Morgan Stanley: The 5TWh Energy Storage Wave Will Reshape the Global Electricity Market

Overview

This is a global deep-dive report from Morgan Stanley’s ‘Future of Energy’ series, focusing on how commercial (merchant) battery energy storage systems (ESS) will reshape the global electricity market. The report’s core view is that driven by improving economics and energy security needs, global energy storage capacity will rapidly grow from about 1TWh today to around 5TWh by 2030 (an annual compound growth rate of roughly 46%). By then, energy storage will account for about 8% of global power capacity. While this percentage may seem modest, it already exceeds half of most grid evening peak-load demands, enough to significantly smooth electricity price fluctuations and lower average electricity prices. The report argues that the holy grail for utility markets is technology that can both lower prices for consumers and deliver acceptable returns for investors—and energy storage is now playing that role. The report also provides investors with a proprietary framework for analyzing commercial battery profitability, using Australia’s National Electricity Market (NEM) as a global case study, gradually expanding to cover major markets including the U.S., Europe, Southeast Asia, South Korea, and India, ultimately focusing on affordability of electricity prices and their impact on utility stocks.

Core views

Overall logic ('following volatility'): The report’s central argument is that newly installed energy storage will smooth electricity market volatility and lower average electricity prices. Thus, institutions hold a constructive stance toward energy storage investments in highly volatile markets (high proportion of variable renewable energy, high peak-to-average load ratios, rapid load growth). However, once energy storage starts 'setting' daily peak electricity prices, returns will be compressed—and this tipping point could come faster than expected. In the past year, Australia and Texas (ERCOT) have already seen this phenomenon. Based on this framework, the institution’s preferred commercial markets are PJM, CAISO, ERCOT, and Australia’s NEM, while the least favored are Singapore’s NEMS, South Korea’s KPX, and Japan’s JEPX. Demand and background: Global electricity demand is rising, with long-term electrification combined with AI investment and energy security needs placing a premium on 'quickly deployable' and 'stable dispatchable' capacity. Energy storage fits well in terms of time-to-power and levelized cost, and global grid energy storage penetration is rapidly increasing—Texas ERCOT at about 8%, PJM at about 3%, Europe’s ENTSO-E at about 4%, and Australia’s NEM at about 12%. Institutions estimate global energy storage investment by 2030 at around $0.6 trillion (based on construction costs of about $200/kWh and a 10% annual learning curve). Profitability framework and methodology: The report views energy arbitrage as the primary revenue source for commercial energy storage, typically accounting for 50%-70% of total revenue (directly or through contracts/derivatives). To facilitate cross-market comparisons, the institution focuses on the 'TB4 spread,' which is the average difference between the highest four-hour and lowest four-hour electricity prices each day. The framework presents two scenarios: First, when Top4 and Bottom4 prices are independent, energy storage as a price taker can earn excess economic rent (IRR > WACC, payback period < 5 years); second, when the two are correlated, energy storage itself sets high or low prices, and returns fall between the 'storage required return' and short-term marginal costs. The institution uses Australia’s NEM as a full calculation example. Market-by-market profile: In the U.S., ERCOT is an energy-based market where electricity prices can spike to $5,000/MWh during scarcity periods, and battery economics largely depend on volatility and scarce hours. But battery expansion has already reduced intraday volatility and pushed forward electricity prices below what institutions consider fundamental levels. IPP calls have also pointed out that batteries are one of the reasons behind falling ERCOT prices and weaker developer returns. PJM, meanwhile, relies on fixed income incentives from its capacity market, with the latest capacity auction clearing at about $333/MW-day (equivalent to roughly $49/MWh after factoring in 4-hour daily output and 59% capacity credit). The last two auctions both hit the ceiling price, and the latest cleared capacity was below demand. In Europe, unit costs have dropped dramatically—from over €0.25 million/MW in 2023 to about €0.11 million/MW in 2026, and hybrid solar-storage LCOE has fallen to around €95/MWh, with LCOS dropping from over €115 to about €55/MWh. Europe’s annual new energy storage additions have risen from 7.8 GWh in 2022 to 30 GWh in 2025, with cumulative installed capacity expected to exceed 300 GWh by 2030 (about 85 GWh in 2025). European battery revenues aren’t solely reliant on spot arbitrage; most markets rely primarily on ancillary services (FCR, aFRR), alongside spot arbitrage and capacity markets. Asia and emerging markets: In Southeast Asia, many markets rely mainly on capacity payments or fixed ROCE. Institutions estimate regional projects at about 7%-8% ROCE. Singapore’s spot peak-valley spread is around $80/MWh, the Philippines about $30/MWh, and Indonesia, Malaysia, Vietnam, and Thailand have limited arbitrage space due to regulated electricity prices. South Korea’s market stalled after battery fires in 2019-2020 but is now entering a policy-driven recovery phase. The government has set up a centralized ESS contracting market and offers capacity payments, aiming for 540-600 MW of new capacity annually from 2026-2029 (about 13 GWh), with local battery manufacturers almost entirely taking all winning bids—a contrast to China-dominated global supply chains. Coupled with U.S. OBBBA ITC eligibility, FEOC restrictions, and tariffs against China, Korean battery makers are poised to increase their share in the U.S. ESS market. India is seen as a potential landmark investment theme for the next decade, with battery costs dropping about 70% in three years and tendered electricity prices falling about 75%. Yet cumulative tenders have exceeded 90 GW, while actual commissioning remains small—about 90% of the battery value chain depends on Chinese imports, and 75% of two-hour capacity was awarded at “risk” prices. Handling of utility stocks: In earnings forecasts, institutions routinely factor in electricity prices and profit margins. They’ll cut earnings and EPS forecasts if downside risks arise (such as accelerated battery installation) and the forecast is already among the lowest in the market (as in Australia). Battery profitability is modeled under bull/baseline/bear scenarios: The baseline scenario assumes batteries earn WACC returns and NPV is essentially neutral; the bull scenario assumes batteries capture the spread between 'avoiding fire voltage loads' and 'scarcity pricing'; the bear scenario assumes the battery market is saturated and batteries eat into each other’s arbitrage opportunities (the so-called 'Ouroboros Effect').

