Attachment 7 - Research Topics 693JK324RA0001.docx

AGREEMENT #693JK31910001POTA

Pipeline Safety Research Announcement Topics

Research Announcement #10

a) Climate Change Mitigation

1. Knowledge Development – Characterize Expected Carbon Dioxide Specification Ranges for Various Product Streams The objective of this project is to characterize the expected compositional ranges and product quality specifications for carbon dioxide (CO2) product streams derived from diverse sources, such as ethanol production, cement manufacturing, power generation facilities, steel manufacturing, direct air capture, with an emphasis on near-term emitters.

The lack of data characterizing the expected compositions of CO2 streams from various sources in the carbon capture, utilization, and storage (CCUS) value stream is a significant gap in safety research related to CO2 pipelines. Composition of the CO2 stream is important to the management of transport via pipeline to allow for the consideration of material compatibility, flow behavior, operational safety, blending strategies, and compression optimization. Compiling this data will expand the knowledge and understanding of the possible compositions that will assist in establishing common industry standards and best practices for pipeline transportation of CO2, further supporting the future of CCUS infrastructure.

Results of this project are foundational to future research and will facilitate the development of further knowledge and promote the advancement of CO2 pipeline safety.

The project scope must:

· Conduct a comprehensive review of existing literature, databases, industry reports, and other research efforts on the compositional variability and product quality specifications of CO2 product streams from sources relevant to pipeline transport, to avoid duplication, and to potentially compliment what already exists;

· Prioritize near-term emitters versus future emitters based on the literature review and include those various emitters under the Inflation Reduction Act’s (IRA) 45Q and 45V tax credit structure;

· Analyze existing and emerging product quality specifications for CO2 used in pipeline transportation, considering relevant national and international standards, industry best and recommended practices, and specific downstream utilization requirements (e.g., for enhanced oil recovery, geologic storage);

· Identify key quality parameters impacting pipeline design, operation, and compatibility (e.g., moisture content, maximum allowable impurities);

· Determine the typical and variable components present in the CO2 product stream from each source, including major and minor impurities, potential contaminants, trace elements, and possible odorants. Analyze to identify trends, variations, and key differences;

· Identify key findings and knowledge gaps regarding the impact of source-specific composition of various CO2 streams on pipeline design, operation, and safety;

· Develop a comprehensive and accessible report with a database summarizing the characterization results for each source, including typical range values for key components, potential risks and mitigation strategies, and insights into influencing factors;

· Disseminate research findings through peer-reviewed publications, presentations at relevant conferences and workshops, and engagement with stakeholders in the CO2 pipeline industry. Actively participate in standardization efforts to provide findings for possible incorporation into industry best practices and regulatory frameworks;

· Include participation and input from stakeholder groups, such as operators, service providers, industry experts, and standards organizations; and

· Provide delivery time, not to exceed 12 months, and total project cost.

2. Knowledge Development – Evaluate and Assess the Development of Pipeline System Repair and Maintenance Technologies in Hydrogen (H2), H2-Natural Gas Blends, and Natural Gas Pipelines.

The objective of this research project is to explore the compatibility of existing pipeline and aboveground facilities, such as compressor station repair and maintenance technologies (e.g., welding, joining, hot tapping, stoppling, squeeze-off, purging) for transportation of H2, H2-natural gas blends, and natural gas pipelines to include both metallic and nonmetallic transmission and distribution systems. In addition, on completion of the evaluation, this research project may support the development of new or more robust pipeline and compressor station repair and maintenance technologies.

PHMSA is seeking research to evaluate and assess technologies that can be utilized for repair and maintenance of pipelines transporting H2, H2-natural gas-blends, and natural gas and the compressor stations on those lines.. The research should consider the impact of H2 on the safe application or installation of these technologies and post repair consideration on the longevity, safety, and effectiveness. Additionally, factors that exacerbate or mitigate risk should be considered and modifications to increase the safety should be identified.

