Life Cycle Assessment of Power Plants: A Systematic Review of Environmental Impacts Across Electricity Generation Technologies

Abstract

Life Cycle Assessment (LCA) is widely used to evaluate the environmental impact of power generation systems and inform energy and climate policy decisions. In recent years, numerous LCA studies have examined the life-cycle implications of power plants utilizing renewable, nuclear, and fossil fuel technologies. Nevertheless, the resultant data is fragmented, exhibiting significant diversity among investigations attributable to disparities in system boundaries, technical assumptions, and methodological selections. This document offers a systematic overview of peer-reviewed LCA studies and Environmental Product Declarations (EPDs) evaluating the environmental implications of predominant power production technologies, such as solar photovoltaic, wind, hydropower, nuclear, and natural gas power plants. Various environmental effect categories are evaluated, with a specific focus on Global Warming Potential as the most frequently reported and policy-relevant metric. The review consolidates documented impact ranges, assesses the effects of plant size and technological design, and evaluates the contribution of several life cycle stages to overall environmental performance. The findings emphasize prevalent tendencies and significant variability among technologies and studies, illustrating the susceptibility of LCA results to modeling assumptions and data sources. Although current LCAs offer relevant insights into the environmental impact of electricity generation, the review highlights enduring methodological deficiencies, particularly the inadequate handling of uncertainty, the static portrayal of long-lasting infrastructures, and the lack of explicit attention to technological risk. This study consolidates and critically evaluates existing literature, providing a thorough reference on the life-cycle environmental consequences of power plants and facilitating a more educated interpretation of LCA results within energy system planning and policy analysis.

1. Introduction

Life Cycle Assessment (LCA) has emerged as a crucial methodological instrument for assessing the environmental implications of electricity generation technologies and for supporting energy and climate policy decisions. LCA facilitates systematic comparisons among technologies with significantly different technical characteristics and operational profiles by considering emissions and resource utilization throughout the entire life cycle of a power plant from raw material extraction and construction to operation, decommissioning, and waste management. As global energy systems transition toward low-carbon pathways, the application of LCA to power generation technologies has expanded rapidly. A large and growing body of literature has applied LCA to renewable, nuclear, and fossil fuel-based power plants, often focusing on climate change impacts through the Global Warming Potential (GWP) indicator. Despite this extensive literature, reported outcomes remain highly heterogeneous. For identical technology, life cycle GWP values and other environmental metrics may differ by an order of magnitude across studies. Previous research suggests that this variability is predominantly driven by methodological and modeling decisions (i.e., system boundary definition, assumptions on plant lifetime and capacity factor, background energy mixes, and data sources) rather than solely by inherent technical differences. Therefore, LCA results for power plants are more appropriately interpreted as ranges of plausible outcomes rather than as an exact point of estimation. However, existing review studies largely fall into two categories. On the one hand, technology-specific reviews provide in-depth analyses of individual systems—such as wind, hydropower, or photovoltaic plants—but limit cross-technology comparability. Recent examples encompass reviews concentrated solely on wind power facilities, examining life-cycle greenhouse gas emissions and energy performance metrics for both onshore and offshore installations [1], alongside systematic reviews on hydropower systems, which underscore methodological deficiencies and the restricted scope of environmental indicators beyond climate change [2]. A considerable amount of literature has investigated photovoltaic power plants via technology-specific life cycle assessment studies, frequently focusing on inventory development or qualitative sustainability evaluations rather than comparative life-cycle performance among various technologies [3,4]. On the other hand, system-level or scenario-based LCAs evaluate future electricity mixes or national energy pathways (e.g., [5]), which are valuable for policy analysis but do not allow transparent comparison of the life-cycle environmental performance of individual power generation technologies. A comprehensive and structured synthesis that integrates quantitative evidence across renewable, nuclear, and fossil fuel power plants at the plant level, while explicitly addressing the large variability and methodological limitations of existing studies, is still lacking.

This paper addresses this gap through a systematic review of peer-reviewed Life Cycle Assessment studies and Environmental Product Declarations (EPD) that evaluate the environmental impacts of major electricity generation technologies, including solar photovoltaic, wind, hydropower, nuclear, and natural gas power plants. The review consolidates reported impact ranges, with a particular focus on Global Warming Potential as the most widely reported and policy-relevant indicator, using a consistent functional unit. In addition, the study examines the influence of plant size and technology configuration, evaluates the contribution of different life cycle stages to overall environmental performance, and critically discusses structural limitations of current LCA practice, including the treatment of uncertainty, temporal aspects, and technological risk. This review synthesizes and critically evaluates existing evidence across technologies, offering a transparent reference framework for interpreting LCA results of power plants and supporting a more informed use of life-cycle information in energy system planning and policy analysis.

2. Methodology

This research employs a structured methodology to assess the life-cycle environmental performance of major power generation technologies, with a specific focus on GWP. The analysis is based on a systematic literature review of LCA studies, complemented by EPDs and authoritative international and European institutional reports. The objective is to synthesize plant-level life-cycle evidence and to compare the environmental burdens associated with electricity production across fundamentally different technologies. The literature search includes publications available up to 2024.

The review process started with a comprehensive keyword-based search strategy (outlined in

Table 1. Overview of the keywords used in the literature review.

Research Area	Keywords
	Solar	Wind	Hydro	Nuclear	Natural gas
Life Cycle Assessment	“Life Cycle Assessment” OR “LCA”
AND Power Plant	“Solar” OR “Photovoltaic” AND “power plant”	“Wind” AND “power plant” OR “wind farm”	“Hydro” AND “Plant”	“Nuclear” AND “Power plant”	“Natural gas” AND “Power plant”

) applied to major scientific databases (i.e., Scopus, ScienceDirect). The search terms were designed to capture LCA studies of complete power plant systems for solar photovoltaic, wind, hydropower, nuclear, and natural gas technologies. The primary quantitative indicator extracted from the literature is GWP, expressed in g CO_2eq/kWh, which represents the most consistently reported and policy-relevant impact category across studies. Other environmental impact categories are acknowledged; however, due to their heterogeneous definitions, metrics, and reporting frequency, they are addressed primarily through qualitative or semi-quantitative discussion.

The review focused exclusively on studies evaluating entire power plant systems across their life cycle. Studies addressing isolated components (e.g., turbines, photovoltaic modules, balance-of-system elements) or system-level energy scenarios lacking explicit and comparable GWP results per unit of electricity generated were excluded. Moreover, only facilities producing electricity were considered. For solar technologies, the analysis was limited to photovoltaic power plants, excluding solar thermal and hybrid systems, even when broader solar-related keywords were used during the initial search phase.

To ensure consistency and comparability, explicit inclusion and exclusion criteria were applied. Eligible studies were required to:

• be published in peer-reviewed journals or released as verified EPDs or authoritative institutional reports;
• report life cycle GWP results quantified in g CO_2eq/kWh;
• assess complete power plant systems, encompassing construction, operation, and end-of-life phases, where relevant.

Studies published in journals not related to environmental assessment or energy systems were excluded. Additional screening was conducted to remove duplicate records and studies lacking sufficient methodological transparency or quantitative life-cycle results.

The review protocol followed a multi-step procedure summarized in

Table 2. Review protocol and results.