Analysis framework

The main line of reasoning is 'following volatility': First, identify which markets have high volatility and where energy storage can earn arbitrage profits; then determine at what level of storage penetration the volatility will reverse and compress returns themselves, thus making differentiated choices across different markets and individual stocks. Methodologically, the institution starts from traditional electricity market analysis: Using the 'merit order' of generating units sorted by cost to build the supply curve, and overlaying the demand curve to get the price. Then it distinguishes between 'scarce markets' (where prices are high enough to attract new entrants, corresponding to revealing new entry prices/LCOE) and 'missing money markets' (where prices fall to just cover cash costs of marginal units, leaving them only breaking even without capital returns). On this basis, the institution introduces its own commercial energy storage framework: Using the TB4 spread as a common metric for comparing arbitrage revenues across markets, and using levelized energy storage costs (LCOS) as a threshold return, comparing the 'observed TB4 spread' with the 'required return' to rank markets. It also combines volatility factors (renewable penetration, peak-to-average ratio), the proportion of peak demand covered by storage, and revenue stack structure (capacity contracts, ancillary services) for comprehensive assessment. Finally, it ties the analysis back to individual stock earnings and valuations, using Australia as a 'leading sample' because it has high renewable penetration (43% in 2025), high volatility, and is one of the fastest-growing data center markets globally.

Methodology notes

• Industry/sector analysis frameworkSupply-demand framework

  Merit order supply curve + scarcity/missing money dual-state pricing in energy markets

  Generating units are sorted by operating cost from low to high to form the supply curve, then overlaid with demand to determine the electricity price. When prices rise high enough to attract new investment, it’s a 'scarce market'; when they fall just enough to cover cash costs, it’s a 'missing money market'. Understanding this pricing mechanism helps explain why energy storage makes more money in volatile markets.

• Industry/sector analysis framework

  Top-Bottom 4-hour spread (TB4), as a standardized measure of battery arbitrage revenue

  TB4 is the average difference between the highest four-hour and lowest four-hour electricity prices each day, representing the arbitrage space of 'charging low, discharging high.' The report uses it to compare how much money energy storage can make across different global markets—it’s the core tool for this profitability analysis.

• Industry/sector analysis frameworkCost curve analysis

  Levelized energy storage cost (LCOS) and levelized generation cost (LCOE) as investment thresholds

  The lifetime costs of energy storage or power sources are converted into levelized costs per MWh, serving as the threshold for deciding whether an investment is worthwhile. The report compares observed TB4 spreads with LCOS: If the spread is higher than the cost, energy storage earns excess returns; otherwise, returns are under pressure.

