Industry News

GridSME Welcomes Gideon Le'iato to the team!

Tue, 12 Aug 2025 16:48:15 GMT

GridSME Welcomes Gideon Le'iato as our new Senior Meter Inspector!

Welcome Gideon!

We’re excited to introduce Gideon Leiato as the newest member of our Grid Integration team at GridSME. As a Senior Meter Inspector, Gideon brings a wealth of hands-on expertise that strengthens our commitment to accuracy, compliance, and exceptional service.

With a career starting in 2014, Gideon has developed deep experience in metering, CAISO inspections, and field service operations. Over the years, he has commissioned and tested hundreds of energy sites, ensuring everything runs smoothly from initial setup to final inspection. Known for his sharp technical skills and safety-first approach, Gideon thrives when troubleshooting complex systems, reviewing site plans, and leading projects to successful completion.

Gideon also served in the U.S. Army Reserves as a Signal Support Specialist, adding leadership and discipline to his professional toolkit. As a CAISO Authorized Inspector, he plays a critical role in helping clients navigate regulatory requirements with confidence and precision. Currently, Gideon is expanding his expertise in Meter Engineering and the NRI process, continually raising the bar in service quality.

What truly sets Gideon apart is his relentless drive to solve problems with integrity and a positive attitude. He approaches every challenge by asking the right questions, digging deep for solutions, and doing it all with kindness and humility.

We’re proud to have Gideon as part of the GridSME family and look forward to the impact he will make in advancing our Grid Integration efforts.

Welcome to the team, Gideon!

GridSME Welcomes Jill Loewer to the team!

Thu, 12 Jun 2025 17:24:39 GMT

GridSME Welcomes Jill Loewer as an Independent Consultant and Senior Compliance Analyst!

We are excited to welcome Jill Loewer to the GridSME team as an Independent Consultant and Senior Compliance Analyst within our Compliance Practice Area.

Jill brings with her a wealth of experience and a deep, working knowledge of the NERC Reliability Standards and framework. She recently retired from Utility Services after 16 years as a Senior Operations & Planning (O&P) Analyst, where she supported NERC compliance programs across a range of entities including generation (conventional, wind, and solar), transmission, and distribution providers.

Throughout her career, Jill has developed, implemented, and maintained comprehensive NERC compliance programs for her clients. Her work includes the creation of internal controls, training materials, and hands-on support for audits, spot checks, self-certifications, self-reports, and mitigation plan development. Her practical experience and proactive approach have earned her a strong reputation in the compliance community.

Jill has also made significant contributions to industry-wide reliability efforts, serving on multiple NERC Drafting Teams and Committees. She has written and edited key technical documents—such as Reliability Standard language, Technical Rationale, and Implementation Guidance—and has helped shape updates to NERC’s Standard Process Manual. Notably, Jill played an active role in the Cold Weather (EOP-011) and Extreme Cold Weather (EOP-012) Standard Development Projects, helping the industry respond to lessons learned from major winter reliability events.

Jill’s collaborative spirit, technical expertise, and leadership in shaping national reliability standards make her a tremendous asset to both our team and the clients we serve.

Welcome to the team, Jill! We’re thrilled to have you on board and look forward to the meaningful contributions you’ll bring to GridSME and the broader compliance community.

Level 3 NERC Alert and Updated Category 2 Information

Thu, 29 May 2025 17:57:30 GMT

Level 3 NERC Alert and Updated Category 2 Information:

On May 20, 2025, the North American Electric Reliability Corporation (NERC) issued a Level 3 Alert titled “Essential Actions for Inverter-Based Resource (IBR) Performance and Modeling.” This Alert was directed to key industry players including Transmission Owners (TOs), Transmission Planners (TPs), Planning Coordinators (PCs), and registered Generator Owners (GOs).

What Prompted This Alert?

The Level 3 Alert follows up on a previous Level 2 Alert, triggered by concerns over low response rates and IBR model quality deficiencies. While many organizations struggled, GridSME’s clients achieved a 100% response rate—a great milestone! This Alert aims to improve the performance and modeling of inverter-based resources critical to grid reliability.

What Does the Level 3 Alert Mean?

The outcomes of this Alert will:

Supplement earlier findings on IBR performance
Inform future work by Standard Drafting Teams (SDTs)
Influence upcoming revisions to key Reliability Standards FAC-001 and FAC-002

Generator Owners must review and respond to the Essential Actions outlined in the Alert by August 18, 2025.

GridSME is actively working to acknowledge this Alert on behalf of all our Managed Compliance Services (MCS) Generator Owner clients to meet the deadline. If you’re not yet an MCS client, reach out to us at bdgroup@gridsme.com for assistance.

NERC Category 2 – GO IBR Update

NERC’s Category 2 Phase III activities are underway across all regions. Each region will soon send a Request for Information (RFI) to the Primary Compliance Contact for all Category 2 projects. The target effective date for registration of all Category 2 projects is planned for May 2026.

Meanwhile, NERC’s registration tool, CORES, is expected to be ready for Category 2 project registration by August 2025. NERC will provide further updates as CORES becomes available.

If you own or operate Category 2 projects and haven’t started Phase III activities, now is the time to act. GridSME is ready to help—please contact us at bdgroup@gridsme.com with any questions or to get started.

What This Means For You

NERC has issued a critical Level 3 Alert focused on improving the performance and modeling of inverter-based resources (IBRs), which are essential for grid reliability.
Generator Owners must respond to the Alert’s required actions by August 18, 2025 to stay compliant.
GridSME is helping clients meet this deadline and can assist others who need support.
NERC’s Category 2 registration process for IBR projects is moving forward, with important requests and deadlines through 2025 and 2026.
If you have Category 2 projects but haven’t started Phase III activities, there’s still time, but don’t wait!

For detailed information, you can review the Level 3 Alert and Essential Actions document here:
Level 3 Alert Essential Actions IBR Performance and Modeling (PDF)

Stay informed with all NERC alerts and updates on their official page:
https://www.nerc.com/pa/rrm/bpsa/Pages/Alerts.aspx

GridSME Welcomes Max Carpenter to the team!

Thu, 29 May 2025 17:21:20 GMT

Welcoming Max Carpenter to GridSME’s Grid Integration Team

We are pleased to announce that Max Carpenter has joined GridSME as an Independent Consultant (IndCon) and will serve as a Principal Consultant within our Grid Integration Practice Area.

Max is a seasoned expert with over 25 years of experience in the energy industry, bringing a wealth of knowledge in power market operations, commodity trading, and renewable integration. His career has been defined by a strong track record of leadership and results, particularly in managing complex power portfolios and navigating the nuances of competitive electricity markets.

Throughout his career, Max has worked across several major U.S. power markets, including CAISO, PJM, MISO, ERCOT, SPP, and NYISO. His expertise spans a wide range of disciplines, from power scheduling and trading to power purchase agreements (PPAs) and renewable energy resource management. This depth and breadth of experience uniquely position him to support clients in both strategic and operational capacities.

Max joins GridSME at a time of profound change in the energy sector, and he is eager to help clients navigate the evolving landscape of market reform, decarbonization, and grid modernization. His leadership and market insight will be instrumental as organizations adapt to increasingly complex regulatory requirements and opportunities in power market participation.

We are excited to welcome Max to the Grid Integration team and look forward to the positive impact he will have on our clients and their energy strategies.

Please join us in welcoming Max to the GridSME team!

GridSME Welcomes Terry Harbour to the team!

Tue, 27 May 2025 17:15:02 GMT

GridSME Welcomes Terry Harbour, PE as Principal Consultant

We’re excited to officially welcome Terry Harbour, PE to GridSME as a full-time Principal Consultant within our Compliance Practice Area!

Terry brings with him three decades of experience in electrical engineering, system planning, and NERC regulatory compliance. His impressive career reflects a commitment to both technical excellence and strategic leadership in the utility industry.

Most recently, Terry served as Supervisor of NERC Compliance at MidAmerican Energy, where he led the development of internal controls, oversaw audit preparation and execution, and managed a multidisciplinary team of subject matter experts across operations, transmission, and Critical Infrastructure Protection (CIP). He has successfully led multiple NERC audits and played a key role in aligning utility operations with evolving compliance expectations.

Terry’s leadership extends well beyond individual organizations. He served as Vice Chair of the Midwest Reliability Organization (MRO) Compliance Committee, where he guided the development of critical industry resources, including standard-specific guidance for FAC-008. He also contributed nationally as Vice Chair of the Edison Electric Institute (EEI) Reliability Technical Committee (RTC), helping to shape industry responses to new and emerging NERC standards.

In addition to his compliance expertise, Terry is a seasoned engineer with deep technical knowledge in transmission planning, dynamic stability, and wind integration studies. His combination of regulatory insight and engineering depth makes him a valuable resource for our clients as they navigate the ever-evolving reliability landscape.

We’re thrilled to have Terry on board and look forward to the contributions he will make to our team and clients. Please join us in giving him a warm welcome!

GridSME Welcomes Barry Kuehnle to the team!

Fri, 02 May 2025 14:53:42 GMT

Welcome Barry Kuehnle to GridSME!

Please join us in welcoming Barry Kuehnle to the GridSME team as an Independent Consultant!

Barry brings nearly 30 years of expertise in energy infrastructure, cybersecurity, and regulatory compliance. A seasoned engineer and leader, he is highly experienced in NERC CIP Reliability Standards, industrial control systems security, and fostering cross-sector collaboration.

He joins us following a distinguished 15-year career at FERC, where he played a pivotal role in national cybersecurity strategy and regulatory oversight. With a background spanning the military, government, and private sectors, Barry’s insight will be a tremendous asset to our clients and team.

Welcome to GridSME, Barry — we’re excited to have you on board!

GridSME Welcomes Nathan Droivold to the team!

Tue, 22 Apr 2025 14:56:08 GMT

Welcome Nathan Droivold to GridSME!

We’re thrilled to welcome Nathan Droivold to GridSME as a Project Manager on our Compliance team!

Nathan brings over eight years of experience managing hydroelectric and civil infrastructure projects. With expertise in scope development, project analysis, contract negotiation, and team leadership, he has a strong track record of delivering successful projects from start to finish.

Known for his collaborative mindset and attention to detail, Nathan excels at guiding teams, engaging stakeholders, and navigating complex project landscapes. His skills and dedication make him a fantastic addition to the GridSME team.

Welcome aboard, Nathan — we’re excited to have you with us!

Happy 14th Anniversary GridSME!

Tue, 01 Apr 2025 18:48:06 GMT

Celebrating 14 Years of GridSME!

Fourteen years ago, GridSME wasn’t much more than a wild idea—one that our founders, Eric Whitley and Lonnie Rush, decided to bet on. The idea? That the best experts in the industry deserved a great home. In the right environment, they could come together to solve the power grid’s toughest challenges.

They set out to build something different—not just another consulting firm, but a place where people love their work, clients get real, practical solutions, and collaboration thrives.

Fast forward to today, and that idea has grown into something bigger than any of us could have imagined: a thriving community of problem-solvers, innovators, and, let’s be honest, some of the best humans you’ll ever meet.

From the beginning, Eric took inspiration from Patagonia’s culture, where people are trusted to manage their own time, do great work, and still have room for the things that make life meaningful. (We don’t have an official "go surfing" policy yet, but hey, maybe for Year 15?) As Patagonia’s founder, Yvon Chouinard, said:

"The sooner a company tries to be what it is not, the sooner it tries to ‘have it all,’ the sooner it will die."

That’s why, from day one, GridSME has focused on staying true to who we are—a SME-first company that prioritizes expertise, trust, and humility over chasing every shiny opportunity.

Carlyn Marsh, our Finance Manager, highlights the incredible freedom we have to grow and explore in ways that keep us adaptable and relevant:

"There is a lot of freedom based on trusting each SME to find where they do their best work. Once you come in, your initial role or team is not static. As you become curious about different technologies, systems, or projects, you’re encouraged to explore and learn from others. The world around us is changing quickly, and knowing you work somewhere that fosters creativity, continuous learning, and personal growth means you not only feel confident about your future here, but you also know that GridSME is evolving in ways that will keep both the company and our SMEs relevant for years to come."

Curiosity and continuous learning are what keep both a company and its people thriving in an ever-changing world. Like the principles in Let My People Go Surfing, we know that a culture of creativity and personal growth not only makes us better professionals but also ensures that GridSME remains an exciting, relevant, and sustainable place to work. We encourage each other to explore, learn, and carve our own paths within the work we do.

GridSME is more than just a workplace—it’s a community where meaningful, exciting work happens alongside great people. Here, leadership isn’t just a title; it’s a commitmen t to serving others. We believe true leadership means leading by example and supporting those around us:

"If they work for you, you work for them."

As Sara Rhodes, our Vice President of Business Development and Accoun t Management, puts it:

"It's refreshing to work for a company that isn't afraid to say no to opportunities outside of our core strengths. By saying no, we ensure our SMEs work on projects they actually enjoy and feel confident in. GridSME truly puts SMEs first—it’s leadership that walks the walk and talks the talk. This is hands down the best job I’ve ever had, and honestly, I hope I work here forever."

At the heart of it all, GridSME has always been about the people—our SMEs, our clients, and the many partners who make this community what it is. And speaking of people, we’ve welcomed even more brilliant minds this year! But what hasn’t changed is our commitment to bringing in Humble, Hungry, and Smart individuals who want to solve real problems and push the boundaries of what’s possible.

Fourteen years in, and as John Franzino often says, “We’re just getting started.” The grid isn’t getting any less complex, and we’re growing to meet that challenge—all while staying true to the principles that got us here.

Our 50+ year vision? To be the best home for the best SMEs in the industry. Because when you put great people in the right environment, they’ll take great care of our clients—and each other.

To everyone who has been part of this journey—thank you. Here’s to 14 years of problem-solving, late-night brainstorming, and just the right amount of nerdy grid jokes. And here’s to the next chapter—because the best is yet to come.

With the way we’re growing, working here might just be the most renewable resource we have.⚡♻️ Badum tss! ��

Happy 14th Anniversary, GridSME! And a huge thank you to Eric and Lonnie for taking that leap 14 years ago.

GridSME Welcomes Sofia Marcoccia to the team!

Mon, 31 Mar 2025 18:20:19 GMT

Welcoming Sofia Marcoccia to GridSME!

We’re excited to introduce Sofia Marcoccia as the newest member of GridSME’s Business Development team!

Meet Sofia – Our New Proposal Coordinator

Sofia joins us as a Proposal Coordinator, bringing valuable experience in administrative and business operations. She has a strong background in organization, scheduling, and process management, making her a key asset in ensuring seamless proposal development and execution.

A Detail-Oriented and Collaborative Team Player

Sofia is highly detail-oriented, a quick learner, and passionate about problem-solving and continuous improvement. Her ability to adapt to new challenges, stay organized, and collaborate across teams makes her an excellent addition to our growing Business Development group.

Looking Ahead

As we continue to expand our capabilities, we are thrilled to have Sofia on board to help streamline processes, enhance efficiency, and contribute to our mission of delivering outstanding solutions for our clients.

Please join us in welcoming Sofia Marcoccia to the GridSME family! We look forward to her impact and the great work she will bring to our team.

GridSME Welcomes Sherida Alona to the team!

Mon, 31 Mar 2025 18:18:46 GMT

�� Welcome to the Team, Sherida Alona! ��

We’re excited to welcome Sherida Alona to GridSME as a Project Manager on our Grid Integration Team! ��

Sherida brings an impressive depth of experience managing renewable resource projects, with a strong foundation in project scope development, budget management, and the coordination of complex schedules, resources, and risks. With a focus on delivery and accountability, Sherida has successfully led multidisciplinary teams through every stage of the project lifecycle—from system design and development to implementation and reporting.

What sets Sherida apart is her collaborative leadership style. She has a proven talent for aligning internal technical teams, contractors, and external partners to keep projects moving forward, even in fast-paced and evolving environments. Her ability to manage multiple concurrent projects while adapting to shifting priorities makes her a valuable asset to our team and clients alike.

We’re confident that Sherida’s proactive approach, technical expertise, and dedication to excellence will strengthen our project delivery and enhance the value we bring to our clients.

Please join us in giving a warm GridSME welcome to Sherida! We’re thrilled to have her on board and can’t wait to see all the great things we’ll accomplish together.

Upcoming NERC Level 3 Alert – Essential Updates for Inverter-Based Resource (IBR) Operations and Compliance

Fri, 08 Nov 2024 18:05:53 GMT

Upcoming NERC Alert for Generator Owners (GO)

GridSME is hoping to inform Generator Owners (GOs) of significant updates outlined in the draft release of the NERC Level 3 Alert: Essential Updates for Inverter-Based Resource (IBR) Operations and Compliance. These new recommendations, aimed at Transmission Owners (TOs), Transmission Planners (TPs), and Generator Owners (GOs), will very likely impact your IBR operations. Maintaining compliance and operational integrity remains essential, and these developments are designed to help align your operations with evolving standards and bolster grid reliability.

Key Areas of Focus for Other Groups Impacting Inverter-Based Generators:

Enhanced Interconnection and Reliability Planning Requirements
TOs are advised to incorporate IBR-specific performance standards into interconnection and planning processes, including:
Reactive Power Controls : Defined parameters for voltage control modes, deadbands, droop settings, and reactive power limits.
Frequency Response Controls : Detailed requirements for frequency control settings, including deadbands and droop.
Disturbance Ride-Through Capabilities : Specific criteria for response during grid disturbances.
Post-Disturbance Recovery : Specifications for recovery speed and magnitude of power and voltage stabilization.
Performance-Based Modeling Enhancements
Emphasis is being placed on high-fidelity modeling to ensure that simulations accurately reflect real-world conditions. This may require validation to confirm that installed IBRs align with updated models.
Increased Accountability in Model Validation and Documentation
Generator Owners should verify that all IBR installations align with models used in compliance studies. Accurate documentation and verification of equipment and control representations will be essential for compliance audits and maintaining operational efficiency.
Improved Change Management Protocols
All modifications to IBR settings or configurations must be promptly reflected in models and documentation. Establishing robust change management protocols will help prevent potential compliance issues.
Proactive Reporting and Model Verification
GOs will need to conduct periodic performance tests, provide validation reports, and ensure that models align with real-world performance. Working closely with TPs, PCs, and manufacturers will support accurate modeling and regulatory compliance.

Key Areas of Focus for Generator Owners as Outlined by NERC:

Model Accuracy and High-Fidelity Representation
Ensure that models submitted to TPs and PCs accurately reflect IBR performance. This includes:
Requesting validation and benchmarking reports from manufacturers, comparing EMT model performance against actual performance, and explaining any discrepancies.
Aligning models with PSPD and EMT standards for consistency.
Design Compliance
Confirm that installed equipment matches studied models and meets performance requirements. Models should have parameters aligned with product configurations for reliability.
Change Management and Updates
Implement processes to track changes made to IBR models or equipment, ensuring updates are accurately reflected and communicated to TPs and PCs as needed.
Information Organization and Retention
Organize and retain critical IBR information for easy access and review. This includes:

Equipment make, model, firmware, and power capabilities.
Voltage and frequency ride-through settings and protection details.
Plant-level control modes and related parameters.