Step	Description	Solar	Wind	Hydro	Nuclear	Natural Gas
Keywords Search	Articles need to fulfill the search string in their title, abstract, or main text	331	229	71	127	277
Journal selection	Articles need to belong to peer-reviewed journals Exclusion of journal focused on subject areas not relevant for the literature review	224	142	45	84	201
Content Analysis and Consolidation	Duplicates were eliminated and relevance ensured by reading the abstract focusing on relevant topics Ensure relevance by reading the title, the abstract and then the entire article	20	42	15	15	21
Snowball Search	Forward and backward searches based on articles selected in previous steps	10	28	16	1	6
EPD		14	17	2	1	1
Sample size		44	87	33	17	28

. After the initial keyword search, records were screened based on journal relevance and thematic scope. Abstract screening was then performed to assess alignment with the review objectives, followed by full-text analysis to verify methodological consistency and data suitability. Forward and backward snowball searches were subsequently conducted to identify additional relevant studies cited by or citing the initially selected publications. Environmental Product Declarations were included when available, particularly for renewable energy technologies, to complement peer-reviewed LCAs with standardized, product-specific life-cycle data. The final sample size for each technology reflects the cumulative outcome of these selection steps and provides a solid empirical basis for cross-technology comparison.

From each selected study, quantitative GWP estimates, system boundary definitions, assumed plant lifetime, capacity factors, and the contribution of individual life cycle stages were extracted where reported. Due to the substantial variability in methodological assumptions and data sources across studies, results were synthesized as reported ranges rather than standardized point estimates. This approach allows the heterogeneity of the literature to be explicitly represented and avoids overstating the precision of comparative results. The functional unit adopted throughout the review is 1 kWh of electricity generated. This functional unit is widely used in LCA studies of power generation and enables direct comparison of life-cycle environmental burdens across different technologies. System-level characteristics—such as operational profiles, capacity factors, infrastructure requirements, and upstream supply chains—are reflected in the system boundaries and modeling assumptions of the reviewed studies rather than in the functional unit itself.

The review was conducted and reported in accordance with the Preferred Reporting Items for Systematic Reviews and Meta-Analyses (PRISMA) 2020 guidelines [6]. A completed PRISMA 2020 checklist is provided as a Supplementary Materials, and the study selection process is illustrated in Figure 1. The review protocol was not registered in a public database. The PRISMA flow diagram presents the aggregated workflow for all technologies considered and complements the disaggregated results reported in Table 2, thereby improving transparency and reproducibility.

A formal risk-of-bias assessment was not conducted, as life cycle assessment studies do not follow a shared experimental design or standardized reporting framework that would allow the consistent application of conventional risk-of-bias tools. In addition, the substantial heterogeneity in system boundaries, functional units, background datasets, and modeling assumptions would make a formal scoring approach potentially misleading rather than informative. Instead, study quality was addressed during the screening phase by excluding publications lacking methodological transparency, incomplete system definitions, or quantitative life-cycle results. Accordingly, the results are synthesized through a qualitative and descriptive analysis, focusing on reported life-cycle impact ranges and on the critical comparison of methodological choices that most strongly influence the outcomes. No meta-analysis was conducted.

Figure 2 provides a schematic overview of the system boundaries and life cycle stages adopted in this review, clarifying the allocation of processes across upstream, core infrastructure, core process, downstream infrastructure, and downstream operation for the different power generation technologies.

3. Environmental Assessment of Power Plants

This section presents the assessment of the environmental impacts associated with major power generation technologies, as identified through the literature review. The analysis focuses primarily on GWP, expressed per unit of electricity generated, and on the contribution of individual life cycle stages to overall emissions. Summary tables supporting the quantitative synthesis, together with information on data sources and methodological assumptions, are reported in Appendix A to ensure transparency and reproducibility. Other environmental dimensions are also discussed qualitatively to highlight recurring trade-offs and knowledge gaps.

3.1. Solar Power Plants

Solar photovoltaic (PV) capacity is rapidly expanding and is projected to surpass electricity generation from natural gas and coal in the coming years, emerging as one of the dominant global electricity sources. According to projections by the International Energy Agency (IEA), solar PV will maintain an annual growth rate exceeding 25% over the next decade. This expansion is driven by declining installation and production costs, supportive governmental policies, and the increasing urgency to mitigate climate change through low-carbon energy systems.

Technological improvements and economies of scale have substantially reduced the cost of solar electricity generation, which typically ranges between $0.05 and $0.10 per kilowatt-hour, depending on geographic location and project scale. Governments worldwide continue to deploy policy instruments such as feed-in tariffs, tax incentives, and renewable energy mandates to stimulate PV deployment. Beyond economic considerations, public concern regarding environmental degradation and greenhouse gas emissions further supports the diffusion of solar technologies. Despite these advantages, the environmental performance of PV systems must be assessed over their entire life cycle, as significant impacts arise outside the operational phase. Numerous life cycle assessment studies have quantified the environmental footprint of PV technologies; however, reported results vary widely due to differences in system boundaries, technological configurations, geographical context, and methodological assumptions.

Traditionally, PV systems adopt fixed-tilt configurations, in which modules are mounted at a predetermined angle to optimize annual solar irradiation capture. While this configuration is simple and cost-efficient, it does not fully exploit diurnal and seasonal solar variability. Solar tracking systems have therefore been introduced to increase electricity yield by following the sun’s trajectory, albeit at the expense of higher mechanical complexity, increased maintenance requirements, and additional material and energy inputs. The environmental performance of PV systems is also strongly affected by balance-of-system (BOS) components, including inverters, mounting structures, and electrical wiring. These elements can account for a substantial share of the embodied energy of PV installations. For example, the BOS of ground-mounted PV systems may require up to 1900 MJ/m², largely due to the use of energy-intensive materials such as steel and concrete. Silicon-based PV technologies, particularly monocrystalline and multicrystalline (polycrystalline) silicon, continue to dominate the global market. Monocrystalline silicon modules offer higher conversion efficiencies but involve an energy-intensive production process, notably the Czochralski method, which requires around 32 kWh per kilogram of silicon. Polycrystalline silicon modules require less energy during production (approximately 7 kWh/kg) but exhibit slightly lower efficiencies. Thin-film technologies, such as amorphous silicon, reduce material and energy requirements during manufacturing, although they typically achieve lower conversion efficiency. Emerging technologies, including dye-sensitized solar cells (DSSCs) and perovskite solar cells, have attracted increasing attention due to their potential for lower production costs and reduced embodied energy. Nevertheless, limitations related to long-term stability, scalability, and degradation currently restrict their large-scale deployment. For most silicon-based PV systems, the manufacturing phase represents the dominant contributor to life-cycle environmental impact. This phase includes the extraction and purification of quartz sand into solar-grade silicon (99.99% purity), requiring approximately 8 kWh of thermal energy and 49 kWh of electricity per kilogram of silicon. Additional materials include glass, copper for cables, and iron or zinc for mounting structures. The manufacturing process encompasses wafer production, cell fabrication, and module assembly, followed by transportation, installation, and grid connection. PV systems typically operate for 20 to 30 years, after which decommissioning and end-of-life management become relevant. While metals and glass can be recycled, current recycling infrastructure for PV modules remains limited, highlighting the importance of improved end-of-life strategies to reduce environmental burdens and recover valuable materials.

