Electricity Sector in Israel

Israel's electricity sector encompasses five functional segments: production, transmission, distribution, supply, and system management.[1] Production draws on natural gas, coal, renewable sources — chiefly solar — and, increasingly, battery storage. Transmission carries electricity from generating units to switching stations and substations; distribution networks then deliver power to individual consumers. The supply segment covers the sale of electricity to end users, while system management plans, optimizes, and oversees production and future development.[1]

The sector's most distinctive structural feature is its isolation. Israel's grid is not connected to any neighboring or international electricity network, a condition the Institute for National Security Studies (INSS) characterizes as an "electrical island."[2] This isolation, combined with historically high centralization of generation capacity, means that any significant disruption to domestic infrastructure — whether from conflict, natural disaster, or equipment failure — cannot be offset by imports from adjacent systems.[2] That vulnerability shapes Israeli energy policy across all its dimensions: fuel-mix diversification, the push for renewable deployment, the drive to expand storage capacity, and the ongoing structural reform of the market.

The sector's importance extends well beyond lighting and heating. Roughly half of Israel's drinking water is produced by desalination plants that require continuous electricity.[3] Rail electrification, plans to electrify the urban bus fleet, and the gradual adoption of electric vehicles are all adding new layers of demand.[3] Data centers, artificial intelligence infrastructure, and server farms — projected to account for 5–7% of consumption by 2030 — represent a fast-growing new category of load.[4] The Electricity Authority reported record peak demand of 17.3 GW in August 2025, while INSS projects a 30–40% rise in peak demand by 2035.[4][2]

Commercial-scale electricity generation in the land of Israel began in 1923 with the Palestine Electric Corporation, a Zionist undertaking founded and developed by engineer Pinhas Rutenberg, whose shares were traded on the London Stock Exchange.[5] The corporation received exclusive concessions in September 1921 to exploit the Yarkon and Jordan rivers for irrigation and electricity generation.[5] Rutenberg had arrived in Mandatory Palestine in 1919 with financial backing from Baron Edmond de Rothschild and won a British concession in 1921 to build the Jaffa-area grid.[6]

The sector's physical starting point was a diesel-generator station inaugurated in Tel Aviv on June 10, 1923 — the first power station in Mandatory Palestine and the first project completed by Rutenberg's Palestine Electric Company, which he had founded less than three months earlier.[7] That original station had a capacity of 750 kW.[5] From this modest beginning, capacity grew rapidly: to 2,250 kW by 1926, 16,200 kW by 1932 following the opening of the Jordan–Kinneret hydroelectric project, 63,000 kW by 1938, and 75,000 kW on the eve of Israeli statehood in 1947.[5] Manufacturing-industry electricity consumption tracked the growth of generation, rising from 1 million kWh in 1926 to 20 million in 1938 and 86 million in 1947, reflecting the development of large-scale industry and irrigation across the territory.[5]

A landmark in the network's expansion was the Naharayim hydroelectric plant, opened at the confluence of the Jordan and Yarmouk rivers. Rutenberg chose the site for the rivers' strong flow and for the plant's capacity to help regulate water storage in the Sea of Galilee.[8] The plant supplied much of Palestine's electricity until it was destroyed during the 1948 War of Independence. The Center for Israel Education attributes the destruction to Iraqi troops, while the Jewish Virtual Library attributes it to Jordanian forces.[8][9] The Palestine Electric Company supplied electricity throughout Mandatory Palestine except Jerusalem.[6]

With the establishment of the State of Israel, the Palestine Electric Company was renamed the Israel Electric Corporation and became a state-owned enterprise.[9] New power stations were constructed across the country, and electricity production expanded substantially in step with rapid population and economic growth.[9] By 1967, per-capita electricity consumption stood at 1,429 kWh annually; it reached 5,559 kWh by 2000 and 6,232 kWh in 2011.[10] Overall energy consumption in Israel nearly doubled between 1990 and 2008, growing at roughly 4% per year, while per-capita energy consumption rose 27% over the same period.[11]

For most of the twentieth century, Israeli electricity generation depended heavily on coal and heavy fuel oils. A Library of Congress country study records that approximately 50% of Israel's electricity came from coal in 1982–1984.[12] A 2011 snapshot from the Jerusalem Institute for Policy Research confirms that coal still supplied about 62% of electricity that year, with natural gas providing 32% — a share that had stood at 0% as recently as 2003.[10] Power plants were responsible for approximately 50% of total national air-pollution emissions on average.[10]

