassessment intervals, and continuous improvement. The presentation is delivered by Matthew Myers, an experienced pipeline integrity and corrosion expert.
This document discusses the design and construction of new pipelines for compliance, integrity, and corrosion prevention. It covers safety statistics from 2017-2020 showing zero recordable incidents. The agenda discusses jurisdictional analysis to determine pipeline regulations, high consequence area analysis, emergency flow restriction devices, geohazard analysis, leak detection capability analysis, AC interference modeling, cathodic protection design, risk analysis, and installation and commissioning of cathodic protection and AC mitigation systems.
This document summarizes a webinar on hazardous liquid pipeline integrity and risk assessment. The webinar covered regulatory requirements for integrity management programs, including requirements for risk assessment, information analysis, preventative and mitigative measures, and assessment intervals. It discussed how operators can use risk analysis to prioritize pipeline segments, quantify the benefits of mitigation actions, and optimize integrity program resources. The presentation emphasized using a quantitative risk analysis approach considering probability, consequence, and threats to establish reassessment intervals and preventative measures.
The new section 192.607 defines requirements for verifying material properties and attributes of onshore steel transmission pipelines. Operators must maintain traceable, verifiable, and complete records for the life of the pipeline. The rule requires developing procedures to verify unverified material information through destructive or non-destructive testing. It also establishes sampling programs for pipelines with incomplete data to test for properties like minimum yield strength. The impacts are moderate, as operators will need to update practices to comply with the new verification and record keeping standards.
The document summarizes key aspects of PHMSA's final rule for gas transmission pipelines, including:
- Several new definitions are added around engineering critical assessments and moderate consequence areas.
- Requirements are added around material records retention, pipe design records, and component records that must now be kept for the life of the pipeline.
- MAOP establishment and reconfirmation has new requirements, including increasing the Class 1 safety factor from 1.1 to 1.25 and developing procedures to reconfirm MAOP for pipelines lacking complete records or in high consequence areas. Pipelines must complete 50% of reconfirmations by 2028 and 100% by 2035.
Learn about The PHMSA Hazardous Liquid Pipelines Mega Rule Part (1) revisions and new requirements. Discover what the new rule means for pipeline operators.
The document summarizes the final rule on gas gathering line regulation from PHMSA. It provides an overview of gas gathering and the types of gathering lines (Type A, B, C). The rule is effective May 16, 2022 with some exceptions. It clarifies definitions, requires reporting and mapping for Type R lines, and regulates Type C lines 8.625 inches or larger based on pressure and location near buildings. Operators have one year to comply with requirements for Type C lines. The rule also addresses incidental gathering lines, documentation of gathering points, and allows composite materials for Type C lines with notification to PHMSA.
This document provides an overview of corrosion monitoring and assessment requirements for pipelines. It discusses regulatory requirements for external, internal, and atmospheric corrosion control. The document reviews various assessment methods including test point assessments, rectifier assessments, close interval surveys, direct current voltage gradients, bond assessments, isolation assessments, alternating current assessments, and visual inspections. It also discusses data collection and record keeping requirements. The presentation aims to help identify gaps in corrosion control programs and plan future assessments to achieve regulatory compliance.
The document provides an overview of external corrosion direct assessment (ECDA). It summarizes the four phases of ECDA: pre-assessment, indirect inspection, direct examination, and post-assessment. The pre-assessment phase involves collecting pipeline data and selecting indirect inspection tools. Indirect inspections are then performed to identify corrosion indications, followed by direct excavations to validate findings. Finally, the post-assessment phase includes calculations, defining reassessment intervals, and continuous improvement. The presentation is delivered by Matthew Myers, an experienced pipeline integrity and corrosion expert.
This document discusses the design and construction of new pipelines for compliance, integrity, and corrosion prevention. It covers safety statistics from 2017-2020 showing zero recordable incidents. The agenda discusses jurisdictional analysis to determine pipeline regulations, high consequence area analysis, emergency flow restriction devices, geohazard analysis, leak detection capability analysis, AC interference modeling, cathodic protection design, risk analysis, and installation and commissioning of cathodic protection and AC mitigation systems.
This document summarizes a webinar on hazardous liquid pipeline integrity and risk assessment. The webinar covered regulatory requirements for integrity management programs, including requirements for risk assessment, information analysis, preventative and mitigative measures, and assessment intervals. It discussed how operators can use risk analysis to prioritize pipeline segments, quantify the benefits of mitigation actions, and optimize integrity program resources. The presentation emphasized using a quantitative risk analysis approach considering probability, consequence, and threats to establish reassessment intervals and preventative measures.
The document discusses the history and current regulations regarding material traceability for natural gas pipelines. It proposes that operators must acquire and retain manufacturing records for steel pipe, pipeline components, and welder qualifications for the life of the pipeline. The document then outlines a typical workflow for tracking material on new construction projects using radio frequency tags, barcode scanning, and a database integrated with survey mapping. It discusses lessons learned and requirements for ensuring an effective material tracking system that provides value through transparency, communication, and reducing completion time.
Pipeline documentation is required to provide a history of pipelines and ensure regulatory compliance. Key documents that should be retained include pipeline maps, licensing information, inspection records, corrosion monitoring data, repair reports, and audit results. Proper documentation of tasks like right-of-way patrols, material balances, shutdown device testing, corrosion assessments, and repairs provides a history to evaluate pipeline integrity and ensure safety requirements are met. Documentation should generally be kept for the life of the pipeline.
Direct Assessment ECDA Program DevelopmentMTS Webmaster
The document discusses the requirements and process for conducting an external corrosion direct assessment (ECDA) on gas transmission pipelines located in high consequence areas. The key points are:
1. An ECDA involves a 4-step process of pre-assessment, indirect examinations, direct examinations, and post-assessment to evaluate external corrosion risk.
2. The pre-assessment step involves collecting pipeline data and using it to identify ECDA regions and select appropriate indirect inspection tools.
