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Binary cycle

A binary cycle is a type of geothermal power plant designed to generate electricity from moderate-temperature geothermal resources by using a secondary working fluid with a lower boiling point than water, typically in a closed-loop system.^[1] In this process, hot geothermal water, often at temperatures between 107°C and 182°C (225°F and 360°F), passes through a heat exchanger to transfer its thermal energy to the secondary fluid—commonly an organic compound like isobutane or pentane—which vaporizes at lower temperatures and drives a turbine connected to a generator.^[2] The geothermal water, remaining in liquid form, is then reinjected into the reservoir, minimizing surface emissions and environmental release of fluids or gases.^[3] This technology offers significant advantages over traditional dry steam or flash steam plants, which require higher temperatures above 182°C (360°F) and often involve flashing geothermal water to steam, potentially releasing non-condensable gases and minerals.^[4] Binary cycles enable the exploitation of more abundant lower-temperature resources, operate with higher thermal efficiency for such conditions, and produce near-zero emissions of sulfur compounds or carbon dioxide compared to fossil fuel plants of similar capacity.^[5] They also reduce scaling and corrosion issues in the power generation equipment by keeping the geothermal fluid isolated.^[6] Developed in the mid-20th century to address limitations of earlier geothermal technologies, the first binary cycle plant began operation in 1967 at Paratunka in Russia's Kamchatka Peninsula, using a refrigerant as the working fluid.^[7] Since then, binary cycles have grown in prevalence, accounting for the majority of new geothermal installations worldwide due to the predominance of moderate-temperature reservoirs; as of 2024, they represent a key pathway for expanding geothermal capacity, with global installed power exceeding 16 gigawatts across all types.^[8] Today, binary plants are integral to renewable energy strategies, particularly in regions like the western United States, Iceland, and Indonesia, where they support baseload power with high reliability and low operational costs.^[1]

Overview

Definition and Applications

A binary cycle is a thermodynamic process designed for generating electricity from geothermal heat sources with temperatures typically below 180°C, where the geothermal fluid itself does not directly drive a turbine.^[6] It involves a primary closed cycle using the geothermal brine to transfer heat via a heat exchanger to a secondary closed cycle employing a low-boiling-point working fluid, such as an organic compound, which vaporizes to power the turbine.^[2] This dual-fluid approach prevents scaling, corrosion, and non-condensable gases from affecting the turbine, making it suitable for moderate-temperature resources that are incompatible with traditional flash or dry steam methods.^[9] Geothermal energy originates from the Earth's internal heat, stored in subsurface reservoirs of hot water or steam formed by natural geological processes, accessible through drilling wells to depths of several kilometers.^[10] For binary cycles, viable resources generally range from 85°C to 150°C, allowing exploitation of lower-enthalpy fields that constitute a significant portion of global geothermal potential.^[1] Key applications include deploying wellhead generator units at individual production wells to capture energy from isolated or marginal flows, often in remote areas for off-grid power or industrial use.^[11] Binary cycles also integrate effectively with enhanced geothermal systems (EGS), where engineered reservoirs in hot dry rock are stimulated to create fluid circulation, enabling power generation from deeper, higher-temperature but low-permeability formations.^[12] As of 2024, binary cycles represent a growing share of new geothermal installations worldwide, driven by their adaptability to diverse and lower-temperature resources, with organic Rankine cycle variants comprising about 25% of total installed capacity and increasing in recent developments.^[13] This versatility supports expanded deployment in regions like the western United States, Iceland, and emerging markets in Asia and Africa, where moderate-temperature fields are abundant.^[14]

Basic Operating Principles

In a binary cycle system, the primary geothermal fluid, typically hot brine from low- to moderate-temperature reservoirs (below 200°C), circulates through a heat exchanger where it transfers thermal energy to a secondary working fluid with a lower boiling point, such as isobutane or isopentane. This secondary fluid absorbs the heat, undergoes vaporization without direct mixing of the fluids, and the resulting vapor expands to drive a turbine connected to a generator, producing electrical power. After expansion, the vapor condenses back into liquid form through cooling and is then pumped to return to the heat exchanger, completing the closed loop of the secondary cycle.^[6] The heat transfer occurs indirectly via the heat exchanger, ensuring the secondary cycle remains isolated from the corrosive and scaling-prone geothermal brine, which allows for efficient operation without contamination or material degradation in the power generation components. This closed-loop design for the secondary fluid prevents the release of geothermal fluids into the atmosphere and facilitates reinjection of the cooled primary fluid back into the reservoir, promoting sustainability.^[9] The energy flow in a binary cycle converts low-enthalpy heat sources into mechanical work through an adapted Organic Rankine Cycle (ORC), optimized for temperatures as low as 90°C, where the secondary fluid's latent heat of vaporization plays a key role in maximizing efficiency by enabling phase change at lower pressures. This process assumes familiarity with basic thermodynamic principles, such as heat addition and rejection in a vapor power cycle, while emphasizing the utilization of latent heat to achieve thermal-to-electrical conversion efficiencies of 9–15% in practical systems. The primary geothermal loop and secondary power cycle interact solely through this heat exchange, with detailed cycle analyses covered in thermodynamic sections.^[15]

Thermodynamic Cycles

Primary Cycle

The primary cycle in a binary geothermal power plant functions as an open loop utilizing geothermal brine as the heat source. Hot brine is extracted from production wells in the reservoir, directed through a heat exchanger where it transfers thermal energy to the secondary working fluid, and subsequently reinjected into the subsurface without undergoing any phase change.^[9] This design keeps the geothermal fluid contained in a single pass, preventing direct contact with power generation equipment.^[9] The geothermal brine in this cycle is predominantly water-based, exhibiting temperatures typically between 85°C and 180°C to suit moderate-temperature resources.^[16] It often features high salinity, which contributes to corrosive properties, along with dissolved minerals and potential non-condensable gases such as CO₂ and H₂S that require management to avoid operational issues.^[9] These characteristics make the brine unsuitable for direct turbine use but ideal for indirect heat transfer applications.^[9] Key process steps include initial production from the geothermal reservoir via pressurized wells to maintain the brine in liquid form, followed by delivery to the heat exchanger for controlled cooling and heat release to the secondary loop.^[9] The cooled brine, now at a lower temperature, is then reinjected into injection wells to sustain reservoir pressure and promote resource sustainability over time.^[9] The heat exchanger provides the critical interface for this thermal handover, ensuring separation between the primary and secondary fluids.^[9] Advantages of the primary cycle include enhanced resource utilization for lower-temperature fields that cannot support flashing, thereby broadening the applicability of geothermal energy.^[9] By eschewing flashing, it minimizes silica scaling risks, as the maintained pressure prevents rapid silica supersaturation and polymerization that occur during phase changes in other systems.^[17]

