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Abu Dhabi and Riyadh compete for capacity

24 March 2025

Electricity generation installed capacity from renewable and nuclear energy sources is expected to overtake conventional installed capacity in Abu Dhabi by 2029.

Based on known projects that are under various stages of procurement and in line with a plan to procure 1.5GW of renewable capacity annually until the mid-2030s, as well as an assumption that the contracts for thermal capacities expiring between 2025 and 2029 will not be renewed, the UAE capital could see its total electricity generation installed capacity rise to approximately 38.5GW by 2029, up from around 22GW as of the end of 2024.

This figure includes the 5.2GW capacity from the solar photovoltaic (PV) project being built by Abu Dhabi Future Energy Company (Masdar), which is expected to come on stream in 2027. The project will supply up to 1GW of baseload capacity in tandem with a 19 gigawatt-hour battery energy storage system plant.

By 2029, the share of renewable energy is expected to reach 37% and nuclear energy 14% of total installed capacity. Capacity from gas-fired fleets is forecast to be 49%, down from 69% this year.

This scenario assumes that all projects under procurement and construction achieve commercial operations according to their timeline, that all four gas-fired fleets with a combined expiring capacity of 7.2GW are not extended, and that another 1.5GW solar PV project will be launched next year, following the Al-Zarraf solar IPP.

This further implies that at least 1.5GW of renewable energy capacity will start operating annually from 2026, and planned gas-fired power plants will be completed successively between 2027 and 2029. It precludes the launch of new thermal power projects apart from those already known or announced.

This massive capacity buildout, equivalent to between 16GW or 70% and 21GW or 94%, if the round-the-clock solar capacity is included, of its current installed capacity, requires Abu Dhabi to rapidly upgrade its grid infrastructure and deploy substantial battery energy storage capacity to ensure grid resilience and flexibility.

Competing for capacity

It also tests the capacity of developers and engineering, procurement and construction (EPC) contractors, which are equally beholden to pursue new contracts in Saudi Arabia.

The kingdom faces a pending deadline to decommission ageing liquid fuel-fired plants as part of an overall energy transition plan for its electricity sector. It aspires to procure 20GW of renewable energy capacity annually until 2030 "subject to demand growth", and have renewable sources account for half its electricity generation capacity at the end of the forecast period.

According to MEED Projects and MEED data, Saudi Arabia entered what could be the busiest period for power generation capacity buildout in its history this year, with over 50GW of power generation projects under construction, or about to start construction.

This is equivalent to over a quarter of its current installed capacity, which will also require a 60% expansion of its electricity grid coverage. 

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The scale and volume of contracts in both jurisdictions are a positive development for many developers and contractors, following a major slowdown in the years before and after the Covid-19 pandemic.

Even those extremely cautious about solar PV projects' ability to deliver desired profits, or those obliged to say no to thermal projects that do not offer a clear carbon capture path, can pivot to the rapidly expanding battery energy storage projects or, indeed, the potential hydropower projects in Neom in Saudi Arabia.

Retreating bidders 

It must be noted, however, that several international utility developers are shifting their geographical focus away from the region and have expressed a desire not to compete in the upcoming tenders for power generation projects.

As a result, the latest tenders in Riyadh and Abu Dhabi generally received fewer-than-expected bids. This trend may continue due to distinct factors affecting each fuel type.

“The volume of utility-scale gas projects is outstripping the availability of credible developers,” notes a senior executive with an advisory firm in the UAE. “Either they are already overloaded, withdrawing from the gas market, or uninterested in a particular country.”

Another key issue for developers and EPC contractors, regardless of the location of these projects, is the gas turbine original equipment manufacturer (OEM) gridlock, which affects delivery time and prices.

In general, top OEM manufacturers are caught between two choices: expand their capacity to accommodate rising demand and secure substantial cash flow going forward, or ignore the short to medium-term demand and eliminate the risk of building capacity that may be stranded beyond 2030, when clients may stop procuring new gas utility plants.

On the other hand, interest in renewables may remain intact, subject to improving returns prospects, another expert tells MEED.

Nonetheless, these developments translate to significant opportunities, particularly for local developers, EPC contractors and other OEM manufacturers – such as Italy's Ansaldo Energia – which have remained on the fringes of the region's utility power projects markets for many years.

Chinese firms that previously only focused on EPC, for instance, are gradually stepping up to the role of utility developers, which can help ensure that the region's offtakers continue to secure world-record-low tariffs for future projects.

This, however, may also seal the decisions by more established developers to exit the region for good.

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Jennifer Aguinaldo

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