Life cycle inventory (LCI) data compiled by Frischknecht et al. [7] provide detailed insights into PV mounting systems and regional photovoltaic mixes, including process-level information on solar-grade silicon production across four macro-regions. Energy Payback Time (EPBT), defined as the time required for a system to generate the amount of energy consumed during its production, varies by technology and location but generally remains below five years for modern PV systems, indicating favorable energy returns over their operational lifetime. While technological progress has significantly reduced the carbon footprint of PV systems, several open issues remain evident in the reviewed literature, particularly with respect to end-of-life management and methodological consistency across studies.

Figure 3 summarizes the ranges of GWP values reported for different PV technologies, expressed per unit of electricity generated, enabling direct comparison across studies despite methodological heterogeneity. Reported GWP ranges reflect variations in material sourcing, manufacturing energy mixes, system design, and assumed lifetimes. Among commercially mature options, cadmium telluride (CdTe) consistently exhibits relatively low and narrow GWP ranges and the lowest reported maximum values, suggesting a more uniform and energy-efficient production process. In contrast, monocrystalline (Mono-Si) and polycrystalline silicon (Poly-Si) technologies display considerably broader GWP ranges, with Poly-Si reaching the highest maximum values among the technologies analyzed. This dispersion indicates that the environmental performance of silicon-based PV systems is highly sensitive to supply chain configuration, electricity mix used during manufacturing, and specific production methodologies. Thin-film technologies generally show lower GWP values due to reduced material intensity and lower embodied energy requirements. However, data availability for these technologies remains limited. Amorphous silicon (a-Si), copper indium gallium selenide (CIGS), and micromorphous silicon are each represented by a single study, highlighting the need for additional life cycle assessments to enable more robust inter-technology comparisons. The relatively low GWP values reported for a-Si, CIGS, and micromorphous silicon are consistent with the characteristics of thin-film PV, which benefit from minimal active material use. CIGS may benefit from high absorption efficiency and thin active layers, while the favorable performance of micromorphous silicon is often attributed to its tandem structure, which enhances light capture without substantially increasing energy inputs. The “Not specified” category, encompassing studies that do not distinguish between PV technologies, exhibits wide GWP variability, further emphasizing the role of factors such as material origin, manufacturing energy mix, and end-of-life assumptions in shaping life cycle results. Despite the observed variability, it is important to note that even the highest GWP values reported for PV technologies remain substantially lower than those associated with fossil fuel-based electricity generation, confirming the overall climate benefit of solar photovoltaic systems.

Plant size also influences environmental performance. As shown in

Table 3. GWP ranges for PV power plants as a function of the plant size.

Plant Size	GWP—Range (gCO2eq/kWh)
SMALL (<25 MW)	11–136
LARGE (>50 MW)	11–48

, large-scale PV installations (>50 MW) tend to exhibit narrower and lower maximum GWP ranges compared to small-scale systems (<25 MW). This trend reflects economies of scale, optimized construction practices, and more efficient BOS configurations in utility-scale projects. Small installations show greater variability, suggesting higher sensitivity to site-specific factors, including transportation distances, component selection, and local grid conditions.

The distribution of GWP contributions across life cycle stages (Figure 4) indicates that upstream processes and core infrastructure (i.e., plant construction, mounting systems) dominate total emissions, while operational and downstream (i.e., distribution systems construction and management) stages generally contribute less. However, considerable variability exists across studies due to differences in system boundary definitions and classification approaches. This variability reinforces the need for transparent and harmonized LCA methodologies when comparing PV systems.

Beyond climate change impacts, PV power plants may exert additional environmental pressures related to land use, biodiversity, water consumption, visual impact, and health and safety considerations, as summarized in

Table 4. Broader environmental considerations of solar power systems.

Environmental Aspect	Key Concerns	Cause	Mitigation Strategies
Biodiversity	Habitat disruption, interference with animal migration	Land clearing and vegetation removal for large-scale installations	Site selection in low-ecological-value areas, wildlife impact assessments
Electromagnetic Interference	Disruption of living organisms and communication systems	Radiation from transmission lines	Avoid siting near residential zones and sensitive electronics (e.g., broadcast towers)
Water Consumption	Water stress in arid regions	Water use for cooling (in CSP) or cleaning panels (in PV)	Use of closed-loop cooling, dry cleaning systems, and water-efficient washing technologies
Land Use	Competition with agriculture or ecosystems, landscape transformation	Large area requirements for panel arrays and maintenance	Utilize degraded, remote, or dual-use lands (e.g., agrivoltaics), optimize system layout
Visual Impact	Aesthetic concerns in scenic or heritage-rich locations, glare	Large reflective surfaces, alteration of natural views	Anti-reflective coatings, integrating design into the landscape, community consultation
Health & Safety	Toxic material exposure, chemical risks	Use of hazardous substances in manufacturing and maintenance	Enforce safety protocols, adopt non-toxic materials, and implement proper disposal/recycling procedures

. Addressing these aspects through careful site selection, improved system design, and enhanced regulatory frameworks is essential to ensure the sustainable expansion of solar energy systems.

3.2. Wind Power Plants

Wind power is projected to play a pivotal role in achieving net-zero emissions by 2050. Meeting these targets will require a substantial increase in annual wind capacity installations, alongside improvements in permitting processes, public acceptance, environmental impact mitigation, site identification, cost reduction, and project development timelines. Onshore wind power represents a mature technology supported by a well-established global supply chain, while offshore wind energy is experiencing rapid expansion due to access to higher and more stable wind resources. Technological advances in turbine design have increased energy output per unit of installed capacity, enabling economically viable projects even in regions characterized by moderate wind speeds. As a result, the cost of wind-generated electricity has declined significantly, with global average values typically ranging between $0.04 and $0.08 per kilowatt-hour, depending on location and project scale.

From a life cycle perspective, wind power systems require non-renewable material inputs (e.g., steel, concrete, and rare earth elements), and their life-cycle emissions are primarily concentrated in the manufacturing, installation, and maintenance phases. Typical operational lifetimes assumed in LCA studies are around 20 years for both onshore and offshore wind farms, although longer lifetimes are increasingly considered. The reviewed studies mostly focus on onshore installations located in Europe, with a growing body of literature addressing offshore and deep-water systems. All assessments include turbine manufacturing and foundation construction, while grid connection infrastructure is frequently, though not consistently, incorporated. Transportation, installation, and maintenance activities are generally accounted for, though the end-of-life processes are sometimes excluded or modeled differently across studies.

Offshore wind power plants often exhibit comparable or slightly higher life cycle emissions than large onshore installations, despite higher capacity factors. This difference is mainly attributable to the complexity and material intensity of offshore foundations and support structures designed to withstand harsh ocean conditions. Wind turbine systems require substantial quantities of iron, steel, copper, fiberglass, epoxy resins, concrete, and other materials. The average energy intensity reported for electricity generation from wind power is about 0.063 (±0.061) kWh of input energy per kWh of electricity generated for onshore systems and 0.055 (±0.037) kWh/kWh for offshore systems. The wide standard deviations reflect variability in turbine sizes, technological configuration, site conditions, and system boundaries. Excluding turbines with capacities below 100 kW reduces the reported energy intensity range to 0.014–0.137 kWh/kWh [8].

