Updated Digital As-Built Requirements: What Energy Companies Need to Know & How They Can Benefit

August 14, 2023
By Nate Osterberg, Director of Strategic Growth and Garrett Deick, Professional Engineer, WSB

When the Colorado Department of Transportation (CDOT) mandated new permitted utility installations meet Digital As-built Requirements (DAC), WSB adopted a workflow that allowed utilities to meet and exceed these new requirements. At the forefront of this change in Colorado, we helped utilities navigate the new law with cutting-edge technologies and mapping.

Now, many other states across the country are looking to implement similar laws, mandates and programs and there are things utilities should know. What are the rules, how can utility companies prepare and how do these new SUE requirements benefit energy companies and other entities in the long-term?

What are the rules in Colorado?

Essentially, any entity installing utilities in a DOT right of way is required to use a digital as-built. All utility lines will need to be mapped digitally and submitted to CDOT, including plans and existing lines. Utility companies will be required to survey existing utility lines — commonly known as Subsurface Utility Engineering (SUE) — and submit them to the state using their chosen software.

Another key factor is ensuring the utility lines are found to the highest accuracy quality levels using geophysical methods to locate and map them.

With more states adopting similar requirements, how can utilities prepare?

Utility companies need to plan SUE investigations for their new facility installations. In the recent Infrastructure and Jobs Act (IIJA), the federal government is providing grants to utility companies to complete the digital as-built mapping needed starting in 2024. These funds can be used for damage prevention and supporting SUE investigations and installation.

Utilities also must ensure that they are prepared to not only gather the data, but store and use the data too. Preparing teams to use SUE data in the design and construction process has many benefits.

What are the benefits of SUE investigations?

For every dollar spent on a SUE investigation, as much as $22 can be saved in the construction phase. SUE allows utility companies to avoid damage to gas, water, electric and sewer lines that are costly to repair. It also reduces construction down time, which is also costly. In short, SUE helps prevent unexpected changes and expenses during construction.

Preventing damage also helps avoid environmental consequences. If a gas line is hit, gas leaks into the ground and atmosphere, increasing greenhouse gas emissions. These leaks carry serious public safety concerns. By using SUE investigations, damage can be avoided.

In the future, electric companies will benefit greatly from SUE investigations as well. In the Infrastructure and Jobs Act, electric companies will have large grants available to move overhead lines underground. With digital maps of utility lines provided by SUE investigations, electric companies will be able to plan and design around existing underground utilities and make the process more efficient and cost effective.

For many of the same reasons, telecom companies will benefit from SUE investigations. As 5G expands across the country, installation is happening underground to protect lines from natural disasters. With digital maps from SUE investigations, these lines will be easier to install efficiently and prevent damage from future construction.

Lastly, cities will benefit from better mapping data. Much of the nation’s water infrastructure was built more than a century ago and GIS and other modern technologies were not used to comprehensively map water lines. In the next couple decades, many water lines are due to be replaced. With SUE investigations happening now, cities can plan around the current infrastructure when replacing and maintaining their water lines.

How can WSB help?

WSB’s team provides the knowledge and skill to help utilities and governments prepare for and implement new SUE requirements. Utilizing the latest technologies and processes, we helped utilities not only meet, but exceed new state requirements in Colorado. WSB also provides utility companies with all data in GIS/CAD format allowing them to use their data for planning and construction.

WSB’s team can assist with everything from the pre-engineering phase through construction phase. We help with understanding new regulations, securing grant funding, and more for utilities and local governments.

Nate Osterberg has over 12 years of experience in the utility industry and specializes in utility inspection for WSB’s Pipeline group. Nate’s expertise lies in managing inspection staff technology implementation, scheduling and quality control in addition to CFR 192/195 inspection, damage prevention and GIS-based web mapping.

[email protected] | 612.202.2997

Garrett specializes in utility coordination and has worked on a variety of projects including state aid, federal aid, cooperative agreement, trunk highway, and design build projects. He has extensive experience utilizing Microstation, GEOPAK, and Open Roads Designer for plan development, 3D modelling of utilities, and utility conflict analysis.