Summing Things Up

The upcoming NERC Level 3 Alert, expected to be released in Q2 2025, includes actions for Transmission Planners (TPs) and Planning Coordinators (PCs) that could impact certain Generator Owners (GOs). While many of these activities may already align with current practices and Standards, additional measures may be required by GOs to meet the updated requirements set by your TP and PC. This could involve conducting further MOD tests and obtaining more detailed information from your Power Plant Controller and inverter manufacturers. Ensuring your plants’ modeling data accurately reflects actual performance is essential, which may necessitate additional testing to verify model precision. Further action by GOs is likely to be required in late 2025 and beyond.

These updates are intended to strengthen grid reliability, enhance system resilience, and support your operations in meeting regulatory expectations. We are here to help with any questions or preparations needed for implementation.

GridSME Welcomes Casey James to the team!

Mon, 04 Nov 2024 19:01:13 GMT

Welcome Casey James: Our New Senior Meter Engineer at GridSME

We are thrilled to announce that Casey James has joined the GridSME team as our Senior Meter Engineer! With over seven years of experience in metering engineering and management, Casey brings a wealth of expertise to our clients, supporting their needs in large-scale energy projects, regulatory compliance, and advanced metering solutions.

Casey holds a B.S. in Electrical and Electronic Engineering, specializing in Power from California State University, Sacramento, and has built a reputation as an expert in controls and metering integration, battery energy storage systems, and both retail and wholesale metering. His skills also extend to consulting on metering regulations on a national level, where he has guided critical stakeholders and driven innovation in metering standards for the evolving power sector.

In previous roles, Casey has led teams of engineers and technicians across California, establishing best practices, training programs, and compliance workflows for efficient, accurate project delivery. He has been instrumental in developing metering methodologies for some of the largest solar and battery energy projects in the country and has substantial experience with CAISO-compliant inspections, SCADA implementations, and programming complex metering algorithms.

At GridSME, Casey’s technical acumen and leadership will be invaluable as he works to deliver precise, reliable, and compliant metering solutions for our clients. We are excited to have him on board to help advance our mission and further support our clients in the energy industry.

Please join us in welcoming Casey to the GridSME family!

GO-IBR Update: Upcoming New Standard PRC-030-1

Thu, 05 Sep 2024 21:43:02 GMT

Upcoming New Standard: PRC-030-1 Unexpected
Inverter-Based Resource Event Mitigation

Applicable to NERC Generator Owner (GO) and Generator Owner-Inverter-Based Resource (GO-IBR) registered resources. For information on the upcoming NERC GO-IBR registration and category 1 and 2 definitions, see this link .

GO-IBR resources are defined as Non-BES Inverter-Based Resources that either have or contribute to an aggregate nameplate capacity of greater than or equal to 20 MVA, connected through a system designed primarily for delivering such capacity to a common point of connection at a voltage greater than or equal to 60 kV.

PRC-030-1 will have five (5) main actions that a GO must take:

1. Implement a Documented Process (R1):

Identify any complete facility loss of output or changes in Real Power output of at least 20 MW (and at least 10% of the plant’s gross nameplate rating) within a 4-second period.
Exclusions: Changes caused by intermittent energy sources, planned outages, or system misoperations analyzed under PRC-004.

2. Analysis of Power Changes (R2):

Within 90 calendar days of a real power change event (or upon request), analyze the facility’s performance.
The analysis should include:
Root cause determination.
Documentation of ride-through and reactive power response.
Assessment of performance issues.
Applicability of findings to other Inverter-Based Resource facilities.
Provide the analysis results upon request to relevant entities (e.g., Reliability Coordinator, Balancing Authority).

3. Develop a Corrective Action Plan (R3):

If performance issues are identified, develop a Corrective Action Plan (CAP) within 60 calendar days, or provide technical justification if no corrective actions are needed.
Transmit the CAP or justification to relevant authorities (e.g., Reliability Coordinator).

4. Implementation of Corrective Actions (R4):

Implement the CAP and notify relevant authorities if any updates or changes occur to the CAP or its timetable.
Document completion of the CAP once resolved.

5. Compliance Monitoring:

Retain records for compliance audits for up to 36 calendar months after each requirement completion.

These steps aim to ensure that the GO maintains reliable operations and takes appropriate actions when unexpected inverter-based resource events occur.

To analyze the data, it first must be collected at a 4-second scan rate and preserved for 36 months. The data must include the following:

status points.
protective relays status, power plant control alarms, inverter alarms.
Disturbance Monitoring points (where available).
Analog points:
Inverter Watts & Vars
Reactive resource Watts and Vars

Analysis would include determining if the plant was responding to a disturbance on the transmission system or if the disturbance was internal.

For more information or to discuss your project with us, contact us at bdgroup@gridsme.com

Understanding the NERC Standards Development for Category 2 Inverter-Based Resources (IBR)

Thu, 08 Aug 2024 16:35:15 GMT

Understanding the NERC Standards Development for Category 2 Inverter-Based Resources (IBR)

What Happened?

On July 24, 2024, the NERC (North American Electric Reliability Corporation) provided updates to the ORCS (Organization Registration and Certification Subcommittee) to Standards Development for Category 2 IBR. If you missed our previous communication defining Category 2 IBRs, click here .

All GO and GOP Standards have been reviewed and placed into one of three blocks for Standards Development. Standard Drafting Team nominations have been submitted and Drafting Teams are being developed.

What Do We Recommend Now?

At this time, we recommend planning for GO/GOP IBR assets that meet the new registration criteria to be included on the NERC Registry. NERC will begin registering GO/GOP IBR Category 2 resources and plan to complete registration efforts by May 2026 with required compliance thereafter. We also recommend updating project budgets, if necessary, to account for developing, implementing, and managing compliance programs for GO-IBR assets.

The Three Blocks Explained

B lock One Standards : Minor or No Changes Needed

The Standards placed in Block One are those that are planned for GO-IBR applicability, and which do not require additions or revisions. The NERC Rules of Procedure have been updated to make these Standards applicable to Category 2 IBR.

Some of these standards are already part of ongoing projects, so they might still be updated or retired in the future. If you want to stay up-to-date keep in touch with your GO/GOP Drafting Team representative.

Block Two Standards: Pending Approval and Implementation

The Block Two Standards include updates to existing Standards and the development of new Standards, which are waiting for approval from NERC and FERC (Federal Energy Regulatory Commission). Once approved, there will be specific implementation plans for Category 1 and Category 2 IBRs.

Specific implementation plans are being prepared for each of these new standards. For example the implementation plan for PRC-024 and PRC -029 can be found at this link: Implementation Plan PRC -024 and PRC -029

Block Three Standards: Potential Modifications

Block Three Standards are those that could still be modified for Category 2 IBRs. The drafting teams will discuss the risk for Category 2 IBRs and decide on any necessary modifications.

What Next?

Stay Informed: Drafting team nominations have been submitted and teams are currently being formed. Be sure to stay in contact with your GO/GOP representative to keep up with the latest changes.
Stay informed through candidate outreach and education opportunities.
Review Implementation Plans: For Standards in Block Two, check the NERC website for implementation plans and effective dates.

By understanding these updates, you can better prepare for changes in the NERC Reliability Standards and ensure compliance with NERC requirements for Category 2 IBRs.

Looking for more learning opportunities for you and your team? Click Here to Learn More about our GridU Live event this fall!

GridU Live!

Fri, 28 Jun 2024 23:00:51 GMT

GridU Live this October!

�� Join us for GridU Live this October—in person or virtually!

��️ Dates: October 28th - 30th, 2024
�� Location: Lake Natoma Inn, Folsom, CA

Seats are filling up fast, and the event is just 4 months away! You can choose to attend the full event or specific days, such as Day 2 with focused training topics like requirements for the CAISO NRI process, Bucket 1-6 Submittals, and Metering 101.

�� Dive deep into industry insights and best practices with our expert speakers:
- John Franzino
- Taylor McClain
- Kelsey Gormley
- Kaylie Hague
- Jason Miller
- Ben Smith
- Pat McCarthy

�� Agenda Highlights:

�� Monday, October 28th:
- Preliminary Studies and Interconnection Best Practices
- What’s Next? Overview of common changes to the interconnection process

�� Tuesday, October 29th:
- CAISO NRI Overview: Review of requirements for the CAISO NRI process, including interconnection agreements and UAA setup.
- Bucket 1-6 Submittals: Overview of the full network model build, sync approval process, CAISO P2P testing, and more.
- Metering 101: Good utility metering practices, shared facilities/requirements, and key contacts.

�� Wednesday, October 30th:
- NERC 101 and Cybersecurity
- NERC GO and GOP Implementation, Managed Compliance Services
- Model Validation

Click the link below to learn more about each day's training and the exciting topics our SMEs will be leading: https://www.gridsme.com/GridULive2024

➡️ Secure your spot today!

�� For cancellation or rescheduling inquiries, contact us at training@gridsme.com or call (916)-800-4545.

�� Traveling to Folsom? Check out our travel tips!

We’re excited to welcome you to GridU Live for an enriching learning experience! We look forward to seeing both familiar and new faces. Join us and be part of this incredible event!

NERC Alert!

Thu, 06 Jun 2024 21:20:17 GMT

NERC Alert: Inverter-Based Resource Model Quality Deficiencies

NERC has released a crucial alert addressing significant deficiencies in the modeling and study practices of inverter-based resources (IBR). This comes after analyzing 10 large-scale disturbances since 2016, resulting in nearly 15,000 MW of unexpected IBR output reduction, predominantly occurring between 2020 and 2024. Reporting of these efforts is required by September 2, 2024.

Scroll to read the full NERC Alert Article.

Key Points:

1) Modeling Deficiencies: Poor modeling practices have been identified as a major contributing factor to these disturbances. Accurate and detailed dynamic models are essential for reliable bulk power system (BPS) operation.

2) Recommendations for Improvement:

Model Validation: Models should be validated at both the inverter and plant levels, ensuring they accurately reflect in-service performance.
Lifecycle Updates: Continuous updates and validations of models throughout the lifecycle of IBR plants are necessary.
Standard and Equipment-Specific Models: Both standard library and equipment-specific models should be used, with rigorous testing and documentation to ensure accuracy.

3) Coordination and Reporting: Generator Owners (GOs), Transmission Planners (TPs), and Planning Coordinators (PCs) must collaborate with manufacturers and third-party consultants to address modeling deficiencies. Reporting of these efforts is required by September 2, 2024.

Final Thou ghts:

As the penetration of IBRs increases, the complexity of maintaining BPS reliability grows. NERC's alert underscores the importance of robust modeling practices and continuous validation to prevent future disturbances. Stakeholders are urged to implement these recommendations promptly, ensuring the resilience and stability of our power systems.

Link to full NERC Alert Article: READ HERE

Update Alert - NERC’s New Reliability Standards for Inverter-Based Resources

Wed, 15 May 2024 21:58:17 GMT

A Quick Refresher: NERC’s Work Plan and Initiative to Enhance Grid Reliability

As many are aware, the growing number of inverter-based resources (IBRs) that are connected to the Bulk Power System (BPS) has created reliability concerns which prompted FERC to issue Order 901 in October 2023. FERC Order 901 directed NERC to update its Reliability Standards to include and address IBRs reliability risks in four main areas:

Data Sharing
Model Validation
Planning and Operational Studies
Performance Requirements

In response to FERC Order 901, NERC released a work plan in January 2024, that outlines the next steps in identifying and registering owners and operators of unregistered IBRs, addressing the main reliability risks, and implementation timelines. The plan involves revising NERC’s Registration Program to include new criteria for IBR owners and operators, ensuring compliance with applicable Reliability Standards.

The proposed revisions, detailed in NERC’s draft Rules of Procedure, aim to accommodate unregistered IBRs and establish Category 2 Generator Owners and Operators. More on Category 1 versus Category 2 below. Through a series of milestones, NERC plans to identify, assess, and register these generators to bolster grid reliability by early 2026.

Upcoming NERC Compliance Certification Committee (CCC) Meetings:

For those interested in participating in these discussions, here are the dates for the upcoming Compliance and Certification Committee (CCC) meetings in 2024:

July 23-25: Folsom, CA (California ISO – CAISO)*
October 15-17: Atlanta, GA (NERC Offices)

*GridSME will be attending the CCC meetings. If you plan to attend the July 23-25 meeting in Folsom, CA, we would love to host you in our office that week (July 23-235). Please reach out to srhodes@gridsme.com or bdgroup@gridsme.com for coordination.

Noteworthy News and Updates

This update is to provide owners and operators with a summary of the latest updates from NERC, as well as links to NERC resources and other helpful information. GridSME also aims to provide guidance on next steps, if any, for owners and operators to take and/or plan for in the coming months.

1) What does the timeline look like and when do I need to take action?

When first announced, NERC identified four (4) key milestones and approximate dates for deliverables, decisions, and implementation of the GO-IBR requirements. In addition to those milestones, there are three (3) Phases that Generator Owners (GO) and Generator Operators (GOP) need to be aware of:

Phase 1, which started in May 2023 and ended in May 2024 included:

Complete Rules of Procedure revisions and approvals
Commence Category 2 GO and GOP candidate outreach and education

Phase 2, which is the current state of the program, spans from May 2024 through May 2025. This Phase includes:

Complete identification of Category 2 GO and GOP candidates
NERC outreach and education to Category 2 GO and GOP candidates

Phase 3 is expected to begin in May 2025 and continue until May 2026. This phase will include:

Registration of Category 2 GO and GOP candidates

Recommended Action: Generator Owners and Generator Operators should expect to begin the registration process for existing, non-registered Category 2 assets starting in May 2025. GridSME highly recommends, whenever possible, starting this process as soon as practicable.

2) What is Category 2 and how do I know if my project is required to register ?

NERC has identified a new definition, Category 2, that outlines the thresholds and project characteristics that will trigger GO-IBR registration. If your project meets the criteria in one of the Categories identified below, it will need to go through the process of registration. The Category 1 and Category 2 terms are defined as:

Category 1:

Category 1 identifies IBRs currently registered today, and meeting NERC GO thresholds of greater than or equal to 75 MVA nameplate rating and interconnected at a voltage greater than or equal to 100kV.

Category 2:

Category 2 is a new term that identifies IBRs not registered today that are greater than or equal to 20 MVA nameplate rating and interconnected at a voltage greater than or equal to 60 kV.

3) Standards Update and Changes Impacting GO-IBR: Click Here

While the specific Standards required for GO-IBR projects have not been officially stated, NERC’s Standard Drafting Team (SDT) has identified currently in progress updates and changes to Standards that will be effective for both Category 1 and Category 2 sites. The Standards summarized below have been identified as IBR/DER-related projects to address FERC Order No. 901:

PRC-028-1: In April 2023, NERC’s (SDT) submitted a revised SAR to create a new Standard (PRC-028-1) for monitoring requirements for BES connected IBRs and Non-BES connected IBRs that either have or will contribute to an aggregate nameplate capacity of greater than or equal to 20 MVA and interconnected at a voltage greater than or equal to 60kV.
Status of Standard: The second 25- day comment period and formal ballot was posted from March 18 through April 11, 2024 with a waiver.
Tentative Deadline for Compliance: Entities shall comply with Requirements R1 through R7 at 50% of their generating plants/Facilities within three (3) calendar years of the effective date of PRC-028-1 and 100% of their generating plants/Facilities by January 1, 2030.

PRC-024-3: The Standards Committee authorized drafting of revisions to PRC-024-3 or replacing the Standard with a performance-based ride-through Standard. FERC Order 901 requires that IBR-related performance requirements for ride-through are completed and filed with FERC by November 4, 2024. The functional entity responsible for assuring acceptable ride-through performance of IBR is the Generator Owner (GO) and Transmission Owner (TO). Applicable Facilities include any IBR that meets NERC registration criteria and are those Facilities consistent with FERC Order No. 901.
Status of Standard: Pending results of comment period and ballot
Tentative Timeline:
Effective date for PRC-024-4 is six (6) months after approval by applicable governmental authority
Effective date for retirement of PRC-024-3 is immediately prior to effective date of version 4
Effective date for PRC-029-1 is six (6) months after approval by applicable governmental authority while requirement R6 is effective another six (6) months after (12 months total following approval)

PRC-030-1: Due to multiple NERC disturbance reports, PRC-030-1 Unexpected Inverter-Based Resource Event Mitigation was developed and the formal comment period and initial ballots for draft one concluded on Thursday, April 18, 2024. The SAR Drafting Team believes this new Standard should be developed and implemented to ensure any unexpected ceasing of current injection (partial or full) is analyzed by the applicable GO and mitigated to the extent possible.
Status of Standard: Pending results of 25-day initial ballot and comment period, which closed on April 18, 2024.
Tentative Deadline for Compliance: PRC-030-1 shall become effective on the first day of the first calendar quarter that is six (6) months after the effective date of the applicable governmental authority’s or NERC Board of Trustees order approving the Standard, or as otherwise provided for by the applicable governmental authority or NERC Board of Trustees.

4) What other Standards should we expect?

GridSME’s team has participated in various committee meetings, and we have been tracking the progress of the new IBR registration initiative since its inception. Our SMEs have provided a speculative summary of the additional Standards that may be applicable to the Category 2 sites, based off of FERC Order 901’s four key areas of risk. Those Standards we anticipate for Category 2 sites include:

CIP-002 – Cyber Security – BES System Categorization
CIP-003 – Cyber Security – Security Management Controls
EOP-004 – Event Reporting
EOP-012 – Extreme Cold Weather Preparedness and Operations
FAC-003 – Transmission Vegetation Management
FAC-008 – Facility Ratings
IRO-010 – Reliability Coordinator Data Specification and Collection
MOD-025 – Verification and Data Reporting of Generator Real and Reactive Power Capability and Synchronous Condenser Reactive Power Capability
MOD-026 – Verification of Models and Data for Generator Excitation Control System or Plant Volt/Var Control Functions
MOD-027 – Verification of Models and Data for Turbine/Governor and Load Control or Active Power/Frequency Control Functions
MOD-032 – Data for Power System Modeling and Analysis
TOP-003 – Operational Reliability Data
VAR-002 – Generator Operation for Maintaining Network Voltage Schedules

5) NERC’s 2024 Q1 Update: Click Here

NERC released a 2024 First Quarter Update, which can be found at the link above. In this update, NERC highlighted key activities that took place. Some of those include:

· NERC Board of Trustees approval of the proposed revisions to the NERC Rules of Procedure in February 2024.

Highlights from the Frequently Asked Questions from NERC’s FAQ Document Link Here :

In the NERC ROP, will the unregistered IBR owners and operators be classified using the current GO and GOP functional entities as defined in the ROP’s Registry Criteria, respectively?

The Category 2 GOs and GOPs will be a new category of GOs and GOPs in the ROP as reflected in the proposed ROP revisions.

What was the technical justification behind NERC’s proposed expansion of the Registry Criteria?