Wind power plants typically require several months to a few years for construction and operate for 20–30 years. Figure 5 presents the GWP ranges associated with different wind power technologies, expressed in grams of CO₂ equivalent per kilowatt-hour (gCO_2eq/kWh). Onshore wind systems show a broad GWP range, from 2.02 to 116 gCO_2eq/kWh, reflecting sensitivity to foundation design, transportation distances, turbine size, and site-specific wind conditions. Offshore wind power shows a higher minimum GWP but a narrower and lower maximum (up to 79 gCO_2eq/kWh), suggesting more consistent life cycle performance, potentially due to standardized construction practices and higher average capacity factors.

The influence of wind resource quality on life cycle emissions is further illustrated in

Table 5. GWP ranges for different wind conditions.

Wind Conditions	GWP—Range (gCO2eq/kWh)
HIGH—IEC class I	5.5–9.9
MEDIUM—IEC class II	5.33–11.5
LOW—IEC class III	6.2–15.9

, which reports GWP ranges according to IEC wind classes. Sites characterized by high wind availability (IEC class I) exhibit lower and more consistent GWP values, as turbines operate closer to optimal performance, distributing embodied emissions over a larger electricity output. Medium (class II) and low (class III) wind conditions are associated with progressively higher GWP ranges, highlighting the importance of site selection in minimizing life cycle emissions.

Figure 6 summarizes the distribution of GWP contribution across different lifecycle stages of wind power plants, presented as minimum, average, and maximum percentage contributions to the total GWP. The core infrastructure phase, which includes turbine components (i.e., blades, towers, nacelles) and foundations, represents the dominant contributor, accounting for approximately 60% of total GWP on average. Upstream processes, including raw material extraction and processing, contribute around 27% on average but exhibit high variability across studies. The core process phase, encompassing operation and maintenance, and the downstream phase related to grid infrastructure and distribution, generally contribute smaller shares, although values approaching 20% are reported in specific cases. These results indicate that material choices, foundation design, and supply chain configuration play a critical role in determining the environmental performance of wind power systems.

In addition to climate change impacts, wind power plants are associated with a range of other environmental considerations, summarized in

Table 6. Broader Environmental Considerations of Wind Power Systems.

Environmental Aspect	Key Concerns	Cause	Mitigation Strategies
Noise Pollution	Annoyance, sleep disturbance	Turbine operation noise influenced by design, wind speed, distance	Careful site selection; noise-reducing turbine designs; operational optimization
Biodiversity Impact	Habitat loss, wildlife disturbance	Land clearing, turbine placement, marine ecosystem disruption (offshore)	Environmental assessments; avoid sensitive habitats; bird/bat deterrents; ongoing monitoring
Visual Impact	Landscape alteration, community opposition	Turbine size, location, visibility in scenic areas	Thoughtful turbine design; strategic placement; camouflage techniques
Electromagnetic Fields (EMF)	Potential health concerns	EMF emissions from electrical components	Compliance with safety standards; monitoring; minimal risk confirmed
Land Use	Habitat fragmentation, land footprint	Turbine size and spacing; infrastructure requirements	Optimize turbine layout; prioritize offshore sites
Water Consumption	Resource use in manufacturing	Water used in production of components (blue water)	Use low-water manufacturing processes; minimize operational water use

. These include noise emissions, biodiversity impacts, visual effects, electromagnetic fields, land use, and water consumption. While many of these impacts are site-specific, appropriate planning, technological solutions, and regulatory measures can substantially mitigate their significance.

End-of-life management of wind turbine blades represents an emerging environmental challenge due to the widespread use of glass-fiber-reinforced thermosetting polymer composites, which are difficult to recycle using conventional methods [8,9]. As installed wind capacity continues to grow, blade waste volumes are projected to increase substantially. Current disposal options, such as landfilling and incineration, present environmental limitations, including land use requirements and inefficient material recovery with hazardous by-products. Several recycling pathways are under investigation, including mechanical, thermal (e.g., pyrolysis and fluidized bed processes), and chemical recycling, although each approach faces technical, economic, and scalability constraints. Alternative strategies, such as blade reuse and repurposing in civil and architectural applications, offer promising opportunities to extend material lifetime and reduce waste generation.

Table 7. Summary of Wind Turbine Blade End-of-Life Considerations.

Aspect	Description	Challenges	Mitigation/Solutions
Material Composition	Glass-fiber-reinforced thermosetting polymer composites	Difficult to recycle/separate components	Research into advanced recycling methods
Waste Volume	~200,000 tons expected by 2034	Large waste stream requiring management	Develop infrastructure for handling blade waste
Disposal Methods	Landfilling and incineration	Landfills waste space; incineration inefficient and produces ash	Move towards recycling and repurposing solutions
Mechanical Recycling	Shredding, grinding; used as filler materials	Low material value; limited industry uptake	Promote industrial use, develop higher-value reuse
Thermal Recycling	Pyrolysis, fluidized bed processes recover fibers	Mechanical properties of fibers degrade	Improve fiber recovery processes
Chemical Recycling	Chemical depolymerization to recover fibers and matrix	High cost; limited commercial adoption	Cost reduction and scale-up needed
Reuse	Direct reuse of functional blades	Limited by blade condition	Regular condition assessment for reuse potential
Repurposing	Structural reuse in urban furniture, playgrounds, civil uses	Design and implementation challenges	Develop standards and markets for repurposed products

summarizes the main challenges and mitigation strategies related to wind turbine blade end-of-life management.

3.3. Hydropower Plants

Hydropower has historically represented the dominant renewable electricity source worldwide, providing reliable, flexible, and dispatchable power generation that effectively complements variable renewable technologies such as solar and wind [10]. Although its global expansion has slowed in recent decades due to environmental concerns, limited availability of suitable sites, and increasing competition from alternative technologies, hydropower remains among the most cost-effective sources of electricity. It also plays a critical role in grid stability and energy storage, particularly through pumped storage systems. A major challenge for the sector is the aging of existing infrastructure, which requires significant investments for refurbishment and modernization. To sustain hydropower’s contribution to long-term decarbonization objectives, several issues must be addressed, including lengthy permitting processes, mitigation of environmental impacts, performance upgrades of existing facilities, technological innovation to enhance operational flexibility, and adaptation to hydrological changes induced by climate change.

Hydropower systems exhibit considerable heterogeneity in scale, design, and environmental performance. Technology type and project size are key determinants of lifecycle greenhouse gas emissions. Large- and medium-scale hydropower facilities typically adopt accumulation-type, pumped storage, or weir-based configurations [11]. Accumulation systems rely on reservoirs formed by dams or surge weirs to regulate water storage and electricity generation. Pumped storage plants employ two reservoirs at different elevations, allowing electricity storage through water pumping during low-demand periods and electricity generation during peak demand. Weir-type plants use river regulation structures to control flow and optimize power output. In contrast, small-scale hydropower installations, including micro and pico systems, often utilize run-of-river (ROR), small-pumped storage, or compact weir-based configurations. ROR systems generally exploit the kinetic energy of flowing water without large-scale impoundment, while small-pumped storage and weir systems may combine natural and artificial hydraulic structures.

Hydropower projects typically involve long construction timelines, often ranging from 5 to 10 years, but benefit from exceptionally long operational lifetimes that frequently exceed 50 years and can surpass 100 years in some cases. This longevity can partially offset high initial environmental and economic investments, particularly for large-scale installations, when impacts are normalized per unit of electricity generated over the full life cycle.