3. Indirect inspections are then conducted using two or more tools to identify and classify corrosion indications by severity. Direct examinations are then focused on the most severe indications.
4. The post-assessment step defines reassessment intervals
SCT an Advanced Pipeline Integrity SolutionBrett Payton
The SCT Technique fills the gap in the armory of integrity engineers when assessing the condition of difficult to inspect pipelines and is being referred to as a "game changer" by many individuals in the industry.
New Rulemakings: What Can We Expect - Gary Krichaunacetwincities
The final rule expands requirements for gas transmission pipelines related to in-line inspections, records documentation, MAOP reconfirmation, and integrity assessments. Key aspects include incorporating new in-line inspection standards, requiring records of additional material properties, expanding the definition of moderate consequence areas, and outlining six methods for operators to reconfirm MAOP. The rule is expected to drive the need for additional in-line inspections, material verification testing, engineering analyses, and planned pressure test or assessment work over the next 15 years to meet reconfirmation deadlines. Additional rulemakings are anticipated to address repair criteria, corrosion control, and other integrity management topics.
This document provides an overview of total asset integrity management and pipelines regulatory compliance. It discusses:
- The objectives of pipeline integrity management programs and the Alberta Energy Regulator's focus.
- The different regulatory jurisdictions for pipelines in Canada and Alberta. Pipelines in Alberta are primarily regulated by the Alberta Energy Regulator.
- The key documents that comprise a pipeline integrity management program, including the Pipeline Integrity Management Program manual, Pipeline Operations and Maintenance manual, and Pipeline Integrity Management Strategy.
- The various requirements for pipeline integrity programs as outlined in CSA Z662 and other standards, including hazard identification, risk assessment, inspection and testing, documentation, continual improvement, and incident investigation.
Jimoh Adumoh has over 7 years of experience as an instrumentation and metering engineer in the oil and gas industry. He has worked for Shell Petroleum, General Electric, and Krohne Oil and Gas in both offshore and onshore roles commissioning, maintaining, and validating various metering equipment such as flow meters, pressure and temperature transmitters, and gas chromatographs. His responsibilities included ensuring accurate measurement and minimizing measurement errors. He is seeking a new position as a measurement or instrumentation engineer.
The document discusses proposed changes to ANSI standards regarding field testing of electricity meters. It outlines:
1) Planned updates to ANSI C12.1 and C12.20 that will refer to a new ANSI C12.29 standard focused specifically on field testing procedures.
2) The new C12.29 standard is being drafted and will provide best practices for testing meters, instrument transformers, and auxiliary devices in the field.
3) The future of field testing is expected to involve more comprehensive checks of meters and installations beyond just accuracy, including software verification and tamper detection.
110921 commissioning of offshore installationslaithu2908
This document discusses the commissioning process for offshore installations built in yards. It covers the total commissioning activity and defines the key phases of mechanical completion, pre-commissioning and commissioning. Mechanical completion involves verifying construction work is complete according to design. Pre-commissioning verifies functionality and system integration. Commissioning verifies systems are ready for operation. The document provides details on planning, organization and activities for each phase. Estimates suggest 95-105 systems for an FPSO requiring around 135,000-145,000 hours for commissioning, taking around 6 months with a team of 90 people. Addressing issues can help improve estimates over time.
The document discusses commissioning of offshore installations in building yards. It covers the total commissioning activity and defines the key phases of mechanical completion, pre-commissioning, and commissioning. Mechanical completion involves verifying construction meets design requirements through testing. Pre-commissioning focuses on verifying system functionality and instrument calibration. Commissioning execution involves final checks before handover to operations. Effective planning is critical to the success of each phase.
The document provides an overview and schedule for the hook-up and commissioning services by PBJV Group Sdn Bhd for Lundin Malaysia B.V.'s Bertam offshore development project. Key details include the contracting parties, administrative requirements, technical scope of work, use of marine vessels, quality and safety plans, procurement, financing, scheduling and reporting, and document control. The project involves installing and commissioning equipment on the wellhead platform between May 2014 and December 2014 to achieve first oil.
Understand contents of ANSI C12.20-2010 for 0.2 and 0.5 Accuracy Class Meters.
Understand the Relationship of C12.20 to C12.1.
Understand ANSI C12.20 Changes Planned for 2015. Edition and ANSI C12.1 changes planned for 2014.
Understand new ANSI C12.29 for Field Testing and potential time frame.
Discuss – Will this affect how we test in the field?
Final well control rule (blowout preventer and well control operations)Dr Dev Kambhampati
This final rule by the Bureau of Safety and Environmental Enforcement (BSEE) consolidates equipment and operational requirements for offshore oil and gas drilling into one part of the regulations. It focuses on blowout preventer (BOP) and well control requirements, incorporating industry standards and revising existing regulations. The rule addresses recommendations from investigations into the 2010 Deepwater Horizon incident, and aims to enhance safety and environmental protection for drilling, completion, workover and decommissioning operations. Key provisions include new requirements for well design, casing, cementing, real-time monitoring, subsea containment, and BOP systems. The rule also incorporates guidance from notices to operators.
The document outlines requirements and procedures for mechanical completion and handover of projects from construction to commissioning. It discusses establishing inspection and test records, punch lists, certificates, and documentation like as-built drawings and manuals. Responsibilities include contractors performing mechanical completion and pre-commissioning activities with oversight from the client. Systems are handed over in phases from contractors to the client and eventually to the operator once pre-commissioning and commissioning are complete.
The document provides a resume for Matthew Omavowan Azanor, an Instrument & Control Engineer with over 13 years of experience working on various oil and gas projects in Nigeria, South Korea, the US and Houston for companies like Chevron and Nigeria Agip Oil Company. His experience includes roles in engineering design, construction, commissioning, start-up, and maintenance of electrical, instrumentation and control systems on offshore platforms and FPSOs. He also has qualifications in electrical/electronics engineering and instrumentation and control technologies.
