Final Results

About this update from Gore Street Energy Storage Fund Plc

[{"type":"text","content":"\n \n      15 July 2024 \n Gore Street Energy Storage Fund plc   \n (the \"Company\" or \"GSF\")   \n Audited Full-Year Results \n Strong revenue generation, increasing operational capacity and robust balance sheet \n Gore Street Energy Storage Fund plc, the internationally diversified energy storage fund, is pleased to announce its Audited Full-year results for the year ended 31 March 2024. \n Financial highlights for the year ended 31 March 2024: \n ·    NAV as of 31 March 2024 was £541 million, bringing NAV total return since IPO to 48.4%. \n ·    NAV per share as of 31 March 2024 was 107.0p (31 March 2023: 115.6p). \n ·    The portfolio generated £41.4 million in revenue during the fiscal year (31 March 2023: £39.3 million). \n ·    The portfolio generated an operational EBITDA of £28.4 million. (31 March 2023: £27.8 million). \n ·    As of 31 March 2024, the Company had £60.7 million in cash or cash equivalents, as well as £58.6 million in debt headroom on its existing facilities, sufficient to cover all contractual obligations and continue to build out the Company's portfolio to over 750 MW. \n ·    The Company maintained a low level of gearing, equal to 6.5% [1] of GAV as at 31 March 2024. During FY24/25, the Company expects to draw down on its available debt lines to support the buildout of the Company's near-term portfolio and expects net debt to reach c.15 % of GAV once fully drawn. \n ·    Dividends announced for the period of 7.5 pence per share. Dividend yield of 11.6% [2] (31 March 2023: 6.9%). \n ·    The Company achieved an operational dividend cover of 0.78x and a fund-level dividend cover of 0.56x. \n ·    The weighted average discount rate increased to 10.2% (31 March 2023: 10.1%). \n Operational highlights: \n ·    Energised capacity increased by 45% to 421.4 MW (31 March 2023: 291.6 MW) following the successful energisation of Stony and Ferrymuir. As of the date of publication, both assets are revenue generating. \n ·    Average operational capacity over the year increased by 7% to 311.5 MW (31 March 2023: 291.6 MW). \n ·    Total revenue generation increased by 5.5% to £41.4 million (31 March 2023: £39.3 million). \n ·    Average revenue of £133,000 per MW/yr (31 March 2023: £135,000 per MW/yr), highlighting the benefits of the diversification strategy. \n ·    The Company increased its asset base on the Irish Grid to 385 MW (31 March 2023: 310 MW), of which 130 MW is operational, following the acquisition of a 51% stake in a 75 MW pre-construction energy storage asset (Project Mucklagh) located in the Republic of Ireland. \n Capital Raising: \n ·    The Company issued shares at the prevailing NAV at the time to strategic partners Nidec and Low Carbon for a total consideration value of c.£27 million. \n ESG & Sustainability \n ·    During the reporting period, the operational portfolio avoided 15,178 tCO 2 e and stored 26,232 MWh of renewable electricity. \n ·    The FY 2023/24 ESG and Sustainability Report will be published and available on the Company's website in early September 2024. \n Outlook \n ·    Of the 332 MW of assets in construction due to become energised over the next seven months, 275 MW / 475 MWh is eligible to benefit from an investment tax credit (ITC) of between 30-40% of qualifying capital expenditure through the Inflation Reduction Act, which was passed in late 2022. \n ·    The Investment Manager expects the Company to benefit from a cash inflow in the range of $60 million to $80 million. \n ·    This includes the 200 MW Big Rock asset, which, when completed, will play a material role in supporting the CAISO grid (California)-the Company's fifth market to date-to integrate rising levels of renewable generation. \n Updated Dividend Policy: \n The Company will target a dividend for the financial year ending 31 March 2025 of 7.0 pence per ordinary share, which is consistent with investors' expectations based on the current NAV. This will be subject to cash generation from the underlying portfolio, reflecting prevailing market conditions and performance, financial position and outlook, and the fiscal environment in which the Company operates. From the 2024/25 financial year, the profile and quantum of dividend distributions will be more closely aligned with operational and other cashflows. \n See the Chair's Statement and the Investment Manager's report for further details. \n \n Pat Cox, Chair of the Company, commented: \n \"Despite challenging market conditions, the Company has achieved significant growth by raising new funds and expanding our diversified energy storage portfolio to approximately 1.25 GW across five markets. \n \"The Company met its dividend target, taking total NAV returns since IPO to 48.4%, and with £60.7 million in cash and £58.6 million in debt headroom, we are well-positioned to support the construction of the priority assets over the coming months. With 332 MW of new capacity expected to be added to the energised portfolio, which reached 421.4 MW in the reporting period, by the end of the current financial year in the US and elsewhere, the Company is poised to take another significant step forward in scale. \n \"I remain fully confident that this diversified approach will continue to deliver strong and sustainable returns to investors while contributing to the decarbonisation needed across the global energy system.\" \n Results Presentation Today \n There will be a presentation for sell-side analysts at 9.30 a.m. today, 15 July 2024. Please contact Buchanan for details on  [email protected] \n A presentation for investors will also be held today, 15 July 2024, on the Investor Meets Company Platform at 11:00 a.m. \n Investors can sign up to Investor Meet Company for free and add to meet GORE STREET ENERGY STORAGE FUND PLC v ia : https://www.investormeetcompany.com/gore-street-energy-storage-fund-plc/register-investor \n Annual Report: \n The Company's annual report and accounts for the year ended 31 March 2024 are also being published in hard copy format and an electronic copy will shortly be available to download from the Company's webpages  https://www.gsenergystoragefund.com/ . \n Please click on the following link to view the document: http://www.rns-pdf.londonstockexchange.com/rns/2708W_1-2024-7-12.pdf \n The Company will be submitting its Annual Report and Accounts to the National Storage Mechanism, which will shortly be available for inspection at:  https://data.fca.org.uk/#/nsm/nationalstoragemechanism . \n \n   \n   \n \n   \n Gore Street Energy Storage Fund plc Annual report for the year ended 31 March 2024   \n Key Metrics \n For the year ending 31 March 2024 \n NAV PER SHARE \n 107.0p \n (2023: 115.6p) \n OPERATIONAL EBITDA \n £28.4m \n (2023: £27.8m) \n DIVIDEND YIELD \n 11.6% \n (2023: 6.9%) \n NAV TOTAL RETURN \n for the year ended 31 March 2024 \n -1.2% \n (2023: 12.6%) \n OPERATIONAL CAPACITY \n 371.5 MW** \n (2023: 291.6 MW) \n DIVIDENDS PAID DURING THE YEAR \n 7.5p \n (2023: 7.0p) \n \n \n \n \n KEY METRICS \n \n \n As at 31 March 2024 \n \n \n As at 31 March 2023 \n \n \n \n \n Net Asset Value (NAV) \n \n \n £540.7m \n \n \n £556.3m \n \n \n \n \n Number of issued ordinary shares \n \n \n 505.1m \n \n \n 481.4m \n \n \n \n \n NAV per share \n \n \n 107.0p \n \n \n 115.6p \n \n \n \n \n NAV Total Return for the year* \n \n \n -1.2% \n \n \n 12.6% \n \n \n \n \n NAV Total Return since IPO* \n \n \n 48.4% \n \n \n 52.4% \n \n \n \n \n Share price \n \n \n 64.5p \n \n \n 100.8p \n \n \n \n \n Market capitalisation \n \n \n £325.8m \n \n \n £485.3m \n \n \n \n \n Share price Total Return for the year* \n \n \n -30.0% \n \n \n -5.1% \n \n \n \n \n Share price Total Return since IPO* \n \n \n -10.2% \n \n \n 30.9% \n \n \n \n \n Discount to NAV* \n \n \n -39.7% \n \n \n -12.8% \n \n \n \n \n Portfolio's total capacity \n \n \n 1.25 GW \n \n \n 1.17 GW \n \n \n \n \n Portfolio's operational capacity \n \n \n 371.5 MW \n \n \n 291.6 MW \n \n \n \n \n Average operational capacity \n \n \n 311.5 MW \n \n \n 291.6 MW \n \n \n \n \n Total portfolio revenue \n \n \n £41.4m \n \n \n £39.3m \n \n \n \n \n Average revenue per MW/yr \n \n \n £132,905 \n \n \n £134,774 \n \n \n \n \n Operational EBITDA \n \n \n £28.4m \n \n \n £27.8m \n \n \n \n \n Total Fund EBITDA \n \n \n £20.2m \n \n \n £16.8m \n \n \n \n \n Dividends per ordinary share paid during the year \n \n \n 7.5p \n \n \n 7.0p \n \n \n \n \n Operational dividend cover for the year \n \n \n 0.78x \n \n \n 0.90x \n \n \n \n \n Total Fund dividend cover for the year \n \n \n 0.56x \n \n \n 0.54x \n \n \n \n \n Dividend Yield* \n \n \n 11.6% \n \n \n 6.9% \n \n \n \n \n Gross Asset Value (GAV)* \n \n \n £578.1m \n \n \n £556.3m \n \n \n \n \n Gearing* \n \n \n 6.5% \n \n \n 0.0% \n \n \n \n \n Ongoing Charges Figure* \n \n \n 1.42% \n \n \n 1.37% \n \n \n \n \n *       Some of the financial measures above are classified as Alternative Performance Measures, as defined by the European Securities and Markets Authority and are indicated with an asterisk (*). Definitions of these performance measures, and other terms used in this report, are given on page 101 of the 2024 annual report together with supporting calculations where appropriate. \n **     The 49.9 MW Ferrymuir asset was energised during the reporting period, taking total energised capacity to 421.4 MW at year end. \n   \n Chair's Statement \n On behalf of the Board of the Gore Street Energy Storage Fund plc, I am pleased to present the Company's Annual Results for the year ended 31 March 2024. \n Overview and Performance \n Despite challenging conditions in the Great Britain (GB) energy storage and listed markets, the 2023/24 reporting period saw the Company successfully raise new capital, increase its energy storage capacity, and extend its uniquely diversified portfolio to c. 1.25 GW across five uncorrelated markets, all while maintaining its dividend and a prudent level of debt. Total revenue grew to £41.4 million through strong consolidated asset performance, notwithstanding volatile market conditions in GB and a normalisation of power prices in Germany. \n The Company met its target dividend for the year, equal to 7.5 pence per share, taking NAV total return including dividends since IPO to 48.4%. \n During the reporting year, the Company energised the 79.9 MW Stony and 49.9 MW Ferrymuir projects in GB, both of which are now fully operational and generating revenue, while the energisation of the 57 MW Enderby project is scheduled to follow shortly post-period. With an energised portfolio of 421.4 MW during the period, the Company is poised to take one of its biggest steps forward in scale with a further 332 MW of capacity expected in the coming months. This includes the 200 MW Big Rock (CA, USA) and 75 MW Dogfish (TX, USA) projects, taking the energised portfolio to c.753.4 MW by the end of the current financial year. \n This internationally diversified growth is the result of a strategy adopted in 2019 when we first invested in assets outside of GB as it became clear to the Investment Manager and the Company that reliance on revenues from a single grid would expose shareholders to higher volatility than a diversified portfolio. This vision has been vindicated during and after the reporting period, with sole GB investment strategies suffering from low grid services revenues due to overcapacity and the failure of a robust GB wholesale trading market to develop as expected by many. \n Our fleet of operational projects across Ireland, Germany and the US provides a buffer against GB headwinds as they are not only uncorrelated with the GB market but offer different revenue streams for different durations. The Irish and Texas grids continued to provide particularly strong revenues over the reporting period, driven by fundamentals that support energy storage. Wind generation in Ireland grew, providing lucrative market opportunities for battery energy storage systems as grid operators rewarded fast-acting flexible assets. Texas continued to face challenges from periods of extreme weather that increased the grid's need for reserve services and provided attractive trading opportunities. The Company is well-placed to capitalise on