The digitalization of the energy industry is advancing rapidly, and smart metering is at the heart of it. The constant challenge is to ensure that operations are not only secure and flexible, but also reliable and resource efficient. The motto is thereby: after the rollout is before the rollout. A key component in meeting these requirements — and one that more and more energy utilities are opting for — is optimizing the IT infrastructure by switching from an on-prem to a Software-as-a-Service (SaaS) cloud-based solution. Moving to a SaaS solution is not just about transitioning from on-premises systems, it's about embracing a comprehensive model that enables energy utilities to leverage new capabilities and maximize the benefits of smart metering solutions and the data they collect. SaaS adoption across EMEA is accelerating, with the market projected to reach $102.84 billion by 2025 and growing at an annual rate of 19.17%[1]. Similarly, 54% of companies in EMEA have already adopted cloud solutions in most parts of their business[2]. In the utilities sector, 75.3% of enterprises are highly dependent on cloud services[3]. However, the shortage of cloud specialists is a significant challenge, making it crucial for organizations to invest in training and strategic hiring.
Is your grid ready to handle the unpredictable demands of tomorrow? As the energy landscape shifts, the integration of renewable sources like wind and solar is no longer a choice but a necessity. Yet, these sources bring variability, requiring a grid that can adapt in real-time. This is where Head-End Systems (HES) step in, acting as the backbone that supports not only today's grid operations but also the future needs of an increasingly complex energy infrastructure.
The power grid is becoming increasingly complex due to the integration of municipal utilities, renewable energy resources, new substations and millions of smart grid edges like smart meters and EV-charging stations. The majority of this electric infrastructure is located far away from the central control room. Therefore, control is increasingly carried out digitally via remote access. To secure these peripheral systems, distribution and transmission system operators often rely exclusively on firewalls. These might reliably detect known malware. However, with several hundred of thousands of new malware variants each day, cybersecurity limited to identifying known signatures becomes highly unreliable.
How much of this US$3.1 trillion is yours?
The whopping figure covers energy companies’ investments in grid expansions between now and 2030. Part of the costs will likely fall to energy companies and their customers.
Flexibility is key to lowering that number – and your contribution toward it.
Hands down, by now there are probably a trillion articles offering advice on how to “get ready for NIS2” (just do a search in your search engine of choice). Some contain sensible tips, most simply re-list the requirements of the updated Network and Information Security directive and leave the reader in limbo.
Still, even just 1.5 months away from the EU's NIS2 directive turning into national law, many customers in the electrical sector we speak to have difficulties getting their heads around the full impact of NIS2. In particular, the extension of thorough cybersecurity to the OT networks of their grid infrastructure causes headaches. For many electric and multi-utilities this is still new territory with many blind spots and unknown challenges.
The NIS2 directive requires owners and operators of electric and multi-utilities to include their OT networks in risk management procedures and risk analysis. The target is to determine the risk exposure of their critical processes and define appropriate mitigation measures. And this is for good reason, as the results of our vulnerability assessments at IOUs, municipal as well as public utilities highlight.