• Company fundamentals and financial frameworkROIC–WACC spread

  If batteries earn WACC returns, NPV is neutral; only when IRR > WACC does economic rent emerge

  Only when the internal rate of return (IRR) of a project exceeds the weighted average cost of capital (WACC) does it truly create value for shareholders. The report’s baseline scenario assumes batteries earn only WACC, leaving company value essentially neutral; only in the bull scenario do they generate excess economic rent—this is the yardstick for judging whether energy storage ‘boosts earnings.’

• Competition and strategic frameworkEconomies of scale / learning curve

  Battery costs fall by about 10% annually along the learning curve

  As cumulative production rises, unit costs keep falling along the 'learning curve.' The report estimates global energy storage investment size by 2030 based on an annual cost reduction of about 10%, explaining why energy storage economics keep improving and penetration rates accelerate.

• Event game theory and behavioral finance

  Bull/baseline/bear scenario modeling (including Monte Carlo electricity market simulation) and the 'Ouroboros Effect'

  Three scenarios depict the upper and lower bounds of battery profitability: The baseline earns WACC, the bull scenario captures the spread, and the bear scenario sees batteries eating into each other’s arbitrage space due to oversaturation ('Ouroboros Effect'). This scenario-based approach reminds readers that battery returns heavily depend on penetration rates and market saturation, rather than linear improvement.

Asset mapping & comparison

Structured mapping from thesis to named assets (strengths, weaknesses, peers, risks).

• Talen Energy (TLN.O)

  Preferred stock: Attractive valuation, potential premium PPA with data centers, benefiting from rising U.S. electricity prices; institution believes batteries won’t disrupt bullish electricity price logic amid high load growth in PJM/ERCOT

  Strengths

  Attractive valuation, potential for premium data center PPAs, benefiting from rising U.S. electricity prices; currently zero battery exposure but already queued up for over 3 GWh of long-duration storage projects in PJM and cooperating with Eos Energy to deploy zinc-based batteries

  Comparison

  Lower battery exposure compared to peers like Vistra, NRG, CEG; still mainly thermal (fossil + nuclear)

  Risks

  Long-duration storage projects haven’t yet made final investment decisions; queue delays pose deployment risks

• Vistra (VST.N)

  Preferred stock: Attractive valuation, potential premium data center PPAs, benefiting from rising U.S. electricity prices

  Strengths

  Highest battery exposure among peer IPPs (about 2% of portfolio)

  Comparison

  Higher battery exposure than NRG, TLN, CEG at about 1.5%

  Risks

  ERCOT battery expansion has already reduced intraday volatility and forward electricity prices, and recent weaker developer returns could drag down future development

• CEZ Group (CEZP.PR)

  Least favored stock: Judged from local market conditions and electricity price outlook through an evolving perspective of energy storage penetration

  Risks

  Negative impacts from local electricity price outlook and evolving energy storage penetration

• Korea Electric Power (015760.KS)

  Least favored stock: Judged from local market conditions and electricity price outlook

  Risks

  Weak local market conditions and electricity price outlook

• AGL Energy and Origin Energy (ORG, Australia)

  Australian integrated utility model: Generating and storage investments aim for 8%-11% post-tax returns, with rising battery profitability contribution

  Strengths

  Returns are enhancing (observed returns around 8%); AGL has about 1.3 GW/2.3 GWh of on-balance-sheet storage, ORG about 1.0 GW/3.5 GWh, plus off-balance-sheet and dispatched fleet

  Weaknesses

  Neither company separately discloses asset-level profitability; institution’s Australian earnings forecast is already among the lowest in the market

  Comparison

  AGL aims for the upper end of the return range for on-balance-sheet storage, while ORG targets the upper end during the first half of unit lifespan

  Risks

  Downward risk from accelerated battery installation pushing prices down; reverse selection risk in Australia’s Solar Sharer Offer could compress retail margins

