Good morning. Thanks for attending EDP's 2025 results conference call.

We have today with us our CEO, Miguel Stilwell d'Andrade, and our CFO, Rui Teixeira, which will present you the main highlights of our strategy execution and 2025 financial performance. We'll then move to the Q&A session in which we'll be taking your questions, starting with written questions that you can insert from now onwards at our webcast platform, and then by phone.

I'll give now the floor to our CEO, Miguel Stilwell d'Andrade.

Thank you, Miguel. Good morning, everyone, and welcome to the 2025 results conference call.

Just before presenting our results, and as yesterday, I just wanted to address the extreme weather events that impacted Portugal. As Portugal was hit by a series of devastating storms starting at the end of January and then well into February, which at a certain point had winds over 200 km/h, and which really caused unprecedented physical damage to infrastructure in the country, including our own network infrastructure, and also customers.

I think the first thing to say is that we immediately responded with a very coordinated and large-scale support from all the internal and external teams. We had people coming in from Spain, Brazil, France, and Ireland, and I just wanted to thank also all those teams.

The networks and the hydropower teams worked round the clock to limit the damage caused by the storms and to restore power to all consumers. Now, naturally, the first thing is our thoughts are with the people and the communities affected.

We understand the damage that this has caused, the frustration from people that had no power over those weeks. From the beginning, our first priority was to reestablish power in the quickest, safest, and the most effective way possible.

We have now recovered 100% of the customers, only a very few specific situations outstanding that will be resolved very shortly, but I think the worst is definitely over. I also wanted to extend a really sincere word of appreciation for the absolutely extraordinary professionalism and dedication demonstrated by the teams, both internal and external, across all the country.

Their response from grid repair to the hydropower management, the community support, emergency logistics, it was absolutely exemplary. I think it really showed the best of EDP in terms of the commitment to stand with our customers and with the communities that we serve, especially in the moments where they need us most.

I will come back to this later in the presentation just to talk a little bit about the impact on us in more detail, but I would move now into the bulk of the presentation and on to slide three, which essentially shows an overview of our results for 2025. I'd start off by saying EDP had a very strong set of results for 2025.

The recurring EBITDA reached €5 billion, outperformed the €4.9 billion guidance. It's mostly on the back of a better-than-expected fourth quarter in the integrated segment in Iberia from above-average hydro resources in the fourth quarter.

If we compare that with 2024, EBITDA was up 1% year-on-year, reflected a rebound in EDPR's performance, which has had record capacity additions towards the end of last year. Recurring net profit came in at €1.3 billion, also above the guidance, although it's down 8% versus 2024, and that's mostly explained by higher financial expenses.

Net debt ended the year very well, at €15.4 billion, better than the €16 billion guidance. That led us to have a great FFO over net debt of 21% compared with a 19% guided.

The upside versus guidance at all levels allowed us to then increase the shareholder return. We're proposing a dividend of 20.5 cents per share.

That's a small increase, which will be paid this year already in 2026, obviously subject to the General Shareholders' Meeting approval. If we move forward into the next slide to talk a little bit more detailed about the flexgen and customers.

Here we see a structural uplift in the value of flexibility. I really wanted to highlight if you see here on the left-hand side, there's a chart from the International Energy Agency recently, and it shows the capture rates in Spain by technology.

It shows how the market's increasingly rewarding assets that can respond to price volatility and the system needs. You can see natural gas capture prices obviously rising in 2024 and '25, hydro with reservoir also trending upwards, and more intermittent and less flexible technologies, particularly solar, you see obviously a decline in capture rates in 2025.

The takeaway here is that flexibility is being structurally priced in, and that we expect that to remain a long-term feature of the market. You can see that in the figures for EDP for 2025.

The hydro net generation was almost 10 TWh. That's down 2% year-on-year, but still a very strong year for that.

Hydro premium versus baseload increased to 21%, reinforcing the value of the flexible output. On pumped hydro, the pumping volumes increased to 2.3 TWh on the year, up 24% year-on-year, with the pumping spread versus baseload reaching 75%.

If you look at the right-hand side of the slide, and it gives there an update on the reservoir levels in 2026. Given the heavy rainfall, reservoir levels are at historically all-time highs.

They've reached around 96% in February 2026, up from roughly 76% in January. That's consistent also with the hydro production index in Portugal, which has doubled its historical average year to date.

Obviously that's following the heavy storms, which I just talked about in Portugal in January and February. One important thing to note is that the market consequence of these extreme weather conditions is that we also had abnormally depressed pool prices, which, together with higher ancillary services costs in February, it's shown by the Portuguese pool prices going from around €71/MWh in January to roughly €8/MWh until mid-February.