Landfill Compliance Monitoring: Achieving Long Term EfficiencyHydroTerra Pty Ltd
Richard Campbell presentation from the 2017 Institute of Public Works Engineering Australasia (IPWEA) leadership workshop. Richard covers the changing face of landfill environmental compliance reporitng through automated monitoring technology.
BlueScape Learn Air Permits & Compliance Training 7-28-15BlueScape
This training by James A. Westbrook, President of BlueScape Environmental covers what facility operators need to know learn about air quality regulations and permits. The topics include types of air regulations, a discussion on what requirements are found in air permits, development of an Air Quality Management System, and working with agencies.
James can be reached at 877-486-9257 for questions, customized training, and air quality permitting and compliance support.
This document summarizes the objectives and contents of an upcoming presentation on ANSI standards for electricity meter testing. The presentation will:
1) Explain the contents of ANSI C12.20-2010 for 0.2 and 0.5 accuracy class meters and its relationship to C12.1.
2) Discuss planned 2015 revisions to C12.20 and 2014 revisions to C12.1.
3) Introduce a new draft ANSI C12.29 standard focused on field testing and the timeline for its approval.
4) Consider whether the new standards will affect how meters are tested in the field.
The document discusses mechanical completion, which involves checking and testing equipment, piping, instrumentation, and other components to confirm they are installed correctly and ready for commissioning. It describes the documentation involved, including mechanical completion certificates, check records, and punch lists. Various activities involved in mechanical completion are also outlined for disciplines like mechanical, electrical, instrumentation, and piping.
Applying federal environmental laws to co2 enhanced oil recovery pptHolland & Hart LLP
This document provides an overview of federal environmental laws as they apply to CO2 enhanced oil recovery. It discusses how the EPA regulates CO2 injection under the Underground Injection Control program and the Resource Conservation and Recovery Act. Key issues addressed include how the EPA is encouraging CO2 injection for storage through new regulations, concerns about additional regulatory burdens, and legal challenges regarding how the EPA classifies and regulates CO2 streams from industrial facilities.
The document summarizes key aspects of PHMSA's Mega Rule Parts 2 and 3 regarding corrosion control requirements for gas gathering and transmission pipelines. Part 2 focuses on gas gathering and establishes new reporting requirements and compliance standards for Type R and Type C gathering lines. Part 3 addresses deficiencies in cathodic protection, external corrosion control monitoring and surveys, and managing electrical interference currents for gas transmission pipelines. The timeline notes Parts 1, 2, and 3 will be effective between 2020-2023, with compliance dates ranging from 2023-2035.
The document discusses the history and current regulations regarding material traceability for natural gas pipelines. It proposes that operators must acquire and retain manufacturing records for steel pipe, pipeline components, and welder qualifications for the life of the pipeline. The document then outlines a typical workflow for tracking material on new construction projects using radio frequency tags, barcode scanning, and a database integrated with survey mapping. It discusses lessons learned and requirements for ensuring an effective material tracking system that provides value through transparency, communication, and reducing completion time.
Pipeline documentation is required to provide a history of pipelines and ensure regulatory compliance. Key documents that should be retained include pipeline maps, licensing information, inspection records, corrosion monitoring data, repair reports, and audit results. Proper documentation of tasks like right-of-way patrols, material balances, shutdown device testing, corrosion assessments, and repairs provides a history to evaluate pipeline integrity and ensure safety requirements are met. Documentation should generally be kept for the life of the pipeline.
Direct Assessment ECDA Program DevelopmentMTS Webmaster
The document discusses the requirements and process for conducting an external corrosion direct assessment (ECDA) on gas transmission pipelines located in high consequence areas. The key points are:
1. An ECDA involves a 4-step process of pre-assessment, indirect examinations, direct examinations, and post-assessment to evaluate external corrosion risk.
2. The pre-assessment step involves collecting pipeline data and using it to identify ECDA regions and select appropriate indirect inspection tools.
3. Indirect inspections are then conducted using two or more tools to identify and classify corrosion indications by severity. Direct examinations are then focused on the most severe indications.
4. The post-assessment step defines reassessment intervals
SCT an Advanced Pipeline Integrity SolutionBrett Payton
The SCT Technique fills the gap in the armory of integrity engineers when assessing the condition of difficult to inspect pipelines and is being referred to as a "game changer" by many individuals in the industry.
New Rulemakings: What Can We Expect - Gary Krichaunacetwincities
The final rule expands requirements for gas transmission pipelines related to in-line inspections, records documentation, MAOP reconfirmation, and integrity assessments. Key aspects include incorporating new in-line inspection standards, requiring records of additional material properties, expanding the definition of moderate consequence areas, and outlining six methods for operators to reconfirm MAOP. The rule is expected to drive the need for additional in-line inspections, material verification testing, engineering analyses, and planned pressure test or assessment work over the next 15 years to meet reconfirmation deadlines. Additional rulemakings are anticipated to address repair criteria, corrosion control, and other integrity management topics.
This document provides an overview of total asset integrity management and pipelines regulatory compliance. It discusses:
- The objectives of pipeline integrity management programs and the Alberta Energy Regulator's focus.
- The different regulatory jurisdictions for pipelines in Canada and Alberta. Pipelines in Alberta are primarily regulated by the Alberta Energy Regulator.
- The key documents that comprise a pipeline integrity management program, including the Pipeline Integrity Management Program manual, Pipeline Operations and Maintenance manual, and Pipeline Integrity Management Strategy.
- The various requirements for pipeline integrity programs as outlined in CSA Z662 and other standards, including hazard identification, risk assessment, inspection and testing, documentation, continual improvement, and incident investigation.
Jimoh Adumoh has over 7 years of experience as an instrumentation and metering engineer in the oil and gas industry. He has worked for Shell Petroleum, General Electric, and Krohne Oil and Gas in both offshore and onshore roles commissioning, maintaining, and validating various metering equipment such as flow meters, pressure and temperature transmitters, and gas chromatographs. His responsibilities included ensuring accurate measurement and minimizing measurement errors. He is seeking a new position as a measurement or instrumentation engineer.