these opportunities as they emerge across multiple markets. \n We remain in a strong financial position as a result of good liquidity management by the Investment Manager. As at 31 March 2024, the Company had £60.7 million in cash or cash equivalents and £58.6 million in undrawn debt facilities. This ensures the construction of priority assets is fully supported and can continue at pace. We also raised new capital during the period through our long-term strategic battery partner, Nidec, and used our shares to acquire additional interests in operating assets from our strategic development partner, Low Carbon. In the case of Low Carbon, the Company increased its asset base to 385 MW in the lucrative Irish market with minimal cash consideration, agreed at 2019 prices, demonstrating our ability to grow even at a time when capital markets are effectively closed to investment trusts. \n Macroeconomic Environment \n The macroeconomic environment continued to impact the investment landscape throughout 2023/24, with high inflation and central bank interest rates constraining performance across the sector. \n In monitoring the share price volatility experienced across the sector over the financial year, we maintain the view that the discount to Net Asset Value at which the share price has traded materially undervalues the Company and its portfolio. The results reveal the strength of our activities across multiple uncorrelated markets, and we expect to continue to deliver value for shareholders as more capacity is brought online. \n Following price hikes in 2022, capex costs fell as supply chain issues related to the pandemic subsided and lower demand from the electric vehicle market resulted in greater availability of materials. This lowers the capital costs of assets currently being built and, as revenue opportunities emerge to justify additional expenditure, permits the potential augmentation of existing sites. \n The Company maintains its focus on delivering market-leading revenue from a varied range of sources, using assets built at the best value per MWh fully installed, and continues to ensure capex costs are monitored by the Investment Manager when assessing capacity additions to our sites. \n Strategy and Operational Performance \n Maintaining high availability of the assets within the portfolio remains a priority for the Company and its Investment Manager. By exceeding 93% availability across the financial year, the assets were able to capitalise on the most lucrative opportunities possible while ensuring planned maintenance could be carried out to safeguard future operations. \n Our strategy over the period focused on the fundamentals of renewable energy penetration and its associated volatility, which creates demand for ancillary services. In Ireland the ongoing DS3 programme (Delivering a Secure Sustainable Electricity System), which facilitates the integration of wind power and other non-synchronous renewable energy sources, delivered substantial revenue. \n Solar deployment drove revenues in Texas, particularly over the summer when electricity demand soared during periods of high temperatures. The added impact of increasingly steep grid load ramps caused by declining solar output in the evenings resulted in an increased need for reserve services from fast responding, secure sources like energy storage. \n The portfolio also delivered a broader range of activities in markets where ancillary services fell in value, such as Germany. The volatility of the previous reporting period subsided as gas supplies became less restricted and grid service prices normalised. The Company adopted a more wholesale trading-focused strategy in Germany, supported by an increasingly sophisticated data-driven approach, to ensure its asset could access additional revenue streams. \n Overall wholesale trading increased as a proportion of revenues across all markets to 7% compared to the previous financial year's 3% as the Company continued to diversify its revenue stack to deliver sustainable returns to shareholders. These actions, taken as part of the Company's diversified approach, were essential in managing the impact of market saturation and limited wholesale market volatility in GB. \n We are pleased that the outperformance of our international portfolio compared to the GB assets allowed the Company to achieve higher absolute revenues than in the previous reporting period despite declines in GB revenue. The Company is hopeful that GB market conditions will improve, with some signals towards the end of the financial year and post-period suggesting a recovery across some revenue streams. We remain well positioned to maintain strong performance from our international portfolio in addition to any improved revenue generation from GB assets. \n NAV Performance \n Despite best-in-class operational performance across the portfolio and pro-active management delivering strong returns, external factors, including central banking monetary policy to manage inflation and discount rates across the sector, contributed to a NAV decrease across the financial year from 115.6p per share as of 31 March 2023 to 107.0p per share. \n We expect to see improving market conditions as inflation continues to subside and rates come down. The Company remains confident in its ability to continue to deliver long-term value to shareholders as we deploy additional operational capacity by the end of the fiscal year. This will have a positive effect on revenue generation and dividend coverage.  \n Discount Management \n The Board continues to retain the ability to repurchase shares at a price lower than NAV in the interests of discount management. The Company remains fully committed to the build-out of the portfolio with support from shareholders, with the additional debt added during the period dedicated to these construction efforts. Healthy returns are expected to continue from across the portfolio as more capacity is added, including in the CAISO market in California, and discount rates will continue to be unwound as we progress from construction to operations. \n We, therefore, maintain the position that the repurchase of shares is not the right course of action for the Company at the current time, although the Board will continue to monitor the performance of the share price and will act to employ appropriate discount control mechanisms as needed. \n Debt \n The Company increased its £15 million revolving debt facility with Santander to £50 million, including an accordion option to increase beyond £50 million to up to 30% of Gross Asset Value. We also added debt finance secured at the project level for the first time, with $60 million from First Citizens Bank tied to the deployment of the 200 MW/400 MWh Big Rock asset in California, the Company's largest to date. We have long heralded the promise of long-term secured revenue from the Resource Adequacy (RA) mechanism in CAISO and the backing provided by this loan vindicates this position as we look ahead to energising the asset by the end of 2024. \n Capital Allocation \n The Company continues to focus on the correct allocation of capital to ensure long-term, sustainable returns are achieved in the interests of shareholders. This includes prioritising the construction of specific assets to deliver optimal value through their scale, revenue opportunities and geographical spread. We expect to deploy the majority of available cash and lines of credit, both project and fund-level facilities, by the end of the 2024/25 financial year to fund the buildout of 57 MW in GB through the Enderby project and 275 MW across the US projects Big Rock and Dogfish. \n The Company has comfortable headroom to meet its current contractual obligations and we will continue to act prudently regarding leverage in what remains a high interest rate environment. We are also encouraging the Investment Manager to continue exploring options to recycle capital from the portfolio and will keep the market informed of any relevant progress. \n Dividends \n The Board has approved a fourth interim dividend of 1.5 pence per share, bringing the total dividend announced for the period ended 31 March 2024 to 7.5 pence per share in line with the Company's Dividend Policy (the ex-dividend date being 27 June 2024, with the record date of 28 June 2024). The dividend will be paid on or around 15 July 2024. \n Dividend Policy \n We remain committed to regular capital allocation reviews and comprehensive analytical assessments, while remaining receptive to shareholder feedback, to ensure the Company continues to be managed effectively for investors. Following this year's review, the Board has decided to adjust the Company's dividend policy to better align it with the construction schedule of the portfolio. \n It is the Directors' intention to continue to pay, in the absence of unforeseen circumstances, a dividend of 7.0 pence per ordinary share for the financial year subject to market conditions and performance, financial position and outlook, and fiscal environment. This is consistent with investors' expectations based on the current NAV but, from the 2024/25 financial year, the profile and quantum of dividend distributions will be more closely aligned with operational and other cashflows rather than NAV. \n Moving from roughly equal payments across all quarters, the Board has determined to target a dividend of 1.0 pence per Ordinary Share for each of the first three quarters of the financial year. It is intended the amount of the final quarterly dividend (announced in June and paid in July) will make up the balance of the annual dividend target subject to cash flows at the time. As with the current dividend policy, all dividends remain at the discretion of the Board. \n This is a prudent adjustment to the dividend policy reflecting the maturing nature of the Company's portfolio, with a transformative year for increasing operational and revenue-generating capacity. \n Sustainability \n The Company is rooted in sustainability and continues to increase disclosures across a range of ESG metrics measuring the impact of its own operations. Publication of our second ESG & Sustainability report in September 2023 covering the FY 2022/23 reporting period took account of investments in California and Texas, with the latter exposing the Company to a grid system with higher levels of fossil-fuel generation. As these markets increase their renewables deployment, the crucial role of the Company's battery storage assets in enabling decarbonisation will increase while supporting stable grid operations during increasingly frequent periods of extreme weather. \n The ESG & Sustainability Report covering FY2023/24, due to be published in early September, will consolidate the Company's latest Sustainable Finance Disclosure Regulations (SFDR) and Task Force on Climate-Related Financial Disclosures (TCFD) disclosures. An assessment of the Company's Principal Adverse Impacts (PAI) under SFDR is included in the appendix of this report. \n The Company remains committed to increasing transparency in the market for green investment products. As part of this, we will report on progress towards integration of the Principles for Responsible Investment (PRI) for the first time in 2024. We are proud of our track record of transparency across all metrics and will continue to deliver leading levels of disclosure to the market. \n Board Composition and Succession Planning \n As reported last year, the remuneration and nomination committee continue to plan director succession to ensure the four directors appointed at IPO in 2018 retire in an orderly manner. Work on future appointments is advancing, and details are included in the committee's report. \n AGM \n The AGM will be held at the offices of Stephenson Harwood, 1 Finsbury Circus, London EC2M 7SH on Wednesday 18 September 2024 at 10.00 am. Further details are included in the Notice of AGM on page 88. I look forward to welcoming shareholders attending in person. \n If you are not able to attend in person, or prefer to vote by proxy, but have questions for the Board, please contact the Company Secretary at [email protected] . \n Outlook \n The new capacity due online in the coming months, including the 200 MW asset in California, represents a step-change for the Company as we extend our operational and geographical diversification even further. \n Despite recent issues for our sector, I remain fully confident that this diversified approach will continue to deliver strong overall returns while contributing to the decarbonisation needed across the global energy system. \n Investment Manager's Report \n Dr Alex O'Cinneide \n CEO of Gore Street Capital, the Investment Manager \n \"I'm proud to report the Company continued to achieve growth while demonstrating leadership and resilience during an extremely turbulent period. The international portfolio continued to deliver consistent average revenue of £15.1 per MW/hr through best-in-class operational performance and capital management. The Company achieved an operational dividend cover of 0.78x for the year from an average operational fleet of 311 MW. With the energised capacity reaching 421 MW and 332 MW more to follow in the coming seven months, all while maintaining a prudent approach to leverage, the Company is well-positioned to increase dividend cover and continue delivering value for shareholders by generating robust and stable cash flow from its well diversified asset base.