More depressed pool prices in February and higher ancillary service costs. If we move forward to the next slide, and just in a little bit more detail on the storms here in Portugal the first half of February essentially.

First, as I mentioned, just highlighting the efforts made by the team, huge effort done to restore power and to make sure that the dams and that the flooding was limited. The storms impacted around 6,000 km of grid, damaged around 5,800 towers.

We had more than 2,000 people mobilized on the ground, around 2,400 people. As I said, we were able to restore 100% of the customers already by this week.

On hydro, we continuously monitored the rainfall, and I think here is great to see using the advanced hydrological model, we were able to proactively or sort of anticipate what was coming down the road and to be able to also anticipate some of the discharges and coordinated that with the environmental authorities. I think there was a meaningful role in flood control.

Then on the more practical side, with customers and communities, we have put in place schemes to ensure the payment and invoicing support for the customers impacted, as well as assistance with the solar DG reinstallations. On a more social level, we also delivered over 90 tons of essential materials, including sand, roofing tiles, tarpaulins, basically to help people protect their homes.

Obviously, we also helped people in more isolated areas get access to communications, including Starlink devices and power banks. In terms of financial impacts, we're expecting that this will result in around €80 million in capex of infrastructure to rebuild, will be partially supported by insurance.

We're still evaluating additional costs and impacts, and we'll update that in the first-quarter results. Clearly shows increasing vulnerability that climate change is causing, and the importance above all of resilient, flexible systems and long-term investment in networks.

That takes me to the next slide, where I wanted to just stress that already before these events, so as of last year, we were already significantly ramping up the investment to respond to the growing needs of the system. The electrification, the renewables integration, the grid resilience.

Gross investments for the period '26 to 2030 will reach €4.1 billion compared to the €2.6 billion in the '21 to '25 period. That's a 58% increase overall in Iberia, slightly more in Portugal than in Spain, although both geographies are contributing significantly to this.

In Portugal, it's around 66%, almost 70% increase. A big part of this is strengthening grid resilience.

We're assuming around or more than €500 million for grid resilience to ensure that the network is prepared for higher loads, more distributed generation, and greater system complexity. Fortunately, this greater investment is underpinned by much stronger regulatory visibility, as we showed here on the right-hand side.

As the new regulatory framework sets out the 6.7 nominal pretax return for this period till 2029 in Portugal. In Spain, the framework establishes the 6.58% return for the period out till 2031.

Importantly, both frameworks closed as of the end of last year, giving us clarity and stability for the upcoming investment cycle. I think it's also important to note that in Portugal, the 2026 state budget clarifies the conditions under which new investments in networks are exempted from the extraordinary tax.

That supports really this incremental investment that we're doing in the networks. Still on networks, if we move forward to the next slide, can see that the new regulatory terms and approval plans will allow an EBITDA growth in Iberia for networks, it grows to around over €1 billion over this period.

We have to consider that in this period in Portugal, their legacy revenues that end in 2026, worth around €40 million. Removing that means that we'd have a normalized 2025 EBITDA of around €0.89 billion, and that then reaches the 1.05 billion in 2028.

That's an 18% EBITDA growth for '25 to '28, updated already with the new terms. This isn't just a one-off step to 2028, this then continues to grow beyond 2028, and that's supported by the approved returns and also the investment plans that we discussed on the previous slide.

All of this gives us confidence in the continued momentum well beyond 2028 to 2030 and beyond that. If we move on to the next slide and just talking quickly about Iberia, I think what I'd say here is that Iberia is entering a period of much stronger electricity demand growth and driven by electrification.

On the left, you can see the power demand growth in 2025 versus '24. Portugal leads at 3.6%, Spain at 2.8%, which means Iberia clearly outperforming several other European markets.

It's not just a one-year effect, obviously we're seeing strong momentum into 2026. Just in January, the demand was 7.9% in Portugal and 4.8% in Spain, already adjusted for temperature.

Going forward, we see our estimated 2% CAGR in the Iberian electricity demand over the period leading up to 2030. Demand growth should be supported overall not just by the economy is doing well, but by more than 18 GW of data center projects pipeline that have been announced or that are publicly available.

I'd have to highlight here that EDP is obviously engaging with a lot of these projects, two of the more advanced ones that certainly here in Portugal are the Merlin data center north of Lisbon at 180 MW. We had an MOU signed with them back in July of 2025.