NERC’s analysis of energy data from 2016 to 2021 found that around 14% of certain operational power resources weren’t covered by the NERC Reliability Standards, while only 3% of synchronous capacity wasn’t registered. Check NERC’s filings for more info, including the Quick Reference Guide on Inverter-Based Resource Activities for technical assessments related to integrating these resources and their impact on power system reliability.

What is the Purpose of the IBR Order?

The IBR Order aims to ensure the reliability of the bulk power system by identifying and registering owners and operators of IBRs that have a significant impact on the operation and reliability of the power grid.

What are the Proposed Changes to NERC’s Rules of Procedure (ROP)?

NERC has proposed revisions to its ROP, specifically affecting Appendices 2, 5A, and 5B. These revisions include the addition of Category 2 Generator Owners (GOs) and Generator Operators (GOPs) and other adjustments to accommodate the registration of currently unregistered IBRs.

Why Expand the Registry Criteria?

NERC’s analysis found that a significant portion of operational IBRs were not subject to the NERC Reliability Standards, raising concerns about the reliability of the bulk power system. Hence, the proposed expansion aims to address these reliability risks.

Classification of Unregistered IBR Owners and Operators:

Owners and operators of currently unregistered IBRs with aggregate nameplate capacities of 20 MVA or more, delivering such capacity at 60 kV or higher, will fall under Category 2 GOs and GOPs in the revised ROP.

Looking for more learning opportunities for you and your team? Click Here to Learn More about our GridU Live! Event this Fall.

Unlocking California's Renewable Energy Future: Insights from GridSME's Subject Matter Experts

Thu, 02 May 2024 15:50:32 GMT

Insights from GridSME: California's Renewable Energy Roadmap

GridSME's Subject Matter Experts, Gary Brown and Lowell Watros, contributed valuable insights to this article for Reuters. Their expertise helped provide information and analysis on California's latest grid plan, particularly concerning grid improvements, renewable energy projects, and an expected surge in solar and storage projects. With their input, the article offers a comprehensive understanding of the developments in California's energy landscape and the implications for the renewable energy sector. Below are some of the key insights and takeaways from the article.

California's latest grid plan aims to intensify competition and streamline renewable energy projects. It proposes investing $6.1 billion in 26 grid improvements by 2035, focusing on solar and battery storage installations. The plan aims to support 38 GW of new solar capacity, particularly in designated zones like the Westlands area and regions in southern California, Nevada, and Arizona. Detailed zonal information provided in the plan helps reduce speculative projects, improving the likelihood of project completion. California's goal is to achieve 100% zero-carbon power by 2045, necessitating substantial grid upgrades and additional capacity to support electrification and low-carbon generation. Major transmission lines will be built to deliver power from offshore wind projects, totaling 4.7 GW. In addition to offshore wind, the plan includes additional in-state generation and out-of-state imports of wind power. There is a notable surge in standalone battery storage, supported by tax credits, with 6 GW currently operational and 21 GW in development. However, challenges such as permitting delays and community opposition may hinder project timelines. Despite these risks, the plan signals a significant shift towards renewable energy and storage in California's energy landscape.

Despite the challenges ahead, California's ambitious grid plan signifies a transformative shift towards renewable energy and storage. With strategic investments, comprehensive planning, and the expertise of professionals like Gary Brown and Lowell Watros, the state is poised to lead the way in sustainable energy practices. As the plan unfolds, it will not only shape California's energy future but also serve as a model for other regions striving to achieve carbon neutrality and embrace renewable technologies.

Read the Reuters article here.

NERC Alert!

Tue, 30 Apr 2024 22:00:17 GMT

�� NERC Alert: Assessing 6 GHz Communication Impact on Electric Industry

NERC has issued a Level 2 Alert concerning 6 GHz Communication Penetration in the Electric Industry, targeting Distribution Providers (DP), Distribution Provider UFLS-Only (DP-UFLS), Generator Owners (GO), and Transmission Owners (TO). The alert aims to evaluate reliance on 6 GHz technology and potential interference severity. Respondents must address a series of questions by July 8, 2024, to assess the situation comprehensively. Although only registered entities can respond directly, the alert is publicly available. Action items include acknowledging the alert and completing the questionnaire.

Recommendations include identifying critical circuits and conducting baseline performance tests. It's crucial to note that these recommendations are distinct from requirements, as clarified by NERC. This alert underscores the necessity of assessing 6 GHz communication's impact on industry reliability and security. Stakeholders should stay informed and promptly address the alert's requirements.

For further details, visit NERC's website: Link .

See our LinkedIn post about the NERC Alert: here .

GridSME Welcomes Alex Minjarez to the team!

Mon, 27 Nov 2023 22:55:25 GMT

Welcome Alix Minjarez to GridSME's Compliance Team!

Please help us welcome Alix Minjarez as a Compliance Analyst at GridSME! Hailing from Lee's Summit, Missouri, Alix brings a wealth of expertise in contracts and proposals. Her proficiency in navigating the complexities of contractual processes, coupled with a strong commitment to accuracy and compliance, positions her as a valuable asset to our team. With a proven track record and prior leadership experience as a Contract Department Manager, Alix is well-prepared to contribute to our mission of ensuring the reliability and integrity of the electrical grid.

Alix's background in efficiently managing contractual intricacies aligns seamlessly with the collaborative and detail-oriented environment at GridSME. We look forward to leveraging her skills and commitment to excellence as we continue to advance our initiatives in maintaining the highest standards of compliance. Welcome to the team, Alix!

GridSME Welcomes Lucy Schmidt to the team!

Mon, 27 Nov 2023 22:27:13 GMT

Welcoming Lucy Schmidt to GridSME's Compliance Team

We're thrilled to welcome Lucy Schmidt to GridSME's Compliance team. With a background in political campaigns and a strong commitment to compliance, Lucy's meticulous approach and dedication to accuracy make her an ideal addition to our collaborative environment. Lucy, a graduate of the University of Mississippi School of Law, brings versatility and expertise, honed through roles as an Election Worker and Paralegal.

Based in Meridian, Mississippi, Lucy is set to contribute to strengthening our compliance initiatives, including projects with Generator Owner (GO) and Low Impact Generator Operator (GOP) implementation. As she joins our team, we look forward to Lucy's positive impact on our mission of ensuring the reliability and integrity of the electrical grid. Welcome, Lucy!

GridSME is excited to announce three promotions within the Compliance Team

Tue, 07 Nov 2023 18:38:41 GMT

GridSME is proud to announce some exciting developments within its Compliance Team. Three dedicated team members have been promoted to new positions, and their contributions are set to make a significant impact on the organization's pursuit of excellence in compliance services.

Kim Van Brimer, who has been promoted to Manager of Compliance Administrative Services. In her new role, Kim will play a crucial part in supporting the compliance staff with various administrative tasks. Her responsibilities encompass Document Control, SharePoint Administration, Project Management, Procedural Documentation, and enhancing the overall client experience by delivering high-quality services. Kim's promotion signals a strong commitment to ensuring efficiency and seamless operations within the Compliance Department.

Kaylie Hague, who has been promoted to Compliance Implementation Coordinator. Kaylie is set to be a key figure in strengthening GridSME's Generator Owner (GO) and Low Impact Generator Operator (GOP) implementation program. Her technical expertise and proactive approach will play a pivotal role in helping clients successfully navigate the complex landscape of NERC compliance. Her promotion reflects GridSME's dedication to offering top-notch support for clients in the renewable energy industry.

Nick Barse, who has been promoted to Manager of Managed Compliance Services (MCS). Nick's responsibilities extend across the MCS program, which encompasses various compliance programs, including those related to Critical Infrastructure Protection (CIP) and the new GO/GOP Inverter Based Resources (IBR) initiative. His leadership and expertise will be instrumental in the success of these programs, ensuring GridSME continues to provide outstanding compliance services.

These promotions are a testament to GridSME's commitment to excellence and efficiency in compliance services. They are not only a well-deserved recognition of the skills and dedication of these team members but also a vital step towards further enhancing the organization's support for the renewable energy industry. Please join us in congratulating Kim, Kaylie, and Nick as they start on these exciting new roles and continue to contribute to GridSME's mission of compliance excellence.

Changes Coming for Inverter-Based Resources (IBR)

Mon, 30 Oct 2023 14:45:49 GMT

In a recent update, the Federal Energy Regulatory Commission (FERC) has mandated the North American Electric Reliability Corporation (NERC) to develop new standards for addressing issues associated with Inverter-Based Resources (IBR). This change primarily focuses on Generator Owners (GO) and Generator Operators (GOP), and on ensuring the reliability and stability of the grid.

Applicability:

The new standards will require Generation Facilities that produce more than 20 MW and interconnect at 60 kV or greater to register as GO-IBR. Additionally, GOPs operating GO-IBR facilities through a control center or a Remote Operating Center (ROC) will need to register as GOP-IBR.

FERC's directive outlines four key areas of focus, including performance requirements, data sharing, model validation, and planning and operational studies. These changes will influence how IBRs collect and share data during system disturbances, affect the interconnection process, and enhance model validation activities. These modifications are expected to be rolled out by specific deadlines, with the aim of bolstering grid stability.

Next Steps:

To stay ahead of the curve and align with FERC's directives, GridSME encourages that owners and operators of GO-IBR sites plan and budget ahead of time. As these changes unfold, GridSME is committed to keeping a close eye on FERC and NERC developments to ensure that our clients are well-prepared for the evolving regulatory landscape if you have any questions please feel free to reach out to our team at bdgroup@gridsme.com or call at (916) 800-4545.

Download our pdf here

GridSME Welcomes David Greene to the Team!

Tue, 03 Oct 2023 15:50:28 GMT

Welcoming David Greene to GridSME!

We are absolutely thrilled to introduce you to the newest member of our Grid Integration family at GridSME, David Greene. With over four decades of dedicated experience in the power industry, David's journey has been nothing short of remarkable. His expertise in DERMS, SCADA, NMS/ADMS, and smart grid technology is the result of a lifelong passion for innovation and excellence.

Our journey with David began three years ago when he first crossed our path, and now, we're delighted to welcome him into a pivotal leadership role as an independent consultant here at GridSME.

A Multifaceted talent

Beyond his impressive professional journey, David has also chosen to call Austin, Texas, home, where he enjoys life with his beloved wife following his well-deserved retirement.

When he's not contributing his incredible expertise to the world of power systems, you might find David exploring his love for photography or tinkering with custom computers. Additionally, his commitment to his community shines through his active role as a deacon, facilitating a small group Bible study, and contributing to the worship arts at his church.

Join us in extending a warm and heartfelt welcome to David Greene, our esteemed independent consultant. With his wealth of knowledge, dedication, and personal touch, Welcome to the team!

GridSME Welcomes Dom Darling to the Team!

Thu, 28 Sep 2023 20:35:19 GMT

Welcoming Dom Darling to GridME!

GridSME is excited to welcome Dom Darling to our Compliance Team. With extensive experience in energy, sustainability, infrastructure, and compliance auditing, Dom brings a wealth of expertise to our team.

Dom's track record of leadership and strong organizational skills have consistently delivered high-quality results. He excels in audit preparation, offers actionable recommendations based on NERC CIP expertise, and has been instrumental in developing risk-based compliance programs. His educational background in communications and computer science, combined with his extensive experience as a Compliance Auditor, including Subject Matter Expert duties for NERC CIP standards, make him a great addition to GridSME.

An Experienced Compliance Authority

With 15 years in the power industry, including over a decade as a dedicated auditor at WECC, Dom's profound knowledge of NERC CIP and CompTIA Security+ certification will greatly benefit our clients involved in CIP low and medium-impact programs. Welcome to the team, Domenic!

GridSME Welcomes Chelsea Scalzo to the team!

Thu, 28 Sep 2023 20:23:11 GMT

Welcoming Chelsea Scalzo to GridSME's Compliance Team

We are excited to welcome Chelsea Scalzo to GridSME as our new Compliance Analyst. Chelsea brings over a decade of experience as an Operations Project Lead in the electric systems industry, making her a valuable addition to our Canadian NERC Compliance team. Her expertise and meticulous attention to detail will undoubtedly bolster our compliance efforts.

A Dedicated Team Player and Compliance Expert

Chelsea is not only a seasoned professional but also a dedicated team player with excellent communication skills. Her commitment to efficiency and compliance align perfectly with our mission. We eagerly anticipate the positive impact Chelsea will have on our team and our continued efforts to ensure the reliability and integrity of the electrical grid. Welcome aboard, Chelsea!

GridSME Welcomes Torri Pugh to the Business Development Team!

Thu, 28 Sep 2023 19:08:19 GMT

Welcoming Torri Pugh to GridSME's Business Development Team

We are thrilled to introduce Torri Pugh, the newest member of GridSME's Business Development team. Torri is a recent graduate from the University of California, Davis, with a Bachelor of Science in Sustainable Environmental Design and a Bachelor of Arts in Spanish, along with a minor in Global Studies. Her passion for sustainability and renewable energy, coupled with her positive attitude, efficient multitasking and attention to detail, make her a valuable addition to our team. Torri will play a pivotal role in proposal coordination, customer relationship management, and marketing/business development, contributing to our commitment to a greener future.

A Bright and Green Future Ahead

With Torri's dedication to sustainability and her enthusiasm for innovation, we are excited to welcome her to the GridSME family. Her unique skill set and commitment to a greener future align wonderfully with our mission. As Torri grows with our dynamic Business Development Team, we look forward to her contributions and the positive impact she will bring to our journey in shaping the future of sustainable energy. Welcome, Torri!

GridSME Welcomes Gavi Dhariwal to the Engineering Team!

srhodes@gridsme.com (Sara Rhodes) — Wed, 26 Jul 2023 19:49:54 GMT

We are pleased to welcome Gavi Dhariwal to GridSME's engineering team.

Previously Gavi was a Teaching Assistant/Tutor at the University of Redlands. He is a math fanatic, which makes him a key addition to the engineering team.

He has participated in Summer Research Programs where he developed the skills to learn and apply new concepts in a limited timeframe. Additionally, his experience at the Budapest Semesters in Mathematics expanded his knowledge of Mathematics even more and furthered his interests in Graph Theory and problem solving.

Gavi's passion for diving deeper into Complex Analysis, Number Theory, Machine Learning, and Non-Euclidean Geometries will allow him to thrive in his Technical Data Analyst role. Gavi has a Bachelor of Science Degree in Mathematics and Computer Science from the University of Redlands.

Welcome to the team, Gavi!

GridSME Welcomes Jacob Wellman to the Team!

srhodes@gridsme.com (Sara Rhodes) — Tue, 18 Jul 2023 20:33:05 GMT

Jacob joins us as a full-time Project Manager on our Grid Integration team and will report to Kelsey Gormley. Jacob comes to us with extensive experience executing projects within the utility space and a passion for learning.

Jacob will assist the team with new and existing client work related to all aspects of the Resource Implementation and Integration process in multiple ISOs; including CAISO, ERCOT, MISO, PJM, SPP, etc. The team is excited to bring Jacob up to speed on managing our grid integration projects from start to finish (e.g., the CAISO New Resource Implementation (NRI) process). He will be performing various portfolio management services for our clients, ensuring project deadlines and milestones are met and the projects comply with ISO and regulatory requirements, in addition to supporting the Grid Integration Practice Area processes - internal administrative, business development, and proposal drafting/processing, and client-serving processes.

Previously, Jacob was a Project Management Supervisor at Nor-Cal Controls, where he was responsible for a portfolio of over $13m of SCADA integration projects for utility-scale solar sites, totaling 2.3 GW of solar generation. Prior to Nor-Cal, Jacob was a Project Manager at Ampirical, managing a multi-million dollar portfolio of Transmission-Line and Substation System Protection engineering projects for California’s largest IOU.

Jacob has obtained a Master of Music, Bassoon Performance from Juilliard. You may be wondering how a Bassoonist turned into a Project Manager. Jacob found his passion for project management and problem-solving while working at a business advisory/consulting firm early in his career. From there, he sought knowledge and exposure to process, planning, scheduling, cost control, account management, and cross-functional team leadership. Jacob obtained his PMP and landed his first role in the Energy Industry in early 2019. He is fascinated by how the bigger picture comes together and thoroughly enjoys the challenge of skill-building to solve complex problems. He has set out on a personal mission to learn as much about the industry overall so he can better understand how everything comes together

GridSME Welcomes Carlyn Marsh to the Team!

srhodes@gridsme.com (Sara Rhodes) — Wed, 21 Jun 2023 20:01:20 GMT

Carlyn Marsh joins GridSME in a Business Analyst role on the CORRE team, where she will be serving both GridSME and GridSecurity. She recently completed her junior year at UC Davis, where she is working on a degree in Managerial Economics. Carlyn will work closely with Matt and other CORRE team members on a number of business management activities, including GridSME and GridSecurity’s accounting, finance, and reporting activities. Carlyn is a problem-solver at heart and loves improving processes. This will be a full-time summer internship position, and we hope Carlyn will stay with GridSME as a part-time employee when she returns to school in September, and then transition into a full-time permanent position after graduation.

Carlyn graduated high school at the age of 16 and took two gap years to experience working full-time with professionals in various industries and organizations. She already has over five years of professional experience working for various organizations in California and Germany, focused on education, agriculture, economic development, and nutrition. Carlyn gained experience in data analysis, economic research and development, fundraising, leadership facilitation, and policy work at those organizations.

GridSME Welcomes Astha Patel to the Compliance Team!

srhodes@gridsme.com (Sara Rhodes) — Wed, 21 Jun 2023 17:24:13 GMT

Astha Patel joins GridSME in a Compliance Administrative Assistant role, where she will be serving the Compliance team. She recently worked as a Compliance and Training Coordinator at Maple Leaf Foods where she gained a wealth of quality assurance/quality control (QA/QC) experience.

Her educational background is in Science Laboratory Technology, and within her work experience, she found a passion for compliance, which drew her attention to our job posting. Astha will be helping the compliance team with a whole host of support tasks, including document flips, evidence reviews, and report preparation.

Astha currently resides in Manitoba, Canada. You will find her cooking, enjoying camping, and exploring the outdoors in her free time.

Reuters Article: California grid plan could offer shorter queues across the Southwest

srhodes@gridsme.com (Sara Rhodes) — Thu, 15 Jun 2023 14:27:49 GMT

California has approved a plan to invest $7.3 billion in building bulk transmission infrastructure to support renewable energy projects in the Southwest region. The plan aims to address connection delays and will facilitate the construction of 17 GW of solar capacity, 8 GW of wind power, and numerous battery storage projects by 2030. The grid operator, CAISO, will prioritize connecting power plants in areas with high solar and wind resources, as well as storage projects near high-load centers in Los Angeles, San Francisco, and San Diego. The plan involves strengthening connections with neighboring states such as Arizona and Nevada to enable increased imports from solar projects in those areas. The development of upfront transmission infrastructure is expected to reduce grid interconnection delays, benefiting renewable energy developers. The plan could serve as a model for other regions in the United States facing similar challenges. The next phase of the plan may include upgrades to accommodate new offshore wind farms along California's northern coast.