\" \n Operational Highlights: \n ·          The portfolio generated £41.4 million of revenue during the fiscal year. This amounted to £28.4 million in operational EBITDA. \n -       The Company achieved an average revenue per MW/hr of £15.1, highlighting the stable revenue profile of the Company. \n -       With its international portfolio, the Company averaged £19.6 per MW/hr over the period, 2.2x the GB portfolio, inclusive of liquidated damages. \n -       The Company achieved an operational dividend cover of 0.78x and a fund-level dividend cover of 0.56x. \n -       Energised capacity increased by 45% to 421.4 MW, following the successful energisation of Stony (79.9 MW) and Ferrymuir (49.9 MW). As of the date of publication, both assets are revenue generating. \n -       Of the 332 MW of assets in construction due to come online over the next 7 months, 275 MW / 475 MWh is eligible to benefit from an investment tax credit of between 30-40% of qualifying capital expenditure through the Inflation Reduction Act, which was passed in late 2022. The Investment Manager expects the Company to benefit from a cash inflow in the range of $60 million to $80 million. \n ·          The Company continued to show good liquidity management. As of 31 March 2024, the Company had £60.7 million in cash or cash equivalents, as well as £58.6 million in debt headroom on its existing debt facilities, sufficient to cover all contractual obligations and build out the Company's portfolio to over 750 MW. \n -       As of 31 March 2024, the Company's gearing was 6.5% of GAV. \n ·          The Company increased its asset base on the Irish Grid to 385 MW, of which 130 MW is operational, following the acquisition of a 51% stake in a 75 MW pre-construction energy storage project (Project Mucklagh) located in the Republic of Ireland. \n ·          The Company's assets continued to support the energy transition by providing services needed to integrate more renewable energy sources into the grid. During the reporting period, the operational portfolio avoided 15,178 tCO 2 e and stored 26,232 MWh of renewable electricity. \n Net Asset Value: \n ·          NAV as at 31 March 2024 was £541 million, bringing NAV total return since IPO to 48.4% \n ·          NAV per ordinary share of 107.0 pence per share \n ·          The main drivers of NAV during the period where updated macro assumptions, reflecting the current environment in which the Company was operating in, as well as pro-active management, resulting in continued strong cash generation and a material increase in energised capacity. \n Table 1: Movement in NAV since March 2023 \n \n \n \n \n Movement in NAV \nsince March 2023 \n \n \n Changes in \nNAV (PPS) \n \n \n \n \n NAV March 2023 \n \n \n 115.6 \n \n \n \n \n Offering Proceeds \n \n \n - \n \n \n \n \n Dividends \n \n \n -7.4 \n \n \n \n \n Revenue Curves \n \n \n -7.0 \n \n \n \n \n Inflation \n \n \n -1.5 \n \n \n \n \n Discount Rates \n \n \n -2.8 \n \n \n \n \n Net Portfolio Returns \n \n \n 10.1 \n \n \n \n \n NAV March 2024 \n \n \n 107.0 \n \n \n \n \n The Investment Manager's Report provides readers with an explanation of the backdrop in each of the markets the Company operates in. It details the revenues generated, how the assets performed, and the specific drivers of the portfolio's NAV. It also includes a Q&A with the Investment Manager's CIO and CFO, Sumi Arima, where he talks about the Company's strategy and his thoughts on the markets in which the Company operates. The Investment Manager's CEO, Dr Alex O' Cinneide, then gives his views on the Company's performance, and outlook of the future. \n A glossary of industry terms can be found on page 104 of the 2024 annual report. \n Portfolio \n 1.25 GW \n Total portfolio (GW) \n 1.62 GWh \n Total portfolio (GWh)+ \n 421.4 MW \n Energised \n 826.8 MW \n Pre-construction and construction phase projects \n Portfolio in GB & Northern Ireland (GBP) \n \n \n \n \n Asset name \n \n \n Capacity \n \n \n Ownership \n \n \n \n \n 1 \n \n \n Boulby \n \n \n 6.0 MW | 6.0 MWh \n \n \n 99.9% \n \n \n \n \n 2 \n \n \n Cenin \n \n \n 4.0 MW | 4.8 MWh \n \n \n 49.0% \n \n \n \n \n 3 \n \n \n POTL \n \n \n 9.0 MW | 4.5 MWh \n \n \n 100.0% \n \n \n \n \n 4 \n \n \n Lower Road \n \n \n 10.0 MW | 5.0 MWh \n \n \n 100.0% \n \n \n \n \n 5 \n \n \n Mullavilly \n \n \n 50.0 MW | 21.3 MWh \n \n \n 51.0% \n \n \n \n \n 6 \n \n \n Drumkee \n \n \n 50.0 MW | 21.3 MWh \n \n \n 51.0% \n \n \n \n \n 7 \n \n \n Hulley \n \n \n 20.0 MW | 20.0 MWh \n \n \n 100.0% \n \n \n \n \n 8 \n \n \n Lascar \n \n \n 20.0 MW | 20.0 MWh \n \n \n 100.0% \n \n \n \n \n 9 \n \n \n Larport \n \n \n 19.5 MW | 19.5 MWh \n \n \n 100.0% \n \n \n \n \n 10 \n \n \n Ancala \n \n \n 11.2 MW | 11.2 MWh \n \n \n 100.0% \n \n \n \n \n 11 \n \n \n Breach \n \n \n 10.0 MW | 10.0 MWh \n \n \n 100.0% \n \n \n \n \n 12 \n \n \n Stony \n \n \n 79.9 MW | 79.9 MWh \n \n \n 100.0% \n \n \n \n \n 13 \n \n \n Ferrymuir \n \n \n 49.9 MW | 49.9 MWh \n \n \n 100.0% \n \n \n \n \n 14 \n \n \n Enderby \n \n \n Energisation | Sep 2024 \n \n \n 100.0% \n \n \n \n \n 15 \n \n \n Middleton \n \n \n Grid Availability | 2026 \n \n \n 100.0% \n \n \n \n \n Republic of Ireland & Germany (EUR) \n \n \n \n \n Asset name \n \n \n Capacity \n \n \n Ownership \n \n \n \n \n 16 \n \n \n Cremzow \n \n \n 22.0 MW | 29.0 MWh \n \n \n 90.0% \n \n \n \n \n 17 \n \n \n Porterstown \n \n \n 30.0 MW | 30.0 MWh \n \n \n 100.0% \n \n \n \n \n 17.1 \n \n \n Porterstown Expansion \n \n \n Energisation | TBC \n \n \n 100.0% \n \n \n \n \n 18 \n \n \n Kilmannock \n \n \n Grid Availability | 2026 \n \n \n 100.0% \n \n \n \n \n 18.1 \n \n \n Kilmannock Expansion \n \n \n Grid Availability | 2027 \n \n \n 100.0% \n \n \n \n \n 19 \n \n \n Mucklagh \n \n \n Grid Availability | 2028 \n \n \n 51.0% \n \n \n \n \n North America (USD) \n \n \n \n \n Asset name \n \n \n Capacity \n \n \n Ownership \n \n \n \n \n 20 \n \n \n Snyder \n \n \n 9.95 MW | 19.9 MWh \n \n \n 100.0% \n \n \n \n \n 21 \n \n \n Westover \n \n \n 9.95 MW | 19.9 MWh \n \n \n 100.0% \n \n \n \n \n 22 \n \n \n Sweetwater \n \n \n 9.95 MW | 19.9 MWh \n \n \n 100.0% \n \n \n \n \n 23 \n \n \n Big Rock \n \n \n Energisation | Dec 2024 \n \n \n 100.0% \n \n \n \n \n 24 \n \n \n Dogfish \n \n \n Energisation | Feb 2025 \n \n \n 100.0% \n \n \n \n \n 25 \n \n \n Wichita Falls \n \n \n Grid Availability | 2025 \n \n \n 100.0% \n \n \n \n \n 26 \n \n \n Mesquite \n \n \n Grid Availability | 2025 \n \n \n 100.0% \n \n \n \n \n 27 \n \n \n Mineral Wells \n \n \n Grid Availability | 2025 \n \n \n 100.0% \n \n \n \n \n 28 \n \n \n Cedar Hill \n \n \n Grid Availability | 2025 \n \n \n 100.0% \n \n \n \n \n *        MWh included for operational sites \n +       Based on expected system duration and may be subject to change \n Revenue Generation and Portfolio Performance \n Renewable energy generation has continued to grow across the markets in which the Company operates, enabled by increased flexible capacity on each grid system. Battery energy storage systems (BESS) deliver value in these jurisdictions by providing frequency services, load shifting, grid balancing, energy arbitrage, and by ensuring reliability of supply during periods of stress caused by extreme temperatures and varying wind conditions. \n During the fiscal year, the fundamentals driving revenues in Ireland and Texas were even stronger than the previous year. Integration of rising levels of wind generation continued to drive the Irish grid's flexibility needs and revenues for BESS, which has become a crucial technology within the ancillary services market. Electricity demand in Texas, meanwhile, continued its upward trend, increasing the system's need for fast-acting reserves. The continued deployment of solar in Texas has also driven the \"Energy Reliability Council of Texas\" (ERCOT) grid operator to introduce services capable of responding to grid load ramps, which have become an increasingly significant challenge during the evening ramp-down of solar generation. \n German ancillary services experienced a drop in value as gas supplies were less constrained than in the previous financial year. Wholesale trading, meanwhile, offered significant opportunity throughout the year, as both supply and demand sought to rebalance positions in the continuous trading markets. This created high liquidity for traders, resulting in more lucrative opportunities for BESS operators. Germany also permitted and facilitated easier access for energy storage to new revenue streams such as aFRR, for which the German asset is now prequalified, FCR prices saw a rise post period in Germany, which can be credited to high solar penetration suppressing mid-day energy prices, increasing the opportunity cost for traditional thermal generation to run to deliver FCR services. \n The GB market was subject to one of the most challenging years to date for BESS as large amounts of energy storage capacity continued to be added to the grid and National Grid introduced changes to the ancillary services procurement methodology, causing ancillary services revenues to fall as a result of increased competition. Trading markets did not provide relief to tight ancillary services markets over the winter, driven by lower gas prices than in previous years and milder temperatures. Changes to market operation through introduction of the Enduring Auction Capability (EAC) for dynamic markets and the Open Balancing Platform in the Balancing Mechanism (BM) did not provide the increased opportunity the market had anticipated. \n The difference in dynamics driving these markets highlights the benefits of the Company's globally diversified portfolio. The portfolio generated a 5.5% uplift in revenues compared to the previous financial year. This global approach has made the portfolio less susceptible to revenue variances over time caused by cyclic downturns in individual markets. \n During the fiscal year, the portfolio increased the number of services offered to the market compared to the previous year (aFRR in Germany, ECRS in Texas, Balancing Reserve in GB). The assets were also more actively trading than in previous years, with 7% of revenues coming from trading, versus 3% in the previous financial year. \n The Investment Manager has continuously sought to maximise the performance of the portfolio in each market. Targeted decision-making, such as changing Route to Market providers \"RTMs\" in multiple geographies, allowed the portfolio to benefit from uplifts in performance. Continuous monitoring of the markets, asset performance, and service delivery also enabled the Investment Manager to identify points of improvement to the portfolio's overall performance, which continues to show a robust and healthy level of revenue generation independent of individual market conditions. The announced addition of new services (Quick & Slow Reserve in GB, Dispatchable Reliability Reserve Service (DRRS) in ERCOT, Capacity Market in Germany), coupled with market changes (REMA in GB, Future Arrangements for System Services and Day Ahead System Service Auction in Ireland), are expected to produce new opportunities for BESS. \n Great Britain \n Table 2: Overview of the GB Market \n \n \n \n \n TSO \n \n \n National Grid \n \n \n \n \n \n \n \n GB Portfolio \n \n \n 189.6 MW / 180.9 MWh \n \n \n \n \n \n \n \n Market Share \n \n \n 5% 1 \n \n \n \n \n \n \n \n Revenue during the period (m) \n \n \n £10.1 2 \n \n \n \n \n \n \n \n Revenue per MW/yr \n \n \n £77,300/MW \n \n \n \n \n \n \n \n Revenue per MWh/yr \n \n \n £82,900/MWh \n \n \n \n \n \n \n \n 1      3,884 MW buildout at 31st March 2024, from MODO GB Asset Database \n 2      The figure includes c.