Also the Start Campus project in Sines, with an MOU that we signed yesterday. The Sines project, as is expected to reach 1.2 GW over the next couple of years.

I can detail a little bit more of what that means in the Q&A if you think that's appropriate. If we move forward still to talking about Iberia, and this is a slide which I think is also extremely important because it's not just about demand growth, it's also that Iberia combines this demand growth with structurally affordable power prices.

That's supported by improving system fundamentals. That's really an important advantage for customers, for electrification, for the broader competitiveness of the economy.

When there's so much talk in Europe and elsewhere about affordability and about competitiveness, Iberia has a really distinctive advantage in Europe, and I think we will benefit from that sort of on the electrification front. On the left-hand side, you can see the evolution of the B2C electricity prices.

The key takeaway is that Portugal and Spain sit among the most affordable markets in Europe, around 17% below the European average. Going forward, at the European level, Northern Europe faces higher expected network investments that typically puts upward pressure on the end-user prices over time.

By contrast, in Portugal and Spain, we have several structural elements that we think will support the affordability. One is that the historical electricity system debt is expected to be fully paid by 2028.

That means that there'll be significant cost reductions in the tariff structure going forward. Second, there's a gradual phaseout of legacy support schemes like the feed-in tariffs in Portugal and the RECORE scheme in Spain, that also reduces access tariff costs.

In Portugal specifically, the regulator, ERSE, has simulated annualized reductions in the B2C reference end-user tariffs from 2026 to 2030. That helps create room to accommodate new system needs like ancillary services, capacity mechanisms, additional investments in networks, without compromising competitiveness.

I think we are able to get the best of both worlds, which is more investment, more ancillary services, more capacity mechanisms to make sure that we have a stronger, more resilient system and still have sort of annualized reductions in the end-user tariffs. Moving on to EDPR, again, you had more detail on that yesterday, just a quick note here.

We are seeing really strong execution momentum and better visibility on the business plan delivery. Over the last 6 months, EDPR secured 1.3 GW of capacity.

On the left-hand side, you can see the main projects secured during this period. It's a combination of PPAs with utilities, global tech companies.

We also have build-and-transfer agreements in the US, it's really a diversified set of offtakers and structures. Across the '26 to '28 period, we already have 2.8 GW secured, and we expect to continue on securing more projects over the coming weeks and months.

If we break it down year by year, 2026 is already 100% secured, almost all of that under construction, a couple of projects coming into construction in the very short term. That gives us very good confidence on the 2026.

2027 is already 65% secured, and 2028 is at 10% secured. That gives us roughly already 55% secured for '26 to '28.

As I say, we have good visibility on additional projects that are coming down the pipeline to help us meet the rest of these projects. With that, I'd stop here.

I pass it over to Rui to go through the '25 results in more detail, and I'll come back for closing remarks. Thank you.

Thank you, Miguel, and good morning to you all. Let me start with the EDP's results.

Recurring EBITDA reached €5.03 billion in 2025. It's up 1%.

If we exclude asset rotation gains and FX, the underlying growth was 7% year-on-year, driven by a strong EDPR performance and resilient network space. Looking at the recurring figures by segment, Renewables, Client and Energy Management increased by €65 million year-on-year, reaching €3.4 billion, and now represent 69% of group EBITDA.

Within this segment, the Hydro, Clients and Energy Management declined €260 million year-on-year, mainly reflecting the normalization of gas sourcing conditions in Iberia versus the extraordinary environment that we had in 2024. This was more than offset by strong EDPR performance, up €390 million year-on-year, reflecting 2024 record additions translating into higher generation.

On the Networks side, recurring EBITDA stood at €1.54 billion, now representing 31% of group EBITDA. While EBITDA decreased €68 million year-on-year, this is mainly explained by Brazil FX impact and the absence of capital gains.

Again, excluding FX and asset rotation, the underlying networks EBITDA increased 3%, supported by a positive performance in Iberia, both from regulatory framework and reinforced operating discipline. Finally, recurring opex decreased 2% year-on-year, or 5% in real terms, reinforcing also the operational discipline, which I will detail in the next slide.

If you look to the opex, this slide highlights an important enabler of our EBITDA performance, which is sustained cost discipline. Recurring opex decreased 1% to €1.88 billion, trending down year by year, a total reduction of around €160 million in '25 versus '23.

Over the last 12 months, inflation was around 3%, and yet, we still delivered a 2% nominal reduction in recurring opex. Excluding FX, opex is slightly below, which means that we are effectively absorbing inflation through efficiency and productivity gains.