Key data

• Global energy storage (ESS) capacity outlookAbout 5TWh by 2030, compared to about 1TWh todayAnnual compound growth rate of about 46%
• Energy storage as a share of global power capacityAbout 8% by 2030Global power capacity is about 11TW, growing about 7% annually; 8% already exceeds half of most grid evening peak-load demands
• Global energy storage investment sizeAbout $0.6 trillion by 2030Estimated based on construction costs of about $200/kWh and a 10% annual learning curve
• Energy storage penetration rates by marketERCOT about 8%, PJM about 3%, Europe’s ENTSO-E about 4%, Australia’s NEM about 12%Penetration rates are rising rapidly
• Energy arbitrage’s share of battery revenueAbout 50%-70%Directly or through contracts/derivatives, it’s the primary revenue source for commercial batteries
• Energy storage penetration needed to affect electricity pricesAs low as 5% of total grid capacityInstitutions estimate this level can significantly influence price formation and lower wholesale electricity prices (based on ERCOT and NEM examples)
• Australian residential electricity price capDown 3%-7% next yearBatteries have lowered and smoothed wholesale electricity prices; large-scale corporate batteries still aim for 11% post-tax returns, compared to the global observed average of about 8%
• PJM recent capacity auction priceAbout $333/MW-dayBased on 4-hour daily output and 59% capacity credit, equivalent to about $49/MWh; price jumped about 9 times from the previous auction
• European energy storage costsUnit costs fell from over €0.25 million/MW (2023) to about €0.11 million/MW (2026); LCOS fell from over €115 to about €55/MWhHybrid solar-storage LCOE fell to about €95/MWh
• Europe’s annual new energy storage additionsFrom 7.8 GWh in 2022 to 30 GWh in 2025, expected to reach 55 GWh by 2030Cumulative installed capacity expected to exceed 300 GWh by 2030 (about 85 GWh in 2025)
• South Korea’s energy storage policy targets540-600 MW annually from 2026-2029Equivalent to about 13 GWh based on 6-hour system demand; local manufacturers almost entirely take all winning bids
• India’s battery costs and electricity pricesBattery costs fell about 70% in three years, tendered electricity prices fell about 75%Cumulative tenders have exceeded 90 GW, but actual commissioning remains small—about 90% of the value chain depends on Chinese imports

Impact & implications

The report believes that scaled-up energy storage will curb electricity market volatility, delay capital spending on transmission and distribution expansions, and potentially lower consumer electricity prices—making it a 'holy grail' technology for utility investors and policymakers alike. For markets, institutions hold a more constructive stance toward energy storage investments in highly volatile markets (PJM, CAISO, ERCOT, Australia’s NEM) and are more cautious about low-volatility/market-regulated arbitrage spaces (Singapore’s NEMS, South Korea’s KPX, Japan’s JEPX). For individual stocks, institutions favor Talen Energy and Vistra due to attractive valuations, potential premium long-term PPAs with data centers, and rising U.S. electricity prices. They believe that in the context of fast-growing loads in PJM and ERCOT, the bullish logic on electricity prices won’t be disrupted by batteries. Meanwhile, based on local market conditions and electricity price prospects, they see CEZ Group and Korea Electric Power as relatively less favorable from an evolving perspective of energy storage penetration. The institution also warns that as accelerated battery installations bring downside risks to electricity prices, they’ll gradually cut earnings and EPS forecasts for related utility companies.

Risks

• Once energy storage starts setting daily peak electricity prices, returns will be compressed, and this tipping point could come quickly (already seen in Australia and Texas over the past year)
• Battery market saturation and batteries eating into each other’s arbitrage opportunities ('Ouroboros Effect'); recent weaker returns for ERCOT developers could slow down further development
• Rising consumer electricity prices increase the social license risk for utilities, triggering policy intervention
• Queue delays for interconnections become a risk for rapid deployment
• Battery supply chains heavily dependent on China and tariff disruptions (U.S. costs are higher due to tariffs against China, around $200-250/kWh)
• India’s battery value chain depends on Chinese imports for about 90%, and 75% of two-hour capacity was awarded at 'risk' prices; price declines partly stem from Chinese overcapacity, which could reverse if prices rebound
• Australia’s Solar Sharer Offer carries reverse selection risk, temporarily squeezing supplier profits

What to watch

• Whether energy storage penetration approaches the critical point of 'starting to set peak prices' (watch leading markets like Australia and Texas)
• Clearing prices and volumes of capacity auctions like PJM, progress of reliability backup auctions (RBP)
• Changes in observed TB4 spreads relative to required returns (LCOS)
• Legislative and regulatory moves around electricity price affordability in various markets in 2026
• Policy evolution in the U.S. regarding non-Chinese battery supplies (ITC eligibility, FEOC restrictions, tariffs) and its impact on Korean battery maker market shares