£3.0m of Liquidated Damages \n The GB market experienced a significant decrease in generated revenues from the previous financial year. Market indices indicate a 69% fall in overall market performance between FY23/24 and FY22/23, on a per MW basis, primarily driven by increased competition in ancillary services markets and suppressed volatility in the traded markets throughout the year. \n GB added 1.4 GW of new BESS on the grid during FY23/24, the highest increase seen to date, while average EFA block ancillary service procurement levels increased by only 1 GW compared to the previous financial year. This uneven increase led to saturation of ancillary services markets, especially Dynamic Containment/Moderation/Regulation (DC/M/R). A further contributor to market decline was the phase-out of dynamic FFR into November 2023, reducing the number of markets accessible to BESS. Average DC prices through the year reduced by 71% in comparison to the previous financial year. \n In November 2023, National Grid ESO also introduced EAC, which allowed bidding between multiple dynamic services simultaneously and negative price bidding. The platform contributed to a further reduction in dynamic services pricing, with DC/M/R seeing a weighted average drop in prices of 32% in November 2023 versus October 2023. \n Simultaneously, regular trading opportunities did not materialise for BESS as energy prices decreased compared to the previous financial year. Trading in wholesale markets, therefore, did not provide a significant upside to ancillary services participation, further contributing to market saturation as assets did not have a consistent alternative revenue source. \n Balancing Mechanism (BM) skip rates of batteries were widely criticised by BESS operators who grew increasingly frustrated by the apparent preference of the system operator to utilise thermal generators to provide system action rather than BESS, which were reportedly more cost-effective. The introduction of National Grid's new platform to administer the BM (Open Balancing Platform or OBP) in December 2023 sought to rectify this by automating part of the BM process, allowing the grid to take more decisions and dispatch from a wider asset base. Since the introduction of the OBP, BESS have seen some increase in BM participation, however, this has not had a material impact on the overall revenues of batteries while increasing competition in the marketplace between smaller assets. \n Further changes came to the market in March 2024 as Balancing Reserve (BR) was introduced for BM-registered sites to act as a payment for sites that are to be made available in the BM. BR did not significantly impact BESS revenue at the close of the financial year, though operational information is currently limited. \n The annual Capacity Market (CM) auctions cleared at a high price, driven by increasing requirements set by The Department for Energy Security and Net Zero (DESNZ) and limited existing capacity. The Company secured a combined 251.5 MW of non-derated Capacity Market contracts across both the T-4 CM auction, which cleared at a price of £65/kW/year, and the T-1 CM auction, which cleared at £35.79/kW/year. These agreements will provide an additional c.£1.7 million in two delivery years, alongside existing CM commitments. All GB assets, therefore, continue to have ongoing CM contracts. \n At the beginning of the reporting period, BESS buildout reached its highest rate on the grid to date. However, Q4 saw the lowest build-out of capacity since Q2 of FY22/23. This points towards the cyclical nature of the GB market as capacity build-out starts to slow down as a result of lower revenues. As grid volatility and ancillary services procurement increases in line with the deployment of further wind and solar across the grid, the trend of lower BESS buildout should allow increased opportunities in the future for current market participants. \n Ireland \n Table 3: Overview of the Irish Market \n \n \n \n \n TSO \n \n \n EirGrid & SONI \n \n \n \n \n Irish Portfolio \n \n \n 130.0 MW / 72.6 MWh \n \n \n \n \n Market Share \n \n \n 15% 3 \n \n \n \n \n Revenue during the period (m) \n \n \n £ 23.6 \n \n \n \n \n Revenue per MW/yr \n \n \n £181,600 \n \n \n \n \n Revenue per MWh/yr \n \n \n £325,200 \n \n \n \n \n 3      849 MW of BESS capacity in both ROI and NI, based on Aurora Ireland Flexible Energy Market Report May 2024 \n The Delivering a Secure Sustainable Electricity System (DS3) initiative holds a pivotal role within the combined Irish energy system by facilitating the integration of non-synchronous renewable energy sources, primarily wind power. At the heart of DS3's functionality lies the System Non-Synchronous Penetration (SNSP) scalar, a real-time metric that gauges the level of intermittent renewable generation and net interconnector flows within the single electricity market of Northern Ireland (NI) and the Republic of Ireland (ROI), defined as a percentage of electricity demand on the system. DS3 rates increase as SNSP increases, meaning that batteries delivering DS3 services see increasing remuneration per hour for their response at times when the system needs it the most. \n Throughout the reporting period, as the buildout of renewable generation continued across the Irish market, the system encountered a substantial increase in both absolute levels and volatility of wind power generation, exhibiting an average SNSP increase of 27% compared to the previous year. This resulted in a notable c.40% year-on-year surge in DS3 revenue. In addition, the high availability maintained by assets throughout the year contributed to a consistent monetary performance by the Irish assets. \n Wholesale trading, or energy arbitrage, continued to play an important role as opportunities were capitalised on during periods of high demand and low wind generation, resulting in a spike in Day-Ahead or Intra-Day pricing. The Investment Manager's dynamic approach executed by the Company's RTM partner allowed for the reallocation of higher volumes into this wholesale revenue strategy rather than solely relying on DS3. This enabled additional access to revenues, especially for Porterstown in ROI that has a fixed price capped contract. \n The Company successfully secured lucrative CM contracts at £100/kW/year for Mullavilly and Drumkee in the T-4 27/28 auction and £128/kW/year for Porterstown in the T-1 24/25 auction, adding to the existing CM contracts in place during the fiscal year. The diversification of revenue from multiple sources surpassed forecast projections, resulting in a significant performance increase of 41% for NI and 23% for ROI compared to the previous reporting period. \n Wind volatility is expected to continue to shape Ireland's dynamic electricity market structure, with BESS positioned at the forefront of maintaining grid security and stability to support the increase in SNSP to up to 95% by 2030 from up to 75% today and aid in achieving Ireland's 2050 net-zero goals. \n Germany \n Table 4: Overview of the German Market \n \n \n \n \n TSO \n \n \n 50 Hertz, Amperion, Tennet, Transnet BW \n \n \n \n \n \n \n \n German Portfolio \n \n \n 22.0 MW / 29.0 MWh \n \n \n \n \n \n \n \n Market Share \n \n \n 2% 4 \n \n \n \n \n \n \n \n Revenue during the period (m) \n \n \n £1.8 \n \n \n \n \n \n \n \n Revenue per MW/yr \n \n \n £80,000 \n \n \n \n \n \n \n \n Revenue per MWh/yr \n \n \n £60,700 \n \n \n \n \n \n \n \n 4      As at 31 March 2024, German had 1,353 MW of grid scale BESS capacity operational \n Both the German and broader European energy markets saw decreases in energy prices during the reporting period that impacted the revenues available to BESS. Gas and electricity wholesale markets prices experienced reductions of 69% and 62%, respectively, compared to the previous FY as a result of milder temperatures during the winter, increased availability of gas storage, and a steady influx of liquefied natural gas (LNG) from global sources as Germany diversified its supplies away from Russia. EU regulation aimed at ensuring gas stores are replenished led Germany to import an increasing volume of gas from the United States and Qatar. The normalised gas prices served to reduce energy price volatility, contributing to a 50% decrease in Frequency Containment Reserve (FCR) prices compared to the previous reporting period. \n The Company's Cremzow asset strategically diversified its participation beyond a sole focus on FCR in anticipation of these market challenges. The Investment Manager's engagement of a new RTM provider offering algorithmic trading methods led to enhanced flexibility and revenue potential through high-frequency trading, which mitigated the risks associated with an FCR-centric strategy. Cremzow was also successfully prequalified for both sub-services of automatic Frequency Restoration Reserve (aFRR) - energy and capacity - following the PICASSO reform, which enabled participants to deliver balancing energy for 15 minutes instead of the previous requirement of at least four hours. This combined approach, leveraging additional services and algorithmic trading, allowed the equivalent capacity from the Company's German asset to surpass the revenue achievable from a strategy focused solely on FCR by 43% across the reporting period. \n Despite the increase in LNG supply and the milder temperatures leading to price dips, the structural deficit in European natural gas persists due to the shortfall from lost Russian imports. European energy prices remain vulnerable to supply disruptions or spikes in demand, especially during winter, hot summers, or periods of high renewable energy penetration on the system increasing the need for flexibility. In these situations, BESS assets like Cremzow play a pivotal role in providing flexibility services to stabilise the grid and meet fluctuating energy demands. \n Post-period the Company has begun accessing a broader spectrum of revenue streams with the commencement of aFRR capacity in May 2024.This strategic positioning underscores the significance of enhancing market resilience despite the challenges posed by market dynamics. \n This increased market access also positions the Company to capitalise on upcoming opportunities as Germany grows its energy storage ambitions. In December 2023, the Federal Ministry for Economic Affairs and Climate Protection (BMWK) published an electricity storage strategy designed to remove barriers for the asset class to support Germany's renewable energy targets for 2035. This was followed by the announcement of a CM mechanism, set to launch in 2028, similar to those used in other markets to secure long-term contracted revenue. \n Texas \n Table 5: Overview of the Texas Market \n \n \n \n \n TSO \n \n \n ERCOT \n \n \n \n \n Texas Portfolio \n \n \n 29.85 MW / 59.7 MWh \n \n \n \n \n Market Share \n \n \n 1% 5 \n \n \n \n \n Revenue during the period (m) \n \n \n £ 6.0 \n \n \n \n \n Revenue per MW/yr \n \n \n £200,400 \n \n \n \n \n Revenue per MWh/yr \n \n \n £100,200 \n \n \n \n \n 5      3,243 MW stand-alone BESS buildout at 31st March 2024, from MODO ERCOT Asset Database \n Assets connected to the ERCOT market in Texas saw overall increases in revenue over the reporting period in comparison to the previous fiscal year, driven primarily by volatility over Q2. Temperatures continue to be a key driver of prices in Texas, with overall demand on the grid increasing year-on-year. Peak summer demand for 2023 was 5 GW higher than the equivalent peak in 2022, contributing to low available headroom on the grid and driving reserve prices and scarcity pricing. \n In June 2023, the grid operator