This is translating into improved efficiency ratios. Opex as a share of gross profit improved from 28% in '23 down to 26% in '25.

Key drivers for this: EDPR delivering efficiency growth, we're reducing adjusted opex per megawatt by 12% year-on-year to €40,000/MW, this while scaling capacity; a leaner, more focused workforce aligned with the company's growth priorities; digital and AI-driven initiatives to improve O&M efficiency, decision-making, customer experience. I think the message is very clear.

We are growing and investing while structurally improving the cost base. Obviously, this supports cash generation as we deliver the plan.

Now let me move to FlexGen and client segments. EBITDA for '25 stood at €1.46 billion, this is down 13% year-on-year, and this reflects the normalization versus an extraordinary 2024, but also flexibility revenues structurally increasing.

In Iberia, 2024, as was impacted by extraordinary gas sourcing costs. 2025, baseload hedging price normalized from €90/MWh to €70/MWh.

However, this was partially offset by stronger flexible generation revenues: pumping generation increasing by 24%, pumping spreads reaching 75% over baseload prices, hydro premium improving to 21%, and CCGT generation increasing by approximately 3 TWh, reflecting the system operator needs. In Brazil, EBITDA declined from €184 million to €156 million, mainly due to forex impact.

Overall, while the headline EBITDA reflects normalization, the structural uplift in flexibility was very solid, with €0.3 billion contribution to overall group. Now we move to slide 15, turning to EDPR, which we also commented yesterday's call.

Recurring underlying EBITDA, ex-forex, grew by 27% year-on-year. This growth, very robust growth, reflects a significant step-up in the generation following the record capacity additions in '24, offsetting worse renewable resources and also normalization of selling prices, primarily in Europe.

Overall, EDPR continues to deliver strong operational momentum and translate capacity growth into earnings growth. Now looking at the Networks EBITDA on slide 16.

Recurring EBITDA reached €1.54 billion in 2025, representing a 4% decrease year-on-year, but this is primarily explained by devaluation of the Brazilian real, the absence of asset rotation gains in Brazil, which amounted to €71 million in '24, combination of deconsolidation of transmission assets, the decrease on the distribution company's residual value update, and on transmission inflation update. This is compensated overall by improving operating performance.

Again, excluding FX and asset rotation, underlying EBITDA increased 3%. It has an important contribution of €56 million in EBITDA from Iberia, following inflation update in Portugal and RAB growth overall.

All in all, the network segment is showing a resilient operational performance with very supportive regulatory frameworks, as Miguel just described, going into the future. On financial costs, following slide.

Net financial costs increased from €865 million to €989 million. There are two main drivers to this.

The first one is that net interest costs, which add about €54 million, they reflect higher average debt and a higher cost of debt in Brazilian reals, where the average cost rose from 11.7% to 14.1%, reflecting the macro conditions in the country. Excluding Brazil, the average cost of debt reduced to 3.3%.

Second, lower capitalizations and other effects, contributing with an additional €69 million. This is largely explained by the €1.2 billion reduction in works in progress as projects entered operation, and therefore reducing capitalizing interest.

If you look to the right-hand side, average nominal debt by currency remains broadly stable year-on-year. The portfolio continues to be predominantly euro-denominated with 64%, followed by US dollar, 16%, and Brazilian real at 15%.

Finally, in terms of recent financing activity, we issued a 6-year senior bond, €650 million in January with a 3.25% coupon, this confirms the competitive access of EDP to funding in the debt markets. Now let's move to the cash flow on the following slide.

Organic cash flow reached €3.3 billion, up €0.5 billion year-on-year, driven by EBITDA improvement and working capital management. Net interest paid amount to €0.8 billion, partially offsetting operating improvement.

On investments, gross investments totaled €3.9 billion, mainly €2.4 billion in EDPR and €1.1 billion in electricity networks, also €0.4 billion in FlexGen and clients. These gross investments were funded through €1.6 billion of asset rotation and €0.8 billion of tax equity proceeds.

There are also €0.5 billion of other impacts, mainly related with payments to fixed asset suppliers. As a result, a total of €1.7 billion of net cash investments, of which close to 50% in electricity networks and around 40% in EDPR.

Now on slide 19, net debt stood at €15.4 billion, down from €15.6 billion at the end of 2024, and outperforming the €16 billion guidance that we gave to the market. The key drivers for the change in net debt include €3.3 billion of organic cash flow, obviously the €0.8 billion of dividend annual payment and €100 million share buyback throughout '25, the €1.7 billion of net cash investments that I just explained, also €0.8 billion of regulatory receivables, and about €0.3 billion from FX and other, mostly related to US-denominated debt.