Secondary Cycle

The secondary cycle in a binary power plant operates as a closed-loop system akin to the Rankine cycle, utilizing a low-boiling-point working fluid—such as hydrocarbons like isopentane or ammonia-water mixtures—that is heated by the primary geothermal fluid without direct contact. This fluid undergoes vaporization in a heat exchanger, expands to drive a turbine for electricity generation, condenses in a cooling system, and is recirculated via a pump, ensuring efficient reuse and minimal environmental impact due to the sealed design.^[16]^[18] The process begins with preheating and vaporization of the secondary fluid in the heat exchanger, where it absorbs thermal energy to reach its boiling point and form vapor. This vapor then flows to the turbine for expansion, converting thermal energy into mechanical work that powers the generator. Post-expansion, the vapor passes through a regenerator if present to recover heat, followed by condensation in an air- or water-cooled condenser, after which a feed pump compresses the liquid back to the heat exchanger to complete the cycle.^[18]^[4] A defining characteristic of the secondary cycle is its ability to function at significantly lower pressures and temperatures than traditional steam-based cycles, enabling effective exploitation of low- to moderate-temperature geothermal resources in the range of 90–175°C that would otherwise be unsuitable for direct steam generation. This adaptability stems from the secondary fluid's lower boiling point, which matches the heat source profile and enhances overall thermodynamic efficiency in organic Rankine cycle (ORC) or Kalina cycle variants.^[16]^[18] In terms of system integration, the secondary cycle remains isolated from the primary cycle through the intermediary heat exchanger to prevent fluid mixing and corrosion, though it can serve as a bottoming cycle in hybrid setups to capture residual heat; turbine sharing occurs only in specific combined configurations, but separation is standard to maintain fluid integrity.^[18]^[19]

Historical Development

Early Innovations

The binary cycle concept for geothermal power generation traces its roots to early 20th-century efforts in low-temperature heat engines, where engineers sought to utilize secondary working fluids to harness geothermal heat more efficiently than direct steam systems. The first geothermal power plant at Larderello in 1904, developed by Prince Piero Ginori Conti, used direct steam to generate electricity, but early experiments explored indirect methods to mitigate corrosion from geothermal vapors. By the 1920s, experimental developments expanded on these ideas, with initial concepts exploring organic fluids for closed cycles to improve heat transfer in moderate-temperature resources, adapting principles from reciprocating engines to geothermal applications.^[7] A key milestone occurred in the early 1940s on the island of Ischia, Italy, where Professor Luigi D’Amelio of the University of Naples led the construction of the world's first experimental binary cycle geothermal plant. Operational from 1940 to 1943, this prototype generated 11 kW of mechanical power using monochloroethane as the secondary working fluid, heated by geothermal brine at around 150°C. Italian engineers, including D’Amelio, drew on diesel cycle turbine designs to create compact expansion units suitable for low-enthalpy sources, marking a shift toward organic Rankine cycle variants for geothermal exploitation. A follow-up 250 kW plant was built in 1943 but never entered full operation due to wartime disruptions and technical hurdles.^[20] Early prototypes faced significant challenges, particularly with fluid stability and heat transfer efficiency. Organic working fluids like monochloroethane exhibited thermal decomposition risks at elevated temperatures, limiting operational reliability and requiring careful material selection to prevent corrosion in heat exchangers. Heat transfer inefficiencies arose from scaling and fouling in prototypes, compounded by the need to scale from laboratory models (e.g., a prior 2.6 kW unit) to field applications, which strained design and economic feasibility. These issues were partially addressed through improved exchanger configurations, but they highlighted the need for more stable fluids and robust components in subsequent iterations.^[20]^[21]

Commercial Expansion

The first commercial binary cycle geothermal power plant began operation in 1967 at Paratunka in Russia's Kamchatka Peninsula, with a capacity of approximately 0.7 MW, using R-12 refrigerant as the secondary working fluid to harness geothermal water at 81°C. This facility served a local village and greenhouses, marking the initial commercial application of binary technology for low-temperature resources.^[7] The first commercial binary cycle plant in the United States was commissioned in 1979 at East Mesa in California's Imperial Valley, boasting a capacity of 10 MW and utilizing a secondary organic fluid to harness lower-temperature geothermal resources previously uneconomical for flash steam systems.^[22] This facility represented a pivotal shift, enabling broader commercialization of geothermal energy by addressing limitations in resource temperature and reducing issues like corrosion and scaling associated with direct steam extraction.^[21] The expansion of binary cycle technology gained momentum through supportive policies, notably the U.S. Geothermal Energy Research, Development, and Demonstration Act of 1974, which allocated federal funding for research into low-temperature conversion systems and spurred early prototyping efforts.^[21] This legislative framework, enacted amid the 1973 oil crisis that quadrupled global oil prices and prompted a search for domestic alternatives, catalyzed investments in renewables including geothermal.^[23] Subsequent incentives, such as tax credits and loan guarantees in the U.S. and similar measures abroad, further accelerated adoption by offsetting high upfront costs for binary installations.^[24] Early commercialization focused on regions with accessible moderate-temperature fields, including the U.S. Imperial Valley where multiple plants followed East Mesa, New Zealand's Taupo Volcanic Zone with binary units integrated into existing fields like Wairakei, and Iceland's Reykjanes Peninsula where binary elements supplemented high-enthalpy resources.^[21] By the early 21st century, these areas exemplified policy-driven growth, with the U.S. leading through federal R&D that de-risked deployment in liquid-dominated reservoirs.^[21] Technological advancements post-1980s were crucial enablers, particularly refinements in organic working fluids such as mixed hydrocarbons (e.g., isobutane-isopentane blends) that improved thermodynamic matching and efficiency for temperatures between 100–200°C.^[21] Concurrent innovations in heat exchangers, including direct-contact designs, fluidized-bed systems, and polymer-coated surfaces to mitigate scaling, reduced operational downtime and boosted net output by up to 5% in early installations.^[21] These developments, funded largely by U.S. Department of Energy programs, lowered levelized costs and facilitated scaling. By 2014, binary cycle plants had proliferated globally to 203 facilities across 15 countries, accounting for 35% of all geothermal power stations and generating approximately 2,339 MW, driven by the cumulative effects of energy security needs from the 1970s crises and maturing renewable support frameworks.^[25]