To read the full article, follow this link: https://www.reutersevents.com/renewables/solar-pv/california-grid-plan-could-offer-shorter-queues-across-southwest

FERC Approves NERC Proposed IBR Registration Order

srhodes@gridsme.com (Sara Rhodes) — Thu, 25 May 2023 14:21:35 GMT

New IBR Registration Order Affecting IBRs Over 20MVA Nameplate Capacity

On May 18, 2023, the North American Electric Reliability Corporation (NERC) submitted a plan describing how it will identify and register owners and operators of inverter-based resources (IBR) that are connected to the Bulk-Power System but are not currently required to register with NERC. In this filing, which was approved by the Federal Energy Regulatory Commission (FERC), NERC proposed a three-phased approach to identifying and registering certain IBRs within a period of 36 months.

In the next 2-3 years, existing and future IBRs with nameplate capacity greater than 20MVA interconnecting to the Bulk-Power System at voltages above and below 100 kV, and which are currently unregistered with NERC, will be required to register as GO-IBR. NERC clarified the GO-IBR term includes both the owner and operator of IBRs meeting the criteria.

NERC has not released the list of requirements that will be applicable to GO-IBR yet, but we can anticipate a subset of higher risk Standards will be applicable to GO-IBRs. We expect the list of applicable Standards will include certain CIP, FAC, MOD, and PRC Standards, at a minimum.

If you or your asset management team has any questions, or are unsure if your projects will be required to register, please contact us at bdgroup@gridsme.com or 916.800.4545. There are still a lot of questions surrounding this development, but we’re keeping a close eye on this and are here to help navigate another industry change.

To view the FERC order for Docket No. RD22-4-001, click here.

GridSME Welcomes Sarina San Nicolas to the Engineering Team!

srhodes@gridsme.com (Sara Rhodes) — Mon, 01 May 2023 15:30:01 GMT

We are pleased to welcome Sarina San Nicolas to GridSME's engineering team.

Sarina joins us as a technical data analyst to support the engineering team in process improvement, new system implementation, and improving efficiency across the group.

Previously Sarina worked at Amazon, where she pursued her professional career in recruiting and onboarding. While working there, she found a passion for data analytics, creating processes, and establishing systems to gain efficiencies. Sarina has a strong administrative background with SharePoint and Microsoft Office. She enjoys refining processes and creating SOPs, making her a huge asset to our engineering team. She obtained her Bachelor's Degree in Human Resource Management and General Business from Eastern Washington University.

Please join us in welcoming Sarina!

GridSME Is Turning 12!

srhodes@gridsme.com (Sara Rhodes) — Thu, 30 Mar 2023 19:38:57 GMT

From Seed to Vine, GridSME Turns 12 on April 1

The power industry has made significant strides since 2011, specifically in the renewable space with advancements in energy storage technology, improvements in solar panel efficiency from around 15% to over 20%, increases in wind turbine generator size from around 2MW to 5MW to now over 10MW, developments in smart grid technology, and advancements in hydrogen fuel cell technology that has improved efficiency and affordability. Renewable project owners, developers, operators, and EPCs have encountered new and unknown challenges and experienced significant regulatory changes, which, as a result, led them to GridSME as their partner to find solutions for those problems. As our clients' continue growing, GridSME will continue expanding our capabilities by investing in our SMEs and opening the door for them to grow their opportunities, knowledge, and expertise.

As we continue on toward our goal of being a 50-year company, we will continue building strong and deep foundations with the people, processes, and technology that make up GridSME. To our SMEs and clients, thank you for joining us on this journey! We are pretty excited about the future we are building together.

This industry is just getting started!

There has never been a more exciting time to be part of the power industry...

Matt Barnes

CEO

"There has never been a more exciting time than right now to be a part of the power industry. Today, many of our clients are well underway in a massive transformation of our world’s electricity generation capabilities. The generation landscape is massively different from what it was 12 years ago, and I can only imagine what it will look like 12 years from now. We’re really excited for the next 12 years and the opportunity to help our clients shape the future."

Lonnie Rush

Co-Founder

"From an idea over coffee to Eric Whitley's kitchen table as our first office, I'm in awe of the GridSME team that has been assembled since 2011. With experts spread out around the world, the GridSME team has never been as deep and talented with hundreds and hundreds of years of industry experience to draw upon. Building a sustainable energy future has never been more important to our country and to the world. Our founding is based on partnering with our clients to help solve the grid's complex and ever-changing challenges. Happy Birthday and congratulations to the GridSME team and thank you to our loyal clients who have joined us on this journey. We're just getting started!"

Eric Whitley

Co-Founder

I’ve now been in the electrical industry for 40 years this March with the last 12 years creating, running and now cheerleading GridSME. In that time I’ve seen so much fundamental change from deregulation in California to the tensions within energy transformation to renewables and an emerging shift in the way we think about energy and other critical infrastructure. What I am so grateful for is the opportunity for our team to be at the forefront of facilitating that change. The best part of my career is in GridSME and GridSecurity, and my hope is that we continue making a difference by enabling and encouraging the transformations ahead of us. Thank you to our staff and to our clients for the journey we are on together and the future (with all its problems to solve) ahead of us.

NERC ALERT - March 14, 2023

srhodes@gridsme.com (Sara Rhodes) — Fri, 17 Mar 2023 17:08:04 GMT

Inverter-Based Resource Performance Issues

On March 14, 2023, NERC issued a Level 2 alert to the industry focused on inverter-based resource performance issues for Generator Owners (GOs).

This alert was issued after NERC analyzed multiple large-scale bulk power system (BPS) disturbances. These disturbances involved the loss of inverter-based resources, specifically solar PV resources. The recommendations by NERC should be reviewed and implemented by GOs of BES solar PV resources, and are highly recommended for owners of all BPS-connected solar PV and battery energy storage systems (BESS).

Included in this alert is a request for a large amount of data that must be provided by June 30, 2023. The requested data will very likely involve the cooperation and participation of your inverter manufacturers.

Click here to view the NERC Alert.

GridSME's NERC Compliance consultants are available to answer any questions or assist in meeting the June 30, 2023 deadline.

Ryan Hancock promoted to Director of Engineering!

Thu, 28 Jul 2022 19:07:55 GMT

We are pleased to announce the promotion of Ryan Hancock from Power Systems Engineer to Director of Engineering. Ryan joined GridSME in 2017 as a Staff Analyst and started getting his hands wet in multiple different projects, including compliance, proposals, and energy storage modeling work. Having an engineering degree from Humboldt State, he was destined to join GridSME’s engineering team, quickly learning the ropes from some of our other stellar engineers.

Ryan has proven himself as a strong engineer and a great team player and we have high hopes for his next opportunities as Director of Engineering.

Please join us in congratulating Ryan!

GridSME welcomes Ana Flores to the team!

Tue, 19 Jul 2022 00:14:58 GMT

Ana brings nearly a decade of power industry experience prior to GridSME. She comes from a long stint at Alliant Energy, a midwestern publicly owned utility, where she supported both their NERC Critical Infrastructure Protection (CIP) program and their IT controls. Ana developed and implemented multiple CIP standards while she was there as well as guided the organization through four successful CIP audits.

At GridSME, Ana serves as a Compliance Program Manager where she supports the development, implementation, and ongoing management of our clients’ NERC Compliance programs. Ana’s CIP experience is a tremendous asset for our clients as they transition towards CIP Medium Impact facilities and control centers!

Please join us in welcoming Ana to the GridSME team!

Kelsey Gormley promoted to Senior Project Manager!

Tue, 12 Apr 2022 22:38:44 GMT

We are pleased to announce the promotion of Kelsey Gormley from Project Manager to Senior Project Manager within the Grid Integration Team. In June of last year, Kelsey joined GridSME and immediately added value. Kelsey brings over ten years of project management experience for large and small capital projects, programs, and services in various settings and industries, including for public utilities and IPPs in the power industry. She is adept at understanding project requirements, monitoring project costs, and progress, and ensuring compliance with all statutory requirements specific to each project.

Kelsey has rapidly grown as a Grid Integration SME – taking on new projects, solving challenging problems for clients, developing processes, compounding her knowledge, and supporting her fellow teammates. Kelsey’s proficient time-management and organizational skills have shined since she arrived. In her new role, Kelsey will continue to serve clients, facilitate the team’s workload, support business development efforts, and train new team members.

Please join us in congratulating Kelsey!

The Reliable Wire: Q4 2021 Edition

Tue, 07 Dec 2021 21:05:09 GMT

GridSME is pleased to present our new, expanded edition of The Reliable Wire for Quarter 4, 2021. The Reliable Wire will be released quarterly in this expanded format, covering a wider range of electric industry topics with expert insight, Q&A, and whitepaper deep dives.

In this edition, we cover:

Summarizing Recent NERC & FERC Regulatory News
Highlighting Innovation: Canadian Solar’s Crimson Storage project
Extreme Cold Weather Grid Operations, Preparedness and Coordination
Enhancing the Grid Security: A Power Players by Origis Conversation
Q&A With The Experts: Diving Into Critical Infrastructure Protection

Please let us know if you want more information on anything contained in this quarter's issue. We appreciate your feedback on The Reliable Wire.

Contact information: customerservice@gridsme.com

Want to receive future Reliable Wire editions in your inbox? Click HERE to subscribe!

Q4 2021 NERC & FERC Regulatory News

Tue, 07 Dec 2021 20:56:02 GMT

Recent NERC News

NERC and Texas RE published the Odessa Disturbance Report detailing their findings and recommendations of the extreme cold weather event that hit the Texas Interconnection on May 9, 2021. Some of the recommendations listed include making improvements to Generator Interconnection Agreements, making improvements to the standards to address issues with inverter-based resources, and the creation of standards to address performance validations and mitigations.
FERC approved modifications to Cold Weather-Related standards to address extreme cold weather conditions for generating units in response to the findings of the Join Report on the 2018 South Central Cold Weather Event. The modified standards are effective April 1, 2023 and include changes to the following standards: 1) EOP-011-2 (Emergency Preparedness and Operations); 2) IRO-010-4 (Reliability Coordinator Data Specification and Collection), and; 3) TOP-003-5 (Operational Reliability Data).
NERC posted the new Reliability Standard Audit Worksheet (RSAW) for the FAC-008-5- Facility Ratings standard which became effective October 1, 2021.

Recent FERC News

FERC published their annual staff report of lessons learned from CIP reliability audits for 2021. The report is based on findings from site audits, data requests and staff interviews and propose improvements and recommendations for improving the cyber and physical security of BES facilities, systems, and equipment.

Q&A With The Experts: Diving Into Critical Infrastructure Protection

Tue, 07 Dec 2021 20:56:01 GMT

Nick Santora is a certified cybersecurity expert (CISA, CISSP), who spent nearly a decade working for the federal government in critical infrastructure protection before founding Curricula to make security awareness training fun so employees actually learned the skills needed for cybersecurity.

Q: What are some best practices for ensuring organizations are in compliance?

A: When it comes to being in compliance with NERC CIP, there is a lot of ground to cover to meet all the regulations. But these rules were crafted for a reason. Consider for a moment: what is the right order of operations for People, Process, and Technology?

There are so many experts spouting that people are the biggest vulnerability when it comes to meeting compliance requirements but those people have to know what to do. For even the most entry-level employees working in utilities, they’re responsible for protecting the most critical infrastructure by following NERC’s rules. You understand how essential it is for everyone to follow the processes to meet compliance requirements.

And as a certified information security systems auditor, I put on my analyst hat to take a step back and take the time to really analyze these three things — People, Process, and Technology. We hear these terms all the time, but are we sure which order they’re supposed to follow in, especially when it comes to being in compliance with NERC?

Q: Risk assessment always remains an issue. Where do utilities begin here with conducting and implementing these kind of assessments, and how can they ensure it will be satisfactory if/when an auditor ever comes knocking?

A: As a cybersecurity auditor, I built my career around understanding how people play a role in processes and technology when it comes to critical infrastructure protection. In my years of experience, I’ve seen firsthand how these three elements can function well when they all work together (or don’t).

And ultimately, it all comes down to process and how a person should follow an order of operations with information security. Potential security missteps happen because a person wasn’t following a process, or the technology was not in place (or working properly) that was supposed to support those operations. Just look at what happened to Colonial Pipeline.

That’s when an auditor usually steps in to look at the root cause of why this hiccup happened, and it almost always has to do with someone not paying attention or not having the right technology. The organizations that got it right always were always sincerely focused on educating their people and having the right technology in place, not just meeting compliance requirements.

Great organizations implement the motto of people come first, understanding how processes are built with people, and technology is integrated with the process we’ve defined and people we’ve aligned.

Q: How can utilities do better here?

A: This is one of the main reasons you see everyone talking about building a culture of security where their people are trained, then they know what to do to be in compliance with NERC, and have technology in place to support that process of security awareness and threat mitigation.

Higher-ups who understand the importance of security awareness training also recognize the potential for compliance violations, and those are the organizations that often have the least hiccups in their processes, and the least confusion among their people of why they’re doing these things to protect their patients’ information in the first place.

The goal is to get every single employee to understand their role in security. A simple discussion with each department head is a great place to start getting everyone aligned around protecting your organization.

Q: Where are the common missteps related to security and how do you correct?

A: Large enterprise organizations often fumble here because it’s easy to mess up. The bigger your team, the more opportunities for operational inefficiency. If you have a bunch of things in place only to meet compliance and don’t focus on the people involved in helping to meet those standards, there’s a strong likelihood for human error that exposes a vulnerability in your system.

When considering potential pitfalls, sit down with your information security team and various department leaders to review all the facets outlined for security management standards including:

If you look at those areas, their implementation specifications, and find technology that helps you to do these things for certain thresholds, then you can make sure everyone is aligned on what actually needs to be done for security, plus go beyond checking the box for compliance.

Q: How can utilities ensure they get the policies and procedures part of compliance requirements right?

A: Let’s take it back here starting with the need – protecting sensitive information. This is a great example of remembering your ‘why?’ Why is this so important to you, and organization itself? Before you even start, remember the reason, and document the mission you’re on — which in this case, it’s keeping your data safe.

At the end of the day, we have to make sure everything regarding security has a process developed around the routine with specifics. Processes are there to guide us into routine behavior. It’s about an order of operations to follow for even something as simple as setting up a password.

Technology always comes last because if you haven’t nailed the people or the process, the technology implementation isn’t likely to happen or to be successful. You can’t implement a technology without having the process to follow.

To recap these points, it starts with a Process (why you’re doing something to meet requirements), then People (put them in place) as our people are our standard, and then Technology to support the mission and goal. Having a detailed procedure of how to get these things done for compliance will help build a culture around the role all your employees play in security.

Enhancing The Grid Security: An Interview With John Franzino

Tue, 07 Dec 2021 20:56:00 GMT

Intensifying weather events are not the only threats to reliable power delivery; recent high-profile cyberattacks on energy and food infrastructure have exposed the vulnerability of critical networked systems. Following a recent string of cyberattacks, the member nations of the G7 Summit this summer declared a joint effort to address the ransomware crisis and hold member nations accountable. But in the meantime, what can the energy industry do now to protect grid security?

As part of the ongoing Power Players by Origis® podcast series, GridSME CEO John Franzino joined Origis Services Managing Director Michael Eyman to discuss how solar owners and operators can better understand the global security threats facing energy companies, implement fundamental security controls for existing facilities, and incorporate consistent design practices and compliance costs when planning new facilities.

THE THREE BAD ACTORS
During their discussion, Franzino and Eyman addressed three basic categories of cyberattackers. First, individual hackers who disrupt internet-connected resources out of curiosity or fun. Second, criminal organizations who monetize data theft and who may be passively or actively supported by governments. Third, nation state hackers who monitor, expose, and exploit vulnerabilities for geopolitical reasons.

While this third group performs the most sophisticated campaigns of surveillance, espionage, and terrorism, it is in the second category where we are experiencing the largest uptick in cyberattacks. “It’s another business entity,” stressed Franzino. Groups like DarkSide, the hackers responsible for the Colonial Pipeline attack, use sophisticated marketing, research, technology, and customer service to increase profit. “This is called ransomware as a service. . . They have a webpage, or at least they did. . . They have an ethics section about who they’re targeting, who they will not target. What their rules of engagement are.”

The threat doesn’t end there. According to Franzino, energy companies may have to scramble to protect themselves against these agile and innovating groups. “My opinion, we’re 5-10 years behind healthcare and finance industries when it comes to cybersecurity, because, until the advent of ransomware, we weren’t being targeted and beat over the head by the criminal hackers.”

PROTECTING ASSETS AND ACHIEVING NERC CIP COMPLIANCE
“So, as a company in this space, who is managing all these assets [4GW and growing], and for other people out there who are doing the same or who are worried about this, what do you do?” asks Eyman. Franzino has a clear response: “Start with the fundamentals.” For existing facilities, this includes taking an inventory of all internet-accessible resources, no matter how small. Hackers use bots to crawl the internet looking for vulnerabilities constantly, so they’ll find your weaknesses if you don’t first.

Once you’re aware of and tracking all internet-connected resources across an organization, you can apply security best practices such as inventory management, access management, vulnerability management, and patch management. These fundamental controls also share responsibility with operations. All technology needs care and maintenance. Cleaning, repairing, updating, and replacing resources not only boosts operational efficiency but also protects against cyberattacks.

In addition to these suggested best practices, there are also actions that must be taken to be NERC CIP compliant. No matter what kind of company you are—big, small, operator, owner—you have a compliance responsibility when your assets meet certain criteria. As a general rule of thumb, inverter-based resources must register with NERC when their facility has a nameplate rating of 75MVA and interconnecting at 100kV or higher. It’s also crucial to understand that each company must meet compliance for the assets they own: generator owners are responsible for solar facilities, generator operators are responsible for control centers.

REDUCE DESIGN COMPLEXITY
Facilities also have different levels of NERC CIP compliance (low, medium, and high impact) based on size, complexity, and grid context. Franzino explains: “Just to put that in context, in the CIP low impact requirements, there’s about 15 requirements/sub-requirements total, about things that needed to be done, checked off the list, controls implemented. When you go to medium impact, there’s about 190-plus requirements.” That’s a huge jump!

One way that companies can reduce the complexity and cost of both compliance and security is to consider them during planning. Define design criteria upfront, use design templates across facilities, and implement consistent networking. Incorporate consistency into planning, and it will be much easier and faster to inventory, maintain, patch, and secure facilities in the future.

Each company should have in-house security capabilities, but that doesn’t mean you have to go it alone. Michael Eyman, for example, has built both in-house resources at Origis Services and relationships with third-party experts such as GridSME. As Eyman underscored: “Make sure you get the right people in, early in the process, and incorporate those costs into your model.”