Before natural gas entered the fuel mix, Israel imported all of its coal and most of its oil, creating both cost and strategic exposure.[13] As of the end of 2004, the IEC's installed generating capacity of 10,083 MW was composed of 79.1% coal, 16.8% fuel oil, and 4.1% gas oil.[14] The oil-to-coal conversion programs that preceded this snapshot had made coal 17% of Israel's primary energy by 1985.[12]

A Jerusalem Center for Public Affairs analysis described the Mari-B offshore gas field, which contained about 1 trillion cubic feet of gas, as beginning to supply gas-fired power plants in 2004 and helping lift gas's share of electricity production to approximately 40–45% within several years.[15] The same analysis reported that Egyptian imports accounted for about 40% of Israel's gas consumption around 2009–2010, with Mari-B providing the remaining 60%.[15] It further reported that Egyptian supply was interrupted almost continually during 2011 and ended by year's close, as Mari-B itself neared exhaustion.[15]

The same account characterized the Tamar natural-gas discovery by a Noble Energy-led team on January 17, 2009, as averting a potential major breakdown in Israel's energy sector.[15] Gas from Tamar began flowing to the Ashdod reception facility on March 30, 2013.[15] By 2016, natural gas was estimated to supply more than half of Israel's electricity; the 2016 Congressional Research Service data shows gas rising from 33% of generation in 2009 to 42% in 2013.[16] By 2018, the Jewish Virtual Library reports, natural gas provided 70% of Israel's electricity generation.[17] The transition brought measurable environmental gains: sulfur oxide emissions fell by about 46% between 2000 and 2008, attributed mainly to the shift toward lower-sulfur fuels and natural gas.[11]

The Electricity Authority, established in 1996 under the Electricity Sector Law, serves as the sector regulator.[1] It advises the Minister of Energy on electricity policy, sets electricity prices and update mechanisms, grants licenses for sector activities, supervises essential service providers, and promotes competition, renewables, storage, and consumer interests.[4] Its annual reports on the state of the electricity sector are a primary source of official sector statistics.

Noga, the Israel Independent System Operator, manages the national electricity system and became fully operational as an independent company in 2021.[4] Before that, system management was handled internally by IEC. The November 2021 separation — occurring roughly two years later than originally planned — was intended to remove a potential conflict of interest inherent in having a company that competes with other producers and suppliers also manage the overall system.[4] Under the reform-era division of responsibilities, Noga approves connections to the transmission grid and sets technical criteria, while IEC approves distribution-grid connections according to limits and criteria established by Noga; ongoing coordination between the two entities covers grid planning and operation.[2]

Government Resolution 3859, dated June 3, 2018, assigned IEC a monopoly over the establishment, operation, and maintenance of the public transmission and distribution grids, with exceptions for historical distributors, the East Jerusalem distribution company, and certain private campuses.[2] IEC therefore remains a monopoly in grid segments even as its production and supply market shares have declined substantially.[4]

The five segments described by the Knesset Research and Information Center — production, transmission, distribution, supply, and system management — each carry distinct ownership and regulatory arrangements.[1] Transmission and most distribution remain with IEC. Generation has been substantially privatized. System management has moved to Noga. The supply segment has been opened to competition. The resulting structure is more complex than the historic vertically integrated monopoly, but retains important elements of state control over physical infrastructure.

The government approved a sweeping electricity-sector reform in 2018 aimed at increasing competition in production and supply, reducing IEC's generation role through station sales, and transferring system management to a separate government company.[4] The reform framework, agreed with IEC's workforce, envisaged the sale of five older power-station sites with a combined capacity of about 4,000 MW, projected sale proceeds of NIS 15–16 billion over five to six years, and the retirement of approximately 2,800 IEC employees over eight years.[18]

The reform specified that no single entity could hold rights in electricity production stations exceeding 20% of total planned installed capacity at the time of each sale — with the expected maximum corresponding to approximately 2,100 MW — a provision designed to prevent any producer from acquiring undue pricing power while still allowing meaningful competition for new stations.[19]

Station sales proceeded in stages during 2019–2024, with the Electricity Authority recording completed transactions at four IEC power-station sites: Ramat Hovav, Alon Tavor, East Hagit, and Eshkol.[4] A Knesset analysis published in May 2024 documented three completed sales generating approximately NIS 7.73 billion in receipts, of which approximately NIS 4.6 billion exceeded book value; it also noted delays in the Reading and Eshkol transactions and complications around replacing coal units at Orot Rabin.[1]