Design Variations

Dual Pressure Configurations

In dual pressure configurations of binary cycle geothermal power plants, the secondary cycle is divided into high-pressure (HP) and low-pressure (LP) stages to achieve better matching of the working fluid's temperature profile with the geothermal heat source, thereby enhancing overall heat recovery efficiency.^[26] This approach addresses the limitations of single-pressure cycles by allowing the working fluid, typically an organic compound like isopentane, to evaporate and expand in staged processes that more closely follow the cooling curve of the geothermal brine.^[27] Such designs are particularly suited for mid-enthalpy resources where the sensible heat content of the geothermal fluid can be better utilized without requiring fluid changes.^[28] Operationally, vapor generated in the heat exchanger is split or directed through staged expansion, with the HP stage handling initial high-temperature evaporation and the LP stage capturing residual sensible heat from the cooling geothermal fluid.^[26] This staged process minimizes temperature mismatches in the evaporator, reducing exergy losses while the expanded vapor from the HP turbine may be reheated or mixed before entering the LP turbine for further power generation.^[27] The configuration often incorporates recuperators to preheat the working fluid using turbine exhaust, ensuring closed-loop circulation without direct contact between the geothermal brine and the secondary fluid.^[28] The primary benefits include a 10–20% increase in net power output compared to single-pressure systems, achieved through improved utilization of available heat and lower irreversibilities in heat transfer.^[26] Additionally, dual pressure setups reduce pinch point losses in the heat exchanger by maintaining smaller temperature differences throughout the evaporation process, leading to higher exergy efficiencies often exceeding 30% in optimized cases.^[27] These enhancements make the configuration economically viable by lowering the unit cost of electricity production, with reported reductions of up to 17% in some analyses.^[28] Examples of dual pressure binary cycles are prominently applied in mid-enthalpy geothermal fields operating at 120–150°C, such as the Raft River plant in Idaho, USA, where a subcritical, dual-pressure isopentane organic Rankine cycle generates approximately 11–13 MW while optimizing exergy recovery from fluids at around 140°C.^[26] Similar implementations have been studied for fields like Velika Ciglena in Croatia, demonstrating net power gains and exergy efficiencies up to 34% for comparable temperature ranges.^[28] These applications highlight the configuration's role in maximizing output from moderate-temperature resources without the need for advanced fluid mixtures.^[27]

Dual Fluid Systems

Dual fluid systems in binary cycle geothermal power plants employ two distinct working fluids within the secondary cycle to enhance heat transfer efficiency across a wider temperature range. A high-boiling-point fluid is utilized at the hot end of the heat exchanger to capture heat from the higher-temperature portion of the geothermal fluid, while a low-boiling-point fluid handles the colder end, achieving a closer match to the temperature glide of the geothermal source. This configuration minimizes temperature differences during heat exchange, reducing exergy losses and improving overall thermodynamic performance.^[29]^[30] In operation, the two fluids can be arranged in series or parallel flows through the heat exchanger, allowing sequential or simultaneous vaporization tailored to the geothermal fluid's temperature profile. The vaporized fluids then drive expansion, either through separate turbines for each fluid or a shared multi-stage turbine setup, before condensation and recirculation. This staged approach enables better utilization of the available heat, particularly in resources with variable or moderate temperatures.^[29]^[30] The primary benefits include higher cycle efficiency, with improvements of up to 17% compared to single-fluid basic Rankine cycles, due to optimized thermal matching in variable temperature sources. Additionally, the reduced temperature gradients lower thermal stress on heat exchanger components, potentially extending equipment lifespan. However, these systems introduce drawbacks such as increased complexity from managing multiple fluids, requiring separate handling, recovery, and containment systems, which elevate capital and operational costs.^[29]^[30]

Key Components

Turbine and Expansion

In binary cycle geothermal power plants, the turbine facilitates the isentropic expansion of the vaporized secondary working fluid, converting its thermal energy into mechanical shaft work that drives an electrical generator. This process occurs in a closed-loop Organic Rankine Cycle (ORC), where the secondary fluid—typically an organic compound like isopentane or isobutane—enters the turbine at elevated pressure and temperature after vaporization in the heat exchanger. The expansion drops the fluid to a lower pressure, producing work output while maintaining near-ideal thermodynamic conditions to maximize energy extraction.^[9]^[18] Turbine design in binary cycles is tailored to the properties of the secondary organic fluid, particularly its higher molecular weight compared to steam, which influences flow characteristics and requires compact geometries for efficient operation at low pressures and temperatures. Radial inflow or outflow turbines are commonly employed for smaller plants (under 5 MW), offering simplicity and suitability for the dense, high-molecular-weight vapors, while axial turbines are preferred for larger installations to handle higher flow rates with multi-stage configurations. Isentropic efficiencies typically range from 80% to 90%, reflecting the ratio of actual to ideal enthalpy drop during expansion, as specified by manufacturers to optimize performance under varying fluid conditions.^[31]^[32]^[33] Performance is significantly influenced by inlet conditions, with higher temperatures and pressures increasing power output and efficiency; for instance, elevating the inlet temperature from 90°C to 150°C can boost net power by about 8-10% in single-stage ORC setups. To mitigate erosion risks from wet vapors during expansion, superheating is often applied to ensure the fluid enters as dry or superheated vapor, reducing moisture content below 15% at the turbine exit and protecting blades from liquid droplet impingement. In hybrid configurations, the binary cycle turbine may integrate with flash steam cycles as a bottoming unit, utilizing residual heat to enhance overall plant output without dedicated hardware.^[9]^[33]^[34]