As a result of cash flow management, balance sheet discipline, and obviously very strong operational cash flow, we do have solid credit metrics, with 20.9% FFO to net debt and 3.3 times net debt to EBITDA. Now on the net profit.

Net profit reached €1.28 billion, that's a reduction of 8% year-on-year, and this is mostly reflected or driven by the higher EBITDA, €74 million; higher D&A and provisions, increasing €60 million year-on-year, reflecting the investment path; higher net financial costs due to higher cost of debt and lower capitalizations; slightly higher income taxes; and lower non-controlling interests. Excluding asset rotation gains and the forex, the underlying net profit increased 3%, confirming a very solid operational performance as we just described.

Reported terms, net profit reached €1.15 billion, including the negative impact of €130 million, mostly related with some non-recurring items in EDPR. Year-on-year, reported net profit therefore increased 44%, also driven by EDPR performance rebound compared to a negative 2024.

This improvement in net profit supports our proposal to increase the dividend to 20.5 cents per share, up 2.5% versus the guidance, to be paid in 2026, obviously subject to the approval at the Shareholders' Meeting. Now let me just address a topic which I think is relevant regarding the net income sensitivity to power prices versus what we presented at the CMD.

On this slide, just again to remind everybody, our exposure to energy markets is well-diversified. As we have a very active energy management.

The portfolio is predominantly long-term contracted. This provides strong cash flow visibility and obviously reduces short-term impact from price volatility.

In Iberia and Brazil, we have a structural short position in generation, which is hedged through our supply business, partially offsetting wholesale price movements. At the CMD, we disclosed that a simultaneous €5/MWh movement in all markets would imply approximately €60 million impact on 2028 net income.

Since then, Iberia 2028 forwards have declined around €10/MWh, but on the other hand, US and Brazil forward curves are moving upwards. This portfolio diversification plus an active energy management have actually reduced the sensitivity.

Today, the same €5/MWh movement across all markets in the same direction would imply approximately €45 million impact on net income 2028, again versus the €60 million that we presented at the CMD, a reduction on the sensitivity. The merchant exposure split is about 65% Europe, 20% Brazil, and 15% North America.

With this, I would hand over to Miguel for final remarks. Thank you.

Thank you, Rui. As you say, I think this issue on the sensitivity to power prices is an important point to note, because I know there are questions on that.

Anyway, if we move forward to the final slide, just before we open it up for Q&A. Summarizing the 2025 results and how we're seeing '26 and beyond.

First, in relation to '25, I think it's undeniable that it was very strong execution and delivery of what we promised. Across the group, we delivered ahead of guidance, and we're seeing a clear structural change in flexgen and clients, with the value of flexibility coming through very strongly.

At the same time, EDPR also improved its performance, has its continued focus on A-rated markets, it's got better visibility on the business plan execution. In networks, we have significantly improved visibility, with the regulatory periods closed in Portugal and Spain, and we also advanced in Brazil with the extension of the concessions.

Importantly, all of this was delivered with financial discipline, increased efficiency, and as Rui spoke about, particularly on the cost side, but also on the debt side, supporting the maintenance of sound credit ratios. Second, looking at the 2026 guidance, we expect recurring EBITDA of around €4.9 to €5 billion, and this is supported by the balanced contribution across the portfolio.

We have the networks around €1.5 to €1.6 billion, EDPR at around €2.1 billion, as mentioned yesterday, flexgen and clients at around €1.3 to €1.4 billion, and we reaffirm our recurring net profit of €1.2 to €1.3 billion. On the 2028 targets, over the course of the next couple of years, we continue to expect around €12 billion of gross investments, and as I say, this will be funded with discipline and supported by around €6 billion of asset rotations and disposals.

We'll keep our balance sheet targets unchanged, we're targeting FFO over net debt of around 22%. In terms of earnings delivery, we remain committed to the €5.2 billion of recurring EBITDA and the €1.3 billion of recurring net profit by 2028.

Overall, the message is consistent: we executed strongly in 2025, we have very clear visibility for '26, and we are reiterating our 2028 guidance. With that, happy to turn it over to Q&A, and back to you, Miguel.

Thanks.

Thank you. We start with the written questions, and we have a first question from Fernando Garcia, RBC, and other analysts, JB Capital, Deutsche Bank, CaixaBank, regarding the guidance for 2026 that we provide.

We are guiding a stable EBITDA versus what we presented at CMD, while at EDPR, there was a slight vision. If we can explain these in detail, these updates of guidance.