The results of the reform in the production market have been substantial. IEC's share of national electricity production fell from 84.2% in 2014 to 46.4% in 2023, when private producers held the larger share for the first time.[1] By 2024, private producers generated about 60% of Israel's electricity and held approximately 53% of installed production capacity, with total installed capacity reaching 24.6 GW — 15.8 GW in the hands of independent power producers and 8.8 GW with IEC.[4]

Surplus proceeds from power-station sales were returned to consumers: the Electricity Authority reports that cumulative tariff reductions attributable to sale surpluses reached approximately NIS 9.8 billion during 2020–2024.[4] The reform also brought changes to natural-gas supply contracts. In January 2016, Edeltech — described as Israel's largest private power producer — agreed to buy 212 billion cubic feet of gas over 18 years from Leviathan's partners in a deal valued at $1.3 billion; in late May 2016, those partners signed an 18-year agreement worth $3 billion to supply up to 459 billion cubic feet to the privately operated IPM power plant in Be'er Tuvia.[16]

A parallel strand of the reform opened electricity supply — the retail sale of power to consumers — to competition. Suppliers without their own generation capacity began offering electricity in 2021, initially only to customers with smart meters capable of more frequent consumption readings.[4] Smart-meter deployment was therefore central to the reform's rollout: the Electricity Authority decided in 2023 to install approximately 2.7 million additional smart meters during 2024–2028, following an earlier plan that covered only about 450,000 units; approximately 800,000 had been installed by March 2024.[1]

On July 25, 2024, a further reform took effect allowing customers to switch suppliers without possessing a smart meter, extending eligibility to approximately 3.1 million customers.[20] Globes, citing Noga figures, reported that almost 300,000 households had moved their accounts to private suppliers by January 13, 2025 — approximately three times the number initially expected within the first six months of the expanded reform.[21] The Electricity Authority's later report counted more than 270,000 consumers as having switched by June 2025, including approximately 250,000 household consumers, with private suppliers serving roughly 35% of total electricity consumption.[4] The sources do not reconcile the lower later total, suggesting that their reporting populations or methods were not identical.

Private suppliers typically offered discounts of 5–7% compared with the IEC tariff, with discounts reaching as much as 20% during off-peak hours.[22] However, the seven suppliers active in the market reported difficulties obtaining sufficient low-cost electricity, characterizing their consumer-supply business as unprofitable.[22] In July 2025, the Electricity Authority moved to address this by permitting conventional gas-fired power plants to sell electricity directly to private suppliers — rather than restricting discounted supply to solar installations and batteries — with an initial competitive process covering 350 MW.[23]

Israel produced 80.4 TWh of electricity in 2024, according to the Electricity Authority.[4] Natural gas supplied 57.4 TWh, representing approximately 72% of total production; coal contributed 11.5 TWh (about 14%); and renewable sources supplied 11.1 TWh (about 14%), with a residual 0.3 TWh from other sources.[4] Of gas-fired production, IEC generated 21.3 TWh and independent producers 36.2 TWh, illustrating the extent to which the formerly state-dominant fuel has been redistributed across producers.[4]

The trajectory of the fuel mix over the preceding decade is striking. Natural gas rose from 44.1% of production in 2014 to 70.9% in 2023, while coal fell from 52% to 17%, and renewables climbed from 0.7% to 11.5%.[1] In 2020, natural gas supplied 67% of Israel's electricity, coal 26%, and renewables 6%.[24] The BDO consulting firm estimated the 2024 generation shares at natural gas 71%, coal 14%, and renewables 14%.[25]

Demand reached 74.9 TWh in 2024, up approximately 4.4% from the preceding year, with an annual peak of 15.3 GW.[4] The Electricity Authority projects demand rising to 87.5 TWh and production to 94.6 TWh by 2030, driven by industrial electrification, electric vehicles, artificial intelligence infrastructure, and server farms.[4] A preliminary assessment identifies server farms as potentially accounting for 5–7% of consumption by 2030.[4]

Geography complicates the delivery of power. More than 70% of Israel's electricity was produced in the south, while 70% of demand was concentrated in central Israel; the distance between major production and consumption points ranges from 100 to 700 kilometers.[3] Hot weather can further constrain the capacity of long-distance transmission lines during summer afternoon peaks, precisely when demand is highest.[3]