Condenser and Cooling

In binary cycle geothermal power plants, the condenser serves as the primary component for heat rejection, where the low-pressure vapor exiting the turbine is condensed back into a liquid state, typically using shell-and-tube or plate heat exchangers to transfer thermal energy to a cooling medium.^[35] This process rejects approximately 70–80% of the input heat to the ambient environment, enabling the secondary working fluid to be recirculated efficiently in the closed loop.^[9] Achieving subcooling in the condenser—often on the order of 0.1–1°C below the saturation temperature—helps prevent cavitation and enhances the net positive suction head for subsequent pumping, thereby improving overall cycle reliability.^[36] Cooling methods for the condenser vary based on site conditions, with air-cooled systems (dry cooling towers) preferred in water-scarce regions to minimize freshwater use, while water-cooled evaporative towers are employed where water availability supports higher efficiency.^[9] Air-cooled condensers rely on forced convection from large finned-tube arrays, but they result in higher back pressure at the turbine exhaust—typically 40–50°C condensing temperatures—reducing power output by up to 10–20% compared to water-cooled alternatives under similar ambient conditions.^[35] In contrast, water-cooled systems maintain lower condensing temperatures (around 30–40°C) through evaporative cooling, lowering back pressure and boosting cycle efficiency, though they require careful design to handle scaling and corrosion.^[9] Performance of the condenser is critically influenced by the approach temperature, defined as the difference between the cooling medium outlet temperature and the working fluid's saturation temperature, typically maintained at 5–10°C to optimize heat transfer without excessive surface area.^[9] A smaller approach temperature enhances cycle efficiency by allowing closer operation to the ambient sink temperature, but it increases condenser size and cost; deviations can reduce net plant output by 1–2% per °C.^[9] Additionally, non-condensable gases, primarily air ingress in the closed secondary loop, accumulate in the condenser and impair heat transfer, necessitating periodic removal through vacuum vents or purging systems to sustain vacuum conditions (around 0.05–0.1 bar).^[9] Condenser sizing is determined by the total heat rejection load, which scales with turbine exhaust conditions and ambient temperatures, often requiring surface areas of 500–1000 m² per MW of gross power to accommodate the non-isothermal condensation of organic fluids.^[35] Shell-and-tube designs dominate due to their robustness against pressure differentials and ease of maintenance, featuring horizontal double-pass configurations for counterflow heat exchange, while plate condensers offer compactness with heat transfer coefficients up to 10–20 kW/m²K for space-constrained installations.^[35] Proper sizing ensures minimal pressure drop (under 0.01 bar) to avoid efficiency losses, with modular air-cooled units allowing scalability for varying plant capacities.^[37]

Feed Pump and Circulation

In binary cycle geothermal power plants, the feed pump serves to pressurize the condensed secondary working fluid, typically an organic liquid such as isobutane or pentane, after it exits the condenser and before it enters the heat exchanger for reheating. Centrifugal pumps are commonly employed for this purpose, operating under steady-state adiabatic conditions to increase the fluid pressure from near-vacuum levels at the condenser outlet to the required high pressure at the heat exchanger inlet, ensuring continuous circulation through the closed Organic Rankine Cycle (ORC).^[38] These pumps consume approximately 2-3% of the gross turbine power in higher-temperature ORC configurations, representing a minor but essential parasitic load that impacts net plant efficiency.^[38] Design considerations for these feed pumps emphasize reliability and efficiency in handling the low-density organic fluids. Multi-stage centrifugal configurations are often utilized to achieve the necessary pressure heads, particularly in systems with significant elevation differences or pressure drops, while maintaining compact footprints suitable for modular plant layouts. To prevent cavitation, which can degrade performance and cause mechanical damage, pumps are engineered with adequate net positive suction head (NPSH) margins; this may involve pre-feed booster pumps to elevate inlet pressure, strategic pump placement below the condenser for gravity assist, or subcooling the condensate to reduce vapor pressure.^[38] Efficiencies typically range from 70-85% for well-designed centrifugal units, optimized for the specific fluid properties and operating pressures.^[9] Circulation in the secondary loop relies on precise control of the feed pump to match fluid flow rates with the available heat input from the primary geothermal brine, ensuring optimal heat transfer without overloading the system. Flow rates are scaled to geothermal fluid throughput, for example, around 40 L/s per production well in mid-enthalpy fields, adjustable via variable speed drives (VSDs) that enable load-following capabilities in response to reservoir variations or demand fluctuations.^[9] This dynamic control minimizes energy waste and supports stable operation across partial loads, with VSDs integrated into inverter-driven centrifugal pumps for proportional flow adjustment.^[38] On the primary side, reinjection pumps handle the cooled geothermal brine after heat extraction, returning it to the reservoir to sustain pressure and prevent subsidence. These pumps are robustly designed to manage abrasive particulates, dissolved solids, and corrosive elements in the brine, often using multistage axial-split configurations capable of flows up to 3,200 m³/h and heads to 2,900 m. They operate at elevated temperatures up to 200°C (or higher in specialized models reaching 425°C), incorporating wear-resistant materials like duplex stainless steel or hard coatings to withstand erosion from silica scaling and mineral abrasives prevalent in geothermal fluids.^[39]

Heat Exchanger Design

In binary cycle geothermal power plants, the primary heat exchanger serves as the critical interface for transferring thermal energy from the hot geothermal brine to the lower-boiling secondary working fluid, enabling efficient power generation without direct contact between the fluids.^[9] Common designs include shell-and-tube and plate heat exchangers, with shell-and-tube configurations often preferred in binary applications due to their robustness against high pressures and temperatures associated with geothermal brines.^[9] To enhance heat transfer coefficients, these exchangers may incorporate surface modifications such as fins or twisted tubes, which promote turbulence and increase the effective contact area between fluids.^[40] Plate designs, while more compact, are selected for smaller-scale or lower-temperature operations where space constraints apply.^[41] Operationally, these heat exchangers typically employ a counterflow arrangement to minimize the temperature difference across the unit, thereby maximizing thermodynamic efficiency and reducing exergy losses.^[42] Geothermal brines, laden with minerals like silica and salts, promote fouling on the exchanger surfaces, which can degrade performance over time; designs incorporate features such as accessible cleaning ports or removable tube bundles to facilitate periodic mechanical or chemical cleaning.^[43] Performance evaluation focuses on the overall heat transfer coefficient (U), which ranges from approximately 500 to 2000 W/m²K depending on fluid properties, flow regimes, and surface enhancements, with higher values achieved in plate exchangers due to their thin boundaries.^[44] Sizing of the heat exchanger relies on pinch point analysis, which identifies the minimum temperature approach between the geothermal brine and secondary fluid (often 5–10°C) to ensure feasible heat transfer while optimizing surface area requirements.^[45] Materials selection emphasizes corrosion resistance on the geothermal side, where titanium alloys are widely used for their immunity to pitting, crevice corrosion, and stress cracking induced by acidic or saline brines at temperatures up to 200°C.^[46] The secondary fluid side may employ stainless steels or other alloys compatible with organic working fluids like isobutane or pentane.^[47]