The document discusses proposed changes to ANSI standards regarding field testing of electricity meters. It outlines:
1) Planned updates to ANSI C12.1 and C12.20 that will refer to a new ANSI C12.29 standard focused specifically on field testing procedures.
2) The new C12.29 standard is being drafted and will provide best practices for testing meters, instrument transformers, and auxiliary devices in the field.
3) The future of field testing is expected to involve more comprehensive checks of meters and installations beyond just accuracy, including software verification and tamper detection.
110921 commissioning of offshore installationslaithu2908
This document discusses the commissioning process for offshore installations built in yards. It covers the total commissioning activity and defines the key phases of mechanical completion, pre-commissioning and commissioning. Mechanical completion involves verifying construction work is complete according to design. Pre-commissioning verifies functionality and system integration. Commissioning verifies systems are ready for operation. The document provides details on planning, organization and activities for each phase. Estimates suggest 95-105 systems for an FPSO requiring around 135,000-145,000 hours for commissioning, taking around 6 months with a team of 90 people. Addressing issues can help improve estimates over time.
The document discusses commissioning of offshore installations in building yards. It covers the total commissioning activity and defines the key phases of mechanical completion, pre-commissioning, and commissioning. Mechanical completion involves verifying construction meets design requirements through testing. Pre-commissioning focuses on verifying system functionality and instrument calibration. Commissioning execution involves final checks before handover to operations. Effective planning is critical to the success of each phase.
The document provides an overview and schedule for the hook-up and commissioning services by PBJV Group Sdn Bhd for Lundin Malaysia B.V.'s Bertam offshore development project. Key details include the contracting parties, administrative requirements, technical scope of work, use of marine vessels, quality and safety plans, procurement, financing, scheduling and reporting, and document control. The project involves installing and commissioning equipment on the wellhead platform between May 2014 and December 2014 to achieve first oil.
Understand contents of ANSI C12.20-2010 for 0.2 and 0.5 Accuracy Class Meters.
Understand the Relationship of C12.20 to C12.1.
Understand ANSI C12.20 Changes Planned for 2015. Edition and ANSI C12.1 changes planned for 2014.
Understand new ANSI C12.29 for Field Testing and potential time frame.
Discuss – Will this affect how we test in the field?
Final well control rule (blowout preventer and well control operations)Dr Dev Kambhampati
This final rule by the Bureau of Safety and Environmental Enforcement (BSEE) consolidates equipment and operational requirements for offshore oil and gas drilling into one part of the regulations. It focuses on blowout preventer (BOP) and well control requirements, incorporating industry standards and revising existing regulations. The rule addresses recommendations from investigations into the 2010 Deepwater Horizon incident, and aims to enhance safety and environmental protection for drilling, completion, workover and decommissioning operations. Key provisions include new requirements for well design, casing, cementing, real-time monitoring, subsea containment, and BOP systems. The rule also incorporates guidance from notices to operators.
The document outlines requirements and procedures for mechanical completion and handover of projects from construction to commissioning. It discusses establishing inspection and test records, punch lists, certificates, and documentation like as-built drawings and manuals. Responsibilities include contractors performing mechanical completion and pre-commissioning activities with oversight from the client. Systems are handed over in phases from contractors to the client and eventually to the operator once pre-commissioning and commissioning are complete.
The document provides a resume for Matthew Omavowan Azanor, an Instrument & Control Engineer with over 13 years of experience working on various oil and gas projects in Nigeria, South Korea, the US and Houston for companies like Chevron and Nigeria Agip Oil Company. His experience includes roles in engineering design, construction, commissioning, start-up, and maintenance of electrical, instrumentation and control systems on offshore platforms and FPSOs. He also has qualifications in electrical/electronics engineering and instrumentation and control technologies.
Landfill Compliance Monitoring: Achieving Long Term EfficiencyHydroTerra Pty Ltd
Richard Campbell presentation from the 2017 Institute of Public Works Engineering Australasia (IPWEA) leadership workshop. Richard covers the changing face of landfill environmental compliance reporitng through automated monitoring technology.
BlueScape Learn Air Permits & Compliance Training 7-28-15BlueScape
This training by James A. Westbrook, President of BlueScape Environmental covers what facility operators need to know learn about air quality regulations and permits. The topics include types of air regulations, a discussion on what requirements are found in air permits, development of an Air Quality Management System, and working with agencies.
James can be reached at 877-486-9257 for questions, customized training, and air quality permitting and compliance support.
This document summarizes the objectives and contents of an upcoming presentation on ANSI standards for electricity meter testing. The presentation will:
1) Explain the contents of ANSI C12.20-2010 for 0.2 and 0.5 accuracy class meters and its relationship to C12.1.
2) Discuss planned 2015 revisions to C12.20 and 2014 revisions to C12.1.
3) Introduce a new draft ANSI C12.29 standard focused on field testing and the timeline for its approval.
4) Consider whether the new standards will affect how meters are tested in the field.
The document discusses mechanical completion, which involves checking and testing equipment, piping, instrumentation, and other components to confirm they are installed correctly and ready for commissioning. It describes the documentation involved, including mechanical completion certificates, check records, and punch lists. Various activities involved in mechanical completion are also outlined for disciplines like mechanical, electrical, instrumentation, and piping.
Applying federal environmental laws to co2 enhanced oil recovery pptHolland & Hart LLP
This document provides an overview of federal environmental laws as they apply to CO2 enhanced oil recovery. It discusses how the EPA regulates CO2 injection under the Underground Injection Control program and the Resource Conservation and Recovery Act. Key issues addressed include how the EPA is encouraging CO2 injection for storage through new regulations, concerns about additional regulatory burdens, and legal challenges regarding how the EPA classifies and regulates CO2 streams from industrial facilities.