CONCLUSION
Security threats–from individuals, criminal groups, or nation-state hackers—are not going anywhere. To protect profitability and the nation’s grid infrastructure, energy companies must adopt certain practices that will allow them to secure resources from known threats and to respond quickly to emerging attacks. It starts by understanding the types of cyberattackers active in the industry, protecting existing facilities, and incorporating consistent design in project pipelines. To read, watch, or listen to Franzino and Eyman’s full discussion, visit episode #2 of Power Players by Origis “Solar Asset Grid Security in an Increasingly Insecure World.”

Extreme Cold Weather Grid Operations, Preparedness, and Coordination

Tue, 07 Dec 2021 20:55:59 GMT

If you’re still reading though the changes approved to NERC Standards EOP-011-2, IRO-010-4, and TOP-003-5 under
Project 2019-06 Cold Weather and planning for their implementation on April 1, 2023, bookmark your place and be advised that the next shoe has dropped at NERC in the effort to increase the Bulk Electric Systems (BES) resiliency during extreme cold weather conditions. Project 2107-07, Extreme Cold Weather Grid Operations, Preparedness, and Coordination was posted on Monday as a new Standards Development Project tasked with addressing the shortcomings noted by FERC in its approval of the Project 2019-06 first generation of cold weather standards approved this past summer.

The stated purpose of this new project is, “To enhance reliability of the BES through improved operations, preparedness, and coordination during extreme weather, as described by the Federal Energy Regulatory Commission (FERC), NERC, and Regional Entity Joint Staff Inquiry into the February 2021 Cold Weather Grid Operations.” The project page can be found HERE.

Standards Authorization Request (SAR) Issued and Open for Comment
The project team has issued a SAR, which opens a formal comment period through December 21, 2021, for industry to submit input on the proposed changes.

The SAR references the report and recommendations issued in response to the February 2021 cold weather event in Texas, as well as other similar grid events going back to the February 2011 event in the Southwest U.S.

There are nine (9) recommendations to be addressed in the development process to support the operation of the BES during cold weather conditions, with six (6) of those recommendations aimed directly at Generator Owners (GO) and Generator Operators (GOP).

GOs are to identify and protect cold-weather-critical components and systems for each generating unit. Cold-weather-critical components and systems are those which are susceptible to freezing or otherwise failing due to cold weather, and which could cause the unit to trip, derate, or fail to start. Implementation Timeframe: Before Winter 2023-2024?
GOs are to design new or retrofit existing generating units to operate to a specified ambient temperature and weather conditions (e.g., wind, freezing precipitation). The specified ambient temperature and weather conditions should be based on available extreme temperature and weather data for the generating unit’s location, and account for the effects of precipitation and accelerated cooling effect of wind. Implementation Timeframe: Before Winter 2023-2024
GOs and GOPs are to conduct annual unit-specific cold weather preparedness plan training. Implementation Timeframe: Before Winter 2022/2023
GOs that experience outages, failures to start, or derates due to freezing are to review the generating unit’s outage, failure to start, or derate and develop and implement a corrective action plan for the identified equipment and evaluate whether the plan applies to similar equipment for its other generating units. Implementation Timeframe: Before Winter 2022/2023
The Reliability Standards should be revised to provide greater specificity about the relative roles of the GOs, GOPs, and Balancing Authorities (BA) in determining the generating unit capacity that can be relied upon during “local forecasted cold weather,” which is language from the revised Reliability Standard TOP-003-5 (effective 4/1/2023), R2.3.
Each GO/GOP should be required to provide the BA with the percentage of the total generating unit capacity that the GO/GOP reasonably believes the BA can rely upon during the “local forecasted cold weather,” including reliability risks related to natural gas fuel contracts.
Each BA should be required to use the data provided by the GO/GOP, combined with its evaluation, based on experience, to calculate the percentage of each individual generating unit’s total capacity that it can rely upon during the “local forecasted cold weather,” and share its calculation with the Reliability Coordinator (RC). Each BA should be required to use that calculation of the percentage of total generating capacity that it can rely upon to “prepare its analysis functions and realtime monitoring,” and to “manage generating resources in its Balancing Authority Area to address . . . fuel supply and inventory concerns” as part of its Capacity and Energy Emergency Operating Plans. Implementation Timeframe: Before Winter 2022/2023
In EOP-011-2, R7.3.2, GOs are to account for the effects of precipitation and accelerated cooling effect of wind when providing temperature data. Implementation Timeframe: Before Winter 2022/2023

Accompanying the SAR is an unofficial comment form where entities are asked to identify which Reliability Standards are appropriate to be updated to include the recommendations, as well as opine on alternatives or more cost-effective options to address the recommendations. Comments will be accepted through 8 p.m. Eastern on 12/21/21.

Entities with generating resources in Texas may want to pay special attention to this project and offer comments urging the drafting team to parallel as closely as possible the ERCOT Winter Weather Readiness Reporting requirements.

GridSME is available to work with entities interested in drafting and submitting comments, which will require registration within the NERC Standards Balloting and Commenting System (SBS).

.

Highlighting Innovation: Canadian Solar’s Crimson Storage Project

Tue, 07 Dec 2021 20:55:53 GMT

Introduction:
Energy production from traditional fossil fuels is slowly killing the planet. Biodiversity is shrinking, climate change looks perilous, and our window to repair the damage is closing. Thankfully there is hope and all of us in the renewable energy sector are doing our best to offset as much carbon emissions as possible through PV, battery storage, and wind project development. As noble as our commitment is, there is still a fiduciary responsibility to develop financially sound projects that can stand the test of time generating power for consumers and investors alike. In concept, this sounds simple, but for anyone who has worked to design, and subsequently operate, a project knows, the reality is far more complicated.

Project development in its complexity has created a multitude of problems that need be solved. One problem we realized at Canadian Solar Inc Asset Management (CSIAM) is that companies who work within silos during development, asset sale, or operations suffer from myopia. Those “silos” operate independently and have little regard for downstream implications of their “cost saving” measures. Given our experience supporting asset managers, we have a unique understanding of implications that early decisions have on projects after a decade or more of operations. This includes lessons learned in construction and operations where project developers focused on capital expenditure (CAPEX) requirements but did little to contemplate operating expenditure (OPEX). That fruit, or more importantly insight realized, correlate directly to the real benefits of a competent asset management team. Therefore, CSIAM created a company-wide feedback loop that began with panel manufacturing and has spread through our owned renewable energy project operations group. Teams with different specialities are coordinating at early stages to optimize development (site, interconnection, technology type, warranty, etc.) while keeping an eye on what pitfalls may present themselves down the road. This early-stage insight has led Canadian Solar Inc. and our partners (GridSME and Axium Infrastructure) to our largest stand-alone storage project, Crimson.

Crimson Overview:
The 350 MW / 1,400 MWh Crimson project will be one of the largest battery energy storage projects in the world when it comes online in summer 2022. Earlier this year, Southern California Edison (SCE) awarded Recurrent Energy, a subsidiary of Canadian Solar, Inc., a long-term energy storage contract for 200 MW / 800 MWh for phase 1 of the Crimson project located in Riverside County, California. The contract includes the stand-alone storage project and is part of reliability procurements directed by the California Public Utilities Commission (“CPUC”). The newly signed agreement with Pacific Gas & Electric (PG&E) is specifically in response to a decision by the CPUC in March 2021 for the California utilities to “take actions to prepare for potential extreme weather in the summers of 2021 and 2022.” This additional energy storage capacity further supports Governor Newsom’s recent emergency proclamation to expedite new clean energy projects in light of the ongoing extreme weather and climate crisis faced by the state.

Additional Benefit Points

Phase I will not require tax equity because it is stand-alone storage and does not qualify for the investment tax credits (ITC)
Cash yield and contracted internal rate of return (IRR) for Phase I is materially higher than comparably sized PV projects and does not require tax equity
Point of Interconnection (POI) well-situated in the CAISO grid connecting California and Arizona providing unique opportunities to capitalize on intra-day energy arbitrage during Phase I’s post-contract period
Project size relative to return on investment (ROI) yield impressive per/acre Crimson is located in Riverside County (CA), one of the highest irradiance areas in the United States

Asset Management Influence:
The strongest benefit realized from our team’s influence in the development stage of the project is the direct correlation between early involvement and operational efficiency. CSIAM prides itself on having streamlined and efficient processes across all divisions, and this is easily realized within the CSIAM team. Inclusion in development stages allows our Asset Managers to be fully prepared for the eventual Operational Phase of the project, while also allowing the team to be fully organized in the following ways.

Software Efficiency: Utilizing software that increases time efficiency is paramount in asset management. At CSIAM, we have selected partnerships with software providers allowing our team to develop and refine workflow processes, which in turn makes our SME’s more efficient and able to provide a more dynamic picture of operations and financial health of the project. Involvement in the development stage of a project allows us to ensure everything is onboarded early. A clean handoff from development to asset management is key to success, and the development stage involvement from our team helps ensure that we have a fully complete and organized data room even before handoff.
Global Workflow Continuity: Another key component to our competence is the workflow processes we have in place. When new software is onboarded, it becomes necessary to refine and restructure certain workflow processes. Once these processes are refined, they can be implemented abroad to make our team more consistent globally. A great team is one that communicates well and has consistent workflow processes globally. This communication allows CSIAM to collaborate and support our clients with less cost relative to time and money.
Foundation For Success: It is our experience that success in terms of asset management is largely dependent on having the proper resources. This encompasses the first two bullet points above, but also includes making sure we have the right headcount on our team to go above and beyond for our clients. We believe that involvement in the development stage helps us to identify any future headcount issues internally, and that the resources needed are available for us to perform high-level asset management services. We also utilize time tracking software internally to keep track of time being spent on each project under management. This software helps us to ensure we are pricing a project accurately and gives us a wholistic view of time spent managing the client.
Technical Preparedness: When involvement begins in the development stage, our group of Asset Managers test operational scenarios based on technical designs shared early in the development cycle. That feedback optimizes the expected CAPEX and OPEX for a proposed project and helps align expected versus actual costs. Performance optimization is a large part of our foundation and having historical knowledge of the development cycle allows us to make more unique recommendations to drive performance and revenue.

While our team is equipped to take over asset management services at any point in the project lifecycle, our presence in the development stage allows us to build our processes early to ensure our project is performing efficiently and profitably. Align that directive with the expected growth of PV installations (fig. 1) and you can begin to realize the benefits of early-stage asset management support can lend significant fidelity to your CAPEX and OPEX
assumptions.

FIGURE 1

The advantages realized by CSIAMs influence on the development of the project correlates directly towards preparation from lessons learned. CSIAM SMEs test operational scenarios based on technical designs shared early in the development cycle. Canadian Solar Inc. will replicate successes from the Crimson project and future designs with benefits passing directly to project investors and, more importantly, to people who consume our power.

Establishing Two Market-Leading Companies with Focused Strategies

Tue, 23 Nov 2021 20:26:04 GMT

Establishing Two Market-Leading Companies with Focused Strategies

GridSME announces that they will be spinning off their GridSecurity division into a standalone company in 2022. The GridSecurity spin-off venture will allow both companies the opportunity to shape their individual business models to better serve new and existing clients in a rapidly changing industry.

GridSecurity

Announcing GridSME’s New CEO

Announcing GridSME’s New VP of Reliability and Compliance

Expectations for the Future

The GridSME and GridSecurity teams will continue a strong partnership as they collectively serve the growing needs of their clients and the power industry. “The caliber of talent and entrepreneurship found in both companies truly blows us away. We have never been more bullish or confident in the direction and future of GridSME and now GridSecurity.” says GridSME’s founders, Eric Whitley and Lonnie Rush, during a GridSME townhall meeting.

As a new or existing client of either company, you can expect the same level of service and innovation that has been synonymous with the GridSME brand and culture over the last decade. Both companies are actively communicating with their clients regarding any necessary modifications or amendments to administrative documents and processes.

GridSME Welcomes Ben Smith to the Reliability and Compliance Team!

Tue, 26 Oct 2021 22:17:12 GMT

Ben joins the Reliability and Compliance team as a Project Manager where he will lead NERC implementation projects, assist with testing projects, and perform analysis in support of these efforts.

Ben comes to GridSME with 15-years of experience in portfolio management, project management, and property management. He has extensive experience managing client deadlines and expectations and has a strong construction background that will be an asset for the R&C team. Ben lives in Folsom and will work from GridSME’s HQ.

Please join us in welcoming Ben to the GridSME and the R&C team!

GridSME Welcomes Charlotte Feildel to our Reliability and Compliance Team!

Tue, 26 Oct 2021 22:07:22 GMT

Charlotte Feildel joins GridSME's Reliability and Compliance team as a Principal Consultant!

Charlotte has over 25 years of experience in the energy industry with 18 years in the electricity industry. As the Manager of Grid Reliability Services for the Alberta Electric System Operator (ISO) she used her passion for risk management to develop, implement and maintain internal compliance programs for both the O&P and CIP standards for the Reliability Coordinator, Balancing Authority, Transmission Operator and Planning Coordinator functions. Charlotte provides her clients with training, documented procedures and a compliance framework which allows each client to focus on their day-to-day operations while meeting standards compliance.

Welcome to the team Charlotte!

The Reliable Wire: Q3 2021 Edition

Thu, 30 Sep 2021 19:13:56 GMT

GridSME is pleased to present our new, expanded edition of The Reliable Wire for Quarter 3, 2021. Going forward, The Reliable Wire will be released quarterly in this expanded format, covering a wider range of electric industry topics with expert insight, Q&A, and whitepaper deep dives.

In this edition, we cover:

Summarizing Recent NERC & FERC Regulatory News
The Multi-Party Dilemma: Securing Distributed Energy Resources
Defining the New Resource Implementation (NRI) process
CIP Low Impact Through the Auditor’s Lens

Please let us know if you want more information on anything contained in this quarter's issue. We appreciate your feedback on The Reliable Wire.
customerservice@gridsme.com

Want to receive future Reliable Wire editions in your inbox? Click HERE to subscribe!

The Multi-Party Dilemma: Securing Distributed Energy Resources

Tue, 21 Sep 2021 19:14:00 GMT

C oncerns regarding climate change, together with the economic opportunities of green energy, are driving the adoption of renewable distributed energy resources (DERs). Yet, due to their distributed nature and multiple involved parties, DER sites can present a large cyberattack surface amid a fast-evolving threat landscape, creating major access management security challenges.

Today, too many DER sites rely on security models that slow innovation and are vulnerable to compromise. As energy companies become a top target for ransomware and other cyberattacks, change is needed.

Traditionally, power producers use perimeter-based and zone/layer-based models to design a security architecture for asset protection. Meanwhile, North American Electric Reliability Corporation (NERC) Critical Infrastructure Protection (CIP) regulations and International Electrotechnical Commission (IEC) 62443 guidelines significantly restrict the number of technicians allowed to access these assets, as all participants are required to meet standards with specific training and background checks to access, operate, and maintain sites. Existing approaches seek to control access to Operational Technology (OT) systems using a complex network architecture that includes numerous firewall rules, jump servers, password vaults, authentication software, Virtual Private Network (VPN) connections, poorly secured machine and desktop access protocols, and multiple interfaces and scripts for managing user access.

This approach can prove vulnerable and costly. As the number of DER sites and participants continues to grow, so does the risk of a significant disruption in power supply. Simply using the same perimeter-based tools and techniques for DERs as were previously in use at single-party large generation locations will become problematic. More parties will require access to significantly more sites as the generation mix evolves. Even though individual DER sites may be smaller and subject to fewer cybersecurity regulations than traditional energy generation facilities, access should still be controlled based on a person’s identity, role, and training as described in many cybersecurity guidelines, including NERC CIP, IEC 62443, and the National Institute of Standards and Technology (NIST) Cybersecurity Framework, to prevent distributed power generation falling victim to a distributed cyberattack.

Independent power producers’ IT and operational organizations spend a significant amount of time and money on not only network and security design and implementation, but also ongoing maintenance to keep security controls updated and patched for protection and compliance needs. And, of course, unguarded open firewall ports, stale, or shared accounts on jump boxes and workstations, VPN-enabled network access, and poorly terminated access-protocols like remote desktop protocol (RDP) and virtual network computing (VNC) all provide entry-points for hackers if not secured.

Using this traditional approach, secure remote access for DERs is both expensive and inefficient; and more importantly, it becomes even more vulnerable to cyberattacks over time.

The Challenge with Multi-Party Access
The frequency of DER workforce changes across multiple parties only exacerbates these issues. Owners, operators, asset managers, vendors, and manufacturers all require differing levels of on-site and remote access over the generation asset’s lifetime. Independent power producers and operators of the assets will need to ensure security compliance that include secure access. Asset management and industrial manufacturers or vendors must ensure all financial and contractual requirements are met, which often include service level agreements or requirements directly attributed to regulatory compliance needs of owners and operators.

With traditional security strategies, operators responsible for controlling remote access must grant broad access and simply trust that users will only access specific sites or specific onsite devices—essentially creating an honor system to avoid enacting complex, overlapping network policies that complicate access altogether.

Using today’s typical tools, operations would be required to set up several different products and configurations to provide multi-party remote access to a single site. Listed below are just some of the typical products to license, configure, and maintain for remote access:

:

VPN software for network authentication and access
Identity access management software for authentication and optional features, i.e., multi-factor authentication (MFA), Single Sign-On
Privileged access control and password vault
Scripts as necessary for device password rotation
Firewalls, associated network and port configurations, i.e., modem IP whitelisting, local (site) active directory, and domain controller set up and management
A physical server, windows accounts to host ICS and device engineering software
File transfer servers and malware scanners to move files (programs, data, etc..) in and out of the DER environments.

These efforts are not trivial for a single site, and the nature of distributed generation is to have many sites under management that require the same level of protection. This makes today’s tools and techniques unscalable for the power industry transformation.

The Impact of Zero Trust & End-to-End Orchestration
Fortunately, the challenges of multi-party access can be managed with zero trust. Solutions like Xage Fabric enable end-to-end orchestration along with centralized policy management and distributed policy enforcement. This makes multi-party access simple to use, administer, and audit while minimizing the attack surface of remote DER operations.

A major principle of zero-trust is for security policies to define what can be done by, and done to, each individual identity. For DERs, identities serve as the core security idea - a user’s identity defines the extent to which a user can traverse from outside the enterprise to the DMZ to the operation, while a device’s identity determines, at the level of the individual device, which users and applications are permitted access. To enjoy the benefits of this granular access management, DERs need an access control solution that embodies the zero-trust principles set forth in NIST SP 800-207, including:

Individual access perimeter based on an identity of each user and an asset, not just party, site, or network segment
Distributed enforcement of access policies with the ability to automate and orchestrate across typical IT, DMZ, and OT network boundaries
Centralized policy management built around identities of people, applications, workstations accounts, and devices that also supports multi-party access
End-to-end orchestrated access control based on authenticated user identities
Ability to orchestrate necessary protocol breaks between zones for compliance

With Xage Fabric’s zero trust remote access solution, independent power producers and operators can reduce costs for not only their power and IT operations but also for vendors and suppliers.

