With more than two decades leading multi-country operations, P&L responsibility, and technology-driven market expansion across Latin America, Europe, and North America, I have built my career at the intersection of digital infrastructure, utilities, telecommunications, and mission-critical communications.

I have held regional leadership roles with full commercial accountability, market-entry responsibility, and partner ecosystem development across multiple infrastructure segments.

My work focuses on helping organizations modernize networks, improve operational resilience, navigate regulatory frameworks, and execute large-scale infrastructure programs with disciplined governance and measurable outcomes in regulated environments. I have led commercial, operational, and technical initiatives across more than 30 countries, working closely with utilities, regulators, government agencies, industry associations, and global technology providers.

Professional experience includes:

General management and regional leadership in complex, multi-stakeholder environments

Regulatory alignment and homologation (ANATEL, ENACOM, IFT, INMETRO, ANEEL)

Digital transformation programs including smart grid, AMI, private LTE/5G, LPWAN, industrial IoT, and mission-critical communications

Market expansion and revenue strategy for global technology firms scaling in LATAM and Europe

Executive-level engagement with utilities, ministries, regulators, and C-suite stakeholders

Cross-cultural leadership of distributed teams and strategic partner ecosystems

Active participation in IEEE, CIGRE, CIRED, and UTC/UTCAL technical communities

I combine executive leadership with technical depth, commercial strategy, and regulatory insight. Fluent in Portuguese, Spanish, English, Italian, and Slovenian, with working knowledge of French and German, I operate effectively across diverse cultural and institutional environments.

In parallel with industry leadership roles, I actively contribute to technical education and knowledge exchange through conference lecturing, peer-reviewed publications, and advisory discussions related to smart grids, private wireless networks, and industrial digital transformation.

Today, I remain engaged in strengthening resilient, secure, and scalable infrastructure for utilities, energy, telecom, and industrial sectors across Latin America and Southern Europe.

If you are working on long-term infrastructure modernization programs in regulated markets and would like to exchange perspectives.

I welcome a constructive conversation.

𝗔 𝗱𝗲𝗰𝗶𝘀ã𝗼 𝗺𝗮𝗶𝘀 𝗰𝗮𝗿𝗮 𝗲𝗺 𝗦𝗖𝗔𝗗𝗔 𝗻ã𝗼 é 𝗲𝘀𝗰𝗼𝗹𝗵𝗲𝗿 𝗼 𝗳𝗼𝗿𝗻𝗲𝗰𝗲𝗱𝗼𝗿 𝗲𝗿𝗿𝗮𝗱𝗼 — é 𝗲𝘀𝗰𝗼𝗹𝗵𝗲𝗿 𝗮 𝗮𝗿𝗾𝘂𝗶𝘁𝗲𝘁𝘂𝗿𝗮 𝗲𝗿𝗿𝗮𝗱𝗮.

No Brasil, decisões de digitalização no saneamento — seja em companhias como S𝗔𝗕𝗘𝗦𝗣, 𝗖𝗢𝗣𝗔𝗦𝗔, 𝗦𝗔𝗡𝗘𝗣𝗔𝗥, ou em utilities como 𝗖𝗘𝗗𝗔𝗘 (𝗥𝗝), 𝗖𝗔𝗘𝗦𝗕 (𝗗𝗙) e 𝗘𝗠𝗕𝗔𝗦𝗔 (𝗕𝗔) — precisam ser tratadas como decisões estruturais de longo prazo, e não como simples aquisições de tecnologia.

Uma análise técnica recente de Arturo Parra sobre o 𝗽𝗿𝗼𝗷𝗲𝘁𝗼 𝗱𝗲 𝗦𝗖𝗔𝗗𝗔 𝗱𝗮 𝗦𝗘𝗗𝗔𝗣𝗔𝗟, 𝗲𝗺 𝗟𝗶𝗺𝗮, serve como um alerta regional claro: atualizar hardware e software mantendo um modelo arquitetural legado reduz riscos imediatos, mas cria custos, limitações operacionais e dependências difíceis de reverter no futuro.