The document summarizes key aspects of PHMSA's Mega Rule Parts 2 and 3 regarding corrosion control requirements for gas gathering and transmission pipelines. Part 2 focuses on gas gathering and establishes new reporting requirements and compliance standards for Type R and Type C gathering lines. Part 3 addresses deficiencies in cathodic protection, external corrosion control monitoring and surveys, and managing electrical interference currents for gas transmission pipelines. The timeline notes Parts 1, 2, and 3 will be effective between 2020-2023, with compliance dates ranging from 2023-2035.
BlueScape 2022 Update: CEQA Air Quality & Greenhouse Gas Impact Studies Webin...BlueScape
The document provides an overview and update on CEQA air quality and greenhouse gas impact study requirements for land use projects in 2022. Key points include:
- Greenhouse gas analyses must now address achieving net zero emissions by 2045 to be consistent with state goals.
- Health risk assessments must consider cumulative impacts from toxic air pollutants on sensitive receptors.
- The Friant Ranch ruling requires air quality impact analyses to connect health effects where feasible or explain why not.
- Technical tools for emissions modeling and health impact analysis are continuously being updated.
The document summarizes the agenda and discussions from a management review meeting at Alghanim International General Trading & Contracting Co. The meeting covered a range of topics required by the company's quality management system including: reviewing actions from the previous meeting, internal and external issues, quality policies, customer and supplier feedback, process and product conformity, compliance obligations, audit results, resource adequacy, risks and opportunities, emergency drills, and areas for improvement. Key discussion points included customer complaints, nonconformities across projects, supplier performance, and strengthening centralized document management and contractor qualification.
ONLINE MONITORING OF DISTRIBUTION SYSTEMmitesh patel
This document discusses the benefits of online monitoring of water distribution networks. Municipalities face challenges in providing safe drinking water 24/7 to consumers from increasingly large and complex distribution systems. Online monitoring can help utilities reduce water and energy losses, improve operational efficiency, optimize supply, and aid in network planning. Some key benefits of online monitoring include water savings, energy savings, improved operational visibility, damage prevention, and early detection of network issues and quality problems. The document outlines important water quality parameters to monitor, such as chlorine residual and E. coli, as well as methods for sensor installation and selecting monitoring locations. Online monitoring provides results faster than conventional techniques and increases consumer confidence through continuous, real-time monitoring.
The purpose of this document is to provide a brief summary of the content of the ANPRM in order to present a snapshot of issues that may be under consideration for a revised final rule. An analysis of the information contained in the ANPRM is not included.
http://blog.willbros.com/category/pipeline-integrity/
This document contains forward-looking statements about Methode's future performance that are subject to risks and uncertainties. It lists 21 factors that could cause actual results to differ from expectations, such as dependence on large customers, various industry sectors, new program launches, supply chain management, raw material prices, global operations, taxes, margins, acquisitions, product defects, intellectual property, foreign cash holdings, business interruptions, and regulations. The presentation promotes Methode's portfolio of products and solutions, growth opportunities, engineering capabilities, management team, strong financial position, and core strategy of delivering customer value and shareholder returns.
Nondestructive Testing and robotic engineering focused on transportation infrastructure. Updating 50 year old manual/subjective inspections with modern technology and robotics. Providing advanced condition assessment reports so asset managers can better allocate assets and make repairs prior to them becoming a danger to the public. By providing more quantitative data, proper maintenance and repairs can help extend the service life of critical infrastructure assets saving billions in untimely repairs and loss of life. Cable Stay Bridges, Suspension Bridges, Pedestrian bridges and more. Turn to Infrastructure Preservation Corporation for your bridge inspection needs. NBI -National Bridge Inventory inspection specialists.
This presentation discusses Methode's forward-looking statements and the various risks and uncertainties that could affect the company's actual results. It notes 21 specific factors that could cause actual results to differ from expectations. The document also provides an overview of Methode's business strategies and growth opportunities.
Using Aspen HYSYS Upstream for Sizing and Scheduling of Gathering SystemsProcess Ecology Inc
This presentation covers the process of sizing and scheduling of Gathering Systems, including how to approach challenges by using model development and automation and interpretation of the results. Additionally, we compare between HYSYS Hydraulics and HYSYS Dynamics.
This document discusses leak management opportunities in industrial facilities and pipelines. It summarizes a leak management program implemented at a refinery in 2006 that was successful in eliminating leaks. The key aspects of the program included: 1) identifying critical joints using a risk-based criteria, 2) reviewing assembly procedures and providing quality control oversight for contractor work, and 3) implementing best practices from ASME PCC-1 including establishing procedures, training personnel, and documenting the work. As a result, the refinery restarted with no leaks after the program and established a leak tracking database to reduce future leaks.
3.0 UK Link Platform Performance Update V2.0.pptxssuserc1306e
Xoserve has identified several opportunities to improve UK Link platform stability and performance through 2022. Initiatives already underway in 2019/2020 include optimizing meter read processing, reducing system defects, improving electronic file transfers, and transitioning task forces to business as usual operations. Additional funding of £600k would allow accelerating two initiatives: implementing audit findings to improve data management and establishing an end-to-end performance test environment. Xoserve will continue reporting progress and risks to customers.
The document describes Hillsborough County's major maintenance and replacement program. It discusses how the program was created to address a large backlog of deferred maintenance projects. It outlines the program's processes of inventorying and assessing facilities, prioritizing projects, funding and budgeting work, procuring contractors, and carrying out repairs/replacements to update facility information and conditions. The program aims to proactively maintain the county's assets and avoid costly emergency repairs.
Polyvinyl chloride (PVC) pipes refer to fundamental components in modern construction and infrastructure known for their versatility and durability. They are renowned for their robustness, resistance to corrosion, and longevity. PVC pipes are available in various types, including unplasticized PVC (uPVC), chlorinated PVC (CPVC), and modified PVC (mPVC), each serving distinct purposes.