Efficiency and Performance Metrics

First and Second Law Efficiencies

The first law efficiency of a binary cycle, also known as thermal efficiency, quantifies the conversion of heat input into net mechanical work based on the conservation of energy. It is calculated as \eta_I = \frac{W_{net}}{Q_{in}}, where W_{net} represents the net work output, primarily the turbine work minus the pump work, and Q_{in} is the heat absorbed from the geothermal source in the heat exchanger. In practical binary geothermal power plants, \eta_I typically ranges from 10% to 13%, reflecting losses due to heat rejection in the condenser and parasitic loads like pumping.^[48] This value is derived from an energy balance across the cycle: for steady-state operation, Q_{in} = W_t + W_p + Q_{out}, where W_t is turbine work, W_p is pump work, and Q_{out} is heat rejected, leading directly to \eta_I = 1 - \frac{Q_{out}}{Q_{in}}. Irreversibilities in components, such as pressure drops and friction, reduce the actual W_{net} compared to ideal assumptions.^[49] The second law efficiency, or exergy efficiency, provides a more insightful measure by accounting for the quality of energy, using the concept of exergy—the maximum useful work obtainable from a system relative to the environment. It is defined as \eta_{II} = \frac{W_{net}}{Q_{in} (1 - \frac{T_0}{T_{in}})}, where T_0 is the ambient temperature and T_{in} is the geothermal source temperature, representing the ratio of actual work to the reversible work potential. In binary cycles, \eta_{II} often achieves 30–50% of the theoretical maximum, highlighting opportunities for improvement beyond mere energy conservation.^[49] This efficiency is derived from exergy balances, incorporating entropy generation: exergy destruction I = T_0 \Delta S_{gen} quantifies irreversibilities, with \eta_{II} approaching 1 only in reversible processes. Component-level analysis reveals that entropy increases due to finite temperature differences and mixing, particularly in the heat exchanger and turbine.^[50] Key factors influencing both efficiencies include the geothermal fluid inlet temperature, which elevates Q_{in} and the exergy potential for higher \eta_I and \eta_{II}, and ambient conditions, where elevated T_0 diminishes the temperature gradient and thus the available work.^[51] Improvements focus on minimizing exergy destruction, with studies indicating that a significant portion of total losses, often over 50%, occur in the heat exchanger due to thermal irreversibilities; optimizing designs like counterflow configurations or enhanced heat transfer surfaces can reduce these by 20–30%.^[52]^[53] Such enhancements elevate \eta_{II} toward 50% without altering the fundamental cycle thermodynamics. The second law efficiency serves as a practical benchmark relative to ideal reversible cycles, emphasizing exergy recovery over raw energy throughput.^[49]

Carnot Efficiency and Limitations

The Carnot efficiency represents the theoretical maximum thermal efficiency for any heat engine operating between a hot source temperature T_\text{hot} and a cold sink temperature T_\text{cold}, both in Kelvin, serving as an upper bound for binary cycle systems in geothermal power generation. It is given by the formula

\eta_C = 1 - \frac{T_\text{cold}}{T_\text{hot}}.

This efficiency arises from the ideal reversible Carnot cycle, which assumes no losses and perfect heat transfer. For a typical binary cycle with a geothermal source at 180°C (453 K) and an ambient sink at 30°C (303 K), the Carnot efficiency reaches approximately 33%, highlighting the potential but rarely achieved limit for low-to-medium temperature resources.^[54] The derivation of the Carnot efficiency begins with the first and second laws of thermodynamics applied to a reversible heat engine. Consider a cycle with heat input Q_\text{hot} at constant temperature T_\text{hot} during isothermal expansion and heat rejection Q_\text{cold} at constant temperature T_\text{cold} during isothermal compression, connected by adiabatic processes. From the first law, the net work output is W = Q_\text{hot} - |Q_\text{cold}|. The second law requires zero net entropy change for reversibility: \Delta S = \frac{Q_\text{hot}}{T_\text{hot}} + \frac{Q_\text{cold}}{T_\text{cold}} = 0, so \frac{|Q_\text{cold}|}{Q_\text{hot}} = \frac{T_\text{cold}}{T_\text{hot}}. Thus, the efficiency is \eta_C = \frac{W}{Q_\text{hot}} = 1 - \frac{|Q_\text{cold}|}{Q_\text{hot}} = 1 - \frac{T_\text{cold}}{T_\text{hot}}, emphasizing the entropy constraint that bounds all real engines.^[55] In binary cycles, actual efficiencies are significantly lower than this ideal, typically 10–13% for plants operating between 85°C and 180°C, due to inherent limitations that introduce irreversibilities. Low source temperatures inherently cap the Carnot efficiency at modest levels (often below 20–30%), while variations in ambient sink temperature further reduce it seasonally. Binary cycles typically achieve 40–60% of the Carnot limit, with advanced designs reaching up to 85% relative to more realistic ideal models like the triangular cycle, primarily because of non-isothermal heat addition in the evaporator—unlike the isothermal process in the Carnot cycle—and finite temperature differences across heat exchangers, which generate entropy through irreversible heat transfer. Additional losses stem from friction in turbines and pumps, as well as pressure drops in piping, all deviating from the reversible adiabatic assumptions. The Carnot model thus overestimates performance for binary systems, where the triangular cycle (accounting for linear temperature decline in the geothermal fluid) provides a more realistic upper bound of about 60–70% of Carnot.^[54]^[55]

Working Fluids

Selection Criteria

The selection of working fluids for binary cycles, particularly in geothermal applications, hinges on a balance of thermodynamic performance, environmental compatibility, safety, and practical feasibility to ensure efficient heat transfer from the primary fluid to the power generation cycle. Key thermodynamic criteria include matching the fluid's critical temperature and pressure to the heat source temperature, typically requiring the critical temperature to exceed the source temperature for effective evaporation without exceeding the critical point. Additionally, fluids with high latent heat of vaporization are preferred, as they enable greater heat absorption per unit mass, leading to higher turbine work output and more compact equipment designs.^[56]^[57] For zeotropic mixtures, the temperature glide during phase change is a critical factor, as it allows better thermal matching with the variable-temperature heat source, reducing exergy losses and maximizing cycle efficiency compared to pure fluids with isothermal boiling. Environmental considerations prioritize fluids with negligible ozone depletion potential (ODP ≈ 0) and low global warming potential (typically GWP < 150), excluding chlorofluorocarbons (CFCs) and hydrochlorofluorocarbons (HCFCs) to comply with international regulations.^[58]^[59] Safety factors emphasize low toxicity and non-flammability to minimize risks in plant operations, particularly for fluids handling high pressures and temperatures. Practical aspects involve ensuring fluid availability and cost-effectiveness, as well as chemical compatibility with system materials like heat exchangers and turbines to prevent corrosion or degradation. Thermal and chemical stability under operating conditions is essential to avoid decomposition, which could reduce performance or require frequent maintenance.^[60]^[56] Evaluation of candidate fluids typically employs thermodynamic screening tools such as the NIST REFPROP software, which provides accurate property data including equations of state for pure fluids and mixtures. Complementary methods include T-Q (temperature-heat) diagrams, which visualize the temperature profile of the working fluid against heat transfer to identify optimal matches and minimize temperature differences in heat exchangers. These criteria collectively guide the choice toward fluids like hydrocarbons or refrigerants that align with binary cycle requirements.^[61]^[56]