𝗪𝗮𝘁𝗲𝗿 𝟰.𝟬 não é sobre adicionar 𝗜𝗔, 𝗗𝗶𝗴𝗶𝘁𝗮𝗹 𝗧𝘄𝗶𝗻𝘀 ou 𝗔𝗠𝗜 depois.
É sobre definir, desde o início, 𝗼𝗻𝗱𝗲 𝗮 𝗶𝗻𝘁𝗲𝗹𝗶𝗴ê𝗻𝗰𝗶𝗮 𝗱𝗼 𝘀𝗶𝘀𝘁𝗲𝗺𝗮 𝗿𝗲𝘀𝗶𝗱𝗲: na borda, orientada a eventos, integrada ao campo e capaz de antecipar perdas antes que elas se materializem.

Com novos ciclos de investimento, modelos de PPP e metas regulatórias mais exigentes, utilities brasileiras enfrentarão esse mesmo ponto de decisão — agora em 𝗲𝘀𝗰𝗮𝗹𝗮 𝗻𝗮𝗰𝗶𝗼𝗻𝗮𝗹 e com impacto direto na eficiência operacional, no OPEX e na sustentabilidade dos ativos.

As organizações que estruturarem corretamente essa base arquitetural capturam valor ao longo do tempo.
As que postergarem essa discussão herdarão complexidade, custo e obsolescência.
#IoT #NBIoT #smartgrid #technologia #innovation #technology #3GPP #4.0

Marco  Pangos

I’m a results-driven Business Development Executive with an exceptional track record in driving revenue growth, forging strategic alliances, and spearheading market entry across global regions
With extensive experience leading initiatives in LATAM, I’ve consistently delivered breakthrough results -including up to 2100% regional growth in both new and turnaround situations
In my executive roles as Regional Director of Sales & Marketing, VP of Sales & Marketing, and beyond, I have:
• Delivered Top Value Creation:
    – Achieved 15X growth at 4RF, solidifying its position as the #1 supplier for utility groups, regulators, and industry leaders in Latin America through customer-centric market development and tailored product strategies
    – Leveraged fluency in five languages to build and strengthen robust VAR, VAD, and OEM channel relationships, collaborating with commercial partners, government agencies, system integrators, distributors, and engineering firms
    – Opened LATAM markets for leading technology innovators such as Extricom, 4RF, Sub10Systems, Huber+Suhner, and Raychem (Tyco), rapidly positioning them as market leaders through strategic marketing plans and deep regional insights
• Demonstrated New & Emerging Market Leadership:
    – Secured high-value commercial relationships in 27 Caribbean & LATAM countries for 4RF and represented the company before influential bodies like the Utilities Technology Council
    – Drove rapid growth at L3 Communications by establishing new channels, negotiating key contracts (including with Telefonica), and introducing strategic broadband and mobility solutions
    – Enhanced revenue streams across the EU and Americas by advancing automation and SCADA agreements with multinational electrical and water utilities
• Technical Leadership:
- Life Senior IEEE member
- Global speaker at International Technology Forums across Americas and Spain
- Expert in wireless technologies and wire & cable systems
• Languages:
Fluent: English, Spanish, Portuguese, Italian, Slovenian
Basic: French, German
My expertise spans a wide range of areas, including: 
Sales & Market Strategy | Market Entry | Pricing Strategy | Direct & Channel Sales | Turnarounds | Global Sales Agreements | Strategic Alliances | Team Leadership | P&L | Partner Development | Contract Negotiations | High-Tech Markets | Multilingual Communication | Distribution Partnerships | Engineering | Relationship Management | Startups | Greenfield Operations
I’m passionate about leveraging innovative technology solutions to solve complex challenges and create lasting value

Global Technology & Infrastructure Executive | LATAM & Europe Market Expansion Leader | Utility, Telecom & Critical Infrastructure Strategy | Board Advisor | IEEE Life Senior Member

𝗧𝗵𝗲 𝗻𝗲𝘅𝘁 𝗯𝗹𝗮𝗰𝗸𝗼𝘂𝘁 𝘄𝗶𝗹𝗹 𝗻𝗼𝘁 𝗯𝗲 𝗰𝗮𝘂𝘀𝗲𝗱 𝗯𝘆 𝗹𝗮𝗰𝗸 𝗼𝗳 𝗴𝗲𝗻𝗲𝗿𝗮𝘁𝗶𝗼𝗻.
𝗜𝘁 𝘄𝗶𝗹𝗹 𝗯𝗲 𝗰𝗮𝘂𝘀𝗲𝗱 𝗯𝘆 𝗺𝗶𝗹𝗹𝗶𝘀𝗲𝗰𝗼𝗻𝗱𝘀.