Figure 7 reports the ranges of GWP values associated with different hydropower technologies, expressed in grams of CO₂ equivalent per kilowatt-hour. Considerable variability is observed across technologies. Canal-based systems typically exhibit moderate GWP values, likely reflecting efficient integration with existing infrastructure and limited reservoir-related impacts. Reservoir-based hydropower plants display relatively contained GWP ranges, primarily driven by emissions associated with civil construction and, in some cases, methane release from flooded biomass, particularly in tropical regions. Run-of-river systems show a wide spectrum of GWP values, reflecting sensitivity to site-specific characteristics, plant design, and assumptions regarding infrastructure requirements. Pumped storage facilities exhibit the widest GWP range, with high values typically associated with scenarios in which electricity used for pumping originates from carbon-intensive sources, combined with emissions from extensive excavation and construction activities.

The influence of plant size on GWP is illustrated in

Table 8. GWP ranges for different sizes of the hydropower plants.

Plant Size	GWP—Range (gCO2eq/kWh /kWh)
SMALL (<25 MW)	1.2–530
LARGE (>50 MW)	2.06–32.63

. Both small and large hydropower plants can achieve low GWP values; however, large-scale installations generally present narrower and lower maximum GWP values. This trend reflects economies of scale, optimized design solutions, and high load factors sustained over long operational lifetimes. In contrast, small-scale hydropower systems exhibit greater variability, with some cases reporting elevated GWP values due to the disproportionate construction impacts, lower capacity factors, or less efficient infrastructure relative to electricity output. These findings emphasize the importance of site-specific assessments, particularly for small hydropower projects.

The distribution of GWP contributions across life cycle stages is summarized in Figure 8. On average, the core infrastructure phase dominates total emissions, accounting for nearly 69% of total GWP. This reflects the material- and energy-intensive nature of civil works, including dam construction, excavation, and concrete production. The core process phase, related to plant operation and maintenance, shows substantial variability depending on plant efficiency and lifespan. Upstream and downstream stages contribute marginally on average but may become more relevant in specific contexts, depending on system boundary definitions and modeling assumptions. These results highlight the importance of transparent system boundary selection and consistent methodological approaches in hydropower LCAs.

Beyond climate change impacts, hydropower plants are associated with a range of additional environmental and social considerations, summarized in

Table 9. Broader Environmental Considerations of Hydropower Systems.

Environmental Aspect	Key Concerns	Cause	Mitigation Strategies
Land Use & Habitat Loss	Destruction of forests, wetlands, and farmland; habitat fragmentation	Reservoir creation inundates large areas of land	Careful site selection, habitat restoration, land use planning
Aquatic Ecosystem Disruption	Decline in fish populations; loss of biodiversity	Altered water flow, temperature, and sediment levels	Fish ladders, fish bypass systems, environmental flow management
Greenhouse Gas Emissions	Methane and CO2 emissions from decomposing vegetation and flooded organic matter	Inundation of tropical forests, peatlands, and biomass-rich areas	Vegetation clearing before flooding, choosing non-peatland sites
Construction Emissions	Emissions from equipment and machinery	Use of fossil fuel-powered machinery during dam construction	Use of low-emission equipment, cleaner fuels, emissions management plans
Sediment Trapping	Altered sediment transport, reduced nutrient flow, and downstream erosion	Dams block natural sediment flow in rivers	Sediment bypass systems, managed sediment flushing, reservoir dredging
Water Quality Impacts	Changes in temperature and oxygen levels affecting aquatic life	Water stratification and altered thermal profiles in reservoirs	Selective water withdrawal systems, aeration technologies
Social and Cultural Displacement	Community relocation and cultural disruption	Construction of large dams in inhabited or culturally significant areas	Fair compensation, participatory planning, community relocation support, cultural heritage preservation

. Key concerns include land use change and habitat loss, disruption of aquatic ecosystems, greenhouse gas emissions from flooded biomass, sediment trapping, water quality alteration, and social displacement. While many of these impacts are highly site-dependent, mitigation strategies such as careful site selection, environmental flow management, sediment management techniques, and stakeholder engagement can substantially reduce adverse effects. Addressing these broader impacts is essential to ensure that hydropower development remains environmentally and socially sustainable.

3.4. Nuclear Power Plants

Nuclear energy currently contributes approximately 10% of global electricity generation, with shares approaching 20% in several advanced economies [12]. It has historically represented one of the largest sources of low-carbon electricity and continues to offer significant potential for decarbonizing power systems. Despite persistent challenges, including public acceptance issues in some regions, high upfront capital costs, and long construction timelines (typically around 12 years), nuclear power provides reliable and dispatchable electricity generation, making it a suitable complement to intermittent renewable sources.

The economics of nuclear power are influenced by multiple factors, including reactor design, construction costs, safety requirements, fuel cycle configuration, waste management, and decommissioning strategies. Reported electricity generation costs typically range between $0.02 and $0.06 per kilowatt-hour, positioning nuclear power among the most cost-competitive low-carbon sources alongside hydropower. Like fossil-based thermal power plants, nuclear facilities operate on a steam cycle; however, heat generation occurs through controlled nuclear fission reactions within the reactor core. Enriched uranium fuel undergoes fission, releasing thermal energy that is transferred to water to produce steam and drive electricity-generating turbines. Residual decay heat must be continuously removed using cooling systems, most commonly water-based, to ensure operational safety. Modern nuclear reactors are built with stringent safety protocols, including containment structures and emergency cooling systems, to prevent accidents and limit radioactive releases.

Several reactor technologies are currently in operation or under development. Pressurized Water Reactors (PWRs) and Boiling Water Reactors (BWRs) are the most widely deployed designs, both using light water as coolant and moderator, with PWRs employing separate primary and secondary circuits. Pressurized Heavy Water Reactors (HWRs) enhance fuel efficiency and allow greater flexibility in fuel cycles using heavy water. Advanced Gas-cooled Reactors (AGRs) utilize carbon dioxide as coolant and graphite as moderator, achieving relatively high thermal efficiencies. Light Water Graphite Reactors (LWGRs) and Fast Neutron Reactors (FNRs), including Fast Breeding Reactors (FBRs), represent alternative designs with distinct performance and safety characteristics. FBRs, in particular, are capable of breeding fissile material and exhibit high fuel utilization efficiency. Small Modular Reactors (SMRs) constitute an emerging class of nuclear technologies characterized by standardized, factory-fabricated components, potentially enabling shorter construction times, enhanced safety features, and reduced costs. International initiatives such as the Generation IV International Forum aim to improve reactor sustainability, safety, and efficiency, with concepts such as the Very High-Temperature Reactor (VHTR) considered among the most promising advanced designs.

Life cycle GWP estimates for nuclear power vary considerably across studies, reflecting differences in reactor technology, fuel cycle configuration, system boundaries, and regional electricity mixes [13]. A key determinant of environmental performance is the uranium enrichment process. Gaseous diffusion, an older enrichment technology, is highly energy-intensive, whereas centrifuge enrichment is substantially more energy-efficient and associated with lower emissions [14]. The carbon intensity of electricity used during enrichment further influences overall GWP; enrichment performed in regions with low-carbon electricity mixes, such as France, results in significantly lower-life-cycle emissions. Uranium ore grade also affects environmental performance, as lower-grade ores require greater energy input for extraction and processing. Several studies indicate that depletion of high-grade uranium resources could increase future life-cycle emissions associated with nuclear fuel production [15]. For example, emissions may rise by more than 100% when uranium concentration decreases from 0.15% to 0.01%, with reported values reaching up to 130 gCO_2eq/kWh in extreme cases [16].