The project scope must:

· Perform a review of literature and research from other private or public efforts on repair and maintenance technologies for H2 , H2-natural gas blends, and natural gas pipeline systems (pipeline and compressor stations) to avoid duplication and to potentially complement what already exists (e.g., review the applicability of American Society of Mechanical Engineers (ASME) B31.8 standards and 49 Code of Federal Regulations (CFR) Part 192[footnoteRef:2]); [2: https://www.ecfr.gov/current/title-49/part-192 ]

· Identify technologies to evaluate and assess;

· Describe the planned testing scheme for the various technologies;

· Document factors that modify the risk of the various repair and maintenance methods;

· Assess the development of new or existing technology to the market, including validation testing under real and varying field conditions, as appropriate;

· Evaluate whether a new standard practice could be created using the results and technology;

· Identify representative implementation costs for new new or more robust pipeline and compressor station repair and maintenance technologies;

· Include participation and input from stakeholder groups, such as operators, service providers, industry experts, and standards organizations; and

· Provide delivery time, not to exceed 24 months, and total project cost.

3. Knowledge Development – Model Risk Assessment of H2, H2-Natural Gas Blend, and Natural Gas Releases The objective of this research project is to conduct a modeling analysis of the potential impact radius (PIR), or radii, for gaseous releases (H2, H2-natural gas blends, and natural gas) from pipelines. The modeling will be used to provide input to evaluate the existing PIR for natural gas and potential development of a PIR for hydrogen blends. The project will include full-scale field trials to validate results for the gases including radiant energy, overpressure potential, and probability of ignition.

PHMSA is seeking solutions to advance the safe design and operation of pipelines that transport H2, H2-natural gas blends, and natural gas. The researcher will evaluate modeling methodologies to calculate the PIR of gaseous releases. In addition, PHMSA is seeking validation of the results through full-scale tests. PHMSA regulations in 49 CFR § 192.903 identify the PIR for natural gas pipelines as the radius of a circle within which the potential failure of a pipeline could have significant impact on people or property.[footnoteRef:3] [3: https://www.ecfr.gov/current/title-49/section-192.903 ]

The project scope must:

· Perform a literature review of relevant research from private or public research efforts to assist in achieving the project goals along with performing industry outreach to aid in the research, to avoid duplication, and to potentially complement what already exists;

· Consider pipeline characteristics, such as diameter and operating pressures;

· Consider local variables, such as geology/geography, wind conditions, and temperatures of the medium;

· Include evacuation time for people in proximity to the pipeline;

· Allow for impurities of H2, H2-natural gas blends and natural gas in the pipeline and how this would impact the model analyses;

· Differentiate between varying impacts of minor leaks and full pipeline ruptures, including evacuation time;

· Validate the model by several tests with various conditions, to include full-scale testing;

· Include experts in pipeline safety and occupational health that can advise on the research. The team should review, among other things, existing literature about how the existing PIR was addressed for natural gas pipelines to inform addressing the PIR determination for H2 pipelines and H2-natural gas blends; and

· Provide delivery time, not to exceed 36 months, and total project cost.

b) Leak Detection

4. Technology Development – Innovative Leak Detection Locating Technologies The objective of this research project is to develop innovative or enhanced leak locating technologies to pinpoint/detect leaks in pipelines and facilities with limited excavation for buried pipelines. This can be conducted via the use of new technologies, modification of existing technologies, or alternative methods.

A cost effective new or modified technology must be capable of quickly and accurately pinpointing a leak location. Technologies may be compatible with buried pipe, aboveground piping, or other pipeline facilities, such as pumping and storage equipment.

The project scope must:

· Perform a literature review of relevant research from private or public research efforts, including service providers and operators. Literature review should cover current and past research on leak detection locating technologies and provide a critical review of current status and challenges that limit current leak detection technologies on accuracy to pinpoint and detect leaks. The review will also assist to avoid duplication and provide the potential to complement what already exists;

· Identify opportunities to implement new technologies and innovative solutions to develop leak detection locating technologies;

· Identify conditions and factors, as well as baseline leak detection technologies, to be considered in the design of experiments for field test and validation. Include a series of field validation demonstrations to test selected new leak detection technologies, to identify the improvements to the existing technologies;

· Include a pipeline operator or service provider to pilot the leak locating technology;

· Document validation testing results, and determine the effectiveness and accuracy of the technologies;

· Include participation and input from stakeholder groups, such as operators, service providers, industry experts, and standards organizations;

· Specify infrastructure type to which technology could pertain (e.g., pipeline or facilities, as well as liquid, gas, underground natural gas storage, H2, CO2, or liquefied natural gas (LNG));

· Identify representative implementation costs for innovative or enhanced leak locating technologies;

· Specify method of application and/or use requirements (e.g., line exposure required, non-soil disturbing, aerial, satellite, ultrasonic); and

Proposals that address advancements/validations to existing technologies also should:

· Focus on tools and technologies that have best potential for being used “as is,” modified, enhanced, or added onto, to perform reliably for all;

· Describe operational tasks for which an operator would use this technology, and in what typical environments; and

· Test for application, as appropriate.