IEEE’s latest Power & Energy Magazine confirms what many utilities are starting to face: modern grid failures are dynamic, software-driven and unfold in sub-second timescales.

We upgraded generation.
We upgraded inverters.
We upgraded sensors.

But many protection architectures still rely on telecom latency and coordination assumptions designed for a synchronous grid that no longer exists.

In inverter-dominated systems, oscillations and cascading trips propagate faster than human response. If teleprotection signaling arrives late, the cascade has already started.

This is no longer only a control problem.
It is a teleprotection + communications + protection coordination problem.

That is exactly what I will address at DISTRIBUTECH.

Because grid reliability is no longer measured in minutes.
𝗜𝘁 𝗶𝘀 𝗺𝗲𝗮𝘀𝘂𝗿𝗲𝗱 𝗶𝗻 𝗰𝘆𝗰𝗹𝗲𝘀.

No alternative text description for this image

𝗛𝗼𝘄 𝗰𝗹𝗼𝘀𝗲 𝗵𝗮𝘃𝗲 𝘄𝗲 𝗮𝗰𝘁𝘂𝗮𝗹𝗹𝘆 𝗰𝗼𝗺𝗲?
Most people remember recent U.S. grid events for the outcome.
Few realize how close the system came to uncontrolled cascading failure.

What’s less discussed is the margin.

I’ve reviewed post-event engineering reports, regulatory findings, and operational timelines down to the minute.
In at least one major U.S. grid event from the last five years, operators held a situation that physics says should not have been holdable.

Skill mattered.
Training mattered.
Discipline mattered.

𝗕𝘂𝘁 𝗽𝗵𝘆𝘀𝗶𝗰𝘀 𝗱𝗼𝗲𝘀 𝗻𝗼𝘁 𝗴𝘂𝗮𝗿𝗮𝗻𝘁𝗲𝗲 𝘁𝗵𝗲 𝗻𝗲𝘅𝘁 𝗲𝘃𝗲𝗻𝘁 𝗴𝗶𝘃𝗲𝘀 𝘂𝘀 𝘁𝗵𝗲 𝘀𝗮𝗺𝗲 𝘄𝗶𝗻𝗱𝗼𝘄.
Luck is not a design parameter.

I’ll walk through what actually happened — and what it means for protection coordination and communication latency.

📍 DISTRIBUTECH — Room 29CD
📅 February 4
🕒 3:00 PM

If cascade physics matters to your role, this session will be relevant.
I’ll continue sharing what the data actually shows over the next days.

Marco Pangos
IEEE Life Senior Member

Question: In fast cascade scenarios, what breaks first in your experience — protection coordination, communications latency/jitter, inverter behavior, or operator response time?
#DISTRIBUTECH2026 #GridResilience #PowerEngineering

Most AMI architecture debates start with the wrong question.
“Should we choose LPWAN or NB-IoT?”
This video shows why that framing is already outdated.
Since 2018, Ubiik has operated far more than one million smart-meter endpoints for Taipower — with a simple empirical result:
 ~90% Weightless LPWAN + ~10% public NB-IoT delivers the best total cost of ownership and the highest QoS.
The key insight is not the radio technology.

 It is the architecture.

As explained in this demo, the new Nimbus 230 integrates:
Weightless LPWAN stack
NB-IoT stack
AMI application stack (DLMS/COSEM)
in a single module, enabling:
primary Weightless with NB-IoT failover, or
primary NB-IoT with Weightless as coverage extension.
This is what AMI 2.0 actually looks like in the field:
 not technology replacement, but designed redundancy, open standards, and deterministic behavior at scale.
I have written extensively about why future-proof AMI depends on open architectures, not single-network bets.
If you are a utility, meter vendor, or system integrator thinking about:
 • hybrid AMI architectures
 • LPWAN vs NB-IoT trade-offs
 • lifecycle cost and resilience
I am always open to a technical exchange.

youtube.com

Weightless™ Private LPWAN Demo: Meter Data over Long-Range Connectivity

𝗦𝗮𝗺𝗲 𝗰𝗼𝗻𝗱𝗶𝘁𝗶𝗼𝗻𝘀. 𝗗𝗶𝗳𝗳𝗲𝗿𝗲𝗻𝘁 𝗼𝘂𝘁𝗰𝗼𝗺𝗲𝘀.
One cascade ended in blackout.
Another stopped in milliseconds.