introduced the ERCOT Contingency Reserve Service (ECRS), an additional reserve service accessible to BESS. The more constraining and demanding requirements of ECRS participation in comparison to Responsive Reserve Service (RRS) lead to ECRS carrying a significant premium throughout the summer, with the average price of ECRS turning out 77% higher than RRS in FYQ2. The operational Texan sites made 72% of their overall revenue in this quarter, as the summer proved once more to be the most lucrative period of the year, driven by high temperatures. The Investment Manager's decision to change RTM in the months prior to unlock access to more markets proved beneficial, allowing the assets to capture the peak ECRS pricing in August. \n As load decreased into Autumn, and with the start of the permitted ERCOT maintenance windows, renewable energy generation as a factor of total demand increased. This invariably led to high price volatility throughout the ERCOT system. In West Texas, where the operational portfolio sites are located, high levels of wind provided lucrative trading opportunities as the assets participated increasingly in trading. \n Texas did not see significant disturbance from winter storms compared to previous years (winter storms Uri and Elliott). The FY22/23 storms led to considerable increases in both energy and ancillary services prices, as they reduced the amount of operational capacity on the grid and impaired infrastructure. In January 2024, winter storm Heather brought freezing temperatures to Texas for multiple days, however, the impact on grid infrastructure was limited. Reserves prices saw an increase over January, with an average ECRS price across three days of $170/MW/hr, raising the month's average to $18.8/MW/hr. The remainder of Q4 was mild, leading to low opportunity in ancillary services and reduced opportunity in wholesale trading, although milder conditions led to more trading as a percentage of revenue, with 20% coming from trading in Q4 compared to 11% in Q3. \n Overall, the Texan portfolio outperformed the previous year by 57%. RRS saw a 22% increase in average price compared to the previous year, however, the distribution of RRS pricing through the year was comparatively more skewed towards higher prices. Less frequent but more exceptionally high-priced days pushed the overall average upwards at the expense of mid- and low-priced days. This further illustrates the value in capturing periods of peak pricing, as well as designing alternative strategies on days of lower prices. \n California \n Table 6: Overview of the Californian Market \n \n \n \n \n TSO \n \n \n CAISO \n \n \n \n \n Current Phase \n \n \n In Construction \n \n \n \n \n Target Energisation \n \n \n December 2024 \n \n \n \n \n California's grid has continued to accommodate BESS, with a further 6.8 GW planned for deployment in the 2024 calendar year 6 . This increase aligns with the additional renewable energy on the grid, as a further 4.8 GW of solar energy capacity is planned to interconnect in 2024. Such increases in renewable generation, especially from solar, have continued to drive the load shape towards a \"duck-curve\". High renewable penetration on the grid has increasingly led to suppressed energy pricing during peak solar generation hours. This trend is expected to yield frequent negative pricing during \"shoulder months\", where the load is at its lowest, increasing availability of spreads available to BESS for trading. \n 6      S&P Global - Outlook 2024: CAISO battery boom continues with over 6 GW planned in 2024 \n At the end of the previous financial year, CAISO and the CPUC approved the implementation of the mid-term reliability programme. As a result of this decision, the relative scarcity of projects available to deliver Resource Adequacy (RA) contracts has led to an increase in RA contract values. As an eligible participant, batteries that are not currently committed to an RA agreement have been able to capitalise on this opportunity. \n These long-term contracts are expected to account for a significant proportion of revenue (up to c.40%), presenting a valuable opportunity for eligible battery projects, including the Company's 200 MW/400 MWh Big Rock asset. \n Overall portfolio performance \n The portfolio generated £41.4m in revenues, an increase of 5.5% compared to the previous year (2023 Financial Year £39.3m), with weighted annualised revenue of c. £130,000/MW (£15.12/MW/hr). This was achieved through geographical diversification and the Company's unique ability to generate revenues even when some markets were hindered by seasonal variation or saturation. \n Table 7: Summary of Portfolio Performance \n \n \n \n \n \n \n \n £(000's) \n \n \n % within grid \n \n \n \n \n GB 189.6 MW / 180.9 MWh \n \n \n \n \n \n \n \n \n \n \n Ancillary Services \n \n \n 3,226 \n \n \n 32% \n \n \n \n \n Capacity Market \n \n \n 2,007 \n \n \n 20% \n \n \n \n \n Wholesale Trading \n \n \n 1,032 \n \n \n 10% \n \n \n \n \n Other 7 \n \n \n 3,795 \n \n \n 38% \n \n \n \n \n Total 8 \n \n \n 10,059 \n \n \n 100% \n \n \n \n \n Ireland 130 MW / 72.6 MWh \n \n \n \n \n \n \n \n \n \n \n Ancillary Services \n \n \n 22,474 \n \n \n 96% \n \n \n \n \n Capacity Market \n \n \n 734 \n \n \n 3% \n \n \n \n \n Wholesale Trading \n \n \n 318 \n \n \n 1% \n \n \n \n \n Other \n \n \n 82 \n \n \n 0% \n \n \n \n \n Total \n \n \n 23,608 \n \n \n 100% \n \n \n \n \n Germany 22 MW / 29 MWh \n \n \n \n \n \n \n \n \n \n \n Ancillary Services \n \n \n 953 \n \n \n 54% \n \n \n \n \n Wholesale Trading \n \n \n 807 \n \n \n 46% \n \n \n \n \n Other \n \n \n - \n \n \n 0% \n \n \n \n \n Total 9 \n \n \n 1,760 \n \n \n 100% \n \n \n \n \n Texas 29.85 MW / 59.7 MWh \n \n \n \n \n \n \n \n \n \n \n Ancillary Services \n \n \n 5,128 \n \n \n 86% \n \n \n \n \n Wholesale Trading \n \n \n 633 \n \n \n 10% \n \n \n \n \n Other \n \n \n 223 \n \n \n 4% \n \n \n \n \n Total \n \n \n 5,983 \n \n \n 100% \n \n \n \n \n Portfolio Total \n \n \n 41,411 \n \n \n \n \n \n \n \n   \n \n \n \n \n Market \n \n \n Revenue \n£(000's) \n \n \n £(000's)/ \nMW/yr \n \n \n £/MW/hr \n \n \n £(000's)/ \nMWh/yr \n \n \n £/MWh/hr \n \n \n \n \n GB \n \n \n £10,059 \n \n \n £77 \n \n \n £8.80 \n \n \n £83 \n \n \n £9.44 \n \n \n \n \n Ireland \n \n \n £23,608 \n \n \n £182 \n \n \n £20.67 \n \n \n £325 \n \n \n £37.02 \n \n \n \n \n Germany \n \n \n £1,760 \n \n \n £80 \n \n \n £9.11 \n \n \n £61 \n \n \n £6.91 \n \n \n \n \n Texas \n \n \n £5,983 \n \n \n £200 \n \n \n £22.82 \n \n \n £100 \n \n \n £11.41 \n \n \n \n \n Weighted Average \n \n \n £41,411 \n \n \n £133 \n \n \n £15.12 \n \n \n £147 \n \n \n £16.69 \n \n \n \n \n   \n \n \n \n \n Total Revenue £(000's) \n \n \n Jun-end 2023 \n \n \n Sep-end 2023 \n \n \n Dec-end 2023 \n \n \n Mar-end 2024 \n \n \n \n \n GB \n \n \n £1,859 \n \n \n £1,775 \n \n \n £1,647 \n \n \n £4,777 \n \n \n \n \n Ireland \n \n \n £3,931 \n \n \n £5,797 \n \n \n £7,145 \n \n \n £6,736 \n \n \n \n \n Germany \n \n \n £340 \n \n \n £509 \n \n \n £530 \n \n \n £381 \n \n \n \n \n Texas \n \n \n £798 \n \n \n £4,325 \n \n \n £338 \n \n \n £522 \n \n \n \n \n Total Revenue \n \n \n £6,928 \n \n \n £12,406 \n \n \n £9,660 \n \n \n £12,416 \n \n \n \n \n Operational Capacity \n \n \n 291.6 MW \n \n \n 291.6 MW \n \n \n 371.5 MW \n \n \n 371.5 MW \n \n \n \n \n 7      Includes REPs, ABSVD, NIV, and Liquidated Damages. \n 8      The Company holds a 49% ownership interest in Cenin (4.0 MW) and retains 49% of the generated revenue. \n 9      The Company holds a 90% ownership interest in Cremzow (22 MW) and retains 90% of the generated revenue, while Enertrag maintains a minority stake in the asset. \n Asset Performance \n The portfolio performed well with average availability incorporating all commercial operations downtime, including planned preventive maintenance, exceeding 93% across the reporting period. \n Great Britain: \n The GB fleet performed well during the period, with the fleet's average availability broadly in line with the consolidated portfolio average. Larport's availability was impacted due to a substation transformer failure, which was resolved in January without ongoing concern. \n Ireland: \n Project performance in Ireland remains a highlight for the portfolio, with over 99% availability over FY 24/25 (a small uplift on FY 22/23). All Irish projects responded to the requirements of DS3 services without issue. As in FY22/23, all DS3 events were responded to correctly and the projects continue to generate revenue in these services without penalties. \n Germany: \n The Cremzow project comprises two phases, a 20 MW phase and a pilot 2 MW phase. The 20 MW phase performed well during the period and met expectations, however, the 2 MW phase had lower availability as it uses older technology. The Investment Manager is currently exploring options to enhance the availability of the 2 MW phase in the long term. \n US - Texas: \n The three operational projects (Snyder, Sweetwater and Westover) performed well in the first half of the reporting period, which was critical for project revenues as summarised in the revenue performance section of this report. Downtime was mostly driven by inverter failures, although communications network connection failures drove some outages. These issues have been addressed by installing redundancy measures such as satellite backup. The Investment Manager has been working closely with the inverter manufacturer and O&M provider to identify measures to upgrade inverters at each site (some firmware updates and upgrades are now completed, with more upgrades due in May 2024). Preventative maintenance is being coordinated to maximise each project's capability for stable performance ahead of the summer season and peak pricing. \n Asset Management Developments \n This was another busy year for both the industry and the portfolio. \n Trials were completed with battery analytics providers and a suitable supplier was identified for supporting the wider portfolio. Insurers valued the material risk reduction of this approach, and the Investment Manager received and accepted quotes for improved premium terms for multiple sites in GB. Shortly after the reporting period, this approach extended to a global portfolio policy utilising the same monitoring and diagnosis software: it is believed this will be the first global policy of its kind for a portfolio of battery storage systems, highlighting the Investment Manager's approach to thought leadership whilst leading by example. Additional projects (since Cremzow) are also being retrofitted with electrolyte vapour detection (an additional mitigation through hardware to avoid thermal runaway occurring), evidencing the Investment Manager's commitment to best practices in safety for the fleet. \n The Investment Manager continued to identify and enact operational performance efficiencies. In GB, reduced prices were negotiated across the majority of O&M contracts and most asset management contracts were terminated in favour of in‑house management enabled by the growing technical capabilities and experience of the Investment Manager. In Ireland, project warranties were reviewed and material cost savings were identified (effective Q1 FY24/25). The Investment Manager will deliver asset management activities for all three operational Irish projects moving forward. Engagement with RTMs in both Germany and Texas remains strong and will facilitate improved coordination and scheduling of downtime to best support revenue optimisation in these markets. \n Data-driven asset management will be a focus of FY24/25. Partners have been identified (with contractual negotiations underway) for the entire portfolio to support data collection, battery analytics, automated operational insight and live alerting. Many benefits are expected from this approach, such as increasing availability by quicker awareness of project faults and better decision-making for RTMs and commercial optimisation teams. \n Project Progress Overview \n Stony (79.9 MW - Great Britain) - Operational \n Construction at Stony was successfully completed in July 2023, and the site was subsequently energised in September 2023. The commissioning process went smoothly, and the asset began providing service in December 