Nuclear power plants typically involve long construction phases, often ranging from 5 to 15 years or more, but compensate for these initial impacts through extended operational lifetimes that commonly exceed 60 years and may be further prolonged through refurbishment and component replacement. Figure 9 summarizes the ranges of GWP values reported for different nuclear reactor technologies, expressed in grams of CO₂ equivalent per kilowatt-hour (gCO_2eq/kWh). Overall, the data indicate that nuclear technologies generally achieve low lifecycle GWP values compared to fossil-based electricity generation. FBRs exhibit the lowest reported maximum GWP values, while SMRs show relatively narrow and low ranges, likely reflecting standardized design and construction approaches. LWRs and GT-MHR, in contrast, present broader ranges and higher maximum values, suggesting greater sensitivity to design choices and fuel cycle assumptions. Fusion reactors, though still at the developmental stage, show moderate GWP values that likely reflect high material and construction requirements. Generation III+ reactors display relatively contained GWP values, consistent with design improvements aimed at enhanced efficiency and safety.

The influence of uranium enrichment technology on life-cycle emissions is further illustrated in

Table 10. GWP ranges for different types of enrichment of nuclear power plants.

Type of Enrichment	GWP—Range (gCO2eq/kWh)
Gaseous diffusion	19.41–84
Centrifuge	1.8–28

. Gaseous diffusion enrichment consistently exhibits substantially higher GWP ranges than centrifuge enrichment, due to its high electricity demand. The wide variability observed within gaseous diffusion systems highlights the importance of the electricity mix used during enrichment. Although uranium ore grade is recognized as an important factor affecting environmental performance, the available literature does not yet provide sufficient data to establish a robust quantitative relationship between ore grade and GWP across all reactor types.

The distribution of GWP contributions across life cycle stages is presented in Figure 10. The upstream stage, encompassing uranium mining, milling, conversion, enrichment, and fuel fabrication, dominates total life-cycle emissions, contributing more than 55% on average. Core infrastructure processes -including plant construction and decommissioning- represent the second largest contribution, reflecting the material- and energy-intensive nature of nuclear facilities. Operational and downstream processes generally contribute to smaller shares but exhibit variability depending on plant efficiency, waste management strategies, and system boundary assumptions. These results indicate that the environmental performance of nuclear power is primarily governed by fuel cycle characteristics and construction practices, while electricity generation itself remains largely carbon-free.

Beyond climate change impacts, nuclear power plants are associated with a range of additional environmental and social considerations, summarized in

Table 11. Broader Environmental Considerations of Nuclear Power Plants.

Environmental Aspect	Key Concerns	Cause	Mitigation Strategies
Air Pollutant Emissions	Emissions of NOx and SO2 during upstream processes	Energy consumption in uranium mining and enrichment; electricity mix used	Use of cleaner electricity sources for enrichment; improving mining efficiency [17]
Water Consumption	High water usage for cooling, impacting water availability and plant siting	Thermal cooling systems requiring direct withdrawals from rivers, lakes, or coastal areas	Deployment of dry or hybrid cooling systems; siting plants in areas with sustainable water resources [18]
Waste Generation	Production of long-lived radioactive waste	Operation of nuclear reactors and accumulation of spent nuclear fuel (SNF)	SNF reprocessing, recycling of uranium and plutonium; use of deep geological disposal [19]
Greenhouse Gas Emissions	Controversy over full life-cycle emissions of new projects	Construction emissions (embodied carbon), uncertainty over uranium ore quality	Adoption of transparent and standardized LCA methodologies; focusing on modular, lower-emission designs
Resource Use and Sustainability	Limited supply of high-grade uranium ore	Long-term fuel requirements and potential scarcity of economically recoverable uranium	Research into alternative fuel cycles (e.g., thorium); improving fuel efficiency and recycling
Delayed Carbon Payback	Long construction times increase embodied emissions	Complex regulatory, safety, and engineering requirements	Streamlining approval processes; using modular reactor technologies to shorten build time
Social and Political Acceptance	Public concerns over safety and waste	Historical nuclear accidents, long-term waste risks, and intergenerational impacts	Stronger safety governance; public education; transparent policy frameworks
Land Use and Siting	Location constraints near water sources	Cooling requirements and safety zones	Optimize siting with environmental and community engagement; expand use of coastal locations

. These include air pollutant emissions during upstream processes, high water consumption for cooling, long-lived radioactive waste generation, resource availability concerns related to uranium supply, delayed carbon payback due to long construction periods, and challenges related to public acceptance and siting. Addressing these aspects through improved fuel cycle efficiency, advanced reactor designs, transparent governance, and robust waste management strategies is essential to optimizing the sustainability of nuclear power systems.

3.5. Natural Gas Power Plants

Natural gas accounts for about one-quarter of global electricity production, largely due to its flexibility, widespread availability, and lower environmental impact compared to other fossil fuels. Its transportability via pipelines or as liquified natural gas (LNG) enables rapid response to fluctuations in electricity demand, making natural gas power plants particularly suitable for load-following and balancing variable renewable energy sources. These plants typically have relatively short construction times, often within a few years, and operational lifetimes of around 30–40 years. Electricity generation costs generally range from $0.03 to $0.07 per kWh, depending primarily on fuel prices, plant efficiency, and regional market conditions.

Two main technological configurations dominate natural gas-based electricity generation. Simple Cycle Gas Turbines (SCGTs) operate by compressing air, mixing it with natural gas, and combusting the mixture to directly drive a turbine. SCGTs are valued for their fast startup times and operational flexibility but exhibit relatively low thermal efficiencies, typically between 30% and 40%. Combined Cycle Gas Turbine (CCGT) plants integrate a gas turbine with a steam turbine, recovering waste heat from the exhaust gases to produce additional electricity through a secondary steam cycle. As a result, CCGT systems achieve significantly higher efficiencies, commonly ranging from 40% to 75%, and are generally more favorable from both environmental and economic perspectives.

Natural gas is often regarded as a transitional fuel in the decarbonization of electricity systems, as it can reduce CO₂ emissions by up to 73% compared to coal-fired power generation [20], while also emitting lower levels of SO₂, NO_x, and particulate matter. However, the climate benefits of natural gas are partially offset by methane (CH4) emissions occurring during fuel extraction, processing, transmission, and distribution. Methane’s high GWP makes these upstream emissions a critical determinant of the overall life-cycle environmental performance of natural gas power plants [21].

Figure 11 presents the ranges of life-cycle GWP values reported for different natural gas power plant technologies, expressed in grams of CO₂ equivalent per kilowatt-hour. SCGT plants exhibit the highest GWP ranges, primarily due to their lower conversion efficiency. CCGT plants demonstrate substantially lower GWP values, reflecting improved fuel utilization. The integration of carbon capture and storage (CCS) technologies further reduces life-cycle emissions, with CCGT plants equipped with CCS showing GWP values that are significantly lower than those of conventional gas-fired systems. These results highlight the strong influence of efficiency improvements and emission control technologies on the environmental performance of natural gas electricity generation.