I’ve been comparing grid events across multiple regions.
What’s striking is not the differences — it’s how similar the stress conditions actually were.

Similar system loading.
Similar renewable penetration levels.
Similar monitoring visibility.

Yet the outcomes were radically different.

In one case, protection actions propagated in under 𝟱𝟬 𝗺𝘀.
In the other, delays pushed beyond the system stability margin.

The difference was not generation mix.
It was not operator intent.
It was not situational awareness.

One variable consistently explains the divergence — and it is rarely discussed.

Physics doesn’t respect borders.
Protection timing doesn’t either.

I’ll break this down with real event data at DISTRIBUTECH.

📍 Room 29CD
📅 February 4
🕒 3:00 PM

For engineers working in protection, telecom, or reliability.

𝗡𝗲𝘅𝘁 𝗽𝗼𝘀𝘁: 𝘁𝗵𝗲 𝗼𝗻𝗲 𝗽𝗮𝗿𝗮𝗺𝗲𝘁𝗲𝗿 𝘁𝗵𝗮𝘁 𝗱𝗲𝗰𝗶𝗱𝗲𝘀 𝗰𝗮𝘀𝗰𝗮𝗱𝗲 𝘀𝘂𝗿𝘃𝗶𝘃𝗮𝗹 — 𝗯𝗲𝗳𝗼𝗿𝗲 𝗼𝗽𝗲𝗿𝗮𝘁𝗼𝗿𝘀 𝗰𝗮𝗻 𝗲𝘃𝗲𝗻 𝗿𝗲𝗮𝗰𝘁.

Marco Pangos
IEEE Life Senior Member

#DISTRIBUTECH2026 #GridProtection #PowerSystems #CriticalInfrastructure

𝗧𝗵𝗲 𝗰𝗼𝗻𝘃𝗲𝗿𝘀𝗮𝘁𝗶𝗼𝗻 𝗴𝗿𝗶𝗱 𝗺𝗼𝗱𝗲𝗿𝗻𝗶𝘇𝗮𝘁𝗶𝗼𝗻 𝘀𝘁𝗶𝗹𝗹 𝗮𝘃𝗼𝗶𝗱𝘀
Grid modernization debates focus on new technology.
Almost nobody asks the uncomfortable question:
𝗜𝘀 𝘁𝗵𝗲 𝗰𝗼𝗼𝗿𝗱𝗶𝗻𝗮𝘁𝗶𝗼𝗻 𝗮𝗿𝗰𝗵𝗶𝘁𝗲𝗰𝘁𝘂𝗿𝗲 𝗶𝘁𝘀𝗲𝗹𝗳 𝘀𝘁𝗶𝗹𝗹 𝗳𝗮𝘀𝘁 𝗲𝗻𝗼𝘂𝗴𝗵?
Today’s grids behave differently than when many protection assumptions were created.
Inverter-based generation.
Distributed assets.
Faster disturbance propagation.
Tighter stability margins.
Yet many coordination models still assume response dynamics that no longer exist.

Most grid modernization conversations focus on:
— Renewables integration
— Storage deployment
— Digital substations
— Communications technologies

All of these matter.

But underneath all of them sits the real systems question:
𝗔𝗿𝗲 𝗰𝗼𝗼𝗿𝗱𝗶𝗻𝗮𝘁𝗶𝗼𝗻 𝗮𝗿𝗰𝗵𝗶𝘁𝗲𝗰𝘁𝘂𝗿𝗲𝘀 𝗳𝗮𝘀𝘁 𝗲𝗻𝗼𝘂𝗴𝗵 𝗳𝗼𝗿 𝘄𝗵𝗮𝘁 𝘁𝗵𝗲 𝗴𝗿𝗶𝗱 𝗵𝗮𝘀 𝗮𝗹𝗿𝗲𝗮𝗱𝘆 𝗯𝗲𝗰𝗼𝗺𝗲?
Blackout investigations across the U.S., Europe, Latin America, and Australia show the same pattern:
cascades are accelerating faster than many protection assumptions were designed for.