Natural gas has become the dominant fuel in Israel's electricity system, transported from offshore reservoirs to coastal reception facilities through two pipelines.[2] Commercial production from the offshore Tamar field began in March 2013; by 2025, the Jewish Virtual Library reported that Tamar supplied 60–70% of Israel's electricity.[17]

The Leviathan field, Israel's other major offshore reserve, provides additional supply and has been the basis for large private-sector supply contracts, including the agreements with Edeltech and the IPM plant at Be'er Tuvia noted above.[16] Estimated gas reserves grew from approximately 780 billion cubic meters in 2012 to 1,087 billion cubic meters in 2023, a 40% increase attributed to discoveries and revised reservoir estimates.[17] A 2023 BDO analysis cited by the Jewish Virtual Library found that the transition to natural-gas use had reduced the carbon-dioxide intensity of Israel's electricity sector by 32% and cut air pollution by the same margin.[17]

Despite these gains, concentration of supply creates strategic vulnerabilities. Israel has no domestic natural-gas storage capacity, and nearly all production is concentrated at a small number of sites.[2] The INSS has assessed that damage to a single gas reservoir or pipeline could significantly impair electricity supply given the system's heavy reliance on gas and the absence of storage buffers.[3] Most power plants can switch to diesel as a fallback, but diesel stocks are finite, supply depends on imports, and prolonged diesel operation could compromise plant availability.[3]

A 2024 Jerusalem Center for Public Affairs account reported that the Tamar field was shut down at the start of the October 7, 2023, war because of rocket-attack risks and concerns for workers. IEC increased coal use when Leviathan could not initially replace the lost volumes, and air pollution rose. The account said that energy supply stabilized and returned to prewar levels after approximately one month and estimated the shutdown's cost at approximately NIS 800 million per month.[26]

Replacing coal with gas carries measurable environmental benefits at scale. Gas-fired plants typically emit 58% as much carbon dioxide per kilowatt-hour as coal-fired plants, and the Congressional Research Service estimated that fully replacing coal capacity with gas could reduce Israel's annual emissions by approximately 13.95 million tons — equivalent to 24.4% of Israel's 2005 emissions level — though it cautioned that a complete coal exit was unlikely and that conversion would require major investment and years to complete.[16]

Israel's renewable-energy push has accelerated markedly since 2020. Government Resolution 465, dated October 25, 2020, set a target of generating 30% of electricity from renewable sources by 2030, with solar expected to provide the vast majority of that generation.[2] The 2020 plan estimated a total cost of NIS 80 billion, encompassing generation installations, storage, grid development, and associated investment; it envisioned 15,773 MW of solar systems and anticipated that wind, water, and biomass would supply the non-solar remainder of renewable electricity.[27]

By the end of 2024, installed renewable capacity had reached 6.89 GW, with approximately 1 GW connected during that year alone.[4] Renewable sources supplied 14.6% of electricity consumption in 2024, up from 12.5% in 2023.[4] The Electricity Authority estimates that approximately 16 GW of renewable capacity is needed to meet the 30% target and projects renewables accounting for roughly 40% of total installed sector capacity by 2030.[4] A 2025 government report also describes a 30% renewable-electricity target for 2030, supported by a grid-development plan intended to enable integration at that scale.[28]

Solar photovoltaic has dominated Israel's renewable expansion, accounting for about 91% of renewable electricity production.[29] Israel's annual solar irradiance of approximately 2,000 kWh per square meter gives it favorable conditions for solar deployment.[30] Most renewable facilities are small, decentralized installations connected to the distribution network, while a significant portion of renewable production is located in peripheral areas and therefore depends on transmission infrastructure to reach central consumption centers.[3]

Research conducted at Ben-Gurion University has quantified the physical and grid limits of ground-mounted solar deployment. A 2022 peer-reviewed study using GIS-based land-suitability analysis estimated that 2.93 GW of installed capacity and 5.16 TWh of annual generation could be integrated into Israel's existing grid without system modifications — representing about 15% of total installed capacity and 7% of energy generation at the time — while identifying grid stability, reliability, supply quality, and limited suitable land as binding constraints.[31] The same study cautioned that meeting the 30% target would be unlikely without additional renewable technologies and major system changes.[31] A 2023 peer-reviewed study found that, of 323 km² classified as appropriate for photovoltaic installations in Israel, 137.6 km² (42.6%) was rated highly or very highly suitable, and emphasized that site prioritization matters for grid-integration cost-effectiveness and land-use management.[32]

