Lower industrial costs. Reduce emissions. Unlock resilient investment.

The World Bank is supporting the Government of Malawi in developing climate-resilient, energy-efficient cooling investments for public healthcare and education facilities under the ASCENT programme, which targets the electrification of 280 health facilities and 1,000 schools. Working with ACE Holdings Limited, we are providing technical, economic, financial and institutional advisory services to assess cooling requirements and prepare a prioritised investment programme for potential Green Climate Fund (GCF) financing. Our scope covers healthcare cold-chain assessments for vaccines, medicines and blood storage; thermal comfort evaluations in schools and healthcare facilities; and identification of efficient passive and active cooling technologies. We are also assessing solar photovoltaic systems, battery storage and reliable electricity supply options, alongside climate vulnerability, refrigerant compliance with the Montreal Protocol and Kigali Amendment, and greenhouse gas emissions. The assignment includes techno-economic modelling, lifecycle investment and maintenance costing, financing strategies, policy and regulatory assessments, stakeholder consultations and institutional capacity-building recommendations. The six-month mission, scheduled from November 2026 to April 2027, will deliver sector assessments, prioritised investment scenarios and technical documentation to support GCF financing preparation and implementation planning.

EDF Côte d’Ivoire commissioned this study to determine whether excess heat from a Biovea-type 23 MW biomass plant could be valorised through an industrial heat network in PK24, addressing the need for a viable solution for industrial heat, cooling and trigeneration. We supported the client by modelling low-pressure steam extraction, assessing network design and trigeneration uses, mapping potential subscribers and testing the economics under different demand assumptions. The study identified 9 relevant industrial users, highlighted Brassivoire as a major potential anchor off taker, and found that the concept could deliver 38.1 MWth through a 10 km DN350 network while increasing overall plant efficiency from 21% to 60%. It also showed an attractive simulated payback of 2.8 years in the base case and 5.1 years under a 50% demand reduction scenario. The project supports cleaner energy use, industrial infrastructure and emissions reduction.

Biovea Energie needed to assess the climate impact of its 46 MW Ayebo biomass power plant, prepare the basis for a future PDD, and position the project for regulatory alignment, operational improvement, sustainable procurement, and access to carbon markets. The mandate focused on designing the GHG project under ACM0018 v06, ISO 14064-2, and the GHG Protocol, including the assessment of the baseline scenario, additionality, relevant sources and sinks, monitoring arrangements, and safeguard requirements. The study confirms a plant made up of two 23 MW units, supplied by around 520,000 tonnes of agricultural residues per year sourced within a 60 km radius, with expected generation of about 348 GWh per year, equivalent to electricity access for 1.7 million people. It also highlights the productive use of residues that would otherwise decay or be openly burned, a supply chain involving around 12,000 palm farmers, and the creation of about 500 direct and 1,000 indirect jobs. The project is presented as a first-of-its-kind initiative in Côte d’Ivoire and is supported by a structured monitoring framework covering electricity, biomass, moisture, transport, and fossil fuel use, with dedicated governance and data archiving requirements. The value created lies in preparing the project for carbon certification and strengthening its sustainability positioning.

AutoX needed to quantify the cradle-to-grave carbon footprint of its lead-acid battery portfolio, identify the main emissions hotspots, and prepare for tighter battery disclosure and carbon requirements in its export markets, especially in Europe. We were mandated to deliver a product carbon footprint assessment aligned with ISO 14067:2018, using an average battery representative of more than 350 models and covering raw materials, manufacturing, transport, use, and end-of-life across South Africa, Southern Africa, the UK, and Ireland. Our approach combined primary operational and supplier data with recognised secondary databases and modelled three charging scenarios to reflect different real-world use patterns. The study found that raw materials and electricity were the key impact drivers: raw materials accounted for 26.26 kgCO2eq per battery, with lead contributing 77% of that phase, while manufacturing accounted for 18.04 kgCO2eq and was almost entirely driven by electricity use. Depending on the charging scenario and country electricity mix, the total carbon footprint ranged from 56.4 to 147.4 kgCO2eq per battery, or 0.195 to 0.510 kgCO2eq per useful kWh. The project gave AutoX a compliance-ready baseline and a clear decarbonisation roadmap, highlighting recycled lead and lower-carbon electricity as the main levers. It also showed that replacing 20% of grid electricity with photovoltaic supply could reduce manufacturing emissions by around 19%.