[email protected] | 612.289.1175

Pipeline Integrity and the PHMSA Mega Rule – What You Need to Know

January 31, 2023

A vital part of a pipeline operator’s job is to ensure the integrity of pipelines always remain impenetrable and intact. The Pipeline and Hazardous Materials Safety Administration (PHMSA), in charge of regulating the pipeline industry, has recently developed new requirements concerning pipeline safety of gas transmission lines, adding layers of complexity and stringent new standards for operators.

The new rule Repair Criteria, Integrity Management Improvements, Cathodic Protection, Management of Change, and Other Related Amendments (also known as RIN2) goes into effect on May 24, 2023, and operators are required to have their integrity management program updated and implemented by February 2024. Because there are so many new complexities and factors involved, operators need to act now to update their program and ensure they adhere to all new guidelines and regulations.

What You Need to Know.

The latest rule specifies that pipeline operators of transmission lines in a regulated Integrity Management Plan update their requirements for repair criteria, assessment repair timelines, management of change procedures, expanded identification of potential threats to pipeline integrity (like a severe weather event), and more.

Where to Place Your Focus and Resources.

As operators review and update their integrity management programs, what are the best practices and things you need to review?

Start by focusing on data integration. PHSMA is requiring operators to incorporate more than forty specific pipeline potential threats into their risk assessments. Updating your integrity program to incorporate these changes is time intensive. New items like geohazard review, external forces, land movement, and water movement are all items to plan for and consider. Operators must start this process by May 24, 2023, and have all required integration complete by February 26, 2024.

Next, it’s important to update corrosion assessment requirements. PHSMA incorporated a standard assessment program that is more prescriptive than before, and corrosion assessments must be built to meet those strict industry standards.

Finally, it’s important to conduct a geohazard review. Operators must now take into account external forces that may affect the integrity of the pipeline. WSB put together a more in-depth article on this topic, and you can find more information on geohazard reviews by clicking here.

Don’t Delay, Act Now.

With so much to do and less than one year to do it all, many operators will find it difficult to allocate the internal resources and time necessary to fulfill all the requirements. Updating the integrity management program takes time, and if you haven’t started, you may already find yourself falling behind.

We have worked in the pipeline industry for over a decade and are available to help update plans, implement procedures, make risk assessments, and meet all requirements to ensure your program is in full compliance with the new rule. We have the team and the know-how to help guide pipeline integrity teams, no matter where you are in the process.

Damage Prevention Awareness

January 12, 2023

By Nate Osterberg, Director of Strategic Growth, WSB

Impacts on the Oil and Gas Industry

According to the Common Ground Alliance (CGA), damages to underground facilities cost $61 billion annually. To protect the public, reduce costs, and incorporate asset management, damage prevention has become a relevant conversation for stakeholders across the construction industry. Advances in technology and the Infrastructure Investment and Jobs Act (IIJA) are spurring more engagement throughout the country.

IIJA Impact

With the passage of IIJA, there is an increase in construction activity including utility, road, and renewable infrastructure. The current demand for utility locators is extraordinary and when coupled with the labor shortage and increasing demand, it is only becoming more challenging. In these circumstances, we rely on technology to guide us. To offset impacts from the labor market we incorporate digital mapping into production locating processes.

Subsurface Utility Engineering (SUE)
SUE is the investigation of buried utilities that identifies conflicts and mitigates risks in the pre-engineering phase of construction. Using survey grade-accuracy with cutting-edge locating and survey equipment, capable of sub-centimeter accuracy, we identify risk and conflicts. Our team captures the location information to digitally map the facilities. When unlocatable utilities are identified, our team of damage prevention specialists approaches the challenge with different means and methods.

Cataloging for the Future

Locating the utility is the first step, but just as important is the data collection. Once a utility is located the information is documented and added to an asset management database. This process is having a major impact on the industry and is assuring accuracy for future locates. Construction plans are evaluated through a digital twin utility map, resulting in cost and time savings and enhanced design data. After decades of stagnant innovation, the industry is advancing quickly because of cutting-edge tools that allow for safer conditions and better planning.

Impact Across an Industry

With hundreds of field staff on active job sites, the collection of highly accurate location data for new and existing facilities is becoming vital to project performance. With minimal impact on budget and a streamlined mapping process, data collection efforts reduce the time it takes to provide facility owners and 811 systems with updated and accurate records.