This session is about that gap — and what communication latency actually means inside protection physics.
No vendor pitch.
No product comparison.
Physics and math only.
📍 DISTRIBUTECH — Room 29CD
📅 February 4
🕒 3:00 PM
🎯 Protection engineers, telecom planners, reliability teams

I’ll continue sharing what the data actually shows.

Marco Pangos
IEEE Life Senior Member
#DISTRIBUTECH2026 #GridEngineering #PowerSystems #ProtectionEngineering

𝗔 𝗺𝗮𝗶𝗼𝗿 𝗽𝗲𝗿𝗱𝗮 𝗱𝗲 𝘂𝗺𝗮 𝘂𝘁𝗶𝗹𝗶𝘁𝘆 𝗻ã𝗼 é 𝗮 𝗲𝗻𝗲𝗿𝗴𝗶𝗮 𝗻ã𝗼 𝗳𝗮𝘁𝘂𝗿𝗮𝗱𝗮.
É 𝗮 𝗲𝗻𝗲𝗿𝗴𝗶𝗮 𝗾𝘂𝗲 𝗻ã𝗼 é 𝘃𝗶𝘀í𝘃𝗲𝗹.
𝗘 𝗼 𝗾𝘂𝗲 𝗻ã𝗼 é 𝘃𝗶𝘀í𝘃𝗲𝗹 𝗻ã𝗼 𝗽𝗼𝗱𝗲 𝘀𝗲𝗿 𝗴𝗲𝗿𝗲𝗻𝗰𝗶𝗮𝗱𝗼.

Por muitos anos, a telemedição foi tratada apenas como uma ferramenta administrativa. Hoje isso não é mais suficiente.

As utilities modernas estão migrando para 𝗔𝗠𝗜 𝟮.𝟬: uma arquitetura operacional distribuída que conecta medição, automação, analytics e controle em tempo quase real.

Ela não apenas mede consumo.
Ela habilita decisões.

Quando bem implementada, permite antecipar sobrecargas, identificar perdas técnicas e comerciais, otimizar ativos, melhorar indicadores de qualidade, integrar geração distribuída, armazenamento e viabilizar resposta à demanda.

Mas existe um erro recorrente:
Tratar AMI 2.0 como um projeto de TI.

AMI 2.0 é um projeto de transformação operacional.
Exige integração entre engenharia, operação, regulação, segurança cibernética e infraestrutura de comunicações.
E esse modelo já não se aplica apenas à energia elétrica: está avançando rapidamente para água, saneamento e gás.

A pergunta estratégica não é:
“Quantos medidores inteligentes instalamos?”

A pergunta certa é:
Quais decisões operacionais hoje só existem graças ao AMI 2.0?

Quem entende isso cedo não apenas digitaliza a rede.
Muda o jogo operacional.

#Telemedição #AMI2 #SmartGrid #UtilitiesBrasil #EnergiaDigital
#InfraestruturaCrítica #TransformaçãoDigital #DistribuiçãoElétrica
#RedesInteligentes #ResiliênciaOperacional

𝗟𝗮 𝗺𝗮𝘆𝗼𝗿 𝗽é𝗿𝗱𝗶𝗱𝗮 𝗲𝗻 𝘂𝗻𝗮 𝘂𝘁𝗶𝗹𝗶𝘁𝘆 𝗻𝗼 𝗲𝘀 𝗹𝗮 𝗲𝗻𝗲𝗿𝗴í𝗮 𝗻𝗼 𝗳𝗮𝗰𝘁𝘂𝗿𝗮𝗱𝗮.
𝗘𝘀 𝗹𝗮 𝗲𝗻𝗲𝗿𝗴í𝗮 𝗻𝗼 𝘃𝗶𝘀𝗶𝗯𝗹𝗲.
𝗬 𝗹𝗼 𝗾𝘂𝗲 𝗻𝗼 𝘀𝗲 𝘃𝗲, 𝗻𝗼 𝘀𝗲 𝗽𝘂𝗲𝗱𝗲 𝗴𝗲𝘀𝘁𝗶𝗼𝗻𝗮𝗿.