For the Majuba Solar PV Project, Mpamot needed an order-of-magnitude but decision-useful view of life-cycle emissions and carbon-credit potential for a 31.67 MWp solar plant planned near Volksrust in Mpumalanga. Our mandate was to quantify cradle-to-grave emissions, identify the main carbon hotspots, test the effect of longer project life and recycling assumptions, and estimate avoided emissions under different South African grid scenarios. Using an ISO 14040/14044 and GHG Protocol-aligned methodology, we modelled raw material production, transport, construction, component replacement during use, and end-of-life treatment. The results showed total life-cycle emissions of 83,807 tCO₂eq and a carbon intensity of about 56 gCO₂eq/kWh over 25 years. The raw material phase accounted for 64% of total emissions, led by PV module manufacturing and mounting structure steel, while the use phase contributed 31%, driven mainly by replacement of modules, inverters and transformers. Extending the project life to 40 years increased total emissions to 98,013 tCO₂eq but reduced carbon intensity to 42.2 gCO₂eq/kWh, demonstrating the environmental value of longer operation. The plant’s carbon payback was estimated at around 1.3 to 2.6 years, and avoided emissions ranged from 810,241 to 1,561,102 tCO₂ over the 27-year project timeline. Indicative carbon-credit revenues ranged from USD 2.59 million to USD 12.93 million. The study gives Mpamot a clear framework for procurement and optimisation decisions, particularly around lower-carbon supply chains, component lifetime extension and circular end-of-life strategies, while confirming the project’s strong contribution to South Africa’s low-carbon power transition.

Mpamot required a refined carbon assessment of the Kleinzee project to clarify methodological assumptions while preserving a decision-useful view of the project’s climate performance and carbon-credit potential. We were tasked with updating the life cycle assessment of the 397.6 MW Kleinzee Wind Farm and 193 MWh BESS in South Africa, clarifying cut-off assumptions, exclusions and end-of-life treatment, and confirming the project’s avoided-emissions and value-creation potential. Using ISO 14040/14044 and the GHG Protocol framework, and a cradle-to-grave boundary based on 1 kWh delivered to the grid over 25 years, we modelled the project from raw materials through construction, use and end-of-life, relying on feasibility-stage client data, Ecoinvent v3.11, ICE v4 and Orki LCA. The assessment confirms a total footprint of 551,608 tCO₂eq and a carbon intensity of 14.39 gCO₂eq/kWh. Raw materials account for 79% of emissions, the use phase 15%, and construction and end-of-life about 3% each, with the BESS replacement cycle remaining a key driver. Sensitivity analysis also shows that avoided-burden recycling assumptions could lower intensity from 14.39 to 13.26 gCO₂/kWh, while a 14-year BESS lifetime could reduce total emissions by about 13% and 70% recycled steel by about 6%. The project therefore offers Mpamot both a robust carbon baseline and a clearer decarbonisation roadmap, while reinforcing its contribution to South Africa’s clean-energy transition.

Mpamot needed a robust, feasibility-stage understanding of the carbon footprint and carbon-credit potential of the Aberdeen Hybrid Project, a large renewable energy development combining 196 MW of wind, 80 MWp of solar PV and a 280 MWh battery energy storage system in the Eastern Cape. Our mandate was to quantify full life-cycle greenhouse gas emissions, identify the main carbon hotspots, test key assumptions, and estimate avoided emissions and potential market value from carbon credits. We carried out a cradle-to-grave life cycle assessment in line with ISO 14040/14044 and the GHG Protocol Product Standard, using project-specific design assumptions together with recognised databases and modelling tools. The analysis covered raw materials, transport, construction, operation and replacements, and end-of-life treatment, with results normalised per kWh delivered to the grid. The study found total life-cycle emissions of 604,489 tCO₂eq and a carbon intensity of 24.3 gCO₂eq/kWh, with raw materials dominating at 64% of total emissions, followed by the use phase at 30%, largely due to battery and module replacements. Despite this, the project shows strong climate performance, with a carbon payback of roughly 0.6 to 1.2 years and avoided emissions estimated at 14.1 to 26.8 million tCO₂ over the project life. Indicative carbon-credit revenue was estimated at USD 43.47 million to USD 217.44 million. The work gives Mpamot a clear basis for design optimisation, supplier engagement, low-carbon material sourcing and investment positioning, while confirming the strategic value of hybrid renewable systems for South Africa’s decarbonisation pathway.