Sure. As I mentioned, I think 2026, we're very comfortable with it.

A couple of points that have improved since the Capital Markets Day last November. The regulated rate of return for the distribution in Portugal was better than the initial proposal, so that was an upside.

The clawback was suspended as of December, and previously, we're assuming that we would have that over the next couple of years, so that's also a positive. January and February saw obviously very strong hydro inflows, and I showed you the numbers in terms of how the reservoirs are there, sort of all-time highs, full capacity there, good visibility also the next couple of months in terms of hydro.

On slightly negative, low wholesale prices in February and higher than normal ancillary services in terms of supply, also some transmission grid restrictions due to the storms, still being fixed, so that's on the negative side. We are expecting these to decline over the next couple of months, and also the wholesale prices in Iberia to normalize again also over the next couple of months.

On FX, we have a slightly lower dollar versus the euro, as we commented yesterday on the EDPR level, but on the other hand, we're seeing a positive rebound of the Brazilian real. We're now seeing 6 reais per euro versus our business plan assumptions of 6.6 reais per euro for 2026.

Quite a few positives, a couple of negatives, but all in, quite frankly, we feel very confident with the 2026 guidance.

We have then a second question about net debt, what contributed to the positive deviation of our net debt figure in 2025, the €15.4 billion versus the €16 billion guidance that we have provided, and also a question around the update for net debt expected evolution over 2026.

Thank you, Miguel. Q4 was very good in terms of operational cash flow, strong contribution from the integrated segment in Iberia.

That's the first one. Obviously, there is some impact from working capital that will see then reverting now in 2026.

What I would say is that, first of all, 2026, we are looking at around €16 billion of net debt towards the year-end. Typically, as we have during the first half a rise in net debt coming either from this working capital, also bear in mind that we had the Greek transaction, but also dividend payments in the second quarter, and then as we start having also the cash in from asset rotation, tax equity proceeds towards the end of the year, it tends to go down again.

That's why we are looking at around the €16 billion by 2026.

We have then a question around the news of yesterday regarding memorandum of understanding with Start Campus, what does it mean for EDP and these engagement? Questions from Alex, Bank of America; Fernando Garcia, RBC.

Sure. It's an interesting step.

I think it's one of many we've been taking. The MOU is just an interest of both parties to explore the synergies between their activities.

Obviously, we are experts on the energy side and them on the infrastructure side. I'd say there are essentially three parts to the MOU.

I think the first is for EDP to be considered a strategic energy partner to the Start Campus project, whether it's through power supply as is or through additionality of projects sort of as the Start Campus infrastructure continues to be built out. The second is just synergies between the Sines data campus center or project and the infrastructure that we already manage, for example, on the Sines power plant, so, for example, on the water side in terms of cooling.

The third is really potential collaboration for other data centers in Portugal that Start Campus might want to develop, leveraging on EDP's assets and capabilities. We have land and generation assets that we own in Portugal, and so explore potential collaborations.

I think above all, it's opening up the possibility for creating additional value from our existing assets and operations, as well as getting additional visibility on future demand volumes, which could support the development of a sizable pipeline of renewable energy projects, as we've discussed in the past. Overall, it's just I think a step, one of many that we expect to take in this area.

We have then also a question from Pedro Alves, CaixaBank, regarding the effective tax rate evolution, from the 28% in 2025, and also explaining the 28% and how we see the evolution for '26.

Thank you. So 2025 28% tax rate was primarily driven by the fact that we had lower asset rotation gains and some costs that are not tax-deductible, and that what basically impacted the rate.

If you think about 2026, you could consider sort of a low 20s. This because we expect again to increase the asset rotation gains from the transactions, and also the declining tax rate in Portugal, which, as will be dropping by 1 percentage point every year until 2028.

So '26, around the low 20s.

We have then a question from Pedro Alves from CaixaBank regarding if we can explain a little bit better the inflation update in terms of the impact in our EBITDA in Brazilian networks in 2025, and how do we see it evolving for '26-'28.

Sure. In '25, we had the extension of the concession in Espírito Santo for another 30 years.

We expect to have that extension as well for São Paulo, as it's being sort of approved by the regulator, we're just pending final signature in the next couple of weeks. There's a positive impact from the inflation update of this residual value, which existed in '25, which becomes immaterial from 2026 onwards.

To be specific, in '25, in the electricity networks in Brazil, we had around €70 million of EBITDA from inflation updates in both the distribution companies and the transmission companies. We had around €20 million from EBITDA from the two transmission lines that we then sold in the fourth quarter of 2025.