2023. Operational notifications have been received from the distribution network operator, and the asset is now active across ancillary services, trading and Capacity Market. \n Ferrymuir (49.9 MW - Great Britain) - Operational \n Works at Ferrymuir were disrupted by the insolvency of the contestable works contractor, Smith Brothers Contracting. The Investment Manager secured critical long lead time equipment and arranged the appointment of a replacement independent connection contractor. Working with the utility operator, Scottish Power, the completion of the contestable works was negotiated, and the site was energised in February 2024. Revenue generation from the asset began in July 2024. As site take-over was scheduled to occur at the end of May 2024, but the milestone was not achieved, the Company is pursuing its contractual remedies to compensate for lost revenues due to those delays. \n Enderby (57 MW - Great Britain) \n Pre-commencement planning conditions were fully discharged, and the contractors mobilised to site in late Spring 2023. Rapid progress was made on the completion of the civil engineering and drainage works at the BESS site and all of the infrastructure is now installed. The batteries, power conversion system (PCS) and substation are delivered, installed and ready for energisation. Connection to the grid has been prevented by delay to National Grid's protection system on account of rectification of security vulnerabilities. National Grid have completed their works and energisation is to commence in August. \n Dogfish (75 MW - Texas) \n At Dogfish, the transformer, switchgear and ancillary high-voltage equipment were procured in September ahead of the close of the EPC to minimise the impact of long lead manufacture and delivery on project schedule. The EPC was signed with Nidec in December and design and procurement are well advanced. Physical works of a significant nature have been completed at the site to safe-harbour 2023/24 energy community designation for the investment tax credit 10% enhancement. Works are on track for energisation in February 2025. This is later than previously reported owing to selection of Nidec as the EPC delivery partner after the opportunity for supplier financing arose. Negotiation of the finance agreements together with re-opening EPC negotiations took time but offered lower risk and better alignment with the Manager's capital allocation strategy. \n Big Rock (200 MW - California) \n Completion of pre-commencement development obligations was completed through the summer of 2023, and ministerial permits were issued by the County ahead of mobilisation. All major procurement is complete for Big Rock and works are progressing well on site. The BESS EPC contractor has completed the access roads, grading and drainage works. All of the foundation piles are installed, and the BESS enclosures have begun to be delivered to the site. The substation and overhead line construction are progressing on schedule while transformer manufacture is complete, and delivery is planned for June. Line outage and switchyard energisation are being scheduled with the local utility for September - system conditions allowing - with commissioning on the BESS to follow. The BESS is on track to be energised in December 2024. \n DEVELOPMENT AND PRE-CONSTRUCTION \n The construction schedule for Porterstown II has been revised to accommodate several important factors. Notably, there was a significant 14% reduction in battery prices 10 between 2022 and 2023 onwards, with this trend extending into 2024. The Investment Manager has, therefore, made an adjustment to the construction schedule to capitalise on the declining prices and policy and liquidity considerations in order to maximise returns. This strategy is consistent with the Investment Manager's history of minimising capex through various means, such as strategic financing, exploiting pricing and policy trends. The Investment Manager is also cognisant of the current interest rate environment and signals from the BOE, and its use of debt in the current environment. Therefore, this adjustment to the construction schedule is viewed as a proactive step that is expected to result in a higher asset IRR and a good example of active management. The Investment Manager will update the market in the near term on construction dates. \n 10    Source: Bloomberg \n The Investment Manager has completed applications for new planning consents for Kilmannock I and II to take advantage of the latest technology configurations and the nature of the site topography. The consent for Kilmannock I and for Mucklagh, the new addition to the portfolio as of March 2024, has been received. Pre-commencement planning conditions for Kilmannock I are being discharged with an archaeological investigation most recently completed in April 2024 without any finds. \n At Middleton, similar archaeology works for a pre-commencement condition are planned, and work is underway on construction environmental management plans, drainage design and system design. \n Long lead procurement for the main grid transformers for Kilmannock and Middleton is underway. Projects are in good readiness to proceed to construction pending final capital allocation. \n Battery prices have continued to fall through 2023 and 2024, reinforcing the Investment Manager's decision not to overbuild assets, ensuring optimal capacity to serve the market opportunities present and configuring projects for future modification. Rapid growth of battery manufacturing has outpaced demand, which is leading to significant downward pricing pressure on battery makers. Looking ahead to 2025, US manufacturers benefiting from IRA subsidies are expected to further intensify competition, potentially driving prices further down. For projects currently in procurement, the Investment Manager has secured price reductions of between 8% to 34% from Q3 2023 to Q2 2024, for combined battery module and container offers. \n Table 8: Sites in construction \n \n \n \n \n Construction \n \n \n Capacity \n \n \n Target Energisation \n \n \n \n \n Stony \n \n \n 79.9 MW \n \n \n Energised \n \n \n \n \n Ferrymuir \n \n \n 49.9 MW \n \n \n Energised \n \n \n \n \n Enderby \n \n \n 57.0 MW \n \n \n Sep-24 \n \n \n \n \n Big Rock \n \n \n 200.0 MW \n \n \n Dec-24 \n \n \n \n \n Dogfish \n \n \n 75.0 MW \n \n \n Feb-25 \n \n \n \n \n Table 9: This table lists the expected availability of grid connections where contracts accepted and signed for pre-construction assets. Completion of development, procurement and ultimately construction will be scheduled to align with connection availability while optimising capital deployment. \n \n \n \n \n Other Portfolio \n \n \n Grid Availability \n \n \n \n \n PBSL2 \n \n \n TBC 11 \n \n \n \n \n Mineral wells \n \n \n 2025 \n \n \n \n \n Mesquite \n \n \n 2025 \n \n \n \n \n Cedar hill \n \n \n 2025 \n \n \n \n \n Wichita falls \n \n \n 2025 \n \n \n \n \n KBSL 1 \n \n \n 2026 \n \n \n \n \n Middleton \n \n \n 2026 \n \n \n \n \n KBSL2 \n \n \n 2027 \n \n \n \n \n Mucklagh \n \n \n 2028 \n \n \n \n \n 11    Energisation target to be determined based on capex pricing and market opportunity. The Investment Manager expects to provide details in the Company's next Interim Report \n \nQ&A with Sumi Arima \n Sumi Arima \n CIO and CFO of Gore Street Capital, the Investment Manager \n Q: What were the key milestones reached in the 2024 fiscal year? \n Unlike the previous reporting period, which was defined by a series of acquisitions that took the Company into three new international markets, FY23/24 was a milestone year in itself as the strength of the diversified strategy was illustrated. We have always believed that, as a responsible investor dedicated to delivering sustainable value to shareholders, diversification was the correct choice to lower risk and access as wide a range of revenue streams as possible. The consolidated portfolio over the reporting period has demonstrated why this choice was the right one by consistently delivering average revenue of £15.1 per MW/hr, or c.£133,000 per MW/year. \n We have been able to report this average figure throughout the year as strong performance in markets like Ireland and Texas offset the decline we've seen in GB and the normalisation of revenues in Germany following the previous reporting period's unprecedented market conditions. This was particularly evident in FY Q2 driven by high volatility in the ERCOT market and our prequalification to deliver the new ECRS service. Reaching approximately £150/MW/hr for the month of August was a particular highlight as the Company's highest monthly revenue per MW ever achieved from a single market. \n More important is that this story continued throughout the year, highlighting the uniquely stable revenue profile the Company has achieved through its diversification strategy. \n We also saw the confidence that this approach has inspired across the market, with contracts negotiated with strategic partners to secure growth, in part, on the basis of share issues. This allowed the Company to grow its portfolio in the lucrative Irish market with a minimal cash consideration, aligning interests between the Company and key stakeholders and demonstrating the value of our track record of success. \n Work is already well underway to continue to build on this record, with the Company's biggest projects to date moving ahead at pace. Energisation of the 79.9 MW Stony asset in September was a key milestone, becoming the largest energised project to date within the portfolio, while progress at the prioritised US sites is positioning the Company to once again capitalise on its international presence through access to new revenue streams. \n We have been able to overcome the complexities of entry into California, one of the most regulated markets in the world, to progress the 200 MW Big Rock asset towards its targeted energisation date in December. The scale of this project compared to the Company's first 6 MW asset in GB is a true reflection of its ambition, and the results we've seen this reporting period show how important it has been to overcome the challenges associated with entering new markets over the last six years to create a diversified and successful portfolio. \n Q: Did revenues emerge as expected over the reporting period? \n We underwrite our assets to declining revenues on the assumption that, as a first mover across multiple geographies, new market players would emerge and build out capacity to compete with the Company's portfolio once the business case is proven and capital costs reduce. The GB market is the best example of this, having undergone cycles in which demand for grid balancing services exceeds supply, bringing new entrants into the market chasing high profitability. This inevitably leads to oversupply of capacity and a reduction in available revenues, causing new capacity additions to subside. \n What did surprise us over the reporting period is how much capacity continued to be built out in GB by peers with a single market strategy. The fundamental driver of increased system volatility that stems, in part, from higher penetration of renewables on the grid was not at the level required to support so much energy storage capacity coming online, which is why the GB market has experienced such suppressed revenues over the reporting period. This situation also effectively reinforces the decision to follow a diversified strategy, as the Company has been able to access a wide range of revenues across an international portfolio. \n Seasonal variations between regions continued to play a role in the revenues that emerged over the reporting period although in a slightly less pronounced way. In Ireland, for example, higher wind generation in the summer as well as winter months resulted in consistently stronger performance throughout the year as the Company's assets helped to ensure stable integration of renewables. \n We anticipated higher overall revenues from ERCOT as a result of our transition to a more sophisticated revenue strategy, which we knew would provide access to a wider range of revenue streams. The Investment Manager is in regular contact with our partners in Texas as well as the grid operator to understand what volatility