This document provides an overview of the organizational structure for construction within the California Department of Transportation (Caltrans). It outlines the roles and responsibilities of personnel at the headquarters, district, and project levels. At the headquarters level, the Division of Construction Chief leads the statewide construction program. Within each district, a Construction Deputy Director oversees construction activities. On individual projects, a Resident Engineer administers each contract. The document aims to provide guidance for administering construction contracts according to Caltrans policies and procedures.
This document discusses a training course on industrial wastewater compliance. The course objectives include discussing the national pretreatment program, permitting process, regulatory inspections, enforcement actions, reporting requirements, and more. The training is aimed at supervisors, engineers, maintenance staff, and others to understand wastewater compliance standards and regulations. The overview explains that the goal is to provide tools to understand compliance and recommend practical actions to integrate good practices.
PERFORMANCE TOOLS FOR ELECTRIC COOPERATIVESjo bitonio
This document discusses key performance indicators (KPIs) and standards (KPS) for evaluating electric cooperatives in the Philippines. It begins by defining KPIs and explaining their importance for meeting goals. It then outlines the rationale, objectives, parameters, and standards for the KPS implemented by the National Electrification Administration (NEA) to measure electric cooperatives' financial, institutional, and technical performance. The KPS covers four major parameters (financial, institutional, technical, and reportorial compliance) and establishes standards in areas like debt ratios, customer service, reliability, and reporting requirements. The NEA is responsible for processing cooperatives' reports and approving their annual performance assessments based on the KPS.
The document summarizes key aspects of environmental impact assessments in India. It discusses how EIA aims to identify environmental, social and economic impacts of projects prior to decision making. It outlines India's history with EIAs, the 2006 amendment that classified projects into categories, and proposed changes in the 2020 draft including reduced public hearing time, exemption of certain projects, and allowing post-facto clearances. Issues raised with the 2020 draft include potentially encouraging violations and weakening public engagement in favor of government discretion.
Fairfax County Wastewater Collection Asset Management Program Oct 2020Fairfax County
This is an overview of the Wastewater Collection Division Asset Management Program including program roadmap, asset risk framework, technology, decision support system, on-going and upcoming efforts.
Presented by PhD student Valerio Benedetto at the CER (Community of European Railway and Infrastructure Companies) Economics group in Brussels on 17th September 2014. The presentation covered the progress of the research on the regulatory impact on railway efficiency, together with the formalisation of a questionnaire on the ideal rail regulator characteristics to be distributed to CER members.
www.its.leeds.ac.uk/people/v.benedetto
Similar to Presentation Slides: PHMSA Final Rule (Part 1) for Hazardous Liquid Pipelines (20)
Comparative analysis between traditional aquaponics and reconstructed aquapon...bijceesjournal
The aquaponic system of planting is a method that does not require soil usage. It is a method that only needs water, fish, lava rocks (a substitute for soil), and plants. Aquaponic systems are sustainable and environmentally friendly. Its use not only helps to plant in small spaces but also helps reduce artificial chemical use and minimizes excess water use, as aquaponics consumes 90% less water than soil-based gardening. The study applied a descriptive and experimental design to assess and compare conventional and reconstructed aquaponic methods for reproducing tomatoes. The researchers created an observation checklist to determine the significant factors of the study. The study aims to determine the significant difference between traditional aquaponics and reconstructed aquaponics systems propagating tomatoes in terms of height, weight, girth, and number of fruits. The reconstructed aquaponics system’s higher growth yield results in a much more nourished crop than the traditional aquaponics system. It is superior in its number of fruits, height, weight, and girth measurement. Moreover, the reconstructed aquaponics system is proven to eliminate all the hindrances present in the traditional aquaponics system, which are overcrowding of fish, algae growth, pest problems, contaminated water, and dead fish.
International Conference on NLP, Artificial Intelligence, Machine Learning an...gerogepatton
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Understanding Inductive Bias in Machine LearningSUTEJAS
This presentation explores the concept of inductive bias in machine learning. It explains how algorithms come with built-in assumptions and preferences that guide the learning process. You'll learn about the different types of inductive bias and how they can impact the performance and generalizability of machine learning models.
The presentation also covers the positive and negative aspects of inductive bias, along with strategies for mitigating potential drawbacks. We'll explore examples of how bias manifests in algorithms like neural networks and decision trees.
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DEEP LEARNING FOR SMART GRID INTRUSION DETECTION: A HYBRID CNN-LSTM-BASED MODELgerogepatton
As digital technology becomes more deeply embedded in power systems, protecting the communication
networks of Smart Grids (SG) has emerged as a critical concern. Distributed Network Protocol 3 (DNP3)
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detection in smart grids. The proposed approach is a combination of the Convolutional Neural Network
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A SYSTEMATIC RISK ASSESSMENT APPROACH FOR SECURING THE SMART IRRIGATION SYSTEMSIJNSA Journal
The smart irrigation system represents an innovative approach to optimize water usage in agricultural and landscaping practices. The integration of cutting-edge technologies, including sensors, actuators, and data analysis, empowers this system to provide accurate monitoring and control of irrigation processes by leveraging real-time environmental conditions. The main objective of a smart irrigation system is to optimize water efficiency, minimize expenses, and foster the adoption of sustainable water management methods. This paper conducts a systematic risk assessment by exploring the key components/assets and their functionalities in the smart irrigation system. The crucial role of sensors in gathering data on soil moisture, weather patterns, and plant well-being is emphasized in this system. These sensors enable intelligent decision-making in irrigation scheduling and water distribution, leading to enhanced water efficiency and sustainable water management practices. Actuators enable automated control of irrigation devices, ensuring precise and targeted water delivery to plants. Additionally, the paper addresses the potential threat and vulnerabilities associated with smart irrigation systems. It discusses limitations of the system, such as power constraints and computational capabilities, and calculates the potential security risks. The paper suggests possible risk treatment methods for effective secure system operation. In conclusion, the paper emphasizes the significant benefits of implementing smart irrigation systems, including improved water conservation, increased crop yield, and reduced environmental impact. Additionally, based on the security analysis conducted, the paper recommends the implementation of countermeasures and security approaches to address vulnerabilities and ensure the integrity and reliability of the system. By incorporating these measures, smart irrigation technology can revolutionize water management practices in agriculture, promoting sustainability, resource efficiency, and safeguarding against potential security threats.