The impact of this inflation update in the networks has declined in 2025 already versus '24, but in 20 in '26, it will be immaterial. I think it's important to note the following.

We are under discussion with ANEEL and which is the regulator in Brazil, we and the other distributors, but we're more advanced in this process because we're the first ones to have our concessions renewed, to change the recognition of investment in the company's asset base. As I mentioned, I think, at the Capital Markets Day, and I'll just reiterate, they're currently only recognized every 5 years with tariff revisions.

There's still no conclusion, but we see a positive sign that at least the regulator is willing to consider this. That would allow us to have this inter-cycle recognition of investments rather than having to wait for the end of the regulatory period.

That's work in progress. We're certainly very committed to it, and we think others will be as well as soon as they start seeing their concessions being renewed as well.

We have a question from Jorge Alonso from Bernstein also regarding the current power price environment. How confident are we to maintain our 2028 guidance, and regarding the assumptions that we provided at CMD and the current forwards, how do we see the guidance for '28?

As I also briefly explained with that slide on sensitivity, effectively, we do have structurally short positions in generation in both Iberia and Brazil. This we hedge primarily through our clients' business, but we also have a very active energy management.

Then on the rest of the other markets, we have from an EDPR standpoint, 85% is actually long-term contracted. On this, basically what we have done since the CMD is obviously to increase the hedging.

They have been working actively on the hedging and energy management. For 2026, 85% of the volumes are hedged at a price which is north of €64/MWh.

For '27-'28, we have about 50% of baseload volumes hedged above the current forward prices. Obviously, this gives us stability and predictability versus the changes in the forward curves.

Also on the other markets, US, the exposure is mostly concentrated in PJM and MISO. We are seeing forward prices going up by around $5/MWh.

Also in Brazil, where we have lower exposure, but still relevant, the PLD has been rising significantly since the CMD. That's why all in all, again, this portfolio diversification, the very active energy management, is giving us confidence towards the 2028 guidance.

More importantly, as I've said, we actually reduced the portfolio exposure to these price movements. At the CMD, in November, we were estimating around €60 million, and now we are looking at a substantially lower number.

We have now questions from Manuel Palomo, BNP: what is your take about increasing concerns about affordability and the approval of the energy decree to reduce prices by the Italian government, and if we could expect any contagion effect?

I think this is an important point. Just to take a step back, I think we are all focused on competitiveness of the economy, and what's good for the overall economy is good for the companies.

As I mentioned, most of our exposure is in Iberia, and we specifically put up a slide which showed that in Iberia, Portugal and Spain, we already have some of the lowest prices in Europe, and they are expected to even trend lower as some of the existing costs in the system come to an end, like the tariff deficit payments, which are being amortized, and like the feed-in tariffs, for example. It's already much lower than the rest of Europe and trending lower.

Affordability and competitiveness, I think in Iberia, is actually a positive, and it means they can take additional investment, they can take sort of some of the ancillary services without impacting the affordability. On the Italian case, I think it still has to go through, be, let's say, finally promulgated, and I'm sure it'll have a lot of discussion at the European level.

Conceptually sort of understand, but disagree with what it's doing. There's been a lot of discussion already 2 years ago about market design, about how to make things competitive, make the wholesale market work differently, and ultimately, it always comes back to the marginal price system is the system that works best.

CO2 has to be internalized, and that continues to be a key priority for Europe. Listen, it's something to watch, but we don't expect it to have any material impact in Iberia.

We move now to the questions on the phone, and we start for the first question that comes from the line of Fernando Garcia from Royal Bank of Canada. Fernando, please go ahead.

Good morning, thank you for the presentation and for taking my follow-up question. I am curious because I am seeing a significant increase in CCGTs output in Portugal, and this despite the strong hydro and wind output so far in the year, particularly in February.

My question here is, is this explained by the elimination of the Portuguese clawback, and if this could be a potential upside to your estimated positive impact? I think you mentioned €25 million for 2026.

Thank you.

Hi, Fernando. You're right, the CCGT output has increased.

The ancillary services means the system operators wanted to keep these working sort of as backup to the system. There's already this trend, following the blackout of last year, and then started to decrease.

Now it's increased significantly because of some specific issues here in Portugal relating to all the storms that happened and sort of the disruption to the network. I wouldn't say it's an upside, probably it's a downside in the sense that higher ancillary costs would have a knock-on impact if they're not passed onto the suppliers.

Anyway, it's something to watch. We expect this to normalize over the next couple of weeks, but it's basically the CCGTs working overtime basically over the month of February.