The Top Drivers in Damage Prevention

Public Safety
Infrastructure Act
5G initiative
Increased Damages to Facilities
Unlocatable and Untoneable Utilities
Workforce Turnover & Experience

Integrity Management of Energy Pipelines

Natural Pipeline Rupture & Fire

October 17, 2022

In May of 2020, a natural gas transmission pipeline ruptured in Hillsboro, Kentucky, causing a fire and millions of dollars in damage. The rupture, which occurred on a hillside pipe segment, had previously been identified by the operator for geotechnical monitoring and mitigation due to the presence of an active landslide. Following the incident, the National Transportation Safety Board (NTSB) released a pipeline investigation report (PIR-22/01) on the incident. While thankfully there were no fatalities or injuries, the operator estimated the cost of property damage and emergency response was $11.7 million.

Between 2018 and 2020, the operator performed multiple integrity management studies, including in-line inspections (ILIs) and geohazard assessments at the site of active landsliding. Integrity studies indicated that the affected pipeline was exposed to external loads, or loads transmitted to a pipeline from an external source. Although the operator planned to mitigate the hazardous site in Summer 2020, hillslope failure and pipeline rupture occurred before mitigation was completed.

Tips for Proactive Pipeline Management and Risk Mitigation

For gas and hazardous liquid pipelines, proactive management of geohazard risks is critical. To ensure pipeline safety and integrity, here are some tips for operators:

Perform comprehensive geohazard risk assessments, including field surveys, to efficiently identify, document and prioritize the nature and extent of potential threats. Detailed investigations should reduce uncertainly and improve risk and financial-based decision-making.
Quantify external loading and load distributions for at-risk pipelines.
Monitor environmental conditions and changing weather patterns. Soil stability can be adversely impacted by changing weather patterns, so it’s important to check soil and surface materials regularly.
With the assistance of geotechnical engineers, design and implement site-specific monitoring and mitigation plans based on risk analyses and load calculations. Monitoring and mitigation plans should provide operators sufficient time and information to act in response to geohazard events.

How WSB Can Help

Due to the complexity and variability of geohazards, WSB’s Energy Sciences team recommends comprehensive geohazard risk assessments be performed for energy pipelines on five-year schedules. Our team of scientists and risk assessment specialists can help you identify, mitigate, and manage geohazard risks through services tailored to meet regulatory requirements and individual risk profiles.

PHMSA Advisory Bulletin Review

Pipeline Safety & Integrity, as Related to Geohazard Risk

On May 26, 2022, the Pipeline and Hazardous Materials Safety Administration (PHMSA) issued an updated advisory bulletin (Docket No. PHMSA-2022-0063) to remind owners and operators of gas and hazardous liquid pipelines about the potential for damage and safety-related issues caused by geologic hazards (geohazards), including earth movements and climate-related hazards. Geohazards are naturally occurring and dynamic processes, capable of causing widespread damage, loss of property and/or injury and loss of life.

Earth movement hazards include slope instability, subsidence, frost heave, soil settlement, erosion, scour, and earthquakes. The causative factors of earth movements are myriad and complex but rooted in the understanding of regional geology, environmental conditions, and human influence. Earth movements can be exacerbated by local surface conditions (variable, steep, and rugged terrain), changing subsurface conditions, and climate-related hazards (e.g. heavy rainfall, flooding, washouts, weakened or unstable soil). It is important to understand that natural geohazards rarely occur in isolation but instead as hazard cascades: events that precipitates another, increasing resultant risks and consequences. Thus, it is imperative to consider and examine all possible geohazard factors when determining risk.

As outlined in 49 CFE 192.103 and 49 CFR 195.110, gas and hazardous liquid pipelines must be designed to withstand external loads, including those imposed by geohazards. In addition, PHMSA requires operators to take preventative and mitigative measures to avoid pipeline failure and consequences, such as those caused by geohazards (49 CFR 192.935 and 49 CFR 195.452). Additionally, integrity requirements pursuant to geohazards can be found under 49 CFR 192.917 and 49 CFR 195.452.

To ensure pipeline safety and integrity against geohazards, operators should consider taking the following actions:

Identify areas surrounding the pipeline which may be prone to earth movement and other geohazards. For each identified location, plans should be developed, with the assistance of geotechnical engineers, outlining design, construction, and monitoring procedures, based on site-specific hazards.
Monitor environmental conditions and changing weather patterns. Note, soil stability can be adversely impacted by changing weather patterns; evaluate soil and surface materials regularly.
Mitigation measures should be designed and implemented, as need be, based on site-specific conditions.