Common Fluids and Properties

In binary cycle systems, particularly those employing organic Rankine cycles (ORC), isobutane serves as a widely used organic working fluid due to its favorable thermodynamic properties for low-to-medium temperature geothermal sources. With a critical temperature of approximately 135°C and a critical pressure of 36.4 bar, isobutane enables efficient vaporization and expansion in heat sources ranging from 100–150°C, achieving thermal efficiencies around 10-12% in typical configurations. However, its flammability poses safety challenges in plant design and operation.^[62]^[63] Pentane, including n-pentane and isopentane variants, is another common organic fluid in ORC-based binary cycles, valued for its enhanced thermal stability at higher temperatures. N-pentane has a critical temperature of 196.7°C and a normal boiling point of 36.1°C, making it suitable for geothermal resources up to 180–200°C, where it supports greater heat recovery and cycle efficiencies compared to lower-critical-temperature fluids. Its non-polar nature contributes to good compatibility with turbine materials, though it shares flammability risks with other hydrocarbons.^[64]^[65]^[62] For Kalina cycle implementations in binary systems, ammonia-water mixtures are the standard working fluid, leveraging their non-azeotropic properties for improved matching of temperature profiles during heat exchange. These mixtures exhibit a variable boiling point that spans approximately 0–100°C depending on ammonia concentration (typically 50–70 wt%), enabling closer approach to the heat source temperature curve and up to 20% higher exergy efficiency than single-component ORC fluids in low-temperature applications. The zeotropic behavior enhances heat recovery by reducing irreversibilities, though corrosion from ammonia requires specialized materials.^[66]^[67]^[68] Other fluids employed in binary cycles include R134a, a hydrofluorocarbon refrigerant with a boiling point of -26.1°C, which is effective for very low-temperature sources below 100°C due to its high latent heat and non-flammable nature, yielding system efficiencies around 7–8% in subcritical ORC setups. Supercritical CO2 is gaining traction in advanced binary designs, with its low critical temperature of 31.1°C and pressure of 73.8 bar allowing compact, high-efficiency cycles (up to 15% thermal efficiency) that are environmentally benign and non-toxic, albeit demanding robust high-pressure components. R134a offers operational simplicity but carries a high global warming potential (GWP) of 1430, while CO2 provides near-zero GWP at the cost of elevated operating pressures.^[69]^[70]^[71]^[72] Post-2020 regulatory shifts, including the U.S. EPA's hydrofluorocarbon phasedown under the American Innovation and Manufacturing Act, have accelerated the adoption of low-GWP alternatives such as hydrofluoroolefins (HFOs) in ORC binary cycles. Fluids like R1234yf (GWP <1) and HFO-R245fa mixtures demonstrate comparable performance to traditional refrigerants in low-temperature operations, with boiling points around -29°C and improved environmental profiles, supporting net-zero emission goals in geothermal power generation. Emerging research as of 2025 explores water as a working fluid in binary cycles for higher-temperature resources above 300°C, particularly in superhot rock geothermal systems, offering thermal efficiencies of 22-27% and reduced reliance on organic fluids.^[73]^[74]^[33]

Environmental and Economic Aspects

Environmental Impacts

Binary cycle geothermal power plants exhibit minimal direct emissions of greenhouse gases, primarily due to their closed-loop secondary fluid circulation, which prevents the release of carbon dioxide (CO₂) and methane (CH₄) associated with the geothermal brine.^[75]^[76] Trace amounts of hydrogen sulfide (H₂S) may originate from the primary geothermal fluid, but these are effectively managed through abatement technologies such as liquid redox processes and reinjection, achieving removal efficiencies of 90% to 99.9%.^[77] Water consumption in binary cycle operations is relatively low compared to other thermal power technologies, with air-cooled variants using approximately 1 L/kWh (0.27 gallons per kWh) and wet-cooled (evaporative) systems ranging from 5 to 18 L/kWh.^[78]^[3] Reinjection of geothermal fluids back into the reservoir not only conserves water but also minimizes surface subsidence by maintaining reservoir pressure.^[79] These plants require a compact land footprint of 1 to 8 acres per megawatt (MW), enabling potential coexistence with agriculture or other land uses and limiting impacts on biodiversity.^[80] However, exploratory and production drilling can disrupt local aquifers through fluid extraction or injection, potentially altering groundwater flow. In enhanced geothermal systems (EGS) integrated with binary cycles, there is a risk of induced seismicity from reservoir stimulation, though events are generally microseismic and manageable through monitoring and controlled injection practices.^[81] Life cycle assessments indicate that approximately 98% of the environmental impact from binary cycle plants stems from exergy destruction during heat transfer and conversion processes. Cogeneration applications, such as combined heat and power from binary systems, can substantially reduce this overall footprint by improving resource utilization efficiency.^[82]^[75]

Economic Considerations

Binary cycle geothermal power plants typically incur higher capital costs compared to flash steam plants, ranging from $2,500 to $5,500 per kilowatt of installed capacity (as of 2017), primarily due to the need for extensive heat exchanger systems to transfer heat from the geothermal fluid to the secondary working fluid without direct contact.^[83]^[84] Recent estimates as of 2024 indicate averages around $4,350 per kW.^[85] Operation and maintenance (O&M) costs are relatively low at approximately $0.01 to $0.02 per kilowatt-hour, benefiting from the technology's high reliability and minimal fuel requirements.^[83] The levelized cost of energy (LCOE) for binary cycle plants generally falls between 5 and 10 cents per kilowatt-hour, making it competitive with variable renewables like solar and wind in regions with suitable low- to medium-temperature geothermal resources. Key economic factors influencing viability include resource exploration risks, which can increase upfront uncertainties and costs due to the need for extensive drilling and testing to confirm reservoir productivity. Government incentives, such as the U.S. Production Tax Credit (PTC) providing about $0.0275 per kilowatt-hour for qualified geothermal electricity, help mitigate these risks and improve project economics.^[86] Under the 2022 Inflation Reduction Act, the PTC can be multiplied up to five times the base rate for projects meeting prevailing wage, apprenticeship, and domestic content requirements. With a high capacity factor of around 90%, payback periods typically range from 7 to 10 years, assuming stable resource conditions and effective financing. The global market for geothermal power, including binary cycle systems, is valued at $6.95 billion in 2025 and is projected to grow to $10.78 billion by 2034, at a compound annual growth rate (CAGR) of 5-8%, driven by increasing demand for baseload renewable energy and technological advancements in low-temperature resource utilization.^[87]