CCS technologies can be implemented through pre-combustion capture, post-combustion capture, or oxy-fuel combustion, with their effectiveness depending on technological maturity, capture efficiency, energy penalties, and fuel characteristics. Reported reductions in greenhouse gas impacts range from approximately 47% to 85.5%, although these gains are accompanied by trade-offs, including increased energy demand, solvent consumption, and additional environmental impacts associated with CO₂ compression, transport, and long-term storage. Carbon capture and utilization (CCU) represents an alternative or complementary approach, particularly in regions where suitable geological storage is limited. Captured CO₂ can be employed in applications such as enhanced oil recovery, mineral carbonation for construction materials, or biological processes, including algae cultivation for biofuels or greenhouse applications [22]. According to Baena-Moreno et al. [23], CCU pathways can reduce life-cycle CO₂ emissions by approximately 29–58%, although actual mitigation potential strongly depends on the specific utilization route and system boundaries adopted.

The contribution of different life-cycle stages to total GWP is summarized in Figure 12. On average, the core process stage—namely fuel combustion during electricity generation—accounts for approximately 90% of total life-cycle GWP, with reported values ranging from 81% to 98%. Upstream processes, including fuel extraction, processing, and transport, contribute between 2% and 6%, while core infrastructure and downstream stages generally represent a negligible share in most studies. In some cases, however, end-of-life activities and decommissioning can contribute to a non-negligible fraction of total impacts. Overall, these findings indicate that mitigation strategies for natural gas power plants should prioritize improvements in thermal efficiency, reduction in methane leakage along the supply chain, and the deployment of CCS and CCU technologies.

Beyond climate change impacts, natural gas power plants are associated with additional environmental considerations, summarized in

Table 12. Broader Environmental Considerations of Natural Gas Power Plants.

Environmental Aspect	Key Concerns	Cause	Mitigation Strategies
Greenhouse Gas Emissions	CO2 and CH4 emissions contributing to climate change	CO2 from combustion; CH4 from extraction, transmission, and distribution	Improve plant efficiency; implement carbon capture and storage; detect and repair methane leaks
Air Pollution	Emissions of NOx and SO2 impacting air quality	Energy use during fuel extraction and enrichment; combustion	Use low-NOx burners; optimize combustion processes; switch to cleaner electricity sources for upstream operations
Water Use	Medium-level water consumption for cooling	Thermal cooling systems	Use dry or hybrid cooling; improve water recycling within plants
Land Use and Habitat Disruption	Infrastructure development can disturb land and ecosystems	Pipeline networks, compressor stations, and plant construction	Minimize land disturbance; route pipelines to avoid sensitive ecosystems
Waste Generation	Low levels of solid waste; higher emissions waste if inefficient	Incomplete combustion; older turbine technologies	Upgrade to combined cycle systems; enforce emissions regulations
Lifecycle Carbon Footprint	Significant variation in GWP depending on technology	Differences in efficiency and use of CCS	Deploy high-efficiency combined cycle plants; expand CCS and CCU applications

. These include air pollutant emissions, water consumption for cooling, land use impacts related to pipeline and infrastructure development, and variability in life-cycle carbon footprints depending on technological configuration and emission control measures. Addressing these issues requires a combination of technological improvements, regulatory frameworks targeting methane leakage, and integrated life-cycle-based decision-making to ensure that natural gas can effectively contribute to near- and medium-term decarbonization goals.

4. Discussion

The systematic review confirms that Life Cycle Assessment is a widely adopted and robust framework for evaluating the impacts of electricity generation technologies. Across solar photovoltaic, wind, hydropower, nuclear, and natural gas power plants, LCA enables the identification of key environmental hotspots along the full life cycle, supporting technology comparison and informing energy policy and system planning. At the same time, the results reveal substantial variability in reported impacts, particularly for GWP, but also for other relevant impact categories such as resource use, land occupation, and water consumption.

A central outcome of this review is that methodological choices exert a decisive influence on LCA results. Differences in system boundary definition, functional units, assumed plant lifetime and capacity factor, background electricity mixes, and levels of technological detail lead to considerable dispersion in reported environmental impacts, even within the same technology category. This variability is evident across all electricity generation options but is especially pronounced for technologies characterized by complex supply chains or large-scale infrastructure, such as nuclear power and hydropower. Consequently, direct comparisons based on individual LCA studies or average values should be interpreted with caution, as they may obscure underlying methodological inconsistencies rather than reflect intrinsic technological performance.

Despite this variability, some robust patterns emerge. The analyzed literature consistently indicates that renewable and nuclear electricity technologies exhibit relatively low life-cycle greenhouse gas emissions, with median or central values generally below 50 gCO_2eq/kWh. Wind and hydropower systems typically report GWP values in the range of approximately 5–30 gCO_2eq/kWh, while solar photovoltaic systems tend to fall between roughly 20 and 80 gCO_2eq/kWh, depending on technology type, manufacturing location, and assumed operational lifetime. Nuclear power plants commonly display life-cycle GWP values between 5 and 25 gCO_2eq/kWh, with construction and fuel cycle stages dominating total impacts. In contrast, natural gas power plants show substantially higher life-cycle emissions, particularly for combined-cycle configurations without carbon capture, with typical values between 400 and 600 gCO_2eq/kWh, largely driven by combustion-related emissions. These differences are illustrated in Figure 13.

Beyond climate change, other environmental impact categories highlight important trade-offs between technologies. Hydropower generally performs well in terms of GWP but can entail significant land use change and ecological disruption. Wind and solar technologies, while exhibiting low operational emissions, tend to show higher material- and resource-related impacts per unit of electricity due to their infrastructure-intensive nature. Importantly, the spread of reported impact values within a single technology often equals or exceeds the differences observed between technologies. This finding underscores that methodological assumptions and contextual factors play a role comparable to, or greater than, technology choice itself, reinforcing the need for careful interpretation of quantitative LCA results.

Another critical issue emerging from this review is the predominantly deterministic nature of most LCA studies. Electricity generation systems are complex socio-technical infrastructures subject to multiple sources of uncertainty, including variability in life cycle inventory data, future operational conditions, capacity factors, technological learning, and changes in background systems such as electricity mixes and material production pathways. However, the majority of reviewed studies report point estimates or broad ranges without systematically propagating uncertainty or clearly identifying its sources. This practice risks conveying a misleading sense of precision, particularly when LCA outcomes are used to support policy decisions or long-term infrastructure planning. Small numerical differences in reported GWP values are frequently interpreted as evidence of superior environmental performance, even though such differences may fall well within the uncertainty associated with modeling assumptions and data variability. The limited and non-standardized application of probabilistic LCA approaches further complicates the distinction between meaningful performance differences and methodological noise. As a result, deterministic rankings of electricity technologies based solely on LCA results should be treated with caution.

In addition to uncertainty, the review highlights structural limitations related to the temporal representation of impacts and the exclusion of technological risk. Conventional LCAs aggregate environmental impacts over the entire life cycle without accounting for the timing of emissions and benefits. This static treatment is particularly relevant for long-lived infrastructure, such as hydropower and nuclear power plants, where construction-related emissions occur upfront, while environmental benefits accrue over several decades. Moreover, technological risks associated with construction complexity, regulatory exposure, operational reliability, or extreme events are largely absent from conventional LCA frameworks, despite their relevance for large-scale energy systems.

Table 13. Main sources of uncertainty in LCA of power plants and their typical treatment in the literature.