5. Technology Development –Improve the Speed and Accuracy for Leak Detection and Quantification The objective of this research project is to develop new, or enhance existing, leak detection sensor technologies for installation directly on or in pipeline facilities.

Current technologies, such as computational pipeline monitoring and supervisory control and data acquisition systems (SCADA), may result in delayed or inaccurate notifications. A potential solution to reduce delay is to improve current leak detection capabilities in terms of detection threshold, accuracy of location, or speed of detection. The goal is to have an improved cost-effective way to detect leaks through new or improved technologies.

The project scope must:

· Perform a literature review of relevant research from private or public research efforts to assist in achieving the project goals along with performing industry outreach to aid in the research, to avoid duplication, and to potentially complement what already exists (e.g. review American Petroleum Institute (API) Recommended Practice (RP) 1130, “Computational Pipeline Monitoring for Liquids,” for applicability);

· Identify what would need to be considered for the specification and limitations for detection threshold, location accuracy, and speed of detection;

· Utilize innovative solutions to develop and design an experimental test plan for field validation/demonstration of the leak detection sensing technologies improved or developed;

· Include a series of field validation demonstrations that demonstrate the enhancements advance technology beyond what is currently available, differentiate between a leak/rupture or operational signal (i.e., source input from equipment, valve, flow sensor, maintenance, etc.), and address any limitations;

· Include a pipeline operator or service provider to pilot the leak detection technology;

· Document the results of the validation testing and determine the effectiveness and accuracy;

· Include participation and input from stakeholder groups, such as operators, service providers, industry experts, and standards organizations;

· Identify representative implementation costs for new or enhanced leak detection sensor technologies;

· Specify infrastructure type to which the technology would pertain, (e.g., pipeline or facilities, as well as liquid, gas, UNGS, H2, CO2, or LNG); and

· Provide delivery time, not to exceed 36 months, and total project cost.

Proposals that address advancements/validations to existing technologies also should:

· Focus on tools and technologies that have best potential for being used “as is,” modified, enhanced, or added onto, to perform reliably for all;

· Describe operational tasks for which an operator would use this technology and in what typical environments, and limitations of those technologies in terms of detection threshold, location accuracy, and speed of detection; and

· Test for application, as appropriate.

6. Knowledge Development –Validate Existing Pipeline System Leak Prevention and Mitigation Technologies The objective of this research project is to test and validate existing leak prevention and mitigation technologies not currently accepted for use on regulated pipelines, pipeline facilities, and other pipeline equipment including, compressors and storage tanks. The project should encompass an assessment of current technological constraints or uses, strengths and weaknesses of each technology, and the formulation of strategies or optimal approaches for selecting the suitable technology to prevent and manage leaks in various situations or locations. The project will focus on a single identified area of interest and may incorporate one or multiple technologies outlined in the proposal.

Technologies to include are market available leak prevention or mitigation technologies for liquid and gas pipeline systems, including CO2, H2 and H2-blends, UNGS systems, and LNG systems. Systems are inclusive of all components, including but not limited to underground pipe, aboveground pipe, pipeline facilities, compressor stations, storage tanks, etc.