By adopting a solution that can manage identities and access policies in a multi-party environment—using zero-trust principles of “just-in-time” and “just-enough-access” coupled with orchestrated and granular access controls securing interactions to individual assets—power producers can operate and collaborate across many distributed sites with a significant reduction in risk at a much lower cost.

Further, the effects of this security architecture will do more than thwart off cyber threats. Eliminating the attack vectors of shared accounts, VPN connections and open firewall rules will reduce IT, operational, and capital expenses. And as demand for renewable energy continues to climb, the connectivity derived from such granular access controls will offer an essential foundation for innovation and growth.

Defining the New Resource Implementation (NRI) process

Tue, 21 Sep 2021 19:13:58 GMT

Generation resources are the backbone of the electric system, helping the grid meet reliability, sustainability, and cost optimization goals. Frequency regulation in California is chiefly the responsibility of the California Independent System Operator (CAISO), and is accomplished via the following objectives:

Continuously matching generation resources to demand to keep the system’s frequency at 60 hertz.
Assuring an appropriate level of generation reserves exist in the event of a forced outage.
Operating the energy and ancillary services markets to meet reliability at the lowest possible cost.

Each of the above challenges depends on meticulous generation data from each California Generation resource. All new resources are integrated into the CAISO control system via the New Resource Implementation (NRI) process, which enables CAISO to forecast the impact of new resources on the system’s ability to meet demand and economically dispatch energy resources in the market.

The NRI process is comprised of six “buckets” or phases of related and sequenced tasks, which provide CAISO with the information needed to ensure a safe, reliable, and economic integration of each new resource into the grid.

The NRI process relies heavily on a web-based interface known as the Resource Interconnection Management System (RIMS) and the project getting into an appropriate Full Network Model (FNM) Build. The NRI Bucket System is derived from the FNM Build and the resource’s project implementation date. These Bucket timelines and deliverables are set to support the resource’s capability and integration into the market systems within the CAISO.

Although the NRI implementation schedule can vary, CAISO’s current process requires approximately three months, with precise milestones prescribed throughout the process. The earlier buckets are focused on precise data collection and contract negotiation. The first buckets generally require weeks to complete. Later buckets are focused on telemetering and confirming data is a faithful representation of reality. The later buckets generally take days to complete. Below is a summary of those buckets.

Bucket 1:
Focused on planning functions and representing the resource in the CAISO’s Full Network Model.

Bucket 2:
Focused on regulatory contracts. In addition to facilitating Bucket 2, GridSME can advise clients in negotiating required agreements.

Bucket 3:
Focus is validation and preparing the market model for the resource’s participation. These items are the most critical to reach the desired implementation date with the CAISO. Bucket 3 deliverables need careful consideration and planning, and they need to be accepted 30 days in advance of the resource’s estimated commercial operation. GridSME will assure that these critical items are properly submitted.

Bucket 4:
Includes CAISO synchronization approval and the trial operation procedures that need to be followed by the Generation Owner and Scheduling Coordinator. The remaining deliverables in Bucket 5 are the final documentation of meters and RIG prior to requesting the project’s Commercial Operation. The Scheduling Coordinator has some responsibilities in Bucket 5, however, GridSME can expedite bringing your project through this critical period toward commercial operation.

Bucket 5:
includes CAISO synchronization approval and the trial operation procedures that need to be followed by the Generation Owner and Scheduling Coordinator. The remaining deliverables in Bucket 5 are the final documentation of meters and RIG prior to requesting the project’s Commercial Operation. The Scheduling Coordinator has some responsibilities in Bucket 5, however, GridSME can expedite bringing your project through this critical period toward commercial operation.

Bucket 6:
Project close-out with the CAISO. The GridSME team will assure that your project closes-out successfully as an integrated part of the CAISO, assuring a reliable electric supply.

The GridSME NRI team understands the current CAISO NRI process and requirements and has developed a system and process that seamlessly integrates with the CAISO NRI process. These customized systems and processes allow our customers the ability to stay ahead of the timelines that CAISO designates and meet the project’s scheduled availability.

Understanding Your Project’s Objectives
If you are embarking on this NRI journey alone, GridSME recommends you answer the following three questions. This will help your project avoid many of the common pitfalls that lead to deficiencies and costly delays to your project.

What are your project’s critical milestone, timeline, and schedule dates?
What Resource Adequacy (RA) obligations does your project have?
What specific obligations do you have under your power purchase agreement (PPA)?

The Advantages of Hiring a Guide to Navigate the NRI Process
The NRI process is critical for CAISO to ensure grid reliability and optimize the market, but it is also very complex. In total, the NRI process and its six buckets include approximately 50 steps, requirements, or “to-do’s” for the resource owner to accomplish. Each step presents an opportunity to miss a CAISO requirement and put the project’s schedule at risk. An NRI guide brings you not only access to procedural knowledge to avoid the common pitfalls, but also a full understanding of what all process stakeholders require. For example, one principal stakeholder of the process is the generator’s PPA off-taker. A resource can complete the NRI process on time and meet all CAISO requirements, but still fail to meet its RA obligations to its off-taker. Off-takers rely and expect the resource to meet its RA requirements and get its RA attributes in the market on time. To do this, the resource owner or NRI guide must monitor all communications from CAISO and translate that information into updated, useful, and actionable information so that submittals to CAISO are completed accurately and on schedule. The NRI process and other steps to get a resource to COD are interrelated and experience navigating these interrelated processes is key.

GridSME’s NRI Portal
GridSME manages the NRI process, coordinates communications between the parties, and manages all these requirements with its NRI Portal. The GridSME NRI Portal provides our clients with access to a site dedicated to your NRI project, which includes critical dates for submittals that include any reviews necessary to make sure that your documentation is accepted the first time it is submitted to CAISO. This tool avoids rework and reduces the risk of missing project milestones. The GridSME team actively monitors the resource’s NRI progress to assure nothing has been overlooked and to stay ahead of the next steps.

GridSME adds value to our clients’ NRI projects by understanding the data required, the data sources, assessing the quality and suitability of submitted data, requirement deadlines, and how the data should be packaged and submitted to CAISO to assure that documentation is accepted with the least amount of back and forth or rework. The CAISO NRI Process is complex and ever-changing, which is a function of CAISO responding to the grid’s ever-changing needs and demands. Any misstep in the NRI process can result in delays in getting a resource into the market or to COD, which can have material financial impacts for the resource’s owner.

The CAISO’s NRI webpage is located at the URL below:

http://www.caiso.com/participate/Pages/NewResourceImplementation/Default.aspx

The GridSME NRI Team understands there are significant risks to mismanaging the deployment of a new resource. These risks can be financial in nature if contractual deadlines are missed and they can become safety concerns if appropriate technical information is missing or omitted. We are committed to collaborating with our clients to avoid missteps in the NRI process that can negatively impact our clients and/or grid reliability. It can be a huge advantage to have an experienced NRI process guide to manage these risks, allow your team to stay focused and avoid distractions or surprises, and achieve COD on time.

Do you want help help connecting your Project to the grid?

CIP Low Impact Through the Auditor’s Lens

Tue, 21 Sep 2021 19:13:58 GMT

These are genuinely exciting times to be working in the power industry. The volume of new generation and storage resources coming online has been well-publicized. But each new resource also introduces a new risk to the reliability and security of the grid. In WECC and TRE alone, there have been more than 130 new registered Generator Owners (GO) introduced to those Interconnections in the past five years. And we are only getting started, as we expect the next five years to see considerably more resource additions to the grid than the previous five years.

Naturally, with all of the new market entrants comes confusion and anxiety. Digesting and understanding the NERC Reliability Standards is certainly part of that. Two of the Reliability Standards that cause the most confusion and anxiety for new Registered Entities (RE) are CIP-002-5.1a Cyber Security – BES Cyber System Categorization and CIP-003-8, Cyber Security – Security Management Controls. These Reliability Standards require soon-to-be REs to first identify and categorize their BES Cyber Systems, and then implement one or more documented cyber security plan(s) for its BES Cyber Systems. Aside from requiring those plans to contain, at a minimum, certain components, the Standard leaves considerable discretion to the you, the Registered Entity.

The CIP journey begins with CIP-002 and the confusion quickly starts right there. The most common question about CIP-002 is whether the RE needs to generate an inventory of its devices that are part of its BES Cyber System. No, the Standard does not explicitly require an RE with low impact BES Cyber Systems to inventory its devices. But once you consider the objective of the CIP Standards is to identify and protect your critical infrastructure, it is almost impossible to get around inventorying the devices that comprise your BES Cyber System(s). After all, it is very difficult for an auditor to assess the effectiveness of your CIP-003 cyber security plans if you do not have not specifically identified what it is you are protecting. How do you protect what you have not identified? CIP-002 and the device inventory is also where the auditor (e.g., WECC, TRE) will begin its assessment. So, although there is no explicit requirement in CIP-002, we highly recommend REs maintain a current inventory of the devices that comprise its BES Cyber System. Additionally, the Regional Entities (i.e., SERC, WECC, TRE) who you will deal directly with on compliance issues, in many cases are requesting that inventory as part of an initial CIP Self-Certification review which may be conducted any time after registration.

CIP-003 is also a considerable source of confusion for new REs. CIP-003 requires REs to develop and implement cyber security plan(s) for the BES Cyber Systems it identified and categorized in CIP-002. CIP-003 is not prescriptive and NERC is intentional in making it non-prescriptive. There are at least a couple reasons for this. First, NERC acknowledges there are many ways an entity might accomplish the Standard’s objective, which is to protect critical infrastructure from cyber and physical security risks. Also, NERC’s strategy for compliance is not to tell REs that if you do these specific things, you will be secure, NERC’s approach is to define the performance objective that needs to be achieved. As we know, there are no absolutes when it comes to security and risk management.

Given the lack of specificity in the CIP-003 Standard, how does an RE really know what to put in its cyber security plans and if they are compliant? The inherent ambiguity and lack of specificity in the Standard confuses many REs on how to build their cyber security plans. And once those plans are developed and implemented, some REs then struggle to assess whether those plans are compliant and “audit-ready.” In evaluating whether its cyber security plans are sufficient and effective in meeting CIP-003’s objectives and therefore compliant, the RE should first ask the question: does our cyber security plan identify sufficient controls to protect its assets?

For example, to meet the requirement and objective to protect its cyber assets from malicious code introduced by Transient Cyber Assets and Removable Media (TCA/RM), an RE may implement a policy control forbidding the use of any TCA/RMs in its BES Cyber Systems. If the RE were audited, the auditor would assess the effectiveness of this policy control by reviewing evidence that proves the null (i.e., is there evidence that demonstrates no TCA/RMs were plugged into the BES Cyber Systems?).

Another RE may also meet the Standard’s objectives by implementing a policy that allows TCA/RMs use with its BES Cyber Systems and to mitigate the risk of malicious code, all TCA/RMs must first be scanned by a device outside of its BES Cyber Systems. In this case, the auditor would then look at a log of all TCA/RMs plugged into the BES Cyber Systems and evaluate evidence showing that each of those devices were properly scanned and cleared beforehand.

Another key to understanding CIP-002 and CIP-003 is in the Reliability Standard Audit Worksheet (RSAW). When conducting an audit, the auditor uses the RSAW, its questions, and assessment tools to assess the effectiveness of your CIP program. An RE can therefore use an RSAW outside of an audit environment to periodically evaluate its compliance program through the lens of the auditor. This can be an especially valuable tool for a newly registered entity looking to gain assurance that it is on the right track. While the heart of your compliance program should not be the RSAW, it can be a valuable tool an RE can use to periodically evaluate how it is doing and where it may have gaps.

To recap, in CIP-002, NERC requires REs to first identify and categorize its BES Cyber Systems – i.e., what it is you need to protect. Next, NERC requires REs to design and implement controls to meet the security objectives addressed in CIP-003. To demonstrate it has met the requirements of these two Standards, the RE must generate evidence that demonstrates it has identified and categorized what it needs to protect, implemented security plans to protect those assets, and the plan’s controls are effective in meeting the plans’ security objectives.

Do you want Compliance Support?

GridSME Welcomes Nick Barse

Mon, 13 Sep 2021 19:12:57 GMT

GridSME is excited to announce that Nick Barse has joined our Reliability & Compliance team as a Compliance Program Manager.

Nick brings nearly a decade of power industry experience prior to GridSME. He has extensive experience in operations particularly with renewable generation and has experience managing NERC programs, developing policies and procedures, and working closely with industry SME's. Most recently, he worked at EDF Renewables as the Senior Manager for their Medium-Impact Control Center.

At GridSME, Nick supports the development, implementation, and ongoing management of our clients’ NERC Compliance programs.

Please join us in welcoming Nick to GridSME!

Title: Compliance Program Manager

GridSME Welcomes Sara Rhodes

Wed, 28 Jul 2021 19:16:09 GMT

GridSME is excited to announce that Sara Rhodes has joined our Business Development team as the Director of Account Management.

Sara brings over 10 years of experience in sales, marketing, and account management for consulting firms serving the power industry. In her new role, Sara will serve as a primary point of contact for our clients and will help guide them throughout each stage of their project’s lifecycle. Her knack for developing seamless account management processes and her desire to constantly find ways to better serve our clients makes her a welcome addition to the GridSME Business Development team.

Please join us in welcoming Sara to GridSME!

Title: Director of Account Management

GridSME Welcomes Kelsey Gormley

Wed, 21 Jul 2021 19:19:50 GMT

GridSME is excited to announce that Kelsey Gormley has joined our Engineering & Interconnection team as Principal Consultant, Grid Interconnection. Kelsey brings over 10 years of project management experience for both large and small capital projects, programs, and services in a variety of settings and industries, including for public utilities and IPPs in the power industry. In her new role with GridSME, she will work closely with our clients to guide them through the CAISO New Resource Implementation (NRI) process.

Please join us in welcoming Kelsey to the GridSME family!

Title: Principal Consultant, Grid Interconnection

Q3 2021 NERC & FERC Regulatory News

Wed, 30 Jun 2021 19:14:02 GMT

Recent NERC News

Registration for GridSecCon is open. Co-hosted by NERC and Texas RE, GridSecCon will take place virtually between October 19-20. This online conference will include presentations and discussions on emerging cyber threats from leading industry subject matter experts. Register HERE .
On July 19th, ERO Enterprises announced the Release 2 launch of the Align tool and ERO Secure Evidence Locker (SEL) for MRO, NERC and Texas RE. The purpose of the Align project is to use a standardized platform for compliance monitoring and enforcement. Training materials are located HERE .
E-ISAC and Dragos Inc. announced an initiative to increase visibility of emerging cyber security threats affecting the North American electricity industry. Dragos Inc., in collaboration with the Department of Energy, is the creator of Neighborhood Keeper which allows participants to share and receive threat insights.
On July 1, TPL-007-4 – Transmission System Planned Performance for Geomagnetic Disturbance Events Requirements R12 and R13 became effective. The new requirements mandate that responsible entities have a process for collecting Geomagnetic Induced Current (GIC) and geomagnetic field data.

Recent FERC News

NERC, FERC and regional entities published a joint report to evaluate system conditions using real-time data to assess existing and potential operating conditions. Their report provides the assessment methodology and concludes with recommendations for system operators to identify performance metrics and data evaluation procedures for assessing loss of Real-time data. The report applies to Transmission Operators and Reliability Coordinators and is located HERE.

On July 15, FERC announced the approval of an Advanced Notice of Proposed Rulemaking to accept public commentary on improving transmission planning as the U.S. transitions to renewable resources. The Notice seeks to address improvements to transmission infrastructure as well as the needs for customer protection, and coordination between transmission providers. The Notice is located HERE .

The Reliable Wire: Q2 2021 Edition

Wed, 30 Jun 2021 19:13:54 GMT

GridSME is pleased to present our new, expanded edition of The Reliable Wire for Quarter 2, 2021. Going forward, The Reliable Wire will be released quarterly in this expanded format, covering a wider range of electric industry topics with expert insight, Q&A, and whitepaper deep dives.

In this edition, we cover:

Complying with the CAISO Telemetry & Security Requirements for Generators
Understanding & Navigating the FERC EQR Reporting Process
Exploring the Benefits of Ciel & Terre’s Floating Solar Technology 9
Understanding How the Colonial Pipeline Breach Occured & How to
Prevent it From Happening Again

GridSME Welcomes Christina Weiler

Mon, 17 May 2021 19:21:46 GMT

GridSME is excited to welcome Christina Weiler to our team. Christina joins GridSME as a Principal Consultant, Grid Interconnection for our Engineering & Interconnection team. Christina brings years of experience in CAISO resource implementation for new and existing generation and transmission projects that wish to participate in the CAISO markets. In her new role with GridSME, she worked closely with our clients to guide them through the New Resource Implementation (NRI) process.

In her previous role at the CAISO, Christina served as the Resource Implementation Support Lead where she managed all new and existing generation and transmission projects. In this role, she worked closely with internal business units and external clients. She is adept at managing complex projects involving multiple business units and processes working with the internal and external stakeholders, and organizing and managing communications, tasks, and overall timeline execution.

Please join us in welcoming Christina to the GridSME family!

Title: Principal Consultant, Grid Interconnection

An Introduction to ADMS & DERMS

Mon, 10 May 2021 22:50:50 GMT

There is a growing interest among utilities and industry stakeholders in modernizing the distribution systems beyond the automation efforts of metering infrastructure field switches. This has led to an increase in procurement of vendor-supplied Advanced Distribution Management System (ADMS) by a growing list of load-serving entities. ADMS solutions integrate SCADA,
Outage Management (OMS), and Distribution Management (DMS) functionality in a common database and user interface.

What is interesting is the “A” in the ADMS product solutions. This “advanced” denotation refers to the ability to perform power
load flows, contingency analysis, and outage management on top of the normal DMS functions. Regardless of vendor claims,
this is a considerable challenge due to the distribution modeling and field SCADA necessary to allow these transmission-type
applications to be accurate and useful. This is a daunting task for many utilities that have not had a need to provide all the data relationships that a detailed network model requires.

Along with ADMS, some utilities are integrating newer functionality called Distributed Energy Resource Management Systems
(DERMS). DERMS support such functionality as: Volt-VAR control, Dynamic Network Topology, DER Load Forecasts, DER
situational awareness, DER susceptibility, network constraint management using DERs, energy arbitrage, and DER fleet management. The market is still deciding if DERMS will be independent systems, integrated with an ADMS, or an extra application

within the “advanced” part of an ADMS. However, to be useful, DERMS requires much more data than just a power flow model
to equitably dispatch distributed generation and charging resources. To be accurate, each generation and storage resource
must be modeled along with the controls implemented for those resources that are or need to be dispatchable. Some DERMS
systems support modeling of Demand Response (DR) contracts, and integration with Demand Response (DR) applications for
data and possibly controls, increasing Distribution system operators’ situational awareness of utility-initiated impacts to the
grid – optimizing the use of DR and Distributed Energy Resource (DER) to relieve constraints on the grid. A very advanced
technology being incorporated into combination ADMS/DERMS systems is an integration of energy arbitrage with reliability
optimization, which ensures grid reliability while maximizing the economics of DER management (minimize Green House Gas
and cost, interfacing with spot and forward market prices where available).