Introduction- e - waste – definition - sources of e-waste– hazardous substances in e-waste - effects of e-waste on environment and human health- need for e-waste management– e-waste handling rules - waste minimization techniques for managing e-waste – recycling of e-waste - disposal treatment methods of e- waste – mechanism of extraction of precious metal from leaching solution-global Scenario of E-waste – E-waste in India- case studies.
Using recycled concrete aggregates (RCA) for pavements is crucial to achieving sustainability. Implementing RCA for new pavement can minimize carbon footprint, conserve natural resources, reduce harmful emissions, and lower life cycle costs. Compared to natural aggregate (NA), RCA pavement has fewer comprehensive studies and sustainability assessments.
TIME DIVISION MULTIPLEXING TECHNIQUE FOR COMMUNICATION SYSTEMHODECEDSIET
Time Division Multiplexing (TDM) is a method of transmitting multiple signals over a single communication channel by dividing the signal into many segments, each having a very short duration of time. These time slots are then allocated to different data streams, allowing multiple signals to share the same transmission medium efficiently. TDM is widely used in telecommunications and data communication systems.
### How TDM Works
1. **Time Slots Allocation**: The core principle of TDM is to assign distinct time slots to each signal. During each time slot, the respective signal is transmitted, and then the process repeats cyclically. For example, if there are four signals to be transmitted, the TDM cycle will divide time into four slots, each assigned to one signal.
2. **Synchronization**: Synchronization is crucial in TDM systems to ensure that the signals are correctly aligned with their respective time slots. Both the transmitter and receiver must be synchronized to avoid any overlap or loss of data. This synchronization is typically maintained by a clock signal that ensures time slots are accurately aligned.
3. **Frame Structure**: TDM data is organized into frames, where each frame consists of a set of time slots. Each frame is repeated at regular intervals, ensuring continuous transmission of data streams. The frame structure helps in managing the data streams and maintaining the synchronization between the transmitter and receiver.
4. **Multiplexer and Demultiplexer**: At the transmitting end, a multiplexer combines multiple input signals into a single composite signal by assigning each signal to a specific time slot. At the receiving end, a demultiplexer separates the composite signal back into individual signals based on their respective time slots.
### Types of TDM
1. **Synchronous TDM**: In synchronous TDM, time slots are pre-assigned to each signal, regardless of whether the signal has data to transmit or not. This can lead to inefficiencies if some time slots remain empty due to the absence of data.
2. **Asynchronous TDM (or Statistical TDM)**: Asynchronous TDM addresses the inefficiencies of synchronous TDM by allocating time slots dynamically based on the presence of data. Time slots are assigned only when there is data to transmit, which optimizes the use of the communication channel.
### Applications of TDM
- **Telecommunications**: TDM is extensively used in telecommunication systems, such as in T1 and E1 lines, where multiple telephone calls are transmitted over a single line by assigning each call to a specific time slot.
- **Digital Audio and Video Broadcasting**: TDM is used in broadcasting systems to transmit multiple audio or video streams over a single channel, ensuring efficient use of bandwidth.
- **Computer Networks**: TDM is used in network protocols and systems to manage the transmission of data from multiple sources over a single network medium.
### Advantages of TDM
- **Efficient Use of Bandwidth**: TDM all
2. Table of Contents
Slide 3
Slide 4
Slide 5
Slide 6-7
Slide 8-9
Slide 10-11
Slide 12-13
Slide 14-15
Slide 16-17
Slide 18-19
Slide 20-21
Slide 22-23
Slide 24-25
Speaker Bio
Agenda
The Rule Effective Date
Unregulated Gravity Line Reporting Requirements
Unregulated Gathering Line Reporting Requirements
Weather Related Event (WRE) 72 Hour Inspection
Non-IMP Segment Assessments
Leak Detection
ILI Tool Accommodation
Pipes Act Provisions
Pipeline HCA Segment Annual Identification
IM Program Data Integration
Future Rulemakings
3. TODAY’S SPEAKER
Bryan Louque has over 25 years of
experience in the pipeline industry. He
has been involved with the design,
construction, and O&M of pipeline
systems with an emphasis on corrosion
control, pipeline integrity and
regulatory compliance programs on
hazardous liquids (Part 195) and
natural gas (Part 192) pipeline systems.
Bryan Louque, P.E.
Vice President of Asset Integrity and Corrosion
Audubon Companies
4. Agenda
When is the Hazardous Liquids Rule Effective?
What’s in the Hazardous Liquids Rule?
What’s not in the Hazardous Liquids Rule?
What’s Next?
WHY AM I HERE?
July 2010 October 2019
5. WHEN IS THE RULE EFFECTIVE?
Effective Date – July 1, 2020
TICK
TOCK
6. WHAT’S IN THE RULE?
1.0 Unregulated Gravity Line Reporting Requirements
What’s New?
Submit annual (195.49), accident (195.50), and safety-related
condition reports (195.55) to PHMSA
• Accident and SRCR Report Effective Date – January 1, 2021
• Annual Report Effective Date – March 31, 2021
Telephonic (195.52), NPMS filings and SDS furnishing not
required
Key Exceptions
Low-stress gravity lines < 1 mile from facility and
do not cross commercially navigable waters
7. WHAT’S IN THE RULE?
What is the Impact?
The impact is LOW
Primarily applies to flow lines upstream of LACT units
1.0 Unregulated Gravity Line Reporting Requirements
8. WHAT’S IN THE RULE?
2.0 Unregulated Gathering Line Reporting Requirements
What’s New?