The project scope must:

· Perform a review of existing tools and technologies that have best potential for being used “as is” for cost effective leak prevention and mitigation on pipeline, UNGS, and LNG systems;

· Evaluate the applicability of Federal and State requirements, industry consensus standards and recommended practices, and representative operator programs pertinent to leak prevention or mitigation;

· Include participation and input from stakeholder groups, such as operators, service providers, industry experts, and standards organizations;

· Develop testing and validation methods to verify that leak prevention and mitigation technologies perform as the specification states and identify additional advantages and/or limitations. In addition, include a series of field validation demonstrations that may enhance the advancement of available technology;

· Describe operational tasks an operator would need to perform for use of each technology and in what typical environments, and limitations those technologies have in terms of leak prevention and mitigation;

· Develop methods or best management practices (BMP) for selecting leak prevention and mitigation technology for pipeline systems;

· Review options to integrate results into a relevant industry standard;

· Create a table to compare the technology or technologies to currently accepted options covering a range of factors such as safety, environmental impact, success stories, lessons learned, reporting requirements, recommended practices, threshold values, and system applications for each technology. Additionally, incorporate a section dedicated to component definitions and widely accepted industry terminology;

· Identify representative implementation costs for leak prevention and mitigation technologies;

· Develop an update plan to ensure integration of the most recent technology into any comparison tables created; and

· Provide delivery time, not to exceed 36 months, and total project cost..

c) Liquefied Natural Gas

7. Knowledge Development – Gap Analysis to Identify Opportunities to Inform Leak Detection and Repair (LDAR) Programs in LNG Facilities The objective of this research project is to evaluate the scope of existing Federal, state, and industry leak detection, repair, and reporting program to identify gaps and inform future DOT PHMSA LDAR program goals and regulatory requirements for LNG facilities.

LNG facilities are subject to a variety of Federal and State safety (e.g., operating and maintenance), environmental (e.g., emissions performance standards), and reporting requirements (e.g., Environmental Protection Agency emissions reporting; Federal Energy Regulatory Commission certificate conditions and orders; and PHMSA incident and safety-related conditions reporting) pertinent to detection and repair of leaks of hazardous fluids from equipment throughout their facilities. LNG facilities may also conform to pertinent industry consensus standards and recommended practices, and their own facility-specific programs. A coordinated approach to identification and evaluation of pertinent requirements, industry standards and recommended practices, and industry programs could minimize regulatory gaps and duplication, thereby improving regulatory oversight by State and Federal authorities while reducing compliance burdens on operators.

The project scope must:

· Evaluate the applicability of Federal and State requirements, industry consensus standards and recommended practices, and representative operator programs pertinent to detection, repair, and reporting of hazardous fluid leaks for all LNG facility types (e.g., import/export terminals, peak shavers);

· Create a comparison table(s) of pertinent safety, environmental, and reporting requirements;

· Differentiate between safety, environmental, and and reporting requirements, industry standards and recommended practices, and operator programs, including discussion of thresholds, methods, frequency, exceptions, and component/equipment definitions;

· Assess the feasibility of a centralized and publicly-accessible portal for:

· pertinent requirements searchable by locality and/or regulatory authority

· submission of required Federal and State reportss on leak and emissions data

· Include participation and input from stakeholder groups, such as LNG operators, industry experts, service providers and standards organizations; and

· Provide delivery time, not to exceed 18 months, and total project cost.

8. Knowledge Development – Consequences of Catastrophic Failure of LNG Storage Tanks The objective of this research project is to study the consequences of a potential catastrophic failure of both high pressure and low pressure LNG tank designs to assist in the preparation of emergency evacuation plans.

Federal regulations at 49 CFR § 193.2509(b)(3)[footnoteRef:4] require LNG plant operators to coordinate with appropriate local officials in the preparation of an emergency evacuation plan that sets forth the steps required to protect the public in the event of an emergency, including catastrophic failure of an LNG storage tank. In order to develop effective evacuation plans, the local first responders must be fully informed of the causal scenarios and hazardous consequences from a catastrophic failure of the liquid container. The research will address different types of LNG storage tanks including low pressure tank systems (i.e., single-containment tank, double-containment tank, full-containment tank, and membrane-containment tank) and high pressure containers designed in accordance with American Society of Mechanical Engineers Boiler and Pressure Vessel Code, Section VIII, Division 1 or Division 2. [4: https://www.ecfr.gov/current/title-49/part-193#p-193.2509(b)(3) ]

· Perform a literature review of relevant research on the failure of high-pressure storage tanks as well as low-pressure large storage tanks from private and/or public research efforts to assist in achieving the project goals along with performing industry outreach to aid in the research, to avoid duplication, and to potentially complement what already exists;

· Identify possible causes for catastrophic tank failure;