Several vendors are offering new approaches to DERMS that piece together the technologies required to give intelligence to a DERMS solution. These new approaches represent flexibility whereas most DMS, let alone ADMS, vendor solutions are pretty
much SCADA systems with bolt on applications. This is a new arena in which some non-ADMS vendors are participating, such
as OSIsoft (solutions such as PXiSE and DERNetSoft, with partners) and mPrest. For example, if a utility utilizes OSIsoft PI, the
data collection and analytical tools for the solutions based on PI come out of the box and the solutions take advantage of that to bring in distribution specific analytics and tools. There are many details in all of this, but it is a chance to actually implement a DERMS solution that can grow and adapt as the utility’s knowledge, needs, and grid complexity expands.

Safe to say, distribution’s time in the sun is now here (literally) and the amount of changes heading its way are enormous on two fronts: distributed generation and dispatchable storage (think EVs, too). Not having a coordinated and manageable set of tools to handle both these areas will be unfortunate for utilities struggling to deal with more and more distribution demands.

GridSME Welcomes Jason Miller

Mon, 19 Apr 2021 19:28:29 GMT

Jason Miller has joined GridSME where he serves as our Director of Reliability Engineering. Jason has over 15 years of experience in utility operations and heavy construction within the energy industry. He has experience with design-build and EPC project delivery, utility operations, engineering for power generation project development, and managing utility safety programs.

At GridSME, Jason is our lead on the operational aspects of the engineering work, as well as supporting project management, CAISO/MOD testing, GO implementation work, and technical analysis for clients.

Welcome to the team Jason!

Title: Director of Reliability Engineering

The Reliable Wire: Q1 2021 Edition

Tue, 30 Mar 2021 19:13:53 GMT

GridSME is pleased to present our new, expanded edition of The Reliable Wire for Quarter 1, 2021. Going forward, The Reliable Wire will be released quarterly in this expanded format, covering a wider range of electric industry topics with expert insight, Q&A, and whitepaper deep dives.

In this edition, we cover:

Connecting To The Grid: Understanding The Process & Avoiding Common Pitfalls
Extreme Weather Preparedness: Key Takeaways From ERCOT’s February Blackout
Minimizing Your Risk: Guidance For The 2021 Wildfire Mitigation Plans
Identifying Threats: Building A Business Case For Cybersecurity
Shutting The Door On Open Access To Critical Infrastructure

How a BESS Addition Can Push Your Non-Registered Generator into Registration Territory

Mon, 04 Jan 2021 23:42:04 GMT

GridSME has been talking to a number of existing generator owners who plan on greatly enhancing the flexibility of their PV and Wind generation facilities through the addition of Battery Energy Storage Systems (BESS). There are many generators who are interconnected at >100 kV who do not have nameplates >75 MVA and are, therefore, not required to register with NERC as BES assets.

Generator owners should be aware that the addition of battery storage contributes to the nameplate capacity for consideration for registration. Even if it does not change the deliverability to the BES from an MVA perspective. An opinion from one of the Regional Entities confirmed that all nameplate capacity would be considered towards the >75 MVA threshold.

Example – An existing >100 kV interconnected 50 MVA Solar PV facility is adding 50 MVA of battery storage capability, but is not changing its Generator Interconnection Agreement (GIA) deliverability to the POI of say 45 MW. Per the NERC BES
Definition, this resource now has 100 MVA of nameplate capacity and must register with NERC as a BES asset even though its deliverability to the PO has not changed.

This may be a startling fact to those considering adding flexibility to existing facilities or planning for new construction that previously would have been thought to be under the NERC registration threshold. Please reach out to GridSME for further guidance to generation facilities and discussion about your unique facility characteristics.

NERC BES Definition Inclusion I4 states:
I4 - Dispersed power producing resources that aggregate to a total capacity greater than 75 MVA (gross nameplate rating), and that are connected through a system designed primarily for delivering such capacity to a common point of connection at a voltage of 100 kV or above.

Thus, the facilities designated as BES are:

The individual resources, and
The system designed primarily for delivering capacity from the point where those resources aggregate to greater than 75 MVA to a common point of connection at a voltage of 100 kV or above.

From the NERC Bulk Electric System Definition Reference Document, August 2018, both BESS and solar PV are applicable under I4.

Dispersed power producing resources are small-scale power generation technologies that use a system designed primarily for aggregating capacity providing an alternative to, or an enhancement of, the traditional electric power system. Examples could include, but are not limited to: solar, geothermal, energy storage, flywheels, wind, microturbines, and fuel cells.

Generator Model Validation

Mon, 31 Aug 2020 23:35:30 GMT

The Background

Just a few years ago, the only generators that needed to worry about Generator Model Validation testing and reporting were those registered with NERC. Those registered generators must comply with three NERC Reliability Standards: MOD-025, MOD-026, and MOD-027, which essentially require Generator Model Validation (GMV) or in NERC’s words, “Verification of Models and Data.” Then the dynamics of the grid became more and more complex with the significant penetration of intermittent renewables. As the changing grid dynamics unfold (e.g., minuscule responses to minuscule changes in voltage and frequency multiplied by thousands of inverters can lead to major events), system operators noticed they need a higher quantity and quality data and models of the system.

And here we are today, whereby nearly every generator in CAISO and ERCOT, whether NERC-registered or not, has a GMV requirement. In CAISO, the generator has 120 days to perform these tests and report the data and updated models to its Transmission Planner (e.g., PG&E or SCE) and CAISO. In ERCOT, generators must perform GMV procedures and reporting as a requirement for COD. Why the increased requirements in CAISO and ERCOT? Their systems have seen some of the highest inverter-based renewable penetrations in the country. With this comes a heightened need for system and generator model accuracy.

What to Plan for as a Generator Owner?

The first question to answer is, “Will these GMV requirements apply to my generator?” If your generator is within the CAISO or ERCOT Balancing Authority Areas, the short answer is yes. If your generator is located outside these areas, the answer is a little more nuanced. Table 1 below details which generators, in most cases, do and do not have GMV requirements.

If one or more of your generators is subject to either the NERC MOD Standards or an ISO’s Generator Model Validation Requirements, you will want to begin planning for this pre-construction. Either shortly before or after your project reaches COD, you will be required to run the generator through its paces demonstrating how the resource performs when at maximum and minimum with real and reactive power output, and how it responds to voltage step changes and simulated high and low frequency events. When performing this staged test, certain data (e.g., MWs and voltage) will need to be recorded at a high sampling rate at various plant locations, such as at the POI, the high side of the GSU, and at an inverter. Recording data at a high sampling rate in these various locations can require renting and plugging-in expensive equipment. But with proper planning, a better alternative is enabling the high sampling rate data recording (“high-frequency recording”) function of your project’s SEL relays.

Once the initial staged test is performed, the data collected at the various plant locations will be used to validate your generator’s steady-state and dynamic models, which were submitted to your Transmission Planner during the interconnection phase of the project. Utilizing this test data, the inverter model, and the power plant controller (PPC) model, power engineers will use specialized software to analyze, validate, and update your generator’s steady-state and dynamic models. These updated models are then submitted to the generator’s Transmission Planner, Transmission Service Provider, and System Operator, along with various analysis and reports required by these entities. And when it comes to this reporting step, do not expect your first submission to be your last. There is often a back-and-forth with these entities to clarify data, answer questions, and update models.

It sounds simple but in each step of the process lies a rabbit hole that can consume resources and cause delays, budget surprises, and non-compliance violations and fines. But if you follow the simple checklist prescribed below and get in front of your obligations ahead of time, meeting these complex GMV requirements does not have to be a painful distraction.

Your Generator Model Validation Planning Checklist

Given the myriad of complexities and potential pitfalls, here is a checklist of items to plan for well in advance.

Budget for GMV activity costs in the project’s construction, or pre-COD, budget and in the operating budget. There is an initial GMV requirement and a recurring analysis and reporting requirement every five years thereafter.
Make sure you have the generator’s steady-state and dynamic models that were submitted during the interconnection phase of the project. These models are the starting point for the GMV process – i.e., these are the models that need to be validated.
Talk to your inverter and PPC vendors about their equipment models and request they provide these models as part of their product scope in PSCAD format or any of the other formats (e.g., PSLF, PSS/E, and/or TSAT/PSAT) requested by the Transmission Planner(s) and/or Planning Coordinator. Vendors like Nor-Cal Controls are out in front of this and have already modeled its PPC in PSCAD. Visit norcalcontrols.net to learn more about its PPC, download the PSCAD PPC Model Validation brochure (halfway down its homepage), and start a discussion with Nor-Cal Controls.
Work with your EPC and protection engineers to enable the high sampling rate data recording function of your project’s SEL relays.
Make sure your generator is compliant with PRC-019, PRC-024, and PRC-025. Even if your generator is not registered with NERC, your generator will need to comply with these Standards. Analyzing your protection equipment against these Standards is beneficial both from a grid reliability and plant profitability standpoint.
Depending on the location of your project, you will likely need special software (e.g., PSCAD, PSLF, PSS/E, and/or TSAT/PSAT) to compile and validate your generator’s inverter and PPC models and data using the data collected during the initial staged test. Locate a vendor with these capabilities early. Rush jobs can often lead to expedite fees.

Unique Considerations to Plan for in CAISO and ERCOT

CAISO
CAISO’s GMV requirements lie within its Transmission Planning Process (TPP) Business Practice Manual (BPM). These requirements culminate in a generator data request submittal requiring six or seven key elements that closely resemble NERC’s MOD-025, MOD-026, and MOD-027 requirements (See the WECC Data Preparation Manual, pages 10 and 38 ). A common mistake to avoid is not planning for and incorporating unique TPP requirements in your MOD testing plans. Too often, generators treat the MOD and TPP requirements as two separate obligations and waste money going back to their vendors with additional requests and tests. Proper planning incorporates and anticipates the TPP requirements in the early stage MOD planning and analysis phase. This way, when your contractor develops the MOD test plan, TPP requirements are accounted for and part of that plan.

There are two unique requirements in the CAISO TPP worth noting that go beyond the MOD Standards. First, all generators need to perform a 10-second simulation of their steady-state and dynamic models using CAISO’s base case in GE’s PSLF software. Second, some synchronous and all inverter-based generators are required to develop and submit an Electromagnetic Transient (EMT) model for their generator. Learn more about the EMT model requirements HERE . Both requirements go beyond the MOD Standards and should be planned for from a time and budget standpoint. Visit this LINK to download a summary of the CAISO TPP Generator Data Request requirements and best practices to avoid the typical data and model deficiencies.

ERCOT
Like CAISO, ERCOT also has a couple unique requirements to consider and plan for. First, as mentioned, ERCOT requires the generator perform a staged test to validate the resource’s real and reactive power capabilities prior to COD (the “Part III” test). If planned for and performed correctly, a generator may be able to use this test to meet some or all of its NERC MOD Standard and ERCOT generator model requirements. This can save your project both time and money. It is best practice to plan-ahead and discuss ahead of time the testing, modeling, and reporting requirements with the generator’s interconnecting Transmission Service Provider and Planning Coordinator. Obtain the applicable entity’s requirements and verify your testing and modeling plan will meet those requirements.

The second unique ERCOT requirement in the GMV process is the need for Powerflow and Short-circuit Analysis Tool (PSAT) and Transient Security Assessment Tool (TSAT) software to perform the generator modeling. This is a new requirement that is catching many asset managers off-guard. The software is not widely available and ERCOT’s requirements are evolving, so allow for plenty of time to perform the modeling and reporting.

A Quick Word About MOD-032

NERC Reliability Standard MOD-032 requires all balancing authorities, generator owners, load serving entities, resource planners, transmission owners, and transmission service providers to provide data according to the Transmission Planner (TP) and Planning Coordinator’s (PC) data request. This Standard is important because it does not state only NERC-registered facilities need to provide the data, even if you are not a NERC Registered entity you are required to provide accurate models per your interconnection agreement.

For generator owners of all sizes, this is important to keep in mind. For example, PG&E interprets this to mean any generator interconnected to their system is required to comply with the MOD-032 requirements. MOD-032 covers all generator elements that are modeled, as well as steady state, dynamic, and short circuit for conductors, transformers, VAR devices, etc. All generator elements are required to be modeled per the Participating Transmission Owner (PTO) and PC’s requirements. TPs and PCs refer heavily to MOD-032’s requirements when developing their modeling and data request needs and for base cases studies. Most WECC Regional entities utilize the WECC Data Preparation Manual to determine modeling requirements.

Don’t Wait Until the Last Minute

If there is one takeaway from all this, it is to not wait until the last minute. Plan-ahead and get in front of this early. Too often we receive calls from an operations or asset manager facing a deadline two months away. Two months may sound like plenty of time to perform these tests and meet these deadlines, but often it is not. Plus, waiting until the last-minute leads to expedite fees and missed opportunities to save money from proper planning (e.g., enable high-frequency recording functions in SEL relays to avoid equipment rental costs). So, if your generator is in the pre-construction or construction phase, or if you are facing a CAISO TPP Data Request due date that is a year away, now is the time to start developing your plan to meet the GMV requirements. Any questions? Give us a call. We’re happy to guide you through the process.

Q&A With The Experts Cypress Creek Renewables SERC O&P Audit

Mon, 18 May 2020 22:57:23 GMT

Cypress Creek Renewables (CCR) recently passed an Operations & Planning (O&P) Reliability Standards audit conducted by SERC. GridSME sat down with CCR to discuss the experience, the results of the audit, lessons learned, and key takeaways. Here is the Q&A:

Can you provide a high-level summary of the audit?
We were first notified by SERC in July 2019 that Cypress Creek was on the audit schedule for 2020 with a proposed audit date in May 2020. The official audit engagement began when we received the Audit Notification Letter (ANL) in January 2020. The ANL identified the specific Reliability Standards and Requirements included in the scope, as well as data requests related to organizational information and internal controls. Our audit scope included Operations and Planning (O&P) standards specific to the Generator Operator (GOP) registration and was conducted remotely by SERC. There were five audit team members, including a Point of Contact (POC) and an Audit Team Lead. Audit documentation was delivered via the SERC portal and the audit team reviewed our compliance evidence in a timely fashion and were very communicative throughout the process. SERC issued just one follow-up data request and finished their review ahead of schedule with zero findings. Overall, the audit went smoothly and was a great learning experience for our entity as one of the first solar specific GOPs to be audited in the SERC region.
What was the audit process like? Was there anything that took Cypress Creek by surprise? Was the process clear?
The audit process was straightforward with deliverables, due dates, additional information requests, and responses communicated to us in a timely manner. We saw this process divided into 5 basic steps following Appendix 4C of the NERC Rules of Procedure:

First, Cypress Creek was notified by SERC of our inclusion in the 2020 annual audit plan in July 2019 and was requested to confirm the proposed dates.

Second, the Audit Notification Letter (ANL) was received about 4 months before the scheduled audit dates. Along with the ANL, there was also a Request for Information, and Certification Letter. The ANL identified the specific Reliability Standards and Requirements for evaluation and the regional entity’s preferred formatting on the Reliability Standard Audit Worksheets (RSAWs). The Request for Information (RFI) included a questionnaire on the organization’s internal control practices, and the Certification Letter requested general company information such as business organizational charts. The audit team scheduled an introductory call soon after delivery of the ANL to introduce themselves and to discuss the process.

Third, the requested audit material was provided to SERC within 30 days. This upload included the completed RSAWs, associated evidence files, and responses to the RFI and Certification Letter.

Fourth, the audit team reviewed the submitted information for compliance with the Reliability Standards. Following this review, SERC provided Cypress Creek with an audit update which included a preliminary determination status for the in-scope Reliability Standards. All standards had been assessed a status of “No Finding” except one, for which additional information was required and a corresponding data request was issued. Cypress Creek had approximately a week and a half to respond to the data request and upload additional evidence for their review of that Requirement. Cypress Creek received a second audit update in late March that confirmed all requirements were moved to a “No Finding” status.

Fifth, SERC conducted an exit presentation, provided the draft audit report for Cypress Creek’s review, and delivered the final signed report to Cypress Creek. As communicated by the audit team during our opening presentation, if a potential non-compliance had been identified, the SERC audit team would have turned the proceedings over to the enforcement team following the exit presentation.

We were pleased with how communicative the auditors were and how the audit was concluded ahead of schedule. Our Exit Presentation was held the last week of March, almost 2 months before our originally scheduled audit date in May. Our audit was also largely uninterrupted by COVID-19 as the audit had already been determined as off site and the initial evidence gathering had already been completed prior to travel restrictions being implemented.
What would Cypress Creek recommend to entities prior to an audit to prepare?
We have a couple recommendations based on our experience and which worked well for us. (1) Conduct a mock audit. We recommend inclusion of all the applicable Reliability Standards to your registration and for your Subject Matter Experts to sit for mock interviews. This exercise is helpful to fine tune organization and presentation, RSAW narratives and citations, and most importantly, to confirm and obtain feedback on evidence. The objective is to prepare the RSAWs and evidence in advance as close to final form as possible. A mock audit will help confirm that your organization is ready for the audit or identify any areas of concern ahead of time. (2) Involve your management team early and often. Cypress Creek’s senior leadership was very supportive and prioritized being present and available to the compliance team throughout the audit. For example, the senior leadership team was present on the Opening and Exit Presentations and asked questions to the audit team, demonstrating engagement. The Regional Entities may notice touchpoints like this since there is a section in the Audit Report about Compliance Culture. (3) Review your Regional Entity’s audit resources. At Cypress Creek, we placed a priority on attending Open Forums and Compliance Seminars, and we were able to refer to internal notes and published recordings and presentations which helped us identify how the Regional Entity conducts their audits. This included identifying how SERC prefers evidence to be organized, including citation format and folder structure, which led to positive feedback from the audit team on our organization and presentation.
During the audit, what were Cypress Creek’s interactions with the audit team like? How many of your team members interacted with SERC during the audit? Was the entire audit conducted remotely and did that introduce any unique challenges? What form of interaction and communication was most effective?

Our interactions with the audit team were positive and professional. The audit team members were responsive and, since the audit was designated as offsite from the initial notice, we went into the audit with a communication philosophy of “early and often” and did not face any unexpected challenges. While it is always a best practice to have designated Point of Contacts from each team, this was especially important for an off-site audit. Written communication was most effective and appropriate for correspondence related to material content while verbal conversations were most effective to establish a rapport with the auditors. For example, the introductory call and opening presentation were key opportunities for senior management to meet the auditors and demonstrate active engagement and for the compliance team to ask questions.
Did the audit result in any material changes to Cypress Creek’s compliance program, policies, or procedures going forward?
Since our audit results included no recommendations and no potential non-compliances, there were no material changes made to Cypress Creek’s compliance program. The results and audit experience confirmed that our program and focus areas for development align with NERC’s risk-based approach and encouraged Cypress Creek to continuously improve elements of our program, such as internal controls. We were pleased to hear that the auditors had positive feedback for an entity of our size regarding our program structure and about the material contents of our documentation.