Durante años, la telemedida fue tratada como una herramienta administrativa. Hoy ese enfoque quedó corto.

En las utilities modernas, la telemedida está evolucionando hacia AMI 2.0: una infraestructura operacional digital que conecta medición, automatización, analítica y control en tiempo casi real.

𝗔𝗠𝗜 𝟮.𝟬 no conecta solo sistemas de información.
Conecta el mundo digital con la operación física de la red.

Esto ya no aplica únicamente a electricidad. También está transformando agua, saneamiento y gas.

La pregunta estratégica no es:
“¿Cuántos medidores inteligentes instalamos?”

La pregunta correcta es:
𝗤𝘂é 𝗱𝗲𝗰𝗶𝘀𝗶𝗼𝗻𝗲𝘀 𝗼𝗽𝗲𝗿𝗮𝘁𝗶𝘃𝗮𝘀 𝗵𝗼𝘆 𝗲𝘅𝗶𝘀𝘁𝗲𝗻 𝗴𝗿𝗮𝗰𝗶𝗮𝘀 𝗮 𝗔𝗠𝗜 𝟮.𝟬 𝗾𝘂𝗲 𝗮𝗻𝘁𝗲𝘀 𝗲𝗿𝗮𝗻 𝗶𝗺𝗽𝗼𝘀𝗶𝗯𝗹𝗲𝘀?

Ahí está la verdadera transformación.

As we kick off the year, it's the perfect time to plan for what's next. 

I'm excited to take the stage at DTECH® 2026 to share what's next in energy innovation.

Don't wait – register now and enjoy 20% off with code D26SPKINV. Make your 2026 kickoff count!
https://lnkd.in/d3VGdpzu

#DTECH

𝗦𝗼𝗺𝗲𝘁𝗵𝗶𝗻𝗴 𝗛𝗮𝘀 𝗖𝗵𝗮𝗻𝗴𝗲𝗱
 
I've spent the last several months studying blackout timelines across three continents.
 
What I found isn't about operator error. It isn't about underinvestment. It isn't about weather.
 
It's about how fast the physics now moves — and whether our protection and communication architectures were ever designed for it.
 
The engineers who built today's grid weren't wrong. They designed for the physics of their era.
 
𝗕𝘂𝘁 𝘁𝗵𝗲 𝗽𝗵𝘆𝘀𝗶𝗰𝘀 𝗵𝗮𝘀 𝗰𝗵𝗮𝗻𝗴𝗲𝗱.
 
More soon.
 
#GridResilience #PowerSystems #CriticalInfrastructure

Most blackout investigations focus on 𝙬𝙝𝙖𝙩 𝙛𝙖𝙞𝙡𝙚𝙙.
Very few ask 𝙝𝙤𝙬 𝙢𝙖𝙣𝙮 𝙘𝙝𝙖𝙣𝙘𝙚𝙨 𝙬𝙚 𝙖𝙘𝙩𝙪𝙖𝙡𝙡𝙮 𝙝𝙖𝙙 𝙩𝙤 𝙨𝙩𝙤𝙥 𝙞𝙩.
In cascade analysis, there’s a number most protection engineers are never forced to calculate — until after the event.
It’s not bandwidth.
It’s not coverage.
It’s not cost per site.
It’s how many coordination actions physically fit inside a cascade window — and how fast that number collapses as latency increases.
When I ran the math, the result surprised me.
The arithmetic is simple.
The implications are not.
I’ll walk through the full calculation and its consequences at DISTRIBUTECH.
📍 Room 29CD
📅 February 4, 3:00 PM
Engineering analysis only. No product pitch.
Marco Pangos
IEEE Life Senior Member