is expected on a quarterly basis. This meant we were prepared for the scale of opportunity achieved over the summer. \n As well as cushioning market decline in GB, the expected strong performance in Ireland and Texas also helped to reduce the impact of revenue reductions in Germany. This fall stemmed from a reduction in power prices compared to the 2022/23 period, which contained extreme gas market volatility as the EU raced to reduce its reliance on Russian gas supplies. With gas setting marginal prices for the power market, revenues available to the Company's Germany asset were higher at that time compared to what we expected to see once the market resettled. With EU efforts firmly in effect over the latest reporting period, power prices returned to more normalised levels as predicted, causing a sharp fall in revenues compared to the previous year's extreme prices. Our strategy for the year accounted for this predicted decline as we adopted a more data-driven, trading focused approach to broaden our activities beyond just ancillary services. \n Q: How has the decline of GB revenues affected the Company's consolidated revenue performance? \n The downturn in GB has been drastic, with a combination of saturation in ancillary services and reduced volatility in the wholesale market reducing the value that can be extracted from this single market. The decisions taken by the Company since establishing the energy storage asset class six years ago-to allocate capital across multiple, uncorrelated markets-have meant that the impact on the consolidated portfolio's performance has been minor. We also appreciated the support of shareholders back in the 2022 General Meeting, where shareholders supported an amendment to allow the Company greater flexibility to invest outside of the UK and Ireland, reducing the minimum allocation to UK from 60% to 40% which further supported our diversification strategy. The Company has, in fact, increased its overall revenue on an absolute basis compared to the previous financial year due to the uptick we've seen in other geographies, highlighting the uniquely stable revenue profile of its diversification strategy. \n The average revenue of £8.80 per MW/hr we've seen in GB, including liquidated damages, compares to £19.6 per MW/ hr from the non-GB portfolio. With almost no correlation between GB revenue and non-GB revenue, the entire operational portfolio has been able to maintain consistent performance and reduce revenue volatility over half, as illustrated in figure 6  on page 22 of the 2024 annual report, compared to what would be achieved by a GB-only strategy. The confidence this provides for investors in the Company's ability to deliver consistent returns is a result of the diversification strategy enacted by the Investment Manager and how capital has been allocated across five international markets to date. We are, therefore, committed to further reducing the Company's exposure to GB as a proportion of capacity on a MWh basis to provide greater value for investors. \n Markets like Ireland and Texas could experience similar cyclical declines as more capacity comes online and their markets become more saturated. The difference, however, is that these markets are adding renewables at a faster rate than we are seeing in GB, driving the fundamental economic case for energy storage. We will also be adding capacity in new markets with the scheduled energisation of the 200 MW Big Rock asset in California by the end of 2024, providing access to long-term contracted revenue from the high-value Resource Adequacy market. As with participation in other uncorrelated markets, this will contribute to revenue stability at a consolidated portfolio level. \n We are already seeing the current weaknesses of the GB market discourage new market entrants and capacity additions, potentially kickstarting the next cycle of recovery. Energy storage is a long-term asset experiencing volatility year by year but, as more renewables are added and the flexibility needs of grid operators increase, the crucial role of the asset class remains strong. \n Q: What is the Company's view on GB market recovery? \n As the Company has a dedicated focus on delivering sustainable returns through its diversified approach, monitoring profitability over the long term rather than reacting to short-term trends is a key role fulfilled by the Investment Manager to ensure this is achieved. \n As one of the first active players in the GB market, we have seen high revenue years followed by overbuild and a subsequent reduction in available revenue from frequency services. This is the situation we find ourselves in today, with GB's c.4 GW of battery energy storage offering more capacity to the ancillary services market than currently required. Wholesale trading revenue, although increasing, still does not offer high enough returns on a consistent basis to make up this shortfall and so value is more difficult to extract. \n In the past this has led to under-build of new projects until profitability returns to previously seen levels and we are already seeing signs of that cycle continuing, with low-capacity additions to the GB fleet in FY Q4. We have remained prudent in our build strategy throughout these cycles, designing assets to suit available revenue streams while minimising capex-on a MW and MWh installed basis-with the optionality to retrofit with additional duration when market opportunities warrant the additional capital expenditure. \n While the timeline for recovery remains unclear, we are seeing National Grid ESO continue to develop new products and capabilities to better utilise the unique capabilities of battery energy storage systems. Higher revenue generation could, therefore, be on the horizon in GB but the timing of this recovery is a complex question. It is largely dependent on the pace of renewable deployment, the grid operator's frequency service procurement needs, the global gas market, and the weather over the coming winter period. Any one of these factors could result in a switch to high revenue generation for the Company's GB portfolio, but it is impossible to forecast the exact timing. \n This illustrates the underlying value of the Company's diversified operational portfolio as it is able to deliver returns for investors throughout these market cycles from across four uncorrelated markets to date, with CAISO in California soon to follow. \n Q: Would you ever consider a tolling agreement to offset revenue risk in the future? \n We regularly test the market for tolling agreements and are yet to be convinced they offer an attractive alternative or addition to our diversified approach to revenues. The recently and widely reported large tolling agreement in GB appears to fall in line with the price levels we've seen when testing the tolling market and, while it may serve to improve confidence among lenders, locking in an agreement at a low point in the market has considerable disadvantages. Any upside from market recovery is eliminated for the tolling agreement period which, for investors, means they are forced to settle for a certain but potentially low return. \n Remaining merchant allows the Company to retain any potential upsides across a portfolio that is already derisked by its geographical spread across five uncorrelated markets. More importantly, we have the control over each asset to optimise the Company's revenue strategy to ensure these upsides are accessible while ensuring they maintain best-in-class operational performance. \n Tolls often come with increased cycle rates, which can degrade the battery, while putting in place stringent availability requirements and penalties if they dip below that level. As an active manager with an in-house commercial and asset management team working in unison to maintain availability while engaging in a wide range of optimal revenue streams, we would not rush to give up that control. \n Q: Why did the Company increase its capacity in Ireland? \n The strategic decision to increase capacity in the Republic of Ireland was driven by the consistently lucrative nature of this market for the Company since its initial international expansion in 2019. The Irish market has exhibited strong fundamentals and continues to represent an attractive investment opportunity aligning with our objectives. \n Through these transactions, the Company acquired the remaining 49% stake in two existing operational Irish assets - the combined 90 MW Porterstown project and 120 MW Kilmannock construction asset - through the issuance of new ordinary shares to our strategic partner Low Carbon. This long-term relationship, which was established when the Company first diversified into the Irish market, also allowed us to exercise the option to secure a 51% interest in Project Mucklagh, a 75 MW pre-construction asset with targeted energisation in 2028, for a development fee agreed back in 2019. This was an attractive cash consideration on a £/MW basis compared to the prices we see now following rapid development of the Irish market, making the legal option agreed by the Company five years ago extremely cost efficient for today. \n These acquisitions represent innovative and efficient capital deployment solidifying the Company's commitment to portfolio diversification across geographic markets while strengthening a strategic partnership by bringing Low Carbon onto the Company's share register. This will ensure all parties are fully aligned during buildout of the assets to ensure they are delivered at pace to join the Irish market, which will remain critical within the Company's diversified portfolio. \n The Company's ability to expand its network of long-term partners enhances its access to a pipeline of development opportunities across target geographies. As evidenced by the Company's continued execution in Ireland, active management of the portfolio through strategic acquisitions and partnerships will remain a key driver of long-term growth and shareholder value generation.. \n Q: How did the Company overcome the difficulties faced in securing capital during a difficult time for raising new funds? \n The rapid increase in interest rates since late 2022 has significantly impacted the investment trust sector, particularly renewable energy investment trusts. These trusts have historically often traded at a premium to their NAV, reflecting investor demand and confidence in the sector's growth prospects, however, as interest rates have surged, the yield offered by these trusts became less attractive over the period relative to the risk-free rates available on government bonds. \n This has led to a sell-off in the sector, depressing share prices and causing trusts to trade at discounts to their NAV levels. The discount levels have become quite pronounced for even some of the largest renewable energy investment trusts. This creates challenges from a capital raising standpoint as trusts are prohibited from issuing new shares below NAV, restricting their ability to fund new projects and acquisitions. \n The challenge for the Company has been to continue to pursue a growth strategy in this environment but the Investment Manager has been able to adopt alternative complex structures in which contracts can be negotiated with strategic partners to include payment, at least in part, through share issuance at NAV. During the reporting period, this allowed us to raise gross proceeds of £15.8 million from our long-term strategic partner Nidec and grow the Company's portfolio in the lucrative Irish market by c. 24% with a minimal cash consideration through well-structured negotiations with Low Carbon. \n This approach reduces the immediate cash burden on the Company while aligning our objectives with partners who have demonstrated confidence in our strategy and ability to deliver strong returns over the long term. These achievements underscore the Company's ability to navigate the headwinds of the current high interest rate environment and maintain a growth trajectory through innovative problem-solving and strong industry relationships. \n While discounts persist, capital raising and funding new projects will remain a key challenge for renewable energy infrastructure investment trusts to navigate, however, we have