Modern Applications and Future Prospects

Notable Power Plants

Binary cycle power plants represent a significant portion of global geothermal electricity generation, accounting for approximately 20–30% of the total installed capacity of around 16 GW as of 2025. This equates to roughly 3.2–4.8 GW of binary cycle capacity worldwide, distributed across an estimated 250 plants, with the majority being smaller modular units. Leading countries include the United States with about 2.5 GW of binary capacity, followed by Indonesia and Turkey, though the latter two rely more heavily on flash steam systems overall.^[8]^[13]^[88]^[89] One of the earliest commercial binary cycle installations is the East Mesa geothermal complex in California's Imperial Valley, USA, which began operations in 1979 with a pioneering 10 MW Magmamax unit and expanded to a total capacity of approximately 45 MW through additional Ormat binary modules by the 1980s. This plant demonstrated the viability of binary cycles for moderate-temperature resources around 165–177°C, achieving reliable operation in a challenging brine environment.^[90]^[91] In New Zealand, the Ngatamariki power plant, commissioned in 2013, stands as one of the largest dedicated binary facilities globally, with an installed capacity of 100 MW from four Ormat Energy Converter units producing 82 MW net. Designed for a low-enthalpy field with fluids at about 250–300°C, it utilizes air-cooled condensers to minimize water use and has operated with high uptime since startup.^[92]^[93] For lower-temperature demonstrations, the Chena Hot Springs plant in Alaska, USA, operational since 2006, generates 400 kW using binary cycle technology with geothermal fluids as low as 74°C, making it a benchmark for micro-scale applications in remote, low-resource settings. This air-cooled organic Rankine cycle system powers the resort's facilities and highlights binary cycles' adaptability to temperatures below 100°C.^[94] The Salton Sea geothermal field in California, USA, features multiple binary cycle units integrated into its 400 MW total capacity across ten plants, including dual-pressure configurations that enhance efficiency from hypersaline brines exceeding 200°C. These plants exhibit high operational reliability, with average availability rates of 95%, contributing to consistent baseload power in the region.^[95]^[96]

Organic Rankine and Kalina Cycles

The Organic Rankine Cycle (ORC) functions as a secondary cycle in binary geothermal power systems, employing pure organic working fluids like isobutane or n-pentane that vaporize at low temperatures to facilitate efficient, non-contact heat exchange with the geothermal brine. These systems are noted for their straightforward design, which minimizes complexity and enhances reliability, with implementations often featuring modular units developed by leading manufacturers such as Ormat Technologies. ORC-based binary plants achieve thermal efficiencies typically ranging from 10% to 12%, making them well-suited for exploiting low- to medium-temperature resources under 150°C, and they constitute the majority of operational binary geothermal facilities worldwide.^[97]^[98]^[9] In contrast, the Kalina cycle utilizes an ammonia-water mixture as its working fluid in binary secondary cycles, enabling a variable boiling temperature that aligns closely with the declining temperature profile of the geothermal heat source for superior heat recovery. This zeotropic mixture exhibits a temperature glide during phase change, where the bubble point temperature (initiation of vaporization) and dew point temperature (completion of vaporization) differ, allowing the fluid to evaporate and condense over a range rather than at a fixed temperature; these points are calculated using correlations such as those by Patek and Klomfar (1995), given by:

T_b = 273.15 + \frac{1}{\frac{1}{T_{sat,NH_3}} - A \ln\left(\frac{P}{P_{crit,NH_3}}\right) + B \left(\frac{P}{P_{crit,NH_3}}\right)^{0.5}}

and similar forms for the dew point T_d, parameterized by the ammonia mass fraction and pressure, derived from experimental vapor-liquid equilibrium data. Kalina cycles demonstrate 15–20% higher power output than equivalent ORC systems under comparable low-temperature conditions (75–150°C), owing to reduced irreversibilities in heat transfer. Pilot installations include the 2 MW facility in Húsavík, Iceland, operational since 2000, and a 1 MW demonstration in New Mexico, United States.^[99]^[71]^[100] When comparing the two cycles in binary applications, ORC systems provide advantages in maintenance ease due to their simpler piping and component layouts using non-reactive organic fluids, whereas Kalina cycles offer better performance for variable-temperature heat recovery but require corrosion-resistant materials to mitigate the aggressive effects of the ammonia-water mixture on standard alloys. The ammonia component promotes general corrosion in alkaline environments (pH >9), necessitating specialized alloys like carbon steel with inhibitors or stainless steels in key components such as heat exchangers and piping. ORC adoption dominates in regions with abundant low-temperature resources, such as the United States (where Ormat operates over 1 GW of capacity) and New Zealand (with multiple sites under 150°C leveraging ORC for distributed generation), while Kalina remains confined to niche, high-efficiency sites prioritizing thermodynamic gains over operational simplicity.^[101]^[102]^[103]