#𝗗𝗜𝗦𝗧𝗥𝗜𝗕𝗨𝗧𝗘𝗖𝗛𝟮𝟬𝟮𝟲 #𝗚𝗿𝗶𝗱𝗣𝗿𝗼𝘁𝗲𝗰𝘁𝗶𝗼𝗻 #𝗣𝗼𝘄𝗲𝗿𝗦𝘆𝘀𝘁𝗲𝗺𝘀

Most grid failures are not sudden.
 What is sudden is the moment when system physics outruns our ability to react.
This article makes a critical point: failures usually begin as small deviations that go unnoticed. AI and predictive analytics are powerful tools to surface those weak signals earlier — and that is real progress.
But recent events reveal a hard boundary. In many cases, the transition from anomaly to cascading impact unfolds in tens to hundreds of electrical cycles, far faster than human decision-making or post-analysis can intervene.
From my recent studies and field work, the lesson is clear: detection is necessary, but not sufficient. Preventing cascading outages requires protection, automation, and communications that can act deterministically, in milliseconds, aligned with the physical time of the grid.
This “80 to 800 cycles” gap — why we often see the warning signs but still react too late, and how teleprotection already available today can close it — is what I’ll be discussing at DistribuTECH 2026 in San Diego.
Detecting problems is intelligence.
 Acting in time is resilience.

Executivo em Energia | Inovação, P&D e Regulação | Transformando problemas complexos em decisão e resultado

No setor elétrico, a maior parte das falhas não nasce como um evento crítico, mas como pequenos desvios que passam despercebidos na rotina operacional. 

A detecção de anomalias com apoio de IA permite identificar esses sinais precocemente, reduzir riscos operacionais e orientar decisões com base em evidência técnica e impacto financeiro. 

Neste artigo, exploramos como essa abordagem pode ser aplicada em ativos elétricos para aumentar disponibilidade, previsibilidade e eficiência dos investimentos.

Ricardo Barbi Costa
Ricardo Fernandez
André Flávio Pereira
Ricardo Gedra
Mônica Mello Ferreira
Mônica Kronemberger
Donorvan Rodrigo Fagundes, MSc
Rômulo César Pereira
José Batista Ferreira Neto
Daliane Lanzarin
André Luís Marques MARCATO
Giovani Junqueira
Elis Mayumi Yamamoto
Alem Junior
Giovanna Oliveira Santos
Renato Nolli
Vitor Fulanetti Costa
Alessandro Miranda


#Inovação #InteligênciaArtificial #ManutençãoPreditiva #TecnologiaIndustrial #IAAplicada #InspeçãoTécnica #Indústria40

Em subestações, linhas e ativos de geração, os problemas relevantes começam de forma sutil: aquecimento anômalo em conexões, vibrações fora do padrão 

Open article: No setor elétrico, falhas raramente são eventos súbitos. Elas são desvios que não foram percebidos a tempo. by Rodrigo Cardoso Orestes • 1 min read

No setor elétrico, falhas raramente são eventos súbitos. Elas são desvios que não foram percebidos a tempo.

𝗔 𝗗𝗶𝘀𝘁𝗶𝗻𝗰𝘁𝗶𝗼𝗻 𝗪𝗲 𝗥𝗮𝗿𝗲𝗹𝘆 𝗠𝗮𝗸𝗲
 
There's a difference between seeing a grid event and stopping it.
 
Most protection and communication upgrades focus on visibility. D𝗮𝘀𝗵𝗯𝗼𝗮𝗿𝗱𝘀. 𝗔𝗹𝗮𝗿𝗺𝘀. 𝗣𝗵𝗮𝘀𝗼𝗿 𝗱𝗮𝘁𝗮. 𝗦𝗶𝘁𝘂𝗮𝘁𝗶𝗼𝗻𝗮𝗹 𝗮𝘄𝗮𝗿𝗲𝗻𝗲𝘀𝘀.
 
All essential.
 
But visibility operates on one timescale. Cascades now operate on another.
 
The gap between those two timescales is where blackouts live.
 
This isn't a technology problem. 
It isn't a training problem. 
It isn't a staffing problem.
 
𝗜𝘁'𝘀 𝗮 𝘁𝗶𝗺𝗲-𝗱𝗼𝗺𝗮𝗶𝗻 𝗽𝗿𝗼𝗯𝗹𝗲𝗺.
 
And most architectures weren't designed for the windows that now exist.
 
#PowerEngineering #GridModernization #Protection

The biggest risk to critical infrastructure is not technology.
 It is regulatory decisions that repurpose strategic spectrum without understanding system consequences.
 Once 450 MHz is fragmented, utilities don’t lose convenience — they lose resilience.

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