WSB Announces Two Key Director Promotions in Oil & Gas Services

Engineering and consulting firm WSB announced today two key director promotions within their Oil & Gas services. Jayson Honer was promoted to director of field services and Nate Osterberg was promoted to director of strategic growth – oil & gas. WSB’s Oil & Gas team provides comprehensive, in-house services for clients that ensure compliance to design standards, procedures, and regulations for safe construction, rehabilitation, and replacement of pipelines.

Jayson Honer
Director of Field Services

Nate Osterberg
Director of Strategic Growth – Oil & Gas

“We are very excited to promote two talented employees within WSB’s Oil & Gas service area to director. Both Jayson Honer and Nate Osterberg are outstanding leaders and team members who will help provide instrumental leadership, direction, and growth for WSB while ensuring unmatched service for our clients,” said John Gerlach, vice president of oil & gas.

As director of field services, Honer will plan, direct, and oversee the operations of oil and gas field services across all regions of WSB. He will coordinate the ongoing management of operation, direction, and coordination of services while driving strategic field service initiatives, process improvement, and client relationship management.

“Ensuring top client service – from pipeline engineering and design to environmental compliance – is important for our clients, and that means efficient, thorough processes and management of our teams,” said Honer. “I look forward to serving in my new role at WSB, continuing to grow our world-class oil and gas services.”

As director of strategic growth – oil & gas, Osterberg will help launch new partnership opportunities that will drive expansion and engagement and grow partner-driven revenue. This role requires a deep understanding of the industry landscape, sound business judgment, and leadership to develop and grow in start-up regions.

“WSB’s oil and gas business is growing and expanding, and I look forward to working collaboratively to further expand opportunities for our business and industry as a whole,” said Osterberg. “Our industry is constantly evolving and changing, so thinking strategically about future trends, partnership opportunities, and how to support WSB’s staff in start-up regions is vital to the success of our industry and ensuring we are continuing to provide top service to our clients.” Learn more about WSB’s oil & gas services here.

4 Takeaways from PHMSA’s Joint Pipeline Advisory Committee Meeting

Last week I tuned into PHMSA’s joint Gas Pipeline Advisory Committee (GPAC) and Liquid Pipeline Advisory Committee (LPAC) meeting. PHMSA leadership and PAC members updated the industry on new priorities and expectations. Throughout the two days of presentations, four things immediately jumped out to me.

1. How do new regulatory priorities affect your business?

It’s been more than a year since the last PAC meetings and the issuance of regulations has been on pause. With changes in the administration, PHMSA leadership, and the new PIPES Act of 2020 law, priorities have been revised. Being prepared for upcoming regulations is the best business decision operators can make.

2. What should you include in your O&M Manual to address ADB 2021-01?

PHMSA considers some sections of the PIPES Act to be self-executing provisions. However, they issued the Advisory Bulletin 2021-01 earlier this year to remind operators to include updates to their procedural manuals on how they plan to eliminate hazardous leaks and minimize natural gas releases. What manual revisions should you include by the December 27^th, 2021, deadline?

3. How does the PIPES Act of 2020 affect PHMSA, future rules, and the industry?

Last December a 2,100 page appropriations bill was signed into law. That document included 34 pages of mandates to PHMSA and the industry. Decoding which sections apply and how they will affect operators can be a lengthy process.

4 . What changes will the proposed Standards Update Rule bring?

Published on January 15^th, 2021, this rulemaking proposes to update more than 25% of PHMSA’s Incorporated by Reference industry standards. Adoption of these more recent specifications can help bring up to date operators, their suppliers, and regulatory bodies with the latest technologies and best practices.

Are you ready for Colorado’s new Digital As-Constructed Requirements?