· For low-pressure large storage tank system (single containment, double containment, and full containment), study how catastrophic failure of the liquid primary container impacts the structure and integrity of the secondary containment system;

· Model the consequences of a catastrophic failure for high-pressure and low-pressure storage tanks;

· Evaluate and confirm the failure rates for different types of LNG storage tanks in NFPA 59A (2023 edition), Table 19.9.1(a);

· Identify appropriate data that LNG plant operators could provide to local officials for an emergency evacuation plan;

· Include participation and input from stakeholder groups, such as LNG operators, industry experts, service providers and standards organizations; and

· Provide delivery time, not to exceed 24 months, and total project cost.

d) Threat Prevention

9. Technology Development – Improved In-Field Evaluation of Strain Demand The objective of this research project is to develop cost effective equipment to instantaneously evaluate the strain state of buried in-service pipelines.

Currently there is limited technology capable of instantaneously evaluating the strain state of in-service buried pipelines, where permanent strain gauges are not currently installed. This technology is critical for evaluating the safety of pipelines that may be subject to geohazards or extreme weather events, such as floods or landslides. PHMSA is seeking research to develop technology capable of instantaneously determining the real-time strain state of in-service buried pipelines. The results must be as close as possible to the same quality as provided by inertial measurement unit (IMU) tools.

The project scope must:

· Perform a review of literature and research results from other private or public research efforts to assist in achieving project goals, along with performing industry outreach to aid in the research, avoid duplication, and potentially complement what already exists;

· Perform a review of the applicability to API RP 1187, “Landslide Integrity Management for Pipeline;” International Organization for Standardization (ISO) 20074, “Geological hazard risk management for onshore pipeline;” 49 CFR § 192.613(c);[footnoteRef:5] 49 CFR § 195.414;[footnoteRef:6] and any other relevant standard identified; [5: https://www.ecfr.gov/current/title-49/section-192.613 ] [6: https://www.ecfr.gov/current/title-49/section-195.414 ]

· Identify limitations of strain evaluation tools and conditions that could restrict field implementation of the tool. Use identified factors for experimental design of field testing to compare results against currently used permanent and temporarily installed strain tools;

· Develop and conduct field tests of tool performance on real field conditions and compare results against IMU tool results;

· Identify representative implementation costs for equipment to instantaneously evaluate the strain state of buried in-service pipelines;

· Utilize participation and input from stakeholders, such as pipeline operators, service providers, industry experts and standards organizations; and

· Provide Delivery time, not to exceed 24 months, and total project cost.

Proposals that address advancements/validations to existing technologies also should:

· Focus on tools and technologies that have best potential for being used “as is,” modified, enhanced, or added onto, to perform reliably for all;

· Describe operational tasks for which an operator would use this technology, and in what typical environments; and

· Test for application, as appropriate.

10. Knowledge Development – Assess and Prevent Threats in Conversion or Repurposing Pipeline Systems The objective of this research project is to conduct an evaluation of pipelines undergoing a change of service and what can be done to minimize the risks involved. The project must include an evaluation of the threats presented, factors that may exacerbate the risks in certain pipelines or conditions, and development of methods or best practices to prevent and/or mitigate identified risks.

Existing pipelines may be repurposed as product changes, flow reversals, conversion to natural gas service under the requirements of 49 CFR § 192.14,[footnoteRef:7] or conversion to hazardous liquid service under the requirements of 49 CFR § 195.5.[footnoteRef:8] Pipelines that undergo these changes may experience new or different threats to pipeline safety including changes to: operating parameters, internal/external corrosion threats, stress corrosion cracking threats, and identification of high consequence areas. [7: https://www.ecfr.gov/current/title-49/section-192.14 ] [8: https://www.ecfr.gov/current/title-49/section-195.5 ]

· Perform a review of relevant regulations, literature, and research results from other private or public efforts to assist in achieving the project goals, along with performing industry outreach to aid in the research, avoid duplication, and potentially complement what already exists;

· Evaluate, for each type of pipeline repurposing, the various threats that may be experienced;

· Identify potential limitations in system components and any relevant pipeline conditions or anomalies that might affect the repurposing;

· Consider risk factors that may greatly increase the risks under the various service changes;

· Develop methods or best practices for conducting these service changes safely;

· Include participation and input from stakeholder groups, such as pipeline operators, industry experts, service providers, and standards organizations; and

11. Technology Development – Improved Training Methods or Technology for Hazardous Liquid Pipeline Emergency and Hazardous Condition Response The objective of this project is to develop new methods and technologies to train hazardous liquid (including carbon dioxide) pipeline personnel for responding to emergencies and hazardous/abnormal operating conditions to improve the quality of pipeline emergency responses. The method or technology should enhance training results by improving: 1) trainees’ ability to recognize emergency and hazardous conditions, 2) knowledge of proper actions to take in these conditions, 3) coordination between emergency response personnel, and 4) long term retention of skills acquired during training.