Metering for AC-Coupled VS DC-Coupled Solar + Storage Facilities

Mon, 06 Apr 2020 22:27:15 GMT

Introduction

As the grid evolves, there is an increasing need and motivation for existing renewable resources (e.g., solar PV) to add storage behind the same point of interconnection. With the coupling of storage to generators come many new challenges, including various challenges to coupling a storage resource on the direct current (DC) side of a renewable resource (i.e., behind the inverters). Now the hard part, how to do that within the rules and protocols of an ISO market, such as CAISO, and is it possible to separate the storage resource from the generation resource even if they are physically intertwined?

This article compares two different metering options for a solar+storage facility:

AC-coupled Storage with AC Low-Side Feeder Metering: AC low-side metering on the low-side of the step-up transformer placed on separated fuel type (e.g., one for PV and one for storage) feeders thus creating two resource ID’s; and
DC-coupled Storage with AC High-Side and Low-Side Metering: AC high-side and low-side AC metering and DC-side metering where the storage is coupled with the solar feeder. This allows for two resource ID’s and two fuel types even though the storage is on the DC-side.

In April 2017, the CAISO put into place metering enhancement rules within the CAISO Metering Business Practice Manual (BPM)
applicable within its Balancing Authority area (BAA). These rules set the stage for metering solar+storage facilities in a way that gives the resource owner and off-taker maximum flexibility.

The metering enhancement rules and Metering BPM give entities inside of the CAISO control area the option to use a Scheduling Coordinator Meter Entity (SCME) to submit settlement quality meter data (SQMD) into the CAISO settlement system. This change to the Metering BPM allows an entity to calculate or extract 5-minute settlement meter data without a CAISO-approved meter by collecting settlement quality data from an approved and accurate device either on the DC-side or AC (alternating current) side of the solar+storage facility.

The CAISO metering enhancement rules are designed to allow SQMD energy submissions into the ISO Market Result Interface Settlement (MRI-S) system directly without an ISO-polled meter. To do this, an entity will need to comply with the CAISO AC-side metering accuracy as directed by the CAISO Metering BPM. The same CAISO metering accuracy, if applied to other interconnection facility hardware (e.g., an inverter), can be used to collect data that can derive 5-minute settlement interval data. The SQMD 5-minute intervals will be submitted into MRI-S system by the selected Scheduling Coordinator.

AC-coupled Storage with AC Low-Side Feeder Metering
Concept: The AC low-side metering is the most common metering settlement concept when a solar+storage facility must have multiple CAISO resource identifiers (“resource ID’s”) for purposes of separately accounting for the solar and storage resources and allowing for two different fuel types (i.e., solar PV and non-generator resource), perhaps because there exist multiple power purchase agreements (PPAs), there is a need for the solar resource to be considered an Eligible Intermittent Resource (EIR), to account for renewable energy credits (RECs), or for the storage resource to provide ancillary services.

Interconnection Planning Model: AC-coupling storage to a solar PV facility uses a separate feeder for each storage layout without changing the interconnection engineering study and planning design of the solar facility. The CAISO production system will model each resource ID as its own fuel type (e.g., solar and storage separate and distinct). In addition, the two resource ID’s will be treated independently in CAISO’s EMS and market models. CAISO will not view the two resource ID’s as a co-located or hybrid resource.

Interconnection Planning Model Considerations: If the solar PV facility was not studied as a co-located fuel type (i.e., solar+storage), then adding storage will require the interconnection agreement to go through the material modification assessment (MMA) process.

Revenue Settlements: Storage and renewable resources electrically connected but on separate feeders on the AC low-side of the stepup transformer can be complex if the entity owner selects polled CAISO metering for the different resource ID fuel types. In order to not violate the CPUC’s Eligible Intermittent Resource (EIR) ruling, these two fuel types must be kept separate (i.e., each have their own resource IDs). To achieve this low-side AC metering on each feeder, or collection of busses under a feeder, a resource must have a CAISO-approved meter. Then each resource ID’s meter, or group of meters, are associated with a single fuel type resource ID. CAISO can aggregate the same fuel type resource meters (e.g., multiple solar PV meters associated with the same fuel type).

DC-coupled Storage with AC High-Side and Low-Side Metering:
Concept: AC high-side metering with a DC-coupled storage resource on the same DC collection bus as the renewable resource and distributed across one or multiple inverters.

Interconnection Planning Model: DC-coupling storage to a renewable resource uses the DC buses and feeders’ electrical connection infrastructure to couple the storage resource without changing the interconnection engineering, study, and planning design of the generator interconnection facility. There may be a need to study the short circuit capabilities when adding storage to a solar DC bus to ensure the inverter can handle the bidirectional power flow, it takes less time for this type of restudy than AC coupled storage.

Revenue Settlements: The storage and the solar resources must be settled separately using an SQMD plan for each resource ID fuel type
(e.g., storage and solar separate). The SQMD must be submitted by a SCME. The data in the SCME submission is derived from:

A. single high-side revenue quality metering,
B. low-side revenue quality metering, and
C. DC metering of the solar and storage output.

With this setup, the DC metering will interface with the low-side AC metering to logically separate the solar and storage production, thereby allowing for the solar resource to appear as its own resource and therefore qualify as an EIR.

Summary
As the saying goes, “the devil is in the details.” There are, of course, a number of complexities here but the important takeaway is to know, no matter the site’s physical configuration (i.e., DC or AC-coupled storage), it is possible to separate your solar resource from your storage resource in the CAISO market. It is just a matter of identifying and implementing the right metering solution within the CAISO rules. If you have any thoughts or questions on this topic, feel free to give us a call or send an email. We’d love to chat.

Interested in learning more
GridSME will be co-hosting a webinar on Operating Hybrid Resources in CAISO on July 15th at 10:30am PT. Join Customized Energy Solutions (CES), Buchalter, and us for an in-depth discussion on metering, telemetry, market participation, and ITC considerations for solar+storage resources operating in CAISO.

Substation Physical Security Initiatives

Mon, 30 Mar 2020 21:23:00 GMT

Have you ever been curious about what events lead to the increase of regulations towards increasing physical security protection of your electric substations? In this article we will take a dive into the events that lead to the standards and how those standards effect your substations.

In the electric energy industry, a predominant compliance driver has focused on cyber security of the bulk electric system
controls. In 2013, the focus on cyber security compliance issues for electric utilities was augmented with some new physical
security requirements. In this article, I’ll introduce you to the events that led to the development of these new regulations and how you can development and implement your new physical security protocol that meets these new guidelines.

Metcalf Substation Attack
The Executive Order seeks to mitigate well known, and long-standing, cyber security supply chain risks. There is no doubt that
on the night of April 15, 2013, several very well-informed attackers caused physical damage to Pacific Gas & Electric’s large 500
kv/230kv Metcalf Transmission Substation located south of San Jose, California. Beginning at about 1:00 AM, the attackers cut
two fiber communication lines. After they were finished, they resealed the telecom vaults and spread garbage in the area to help draw attention away from their actions.

At 1:31 AM the attackers began shooting at the substation transformers and circuit breakers. Ten of the 11 transformers were
struck. It appeared that the attackers only shot at the “hot” transformers (one was down for maintenance). By 1:45 AM the
transformers had begun to shut down, presumably, due to low cooling oil levels and low oil pressures.

The subsequent investigation after the shooting identified 116 impact points on 22 pieces of equipment and 52,000 gallons of
transformer oil was spilled onto the base of the substation foundation. It was also determined during the investigation that the slow response time of the employees and inaccessibility of the substation allowed the perpetrator(s) enough time to get escape before the police arrived on scene.

Metcalf Attack Regulatory Response
After the attack, there was a buzz within the electric energy and security industries, which was filled with conjecture as to the true motivation(s) behind the attack. The local transmission system operators were able to effectively bypass Metcalf, which resulted in no reported electricity outages in the surrounding area.

The “buzzing” reached a crescendo on March 7, 2014 when the Federal Energy Regulatory Commission (FERC) – the government entity regulating the interstate transmission of electricity, natural gas, and oil in the US – directed the North American Electric Reliability Corporation (NERC) to submit a proposed physical security reliability standard for electric transmission substations within 90 days.

The focus of this proposed standard was to “Identify and protect facilities that if rendered inoperable or damaged could result in widespread transmission grid instability, uncontrolled electric network separation, or cascading failure within a transmission interconnection.”

Such a demand from FERC is not abnormal; however, their mandate for a rapid turnaround and production by NERC standards committees was unheard of. Everyone realized FERC was taking the Metcalf event seriously.
The response from NERC was the development of NERC Critical Infrastructure Protection (CIP) Standard 014, “Physical Security.” The final ballot closed on May 5, 2014 – passing at 85%. The NERC Board of Trustees adopted CIP-014 on May 13, 2014. FERC approved this new standard on July 17, 2014 resulting in an effective implementation date of October 1, 2015.

This may seem slow; however, in the regulatory environments of FERC and NERC this was “SUPERFAST!”

CIP-014, Substation Physical Security Standard

The CIP-014 requirements are summarized in the table shown below but the you can view the full
CIP-014 standards by visiting NERC.com or by ( clicking here ).

Since the initial introduction of CIP-014, all North American electric utilities have implemented plans to address the requirements specified within the legislation and most have been audited to ensure the effectiveness of their plans.

California Doesn’t Want to Be Left Behind
While FERC and NERC were busy developing new physical security standards for large electric transmission substations, California lawmakers also showed their concern regarding the Metcalf attack by passing new legislation in June 2015 called Senate Bill 699 (aka, SB-699).

The new legislation addressed two major areas when it effective on January 1, 2016:

Directed the California Public Utilities Commission (CPUC) to explore policies and practices related to physical security of
electric distribution assets (not transmission – that is FERC/NERC’s jurisdiction!)
Directed the CPUC to consider adoption of new standards and rules to address any physical security risk to the distribution system of California’s electric corporations so as to ensure “high-quality, safe, and reliable service.”

SB-699 Development

The actual legislation included in SB-699 is not very detailed. The document is only a few paragraphs long. So, to develop the detailed response to SB-699, the CPUC held three workshops to gather information from the affected California utilities and get a sense of the necessary parameters to include in the actual rules.

The first workshop was held on May 2, 2017 and was focused on information sharing, sensitive data protection, and confidentiality of critical energy infrastructure information. The workshop also established proceeding rules of engagement for input and testimony on sensitive subjects.

The second workshop was held on May 31, 2017 where the discussions were about state, federal, and industry standards and
responses including CIP-014.

On June 21, 2017, the final workshop was held to address how SB-699 informs CPUC response and responsibilities. The meeting
also included discussions on threat assessment, critical substation protections, and incident response resiliency.

Of note, on July 12, 2017, as part of the SB-699 response development process, an administrative law judge issued a ruling requesting straw proposals from the stakeholders on what the SB-699 rules should include.

January 2018 – CPUC Staff White Paper
After digesting the workshop notes and straw proposals the CPUC issued a very informative white paper entitled Security
and Resilience for California Electric Distribution Infrastructure: Regulatory and Industry Response to SB-699. The primary
topics in the paper included:

Electric utility physical security in the Post-Metcalf era
Distribution asset security and resiliency in California
Incident reporting and tracking best practices
Exchange of and access to highly confidential and sensitive information
Utility general rate cases informing physical security efforts, and
Recommendations

This white paper gives you an excellent sense of the State of California electric distribution grid and the challenges with keeping the critical infrastructure information secured from general knowledge – especially from the terrorists and threat actors.

January 22, 2019 – Physical Security Decision
Almost a year after the CPUC white paper was issued – the CPUC approved the “Physical Security Decision (D.19-01-018).”
This made California the first U.S. state to adopt rules to guard the electric distribution grid against terrorist attack.

The decision established general criteria for the identification phase and criteria for the assessment phase, which clearly
defined what parameters are used when deciding what distribution substations should be tagged as critical, and what are the rules that should be followed for the physical security assessments of the identified subs.

Identification Criteria
The general rules in the Physical Security Decision for identifying and declaring which distribution substations are critical
include those that:

Are needed for crank path, black start, restoration of the regional grid
Are an electric power source for a military installation
Serve a regional water and wastewater facilities
Serve a regional public safety (e.g., 911 center)
Serve a major transportation facility (e.g., Los Angeles International Airport)
Serve a Level 1 Trauma Center
Serve > 60,000 electric meters

Assessment Phase Criteria
Once the more critical distribution substations are identified – as noted above – the assessment phase will look at such issues as:

Existing system resiliency and/or redundancy solutions
Spare assets to restore a particular load
Existing physical security protections
Potential for emergency responders to identify and respond to an attack in a timely manner
Location/proximity to gas pipelines, geographical challenges, impacts of weather, etc…
History of criminal activity affecting the substation

Cost Recovery
The decision does allow for the investor-owned utilities to file separate applications for cost recovery associated with their respective distribution security programs. Although the Distribution Security Program documents are considered security-sensitive and cannot be publicly released, the investor-owned utilities may file a public version of the unaffiliated third-party review and CPUC approval in their cost recovery requests.

Security Decision Timeline
According to the Security Decision, each utility’s Security Plan Report is due to the CPUC within 30 months of the approval of the Decision (estimated to be July 2020). The third-party reviews should be completed by April 2021.

Conclusion
The events of the Metcalf substation shooting were profound and a bit rattling to the electric energy utilities and regulators. CIP-014 came out of the event thus affecting most major North American electric transmission utilities. Now California Senate Bill 699 and the derivative Security Decision of January 2019 has been issued thus affecting most electric utilities in California. These two events show a trend towards increased physical security protection of electric substations.

Energy Storage: How Realistic is a Once per Day Cycle Assumption?

Tue, 07 May 2019 19:14:09 GMT

Will Batteries Really Cycle Once per Day? In this article, GridSME discusses four factors challenging the full once per day cycle assumption held by many storage developers. Click Here to Read & Download Article

New CAISO TPP Requirement FAQ - Electromagnetic Transient Modeling

Tue, 07 May 2019 19:14:06 GMT

In preparation for the upcoming CAISO Transmission Planning Process Requirement pertaining to the Electromagnetic Transient (EMT) Modeling Guide for Inverter Based Generators (effective May 31, 2019), GridSME has developed a Frequently Asked Questions (FAQ) bulletin to support effected entities.

GridSME has observed that this requirement has created numerous questions for generators within the CAISO footprint. If your facility is a Category 1 or 2 you may be required to submit an EMT model suitable for sub-synchronous resonance (SSR) studies. These FAQs are designed to provide a better understanding of the EMT model requirements.

Questions addressed in this bulletin:

What is an EMT Model and what is it used for?
How do I know if I have to provide this information to CAISO?
What category has the CAISO identified my generating plant as?
What information is required to complete an EMT model?
What is the format that I need to submit the required data?
What happens if I do not comply on time with the CAISO TPP BPM?

If you would like more information on how this requirement may impact your organization, don’t hesitate to reach out. We look forward to assisting you with the EMT submission requirements or answering any questions that you may have.

Click Here to Read the Full Article

Energy Storage: Tackling the Revenue Modeling Challenge

Fri, 22 Mar 2019 19:14:04 GMT

In an effort to help a broad audience see and understand how storage can be monetized in wholesale electricity markets (such as in CAISO), GridSME is using its eStorm model to simulate a fictional in-front-of-the-meter battery operating on a Bay Area Pnode throughout 2019.

We call this fictional storage project Greenbrier – a 2 MW, 8 MWh standalone storage project. As the year progresses, we’ll share the battery’s performance, strategy, results, and our analysis. Below are the results from March.

Click here to read the complete Greenbrier BESS March Analysis

CAISO Transmission Planning Process FAQ

Thu, 03 Jan 2019 20:14:10 GMT

The CAISO has recently established new modeling requirements for generators as part of its expansion of the transmission planning process. These requirements require action for some generating units starting in May 2019. GridSME has developed these Frequently Asked Questions to help CAISO generators navigate these new requirements, and determine if and when they may apply to you.

Check out our FAQs HERE .

Is The Solar Industry Secure Enough For Smarter Technology?

Wed, 28 Nov 2018 20:14:11 GMT

Check out this great article about the growing cybersecurity needs to keep up with the rapidly expanding solar industry, and what best practices can be taken to protect important systems.

FERC Approves New Supply Chain Reliability Standards To Address Cyber Security Risks

Fri, 19 Oct 2018 19:14:13 GMT

On October 18, 2018, FERC issued a final rule approving NERC CIP Standards on supply chain risk management for high and medium impact BES Cyber Systems. This includes new CIP-013-1 requiring applicable entities to develop and implement a supply chain cyber security risk management plan, and new security controls under CIP-005-6 and CIP-010-3. The implementation period set by FERC is 18 months due to the time needed to implement a plan and controls under the new requirements.

GridSME has prepared a short summary of the final rule and these new requirements, which you can read here . GridSME can help you understand the new standards and develop a roadmap to meet the upcoming compliance requirements.

CAISO’s RIMS5 Changeover

Thu, 21 Dec 2017 20:14:14 GMT

Does your organization interact with CAISO?

If so, you may be aware that CAISO is updating its interconnection process and making the Resource Interconnection Management System v5 (“RIMS5”) the sole location for the transmittal of information pertaining to interconnection applications, interconnection studies, meter installation and maintenance projects (that are not Scheduling Quality Meter Data (SQMD) or Distributed Energy Resource Provider (DERP) projects), and New Resource Implementation (NRI) projects.

What does this mean to you?

You will no longer be able to email, mail, or physically deliver to CAISO documents or information related to the project types noted above. The transmittal of those documents will need to be done through RIMS.

When is this change effective?

December 31, 2017

If you aren’t ready for this change, don’t panic. GridSME can help.

Read the full write-up here

NERC Alert – Crash Override – Challenging Beliefs

Tue, 11 Jul 2017 19:14:15 GMT

NERC Alert issued June 13, 2017 advises on the Crash Override malware found to be behind the December 2016 attack on the Ukrainian power grid. While the NERC Alert provides many great details on the malware’s technical characteristics, the fact of the matter is Crash Override is among the most sophisticated ICS-specific malware variants ever detected, with the ability to “cause loss of visibility, loss of control, manipulation of control, interruption of communications, and deletion of local and networked critical configuration files.” Perhaps most concerning is the malware’s ability to be easily tailored to specific ICS environments, communication protocols, and devices.

This type of sophisticated malware forces us to rethink some common predisposed cybersecurity beliefs:

Read the full post here .

Curtailment Mitigation Strategies

Wed, 14 Jun 2017 19:14:16 GMT

Curtailments and energy imbalances can be costly for any generator, whether you are a new market entrant, such as solar PV, or an industry veteran, such as hydro. Generators used to be able to set it and forget it when it comes to scheduling and operations. There may have been a rare occurrence when the CAISO instructed your generator to curtail through an exceptional dispatch. And the occasional forced outage was inevitable, but nothing to fret over. However, more recently, generators are experiencing frequent instances of curtailment, and greater imbalance uncertainty due to the more intermittent profile of the generation fleet and higher market price volatility.

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