Thank you, Fernando. We have a final question from the line of Alberto Gandolfi from Goldman Sachs.

Alberto, please go ahead.

Miguel, thank you and good morning. My first question is, I wanted to ask you about Brazil.

Is it a region where you think you might be growing exposure, there are potentially assets for sale, you're happy with the status quo, or is it something that given the better returns in Portugal and the clarity in Spanish networks, you might think about deemphasizing a little bit? The second question is a clarification on slide 21.

Am I right in saying that the €45 million impact on net income is therefore adjusted for 50% hedging? In other words, without hedging, do we just double the €45 million, can you maybe help us on that a little bit?

Last one, on these data center opportunities, seems you're very active in this booming Portuguese market. Can I ask you if you are planning to build potential incremental capacity if you were to sign a PPA there, or would it be from existing, and would it be done at EDP or EDPR level if it were to happen?

Thank you so much. Hi,

Alberto. Good questions.

I think in relation to Brazil, listen, we have a long track record in Brazil over 30 years. I think we have a great business there.

We continue to look at opportunities for growth there, to the extent that it makes sense within the overall Brazilian exposure that sort of cap that we've always talked about. Obviously, we continue to see how best to allocate capital, and so we've sold assets in Brazil in the past.

Even recently, we did the asset rotations of transmission lines, we sold the hydro. We will continue to adjust and fine-tune our exposure to Brazil, and obviously reallocate capital to wherever we think is best at any particular time, whether it's Europe or the US at the moment.

I'd say that we like having this diversification of geographies because it does allow us to allocate capital quite well depending on the different cycles and the different geographies. On the third question, and then I'll let Rui take the second question.

On the third question, essentially what we're saying is that there's a certain amount of power that can probably be supplied just as is because there's sufficient reserve margin in the system to be able to supply these data centers without necessarily having to go and build new power plants, and so that's a positive, I think, for the system. We just need to make sure the networks are there, but that's essentially the key issue, because as long as there's reserve margin, you can feed it.

If the demand then starts getting above a certain level, and if you start having Start Campus and Merlin and others, then yes, then we need to think about incremental capacity of different technologies. Then depending on what that incremental technology is, if it's renewables, it will definitely be done through EDP Renewables, which has the exclusivity for renewable development, well, certainly in Iberia, but elsewhere in the world as well.

If it's, for example, if it was to be like a thermal technology, then obviously it would be, for example, with EDP, or if it was hydro, for example, it would be through EDP. There's a certain amount that can be done with existing capacity or supplied with existing capacity, and then above that level, then you start getting into having to build incremental capacity.

We're obviously looking at that and thinking about when that would come down the pipeline. It'll depend on also how the demand is evolving.

Thank you, Miguel. Hi, Alberto.

On the second one, this is also the result of different diversification effects. Looking at the portfolio as a whole to the different trends, again, the active management that we run on every single market, this is how we are bringing down the sensitivity from the 60 to the €45 million.

Again, just bearing in mind, this is if all the markets would move in the same direction during the period of this report. No, you cannot sort of double the sensitivity if the hedging was coming down to zero.

It's a bit more complex than that.

Thank you.

Thank you, Alberto. Pass now back to our CEO for final remarks.

Okay. Final remarks.

Just to reiterate again, 2025 was a great year for EDP. I think we delivered and delivered solidly on all of the different metrics, whether it was on EBITDA, net income, net debt, the credit ratios, improving the dividend, a really solid, solid year for '25.

I think we come into 2026 also on a good footing, with record-high hydro levels and reserves, with improved regulation, improved perspectives in both Portugal, Spain, and many of the other geographies we're in, like the US. Really, I think we are very confident also on the guidance for 2026.

I think that's one of the messages that I really wanted to reiterate. Going forward, we continue to see great projects coming down the pipeline, certainly on the EDPR side, which makes us feel confident in relation to 2028.

Obviously, we'll go on monitoring decisions around the power prices, but as Rui has mentioned, we are relatively protected in relation to that. We think that it's a discussion that will play out over the next couple of months in Europe, but at the end of the day, we're all aligned that competitiveness is important, but it's also important to keep the stability of the rules and make sure that there's space to invest or for investors to capital allocation, and feel safe about their investments, whether it's on the network side or on the generation side.

Listen, good '25, good prospects for 2026, and reiterating the guidance with confidence, and looking forward also to the next couple of years, reiterating also our 2028 guidance. With that, thank you very much.

Look forward to seeing you soon and to keep in touch.