Training of personnel for response to emergency or abnormal conditions is important for both preventing accidents from occurring and mitigating the damage caused by pipeline accidents. This training currently takes the form of controller training as required by 49 CFR § 195.446(h), personnel training as required by 49 CFR § 195.403, response plan training as required by 49 CFR § 194.117, and the operator qualification program as required by 49 CFR § 195 subpart G. These programs include basic training of personnel for duties under emergency conditions, training for recognizing and reacting to abnormal and hazardous conditions, and drills to practice coordination in emergency situations. New cost-effective methods or technologies may be used to improve all of these training programs or any subset of them.

The project scope must:

· Review applicability and compatibility of new training methods and technologies with American Petroleum Institute (API) Recommended Practice (RP) 1168 “Pipeline Control Room Management,” The National Preparedness for Response Exercise Program (PREP) guidelines, and pertinent consensus industry standards and recommended practices;

· Perform a literature review of relevant research from private or public research efforts to assist in achieving the project goals along with performing industry outreach to aid in the research, avoid duplication, and potentially complement what already exists;

· Identify representative implementation costs for new training methods and technologies;

· Include participation and input from stakeholder groups, such as pipeline operators, certified oil spill removal organizations (OSROs), standard organizations, first responders, and other industry stakeholders;

· Describe a validation program to prove the method or technology produces measurable improvement in emergency response abilities;

· Develop and conduct a series of field validation exercises demonstrating (where practicable, measurable) enhancements to existing training methods and technologies, and identify and evaluate any limitations;

· Develop best practices for how the methods or technologies are to be implemented; and

· Provide delivery time, not to exceed 24 months, and total project cost.

Proposals that address advancements/validations to existing technologies also should:

· Focus on tools and technologies that (1) have best potential for being used “as-is” or with minimal modifications/enhancements to existing facilities, and (2) perform with similar efficacy and reliability for a maximal number of part 195-regulated facilities;

· Describe operational tasks for which an operator would use this technology and in what typical environments, and limitations of those technologies in terms of detection threshold, location accuracy, and speed of detection; and

· Test for application, as appropriate.

e) Anomaly Detection and Characterization

12. Technology Development – Nondestructive Means to Determine Pipe Body and Weld Fracture Toughness Through In-Line Inspection (ILI) or In-Ditch Methods The objective of this research project is to develop a method to capture fracture toughness measurements by either an ILI tool or by in-ditch nondestructive evaluation (NDE) technology without destructive testing.

Reliable fracture mechanics calculations require accurate fracture toughness values that currently are impossible without destructive testing. Fracture toughness properties also can vary from joint to joint. Obtaining values for the actual pipe being evaluated would be more accurate than using values from destructive examination on similar pipes. A cost effective methodology or technology is sought that could be used in field conditions or by ILI to obtain appropriate fracture toughness values to improve fracture mechanics analyses and fitness for service.

The project scope must:

· Perform a literature review of relevant research from private or public research efforts to assist in achieving the project goals along with performing industry outreach to aid in the research, to avoid duplication, and to potentially complement what already exists;

· Develop an in-ditch or ILI sensing system to determine fracture toughness (or measurement that can be accurately translated to fracture toughness) in-situ;

· Demonstrate that the process can be used to nondestructively measure fracture toughness (or be translated to fracture toughness);

· Include a demonstration with performance measures that successfully shows measurement of pipe properties that can be used in fracture mechanics calculations as determined by the researcher;

· Include participation and input from stakeholder groups, such as operators, industry experts, service providers and standards organizations; and

· Provide delivery time, not to exceed 36 months, and total project cost.