Israel pursued early solar demonstrations following the 1974 energy crisis. A 5 MW turbine was built by Ormat for a 250,000-square-meter saline solar pond at Beit Ha'aravah, with average output of about 570 kW and the ability to generate higher output during morning and evening peak periods by drawing on stored heat.[30] The government established a solar technology test center at Sde Boker in 1985 and assigned Ben-Gurion University to convert it into a solar research facility in 1991.[30] In the domestic sector, solar water heaters have long been widespread: a typical Israeli unit has a 150-liter tank and a 2-square-meter collector, operates at about 50% annual average efficiency, and can save around 2,000 kWh of electricity per year.[30]

Permitting bottlenecks have slowed the solar build-out. A 2023 Globes report noted that industry participants faced difficulties obtaining permits for new facilities, linking slow solar expansion to the challenge of meeting the 20% target for 2025 and the 30% goal for 2030.[29] A BDO analysis reported in January 2025 said Israel was expected to miss its 2025 renewable-electricity target of 20%.[25] An Electricity Authority oversight report cited by INSS found that only about one-third of grid-connection projects were expected to finish on schedule.[2]

Grid capacity is a critical constraint on Israel's energy transition. A transmission development plan covering 2023–2031 entails approximately NIS 22 billion in investment, of which about NIS 12 billion is earmarked for connecting renewable facilities; plans approved in 2023–2024 targeted connection of approximately 10,000 MW of additional renewable capacity.[2][4] In July 2025, ministers approved a distribution-system development plan for 2025–2030, following an Electricity Authority recommendation, with more than NIS 3 billion in planned investment to improve supply reliability.[4] IEC installed over 2,700 km of underground lines and established more than 800 distribution-grid stations during 2024 alone.[4]

A September 2023 agreement involving the Ministry of Energy and Infrastructure, the Electricity Authority, Noga, and IEC was specifically aimed at adding more than 2,000 MW of renewable power to the existing grid, chiefly in the north and south of the country.[33] The scale of demand peaks that the grid must serve was illustrated by an all-time consumption record of 15,690 MW on August 13, 2023, at which point photovoltaic sources were producing 2,644 MW and coal-fired generation 3,379 MW.[33]

Storage development is accelerating in parallel with generation. Israel's electricity storage capacity stood at 557 MW with energy capacity of 3,428 MWh at the end of 2024.[4] The Electricity Authority's 2030 forecast calls for 9,250 MW and 40,200 MWh of storage — a roughly 17-fold increase in power capacity.[4] A 344 MW pumped-storage facility at Kochav HaYarden became commercially operational in February 2025, representing a significant addition to grid-scale balancing capacity.[4] An earlier 2024 INSS analysis had projected approximately 2.6 GW of storage by the end of the decade, with about one-third connecting to the extra-high-voltage grid under system-manager control and the remainder in smaller decentralized facilities; buildings with paired solar and storage, it noted, could maintain supply for at least a few hours during day and evening periods.[3]

Microgrids represent an additional resilience strategy. The INSS describes them as local systems capable of operating connected to the national grid or disconnecting and operating independently during emergencies, combining decentralized generation, storage, and local demand management.[2] It cautions, however, that local production alone cannot meet all electricity demand and that expanding remote generation still requires transmission development.[2]

Israeli policy has consistently moved toward ending routine coal-fired electricity generation, though the stated deadlines have shifted across successive official documents. The Ministry of Energy's 2021 sector-structure report set an end-of-2025 target for ceasing coal production.[34] The 2025 Biennial Transparency Report described a government phase-out policy with a 2026 target and associated conversion and closure plans.[28] The Electricity Authority's September 2025 report places the end of routine coal use at 2030, with Orot Rabin units 1–4 ceasing routine operation and other units to be converted to natural gas.[4]

Replacing coal with gas carries quantifiable benefits: the Congressional Research Service estimated that fully substituting gas for all coal capacity could cut Israel's annual CO₂ emissions by approximately 13.95 million tons, or 24.4% of the country's 2005 emissions baseline, while noting that conversion would require major investment and many years.[16] In 2008, coal supplied almost two-thirds of Israeli generating capacity; by 2024, it accounted for approximately 14% of electricity production.[13][4]

Israel's status as an electrical island — isolated from regional interconnection — makes the domestic electricity system a focal point of national security analysis. The INSS, in a series of analyses, has highlighted several compounding vulnerabilities.[2]