demonstrated our ability to overcome this challenge and continue to deliver growth and value to shareholders. \n Q: Has the Company's use of leverage evolved in the period as project-level finance or alternative financing structures are employed? \n While still a young asset class, utility-scale energy storage has evolved rapidly in the six years since the Company first listed on the London Stock Exchange. Unlike conventional renewables, which offer long-term contracted revenues to provide certainty to lenders, energy storage remains largely based on a merchant revenue stack, reflecting the uniquely complex and varying capabilities of the technology. This has historically been met with reduced appetite from lenders to provide leverage to investments on attractive terms. As the market has matured and the Company's track record of success has become well-established, lenders are more comfortable than ever with our approach. \n We remain committed to ensuring resilience on the balance sheet by retaining the Aggregate Group Debt below 30% of GAV and had reached just 6.5% of GAV at the end of the financial year. We expect this to rise to c.15% after drawing down on available debt lines to support the buildout of the Company's near-term portfolio while maintaining a low level of gearing but retaining headroom to increase borrowing should it be necessary. We have shown this period that the Company is able to capitalise on its track record to secure additional debt from key partners like Santander and First Citizens Bank at the portfolio and project level. \n During the period we successfully increased the Company's revolving credit facility from £15 million to £50 million to support the construction of its projects in construction. The Company also secured $60m in debt finance at the asset level for the first time to support the 200 MW Big Rock project. The loan from First Citizens Bank reflects the value this project offers to the portfolio through the addition of long-term contracted revenues for up to c.40% of the revenue stack over the project's lifetime. Once fully drawn, the $60 million facility amounts to a conservative level of gearing equal to 25-30% of the gross asset value of the project. \n These agreements demonstrate the Company's ability to raise capital, both equity and debt, in the current climate as part of a strategy to demonstrate and implement appropriate and balanced liquidity management. They also show lenders have become increasingly comfortable with the Company's approach, delivered by the Investment Manager. \n Q: How have capex prices changed over the reporting period and what opportunities arise from these changes? \n Our strategy has always been to build assets to the requirements of revenue streams available in the market at the time of operation. We are unique in operating assets across four different markets all with different system durations, but with a strategic view on future capacity additions should capex costs align with revenue opportunities. \n Many operators in GB, for example, have committed themselves to deployment of two-hour systems at a considerable cost on the assumption that trading opportunities would emerge as the dominant revenue stream to warrant such investment. We have instead deployed capital efficiently to focus on shorter-duration systems, primarily to deliver frequency response and ancillary services but designed with the ability to augment their duration. This approach has allowed us to maintain disciplined control over capital costs and retain the potential to take advantage of changes in capex prices when they prove most advantageous for the Company and its shareholders. \n We have seen capex costs fall dramatically in the last two years driven by economies of scale and technology advancements in manufacturing, alongside a change in demand from the electric vehicle market. Today we are able to purchase equipment at a considerable discount compared to the costs incurred by two-hour projects built in recent years, which remain unrepresentative of the value available on the market. \n We will continue to review options to augment our systems with additional duration in this context of lower capex prices, but will maintain our prudent approach to capital allocation in response to available revenue opportunities. \n We will, of course, remain vigilant about potential headwinds, such as supply chain disruptions, geopolitical tensions, and fluctuations in raw material prices as we continue to build out our portfolio. We are, however, well-positioned to navigate the dynamic energy storage landscape and deliver sustainable returns for our stakeholders. \n Q: What is your key focus for the next financial year? \n As we look ahead to the next reporting period and beyond, we remain committed to driving sustainable growth and maximising returns for our investors. This begins with prioritising the build out of 332 MW of new capacity over the next seven months. This includes our landmark 200 MW Big Rock project, which will fully establish our presence in the CAISO market in California. Bringing these assets online will be crucial for expanding our operational footprint and revenue generation capabilities, improving dividend cover and creating further value for shareholders as projects are derisked as they move to operational stage. \n The prioritised portfolio represents the optimal allocation of capital across the five markets in which the Company has assets, and we will continue to monitor how best to utilise the Company's existing resources. This will include evaluating opportunities to recycle capital into the most attractive jurisdictions through potential asset sales and redeployment of proceeds into higher-returning geographies and revenue opportunities. Our focus remains on maximising profitability and maintaining our leading position in revenue per MW and per MWh. \n Raising capital through other means will also be a priority. We have shown over the reporting period this is possible through alternative structures and are keen to continue leveraging the Company's track record and the Investment Manager's extensive network to secure new finance. \n The fundamental drivers supporting energy storage remain robust, driven by climate policies and energy security needs worldwide. We are well-positioned to capitalise on these conditions and deliver sustainable growth to investors. \n NAV Overview and Drivers \n Table 10: NAV Bridge \n \n \n \n \n \n \n \n £m \n \n \n Pence per share \n \n \n \n \n NAV March 2023 \n \n \n 556 \n \n \n 115.6 \n \n \n \n \n Offering Proceeds \n \n \n 27 \n \n \n 0.0 \n \n \n \n \n Dividends \n \n \n (36) \n \n \n (7.4) \n \n \n \n \n Revenue Curves \n \n \n (35) \n \n \n (7.0) \n \n \n \n \n Inflation \n \n \n (7) \n \n \n (1.5) \n \n \n \n \n Discount Rates \n \n \n (13) \n \n \n (2.8) \n \n \n \n \n Net Portfolio Returns \n \n \n 49 \n \n \n 10.1 \n \n \n \n \n NAV March 2024 \n \n \n 541 \n \n \n 107.0 \n \n \n \n \n Table 11: Reconciliation of Reported NAV \n \n \n \n \n \n \n \n 2024 \n \n \n 2023 \n \n \n \n \n Operational Portfolio \n \n \n 201,662,000 \n \n \n 166,252,000 \n \n \n \n \n Construction Portfolio \n \n \n 290,887,000 \n \n \n 269,037,000 \n \n \n \n \n Fair Value of Portfolio \n \n \n 492,549,000 \n \n \n 435,288,000 \n \n \n \n \n Group Cash \n \n \n 65,168,000 \n \n \n 136,809, 000 \n \n \n \n \n Other Net Assets/(Liabilities) \n \n \n (17,021,000) \n \n \n (15,832,000) \n \n \n \n \n NAV \n \n \n 540,697,000 \n \n \n 556,265,000 \n \n \n \n \n Aggregate Group Debt \n \n \n 37,345,000 \n \n \n - \n \n \n \n \n GAV \n \n \n 578,042,000 \n \n \n 556,265,000 \n \n \n \n \n The Company's independent valuer, BDO, conducted an independent valuation as of 31 March 2024, which included a review of key assumptions. The findings from BDO's valuation aligned with the Company's year-end valuations and the key assumptions adopted which were used to determine the final NAV. \n Successful active management during the period resulted in strong cash generation which along with a significant increase in energised capacity resulted in a 10.1 pence per share increase in NAV. Key macro assumptions, including inflation, revenue curves and discount rates reflecting the prevailing environment in which the Company operated, led to a decrease of 11.3 pence per share during the period. The Company also paid dividends, resulting in a 7.4 pence per share reduction in NAV. Below, the Investment Manager provides an overview of each of the key NAV drivers during the period: \n 1. Offering Proceeds \n The Company issued 23,700,000 new Ordinary Shares to strategic partners Nidec and Low Carbon. The shares were issued at the prevailing Net Asset Value on the date of issuance. In December 2023, 14,000,000 shares were issued to Nidec, followed by an additional issuance of 9,700,000 shares to Low Carbon in January, both at the prevailing NAV. \n 2. Dividends (-7.4 pence): \n The Company met its dividend target during the reported period, equal to 7.5p per share. Due to the issuance of additional shares partway through the reporting period, the per-share dividend included in the above NAV bridge, amounted to 7.4p. \n 3. Revenue Curves (-7.0 pence): \n The Company maintained its approach to revenue curves, taking the mid-case scenario from third-party research houses for the purpose of asset valuation. Where available, the Investment Manager took a blended average mid-case scenario from multiple research houses to gain a more balanced view of future revenue generation. The Investment Manager considers this method to provide a fair reflection of the underlying value of the portfolio. \n Throughout the year, key markets, notably Great Britain, experienced a decline in the revenue forecasts driven by recent weakness in revenue being factored in by research houses. Despite improved outlook in some markets, the net effect compared to the previous reporting period was a decrease of 7.0 pence in NAV. \n Material contracts secured during the period include: one-year T-4 Capacity Market contracts for Port of Tilbury, Lascar, Hulley, Larport and the Ancala assets and one-year T-1 Capacity Market contracts for Port of Tilbury, Stony, Ferrymuir and Enderby in GB; Capacity Market contracts for Porterstown in the Republic of Ireland (October 2023 to September 2024) and the Northern Irish assets (October 2027 to September 2028). In Germany, the forecasts were adjusted to reflect the hybrid revenue strategy (ancillary services & trading) implemented during the period, resulting in a slight increase in the assets valuation. In California, even though merchant ancillary services forecasts have seen a decrease in the period primarily due to changes in CAISO rules causing further state-of-charge management-related costs to batteries, the current market environment for long term fixed price resource adequacy contracts is favourable and is expected to be accretive to NAV once a contract has been secured. The curves were also updated for the Texan assets, with slight increases and decreases in future assumptions, dependent on the node of each asset - the overall effect for the Texan fleet was net neutral. \n The revenue curves used in valuing the Company's assets as of 31 March 2024 are provided in Figure 9 on page 26 of the 2024 annual report. \n 4. Inflation (-1.5 pence): \n As presented below, inflation assumptions applied across grids for 2024 and 2025+ reflect the inflationary macro environment observed globally. These are in line with those presented in the Company's Interim Report for the period ended 30 September 2023. \n Table 12: CPI Assumptions \n \n \n \n \n CPI Assumptions \n \n \n GB \n \n \n Ireland \n \n \n US \n \n \n Germany \n \n \n \n \n 2024 \n \n \n 2.75% \n \n \n 2.75% \n \n \n 2.75% \n \n \n 2.75% \n \n \n \n \n 2025+ \n \n \n 2.50% \n \n \n 2.50% \n \n \n 2.50% \n \n \n 2.50% \n \n \n \n \n 5. Discount Rates (-2.8 pence): \n To combat the persistent inflationary environment, central banks across different geographies raised interest rates, increasing yields for long-term government bonds. To align with the higher return environment, the Investment Manager increased the discount by 25 bps across al...

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