Submit annual (195.49), accident (195.50), and safety-related
condition reports (195.55) to PHMSA
• Accident and SRCR Report Effective Date – January 1, 2021
• Annual Report Effective Date – March 31, 2021
Telephonic (195.52), NPMS filings and SDS furnishing not
required
Key Exceptions
None
9. WHAT’S IN THE RULE?
2.0 Unregulated Gathering Line Reporting Requirements
What is the Impact?
The Impact is HIGH
Update procedures to address new reporting requirements
Train personnel
Maintain accurate maps and records for all unregulated
pipelines
10. WHAT’S IN THE RULE?
3.0 Weather Related Event (WRE) 72 Hour Inspection
What’s New?
Pipelines subject to damage by scouring or movement of
surrounding soil
• Tropical storms, hurricanes, floods, landslides, or
earthquakes
Inspection method determined by Operator
Appropriate remedial action must be taken based on
inspection results
• Pressure reduction, repair / replacement, shut down
(195.452)
Key Exceptions
Notify PHMSA if inspection is impeded / delayed
due to lack of personnel or equipment
11. WHAT’S IN THE RULE?
3.0 Weather Related Event (WRE) 72 Hour Inspection
What is the Impact?
The Impact is HIGH
Update procedures to address new inspection
requirements
Train personnel
Identify all pipeline segments susceptible to
WRE damage (195.452)
Take pre-emptive measures where necessary
12. WHAT’S IN THE RULE?
4.0 Non-IMP Segment Assessments
What’s New?
Segments not subject to IMP must be assessed every 10 years
• Initial assessments due by October 1, 2029
Assessment methods (195.452)
• ILI, Hydrotest, ECDA
Dig and repair anomalies per existing 195 criteria
Key Exceptions
None
13. WHAT’S IN THE RULE?
4.0 Non-IMP Segment Assessments
What is the Impact?
The Impact is HIGH
All pipeline (inside and outside of HCAs)
must be assessed
14. 5.0 Leak Detection
What’s New?
Regulated lines must have leak detection system inside
& outside of HCAs
• Lines built before October 1, 2019 – Effective
October 1, 2024
• Lines built after October 1, 2019 – Effective October
1, 2020
Operators must evaluate leak detection system ability to
protect the public, property, and the environment
(195.452)
Key Exceptions
Offshore gathering and onshore regulated
gathering lines
WHAT’S IN THE RULE?
15. 5.0 Leak Detection
What is the Impact?
The Impact is MEDIUM
Applies to regulated non-gathering lines, most of which
should already have formal leak detection program
(API RP 1175)
WHAT’S IN THE RULE?
16. 6.0 ILI Tool Accommodation
What’s New?
Pipelines located in or could affect HCAs must accommodate
ILI tools
• 20 year implementation window
• Potential waiver for pipelines that would be abandoned
due to the cost of compliance
Key Exceptions
Manifolds, station piping, tank farm, storage piping,
cross-overs, or select offshore piping
WHAT’S IN THE RULE?
17. 6.0 ILI Tool Accommodation
What is the Impact?
The Impact is MEDIUM
Design & construction standards require all new
pipelines be piggable (195.120)
Develop and implement legacy pipeline make-piggable
programs for those located in or could affect HCAs
WHAT’S IN THE RULE?
18. 7.0 PIPES Act Provisions
What’s New?
Provide Federal On-Scene Coordinators and emergency
responders with product safety data sheets (SDS) for spilled
hazardous liquids
• Within six hours of notice to the NRC
Conduct annual integrity assessments of underwater pipeline
facilities located in HCAs and depth is greater than 150 feet
Key Exceptions
Offshore pipeline facilities
WHAT’S IN THE RULE?
19. 7.0 PIPES Act Provisions
What is the Impact?
The impact is LOW
Update Oil Spill Response Plan (194.101)
to include SDSs for all pipeline products transported
WHAT’S IN THE RULE?
20. 8.0 Pipeline HCA Segment Annual Identification
What’s New?
Verify all HCA direct or could affect line segments annually
• Identify the factors in the original HCA analysis
• Determine whether any of those factors have changed
• Assess whether change will affect the results of the initial
HCA segment identification
Effective date – July 1, 2021
Key Exceptions
Unregulated pipelines
WHAT’S IN THE RULE?
21. 8.0 Pipeline HCA Segment Annual Identification
What is the Impact?
The Impact is HIGH
Essentially requires direct or could affect HCA analysis
for all regulated pipelines be performed annually
Similar to what is required for gas lines
WHAT’S IN THE RULE?
22. 9.0 IM Program Data Integration
What’s New?
Integration of IM program information and consideration of
spatial relationships among anomalous information
• For example, evidence of potential corrosion in an area
with foreign pipeline crossings, interference from power
lines, or evidence of land movement
Effective date – October 1, 2020
Compliance date – October 1, 2022
Key Exceptions
None
WHAT’S IN THE RULE?
23. 9.0 IM Program Data Integration
What is the Impact?
The Impact is HIGH
Essentially requires use of geospatial data integration and
storage platform (ArcGIS) to operate IM program
WHAT’S IN THE RULE?
24. Pipeline Repair Requirements:
Operators will NOT be required to comply with the new criteria and
remediation schedules for performing pipeline repairs. PHMSA will be
considering that issue in a separate rulemaking proceeding.
Future Rulemakings: The rule does NOT include two changes to
Part 195 that PHMSA proposed at earlier points in the proceedings
WHAT’S NOT IN THE RULE?
25. Future Rulemakings: The rule does NOT include two changes to
Part 195 that PHMSA proposed at earlier points in the proceedings
Engineering Critical Assessments:
Operators will NOT be required to perform engineering critical
assessments (analytical procedures to determine maximum tolerable
flaw sizes in steel pipe to maintain safe operations) in relation to the
remediation of certain defects. PHMSA will be considering that issue in a
separate rulemaking proceeding.
WHAT’S NOT IN THE RULE?