The geographic mismatch between generation and consumption is a structural challenge: more than 70% of electricity is produced in the south, while 70% of demand is concentrated in central Israel, with production-to-consumption distances ranging from 100 to 700 km.[3] This configuration makes transmission and transformation infrastructure disproportionately important, and hot weather can reduce the capacity of long-distance lines precisely when summer demand peaks.[3]

Gas dependency creates a second axis of vulnerability. With natural gas expected to supply more than 75% of the fuel mix and no domestic storage capacity, damage to a single reservoir or pipeline could significantly impair supply.[3] A 2024 Jerusalem Center for Public Affairs account described the October 2023 shutdown of the Tamar field as a demonstration of this risk: the facility was closed for about a month, with estimated losses of NIS 800 million per month while the system temporarily increased coal use.[26]

The INSS frames decentralization as the key resilience principle: the closer the proximity between production and consumption, and the more distributed the generation base, the lower the risk of supply disruption.[2] This framing supports the policy emphasis on rooftop and distributed solar, battery storage, and microgrids capable of islanding from the main grid when needed.[2] Peak electricity demand is expected to rise 30–40% by 2035, with population growth, electrification of transport and industry, and more frequent extreme weather events identified as the principal drivers. The Electricity Authority reported record peak demand of 17.3 GW in August 2025.[2][4]

The electricity sector has historically been the primary source of sulfur oxide emissions in Israel, while power plants were responsible for approximately 50% of total national air-pollution emissions on average.[11][10] The shift from coal and oil to natural gas, combined with the adoption of low-sulfur fuels, drove a roughly 46% reduction in SOx emissions between 2000 and 2008.[11]

The BDO analysis cited by the Jewish Virtual Library found that the transition to natural gas reduced the carbon-dioxide intensity of Israel's electricity sector by 32% and achieved equivalent reductions in air pollution as of 2023.[17] Natural-gas plants emit approximately 58% as much CO₂ per kilowatt-hour as coal plants.[16]

A 2024 peer-reviewed study from Ben-Gurion University examined an unusual application: supplying "Kosher electricity" — generated and stored so as not to involve Shabbat-prohibited labor — to Israel's ultra-Orthodox population. The authors estimated that serving approximately 1.28 million ultra-Orthodox consumers this way would require storage capacity 18–24 times the world's largest installed utility-scale battery (identified as 450 MWh), while potentially reducing annual CO₂ emissions by 188–474 kilotons. They characterized the required scale as 5–15% of the projected utility-scale storage market by 2030.[35]

The sustainability forecasts compiled by the Jerusalem Institute for Policy Research projected a 74% rise in per-capita electricity consumption through 2030 under a "business as usual" scenario, and noted that energy consumption per unit of GDP declined slightly between 1995 and 2008, suggesting some improvement in economic energy efficiency.[11]

Several aspects of the electricity sector's recent history rest on provisional plans, varying estimates, or figures that differ across official and media sources, and these discrepancies merit acknowledgment.

On coal phase-out, official targets have shifted: the 2021 Ministry of Energy report cited end-of-2025, the 2025 Biennial Transparency Report cited 2026, and the Electricity Authority's September 2025 report cited 2030. None of these targets should be read as a confirmed outcome.[34][28]

The number of power-station sites sold under the 2018 reform is described variously as five in the original plan, three completed by the time of the Knesset's May 2024 review, or four in the Electricity Authority's count for 2019–2024. These figures reflect different stages and definitions of reform implementation rather than a fundamental contradiction.[1][4]

Reported 2024 renewable-electricity shares differ slightly by source and measure: BDO's estimate cited in media gives 14% of generation, while the Electricity Authority records renewables at about 14% of production and 14.6% of consumption. The Authority also distinguishes actual annual renewable consumption from a potential rate calculated from year-end installed capacity, which was 16.2% at the end of 2024.[25][4]

Retail-switching totals also differ. Noga figures reported by Globes placed the number at almost 300,000 households by January 13, 2025, while the Electricity Authority later counted more than 270,000 consumers by June 2025. The sources do not explain the lower later figure, so the totals should not be treated as directly comparable.[21][4]

The Center for Israel Education gives conflicting opening dates for the Naharayim hydroelectric plant — 1930 in its Rutenberg biography and March 9, 1932, in its dedicated plant history — without reconciling the two accounts.[6][8] Sources also differ over the forces responsible for the plant's destruction during the War of Independence: the Center attributes it to Iraqi troops, while the Jewish Virtual Library attributes it to Jordanian forces.[8][9]