Recent Developments and Innovations

In recent years, binary cycle geothermal systems have seen significant capacity expansions, particularly in regions with established geothermal resources. New Zealand added 225 MW of geothermal capacity in 2024 through two new installations, including a binary-cycle unit, marking one of the largest single-year increases globally for this technology.^[8] By the end of 2024, global geothermal installed capacity reached 15.4 GW, with binary cycles playing a pivotal role in recent additions due to their suitability for lower-temperature resources, representing a substantial growth from approximately 1.25 GW of binary capacity reported in 2014.^[14] Innovations in binary cycle integration have focused on enhancing resource accessibility and sustainability. Enhanced Geothermal Systems (EGS) have been increasingly paired with binary cycles to tap deeper, low-permeability reservoirs, enabling efficient heat extraction through closed-loop secondary fluids and hydraulic stimulation.^[12] Additionally, 2025 studies have explored hybrid configurations combining binary geothermal plants with direct air capture (DAC) units, leveraging excess heat from the cycle to drive carbon dioxide removal processes, potentially enabling carbon-negative power generation.^[104] Efficiency improvements have been driven by advancements in turbines and working fluids, with optimized designs achieving up to 15% thermal efficiency in binary systems operating at moderate temperatures.^[105] A 2024 analysis highlighted the development of climate-resilient binary cycle designs, incorporating adaptive cooling and fluid selections like isobutane to mitigate performance declines from rising ambient temperatures due to global warming.^[106] Looking ahead, projections indicate strong growth potential for binary and next-generation geothermal technologies, emphasizing modular units for scalable deployment. The International Energy Agency (IEA) forecasts that supportive policies could drive cumulative investments in geothermal to $1 trillion by 2035, facilitating widespread adoption of advanced binary systems.^[107] The U.S. Department of Energy (DOE) projects that enhanced geothermal, including modular binary configurations, could reach 90 GW of capacity by 2050, a twentyfold increase from current levels.^[108]

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Geothermal Power Market Size to Hit USD 10.78 Billion by 2034
Asia Pacific dominated the position sensor market with the largest market share of 34% in 2024. · Market Size in 2025: USD 6.95 Billion · Calpine · Binary Cycle ...Missing: percentage | Show results with:percentage
[84]
GSR 2025 | Geothermal - REN21
At the start of the 2024-2025 heating season, geothermal heating capacity was reported to have grown more than 17%, serving an additional 120 million m2 of ...Missing: percentage | Show results with:percentage
[85]
Geothermal Energy Market Size And Share Report, 2030
... share of 30.5% in 2023. Binary cycle power plants utilize lower temperature geothermal resources which are more abundant globally compared to high ...
[86]
[PDF] 2021 U.S. Geothermal Power Production and District Heating Market ...
Feb 10, 2020 · In 1974, the Geothermal Energy Research Development and. Demonstration Act (30 U.S.C. § 24) established the first federal loan guarantee ...<|separator|>
[87]
East Mesa Magmamax Power Process Geothermal Generating Plant ...
Dec 1, 1980 · During recent months, Magma Power Company has been involved in the shakedown and startup of their 10 MW binary cycle power plant at East ...
[88]
Magmamax Binary Power Plant, East Mesa, Imperial Valley ...
The first commercial scale binary power plant operating on geothermal energy was dedicated on 6 December 1985. This 50 MW (gross) power plant is built on a 20- ...
[89]
Ormat Successfully Completed Ngatamariki Geothermal Plant
Mighty River Power's modular Ngatamariki geothermal power plant is the largest singular binary power plant ever constructed. The Ormat Energy Converters are ...
[90]
Ngā Tamariki Geothermal System
The Ngā Tamariki Power Station was commissioned in 2013. It has four Ormat 20.5 MW(e) binary cycle units, the largest Ormat Binary Cycle units in the world ...
[91]
Performance analysis of the Chena binary geothermal power plant
In this paper, the IPSEpro model of the Chena Geothermal ORC Power Plant had been developed and validated using the real data.
[92]
1000+ MW of geothermal power generation capacity
Dec 14, 2018 · One of them is POWER Engineers that is proud having worked on geothermal projects of a total of more than 1,000 MW in capacity.
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[PDF] SUSTAINABILITY OF THE SALTON SEA - Colorado College
The majority of the Salton Sea geothermal power plants are flash steam plants but there are binary plants too. ... geothermal since it is a reliable and ...<|separator|>
[94]
Organic Rankine Cycle – ORC - Ormat Technologies
The Organic Rankine Cycle (ORC) is an evolving energy system for power production utilizing geothermal resources and recovered waste-heat.Missing: 10-12% 80%
[95]
Thermodynamic performance evaluation of a geothermal ORC ...
According to the results of the study, thermal efficiency of the geothermal binary plants mostly vary between 8 and 12%; as a result, only 1–2 point increase in ...
[96]
Kalina Cycle Enjoying Commercial Success - Power Engineering
Feb 1, 2002 · The Kalina Cycle uses a binary working fluid of an ammonia-water mixture to drive a turbine-generator. By varying the composition of the binary ...Missing: ORC Denmark Israel
[97]
[PDF] Small-Scale Geothermal Power Plant Field Verification Projects
The projects include a 1-MW binary-cycle plant in Nevada, a 1-MW Kalina-cycle plant in New Mexico, and a 750-kW flash plant in Utah, with direct heating uses.
[98]
[PDF] Corrosion in the Kalina cycle - Skemman
They use a working fluid of ammonia and water, benefiting from the property of mixtures of boiling over a temperature range at constant pressure, to achieve ...
[99]
Kalina Cycle power systems in waste heat recovery applications
Aug 6, 2012 · General corrosion In Kalina Cycle environments the presence of ammonia (NH3) ensures strongly alkaline conditions and consequently pH values of ...
[100]
[PDF] Development of a Low Temperature Geothermal Organic Rankine ...
Nov 20, 2013 · Low temperature geothermal is an abundant resource in New Zealand with over 260 sites with a resource temperature of 150°C and lower.Missing: Adoption Kalina niche
[101]
Advancing geothermal energy utilization opportunities: potential and ...
Jun 18, 2025 · This study explores the potential of geothermal resources to meet the thermal and electrical demands of DAC systems through the development of a geothermal-DAC ...2. Methodology · 3.1. Geothermal-Dac... · 3.2. Geothermal-Dac...
[102]
Modern geothermal power: Binary cycle geothermal power plants
Aug 6, 2025 · Binary cycle power plants have an average unit capacity of 6.3 MW, 30.4 MW at single-flash power plants, 37.4 MW at double-flash plants, and 45 ...
[103]
Impact of Climate Change on the Thermoeconomic Performance of ...
Sep 3, 2024 · This study focuses on the performance analysis of a binary cycle with isobutane for geothermal power generation under the impact of climate change.
[104]
Technology breakthroughs are unlocking geothermal energy's vast ...
Dec 13, 2024 · The report finds that the total investment in geothermal could reach $1 trillion by 2035 and $2.5 trillion by 2050. If next-generation ...
[105]
U.S. DOE unveils roadmap for next generation of geothermal power
Mar 25, 2024 · This report shows how advanced geothermal technology could increase the US' geothermal energy production to 90 GW or more by 2050, a twentyfold increase.