By Nate Osterberg, Pipeline Inspector, WSB

Effective January 14, 2021, the Colorado Department of Transportation (CDOT) will mandate that all new permitted utility installations meet Digital As-Constructed Requirements (DAC) in accordance with the Utility Accommodation Code Rule 3.3.4.6.2. New requirements under State Highway Accommodation Code, 2 CCR 601-18, Rule 3.3.4.6.2 Digital As-Constructed Requirements, Plan and Profile 3.3.4.3 mandate uniformity in utility mapping, as-builts and plan-and-profile submissions. Utility permits will begin stipulating this requirement soon. Additionally, there are new Plan and Profile requirements for all Horizontal Directional Drilling (HDD) operations within CDOT’s Right of Way.

But what does this mean?

Essentially, this means that anyone working within CDOT’s Right of Way must perform a digital utility locate survey for any underground utilities – commonly known as Subsurface Utility Engineering (SUE). The survey must be submitted using their chosen software.

What is SUE?

SUE is an engineering practice used to obtain reliable underground utility information. Accurate and successful SUE practices benefit contractors, transportation departments and utility companies by limited the need for unnecessary utility relocations, avoiding unexpected conflicts and enhancing safety.

How do I do this digitally?

You combine the right tools with the right expertise. The digital world of 3D modeling can be intimidating, but a digital approach is actually more accurate, efficient and safe. Using mobile mapping software, utilities can be captured, recorded and displayed precisely accurately and seamlessly.

Learn more about our complete Pipeline services or Utility Mapping and how to prepare for upcoming requirements.

[email protected] | 612.202.2997

Pipeline inspections: What communities should know

John Gerlach, Director of Pipeline Field Operations, WSB

Learn how inspections and monitoring can keep your utilities running smoothly and safely.

Whether filled with natural gas to fuel and heat homes and businesses or transporting liquid fuels from one location to another, most communities have miles of pipes embedded underground with other critical infrastructure. There’s a misconception that these lines are primarily located in remote areas. In reality, pipeline infrastructure can be found beneath our roadways and sidewalks or near homes, businesses, landmarks, parks and other natural resources. Pipeline infrastructure can range from large, high-pressure steel lines that serve cities and powerplants, to small plastic lines, used to transport gas from the street to your home or place or business. These complex networks require expertise to ensure the safety of people and the environment, as well as reliable access to the fuels we need to enjoy hot showers, drive to work and keep the lights on.

With increasing federal regulatory standards, now is the time to become more focused on pipeline integrity and safety. WSB offers inspections that help utilities and cities understand the condition of their infrastructure, reduce costly and inefficient repairs, improve safety and maintain the long-term integrity of these important pipelines.

Why hire a third-party inspector?

Pipeline inspectors can add value and security to any project near utility lines. Most commonly, inspectors are hired to oversee the contractors working on infrastructure projects such as roadway improvements or utility replacements. When these projects interfere with the natural gas system, pipeline inspectors who can recognize and mitigate potential risks are invaluable.

Third-party experts can also be utilized to verify the results of other inspections, like performing audits that identify pipeline locations before a project is started. A second opinion can identify costly errors before the damage is done. In our experience, an audit of locate work finds mistakes roughly 30% of the time.

A new regulatory environment

Investigations into high-profile pipeline releases over the past decade have prompted new regulatory recommendations and standards. Pipeline releases can have devasting consequences to people and the environment including fatalities, injuries, forced evacuation and damage to properties and natural resources. In many cases, regulators – like the Pipeline and Hazardous Materials Safety Administration and the National Transportation Safety Board – require independent, third-party inspections of pipelines and pipeline projects.

Technology advantage

New technologies have made evaluating pipeline integrity more efficient. Rather than digging up pipelines under a densely populated area to check for deterioration, a device can be sent through the line that shows anomalies like corrosion and damage from past construction. Most pipes should be replaced every 15 to 20 years. Since pipeline replacement projects are typically planned in coordination with other infrastructure improvements, this type of check can help communities identify which projects should be prioritized first.

WSB also offers real-time reporting on pipeline status through an ArcGIS platform. This technology can detect an increase in pressure or corrosion on the line and send notifications to technicians in the field.

At first glance, hiring an outside expert to ensure compliance and verify accuracy can appear costly. In the end, pipeline inspectors can make your project run smoothly, reduce issues in the field and reduce the risk of releases, accidents and other safety hazards. Reach out to WSB’s utility and pipeline experts today to learn more.

John Gerlach is a Director of Pipeline Field Operations with more than 30 years of experience. His expertise extends to pipeline design, construction inspection and safety and risk management.