Proposals that address advancements/validations to existing technologies also should:

· Focus on tools and technologies that have best potential for being used “as is,” modified, enhanced, or added onto, to perform reliably for all;

· Describe operational tasks for which an operator would use this technology, and in what typical environments; and

13. Technology Development – Improved Coatings/Liners for Pipeline Repair The objective of this research project is to develop remediation methods that involve coatings or liners which could be used to rehabilitate or remediate damage to in-service pipelines. Many of the methodologies used in rehabilitation and remediation projects appear limited in the amount of reinforcement provided, thereby not useful in restoring the pressure carrying capacity of a pipeline.

This research project will develop a cost effective, rapid cure method and product that would be minimally invasive and work for in service pipelines. The methodology should include integrity assessment techniques to ensure that the coating/liner will eliminate or reduce the threat that led to installing the liner/coating.

The project scope must:

· Perform a literature review of relevant research from private or public research efforts to assist in achieving the project goals along with performing industry outreach to aid in the research, to avoid duplication, and to potentially complement what already exists

· Develop a coating or lining for pipelines up to 16 inches;

· Demonstrate that the rapid cure installation process provides time savings over the current state of practice;

· Include a demonstration, to include performance measures, that successfully rehabilitates the full length of a pipe segment or a portion of a pipe segment, as determined by the researcher;

· Illustrate how the proposed research could conform to and advance beyond the current state of practice within the American Society of Testing and Materials (ASTM) F2207-06 (2019), “Standard Specification for Cured-in-Place Pipe Lining System for Rehabilitation of Metallic Gas Pipes;”

· Specify the infrastructure type to which the technology would pertain (e.g., pipeline or facilities, as well as liquid, gas, UNGS, H2, CO2, or LNG);

· Identify representative implementation costs for coatings or liners which could be used to rehabilitate or remediate damage to in-service pipelines;

· Include participation and input from stakeholder groups, such as operators, industry experts, service providers and standards organizations; and

· Provide delivery time, not to exceed 36 months, and total project cost.

Proposals that address advancements/validations to existing technologies also should:

· Focus on rapid cure methods and products that have best potential for being used “as is,” modified, enhanced, or added onto, to perform reliably for all;

· Describe operational tasks for which an operator would use this technology, and in what typical environments; and

f. Hazardous Liquids Tanks

14. Technology Development – Monitor Active Vapor Corrosion Inhibitors (VCIs) in Tank Pads The objective of this research project is to develop new monitoring technology for the presence and effectiveness of VCI installed in aboveground storage tank floors.

VCIs can provide effective protection from corrosion when used properly and in sufficient quantities. Industry standards and best practices indicate difficulty in monitoring the effectiveness of VCIs on aboveground storage tank floors and in determining when replenishment is needed. PHMSA is seeking research to address this gap to design a method, convert an existing technology, and/or develop new equipment to measure VCI effectiveness. Additionally, PHMSA seeks to establish a methodology to calculate timetables for replenishment of VCIs on aboveground storage tank floors cost effectively.

The project scope must:

· Perform a literature review of relevant research from private or public research efforts to assist in achieving the project goals along with performing industry outreach to aid in the research, to avoid duplication, and to potentially complement what already exists;

· Review applicability to API Technical Report (TR) 655, “Vapor Corrosion Inhibitors for Storage Tanks,” and The Association for Materials Protection and Performance (AMPP) SP21474, “External Corrosion Control of On-Grade Carbon Steel Storage Tank Bottoms”;

· Develop best practices for when and how to conduct effectiveness measurements and for calculating timelines for VCI replenishment;

· Describe planned testing scheme for various concentrations and application methods, including adequate sampling to achieve validation and statistically meaningful results;

· Conduct validation testing as described in the main project objective to further a new or existing tool to the market, including under real and varying field conditions, as appropriate;

· Utilize participation and input from stakeholders, such as VCI service providers, facility owners, and standards organizations; and

· Deliver reported results, not to exceed 24 months, and provide cost.

Proposals that address advancements/validations to existing technologies also should:

· Focus on tools and technologies that have best potential for being used “as is,” modified, enhanced, or added onto, to perform reliably for all;

· Describe operational tasks for which an operator would use this technology, and in what typical environments; and

· Test for application on tank facilities, as appropriate.