Uncertainty Dimension	Description	Typical Treatment in LCA Studies	Implications for Results
Inventory data uncertainty	Variability and incompleteness in life cycle inventory data (materials, energy use, emissions)	Often implicit; data taken as fixed values from databases	Results appear precise but may mask large data-related variability
Technological assumptions	Assumptions on plant lifetime, capacity factor, efficiency, and degradation	Fixed or averaged values; limited sensitivity analysis	Small changes in assumptions can significantly alter impact results
System boundaries	Inclusion/exclusion of construction, grid connection, storage, or end-of-life processes	Heterogeneous and often poorly harmonized across studies	Major source of result dispersion and limited comparability
Background system variability	Electricity mix, material production routes, and regional context	Static background systems assumed	Ignores future changes that may alter life-cycle impacts
Temporal uncertainty	Timing of emissions and benefits over long project lifetimes	Not considered; impacts aggregated over life cycle	Long-lived infrastructures treated equivalently to short-term systems
Operational variability	Differences in actual vs. expected operation and maintenance	Typically neglected or averaged	Underestimation of real-world performance variability
Extreme events and failures	Accidents, unexpected shutdowns, or performance losses	Excluded from conventional LCA	Risk-related environmental consequences not reflected
Methodological uncertainty	Choice of impact assessment methods and characterization factors	Single method usually applied	Results depend on methodological conventions rather than robustness
Overall uncertainty propagation	Combined effect of multiple uncertainty sources	Rarely quantified (limited use of probabilistic LCA)	Deterministic results may be misinterpreted as robust rankings

summarizes the main sources of uncertainty affecting LCA studies of power plants and their typical treatment in the literature. The overview illustrates that uncertainty is often implicitly embedded rather than explicitly addressed, limiting the interpretability and comparability of results. Addressing these limitations would require broader adoption of sensitivity and uncertainty analyses, improved transparency in methodological assumptions, and increased use of dynamic and probabilistic LCA approaches. Overall, the findings of this review suggest that while LCA remains an indispensable tool for assessing the environmental performance of electricity generation technologies, its results should be interpreted as ranges of plausible outcomes rather than precise values. Greater methodological harmonization, explicit uncertainty treatment, and improved temporal and risk representation would enhance the robustness of LCA-based comparisons and strengthen their relevance for supporting the energy transition.

Following the synthesis presented in Table 13, it is important to emphasize that both the relative importance of uncertainty sources and the geographical scope of the selected studies vary substantially across power generation technologies. For solar photovoltaic systems, most LCAs are based on manufacturing processes located in East Asia, combined with deployment scenarios in Europe or North America. As a result, reported impacts are strongly influenced by assumptions regarding manufacturing electricity mixes, module transport distances, degradation rates, and system lifetime. Wind power plants are predominantly assessed in European contexts, where mature supply chains and relatively homogeneous regulatory frameworks contribute to more consistent system boundaries, with variability mainly driven by site-specific wind conditions and capacity factors. Hydropower and nuclear power plants exhibit the highest heterogeneity in both geographical scope and system definition. Hydropower LCAs span a wide range of climatic regions, including temperate and tropical areas, leading to substantial differences in land-use change, reservoir-related emissions, and infrastructure requirements. Nuclear power studies reflect diverse national fuel cycle configurations, particularly with respect to uranium mining locations, enrichment technologies, and background electricity mixes, which significantly affect upstream emissions. In contrast, natural gas power plant LCAs tend to adopt more standardized scopes focused on fuel extraction, combustion, and efficiency, yet remain highly sensitive to country-specific methane leakage rates and fuel supply chains. Across all technologies, differences in system boundary definition—particularly the inclusion or exclusion of grid infrastructure, storage, end-of-life stages, and indirect upstream processes—represent a dominant source of variability, often exceeding the influence of technology-specific design parameters. Given this combination of geographical diversity and methodological heterogeneity, life cycle results should be interpreted as indicative ranges rather than precise values. Comparative conclusions based on single-point estimates may therefore be misleading, underscoring the need for transparent reporting of country context, scope definition, and background system assumptions in future LCA studies.

Based on the evidence emerging from this review, several recommendations can be formulated to support more robust and decision-relevant LCAs of power generation technologies:

• Harmonized system boundaries should be explicitly defined and justified, particularly for infrastructure-intensive technologies (e.g., hydropower, nuclear, offshore wind), where construction, auxiliary systems, and grid connections can dominate life cycle impacts.
• Key technical assumptions, including plant lifetime, capacity factor, efficiency, and degradation rates, should be transparently reported and explored through sensitivity or scenario analyses, as small variations can substantially alter GWP outcomes.
• Geographical context and background systems (electricity mix, material production routes, fuel supply chains) must be clearly specified, as country-level differences consistently emerge as major drivers of variability across technologies.
• Upstream processes require careful modeling, especially for nuclear and natural gas systems, where fuel extraction, processing, and enrichment stages represent dominant contributors to life cycle emissions.
• Uncertainty treatment should be strengthened by moving beyond deterministic point estimates and systematically applying sensitivity or probabilistic approaches to improve result robustness and interpretability.

From a policy perspective, the findings of this review suggest that LCA-based evidence used to support energy planning should extend beyond static life-cycle indicators. Decision-making frameworks would benefit from explicitly accounting for the timing of emissions over long infrastructure lifetimes and from integrating technology-specific risk profiles, including construction delays, operational uncertainty, and exposure to extreme events, to enable more resilient and forward-looking energy transition strategies.

5. Conclusions

This systematic review synthesizes Life Cycle Assessment studies and Environmental Product Declarations concerning the environmental performance of primary electricity generation technologies, including solar photovoltaic, wind, hydropower, nuclear, and natural gas power plants. The consolidated evidence confirms substantial differences in life-cycle Global Warming Potential across technologies, with wind, hydropower, nuclear, and solar photovoltaic power plants typically exhibiting GWP values below 50 gCO_2eq/kWh, while natural gas-based power generation—particularly combined-cycle plants without carbon capture—shows significantly higher impacts, typically in the range of 400–600 gCO_2eq/kWh, dominated by operational emissions. Beyond climate change, the review highlights that other environmental dimensions, such as resource use, land occupation, water-related impacts, and ecological effects, play a critical role in shaping the overall environmental profile of power plants and may alter technology rankings depending on the impact category considered. Infrastructure-intensive technologies tend to exhibit higher upstream and construction-related impacts, whereas fossil-based systems are primarily influenced by fuel combustion and associated supply chains. A key finding of this review is the pronounced variability of reported LCA results within the same technology, often comparable to or exceeding differences across technologies. This variability is largely attributable to methodological choices, including system boundaries, assumptions on plant lifetime and capacity factor, background energy systems, and data sources. The widespread use of deterministic point estimates, combined with the limited and non-standardized treatment of uncertainty, risks overstating the robustness of comparative conclusions. In addition, conventional LCAs typically adopt a static representation of long-lived infrastructures and neglect technological risk, further constraining their ability to fully inform long-term energy infrastructure decisions. From a policy and planning perspective, these findings suggest that LCA results for power plants should be interpreted as indicative ranges rather than exact rankings of technologies. Transparent reporting of assumptions, sensitivity to key parameters, and explicit acknowledgment of uncertainty are essential when using LCA to support energy strategy and climate mitigation decisions. Future research should focus on enhancing LCA methodologies that explicitly incorporate uncertainty analysis, temporal dynamics, and risk considerations, while preserving transparency and comparability. Strengthening these aspects will enhance the reliability and policy relevance of LCA as a decision-support tool for the transition toward low-carbon electricity systems.