For the Arnot Solar PV Project in Mpumalanga, Mpamot required a clear estimate of the plant’s life-cycle carbon footprint and its potential to generate avoided emissions and carbon-credit value. Our mandate was to assess the environmental profile of the 12.82 MWp solar PV plant at feasibility stage, identify the main emission drivers, and translate the results into strategic insights for design, sourcing and long-term value creation. We applied a cradle-to-grave LCA methodology aligned with ISO 14040/14044 and the GHG Protocol Product Standard, covering materials, transport, construction, component replacements and end-of-life treatment over a 25-year operating life, with a sensitivity test extending operations to 40 years. The assessment showed total life-cycle emissions of 32,970 tCO₂eq and a carbon intensity of 51.66 gCO₂eq/kWh, which sits within the typical international range for utility-scale PV. The raw material phase was the largest contributor at 65%, driven mainly by PV module manufacturing and galvanised steel structures, while the use phase accounted for 30% because of module and inverter replacements. Extending the plant life to 40 years increased total emissions moderately but improved carbon intensity by about 25%, down to 38.7 gCO₂eq/kWh. The project’s carbon payback was estimated at about 1.3 to 2.6 years, and avoided emissions were estimated at 348,594 to 669,049 tCO₂ over 27 years, corresponding to indicative carbon-credit revenues of USD 1.11 million to USD 5.53 million. This work gives Mpamot a practical basis for improving supplier selection, extending component life and strengthening the climate value proposition of the project.

LuxDev commissioned this study to assess whether two community-based carbon credit projects led by AGED and Reach Italia in Burkina Faso could deliver a robust, viable and replicable financing model for rural development under fragile institutional and market conditions. Our mandate was to analyse the full economic and organisational model of these Plan Vivo-certified nature-based projects, from project design and certification to carbon credit sales, revenue sharing and post-credit monitoring. We combined document review, benchmarking and five semi-structured interviews with key public, private and project stakeholders, then analysed findings through governance, capacity, economics, community anchoring and market-access lenses. The study showed that while both projects are credible high-integrity community initiatives with strong local co-benefits, their model remains structurally fragile: feasibility, PDD and MRV phases are costly and complex; governance is fragmented; local ownership is limited by dependence on external consultants; and revenue stability is exposed to voluntary carbon market volatility. Average development costs were estimated at USD 13.97/tCO2e, significantly above larger AFOLU projects, although historical sales of 8,384 tCO2e at EUR 7–17/tCO2e confirm an ability to capture value through strong community positioning. The study translated these findings into 17 operational recommendations, including clearer project leadership, stronger budgeting tools, more transparent contracts, digitalised MRV, buyer diversification and long-term price-stabilising agreements. The value created lies in giving LuxDev and its partners a practical roadmap to move from externally supported pilot projects toward more autonomous, traceable and scalable carbon finance models.

Mpamot asked us to evaluate the environmental performance and carbon-credit potential of the Duvha Solar PV Project, a 22.83 MWp plant planned near eMalahleni in Mpumalanga. The challenge was to produce a credible, feasibility-stage carbon assessment that could support design decisions, future procurement choices and the project’s wider decarbonisation case. Our mandate covered full life-cycle greenhouse gas modelling, hotspot analysis, lifetime sensitivity testing and estimation of avoided emissions and possible carbon-credit revenues. We carried out a cradle-to-grave LCA in accordance with ISO 14040/14044 and the GHG Protocol, using project-specific technical assumptions combined with recognised secondary datasets. The study found total life-cycle emissions of 60,259 tCO₂eq and a carbon intensity of 53.03 gCO₂eq/kWh over 25 years. The raw material phase contributed 64.5% of total emissions, with PV modules and steel mounting structures clearly dominating, while the use phase contributed 30.5%, mostly due to replacements. A 40-year sensitivity scenario showed that extending operating life would raise total emissions by about 17% but improve carbon intensity by roughly 25%, to 39.9 gCO₂eq/kWh. The project also demonstrated strong climate value, with a carbon payback of approximately 1.3 to 2.5 years and avoided emissions estimated at 619,103 to 1,189,662 tCO₂ depending on grid decarbonisation assumptions. Indicative carbon-credit revenues ranged from USD 1.98 million to USD 9.83 million. The assessment gives Mpamot a solid evidence base to prioritise low-carbon module sourcing, durability improvements, and end-of-life recovery strategies while reinforcing the strategic contribution of the project to South Africa’s energy transition.

ACIPAC needed to reduce electricity costs, improve operational control and strengthen the energy performance of its continuously operated industrial site. We supported the company through a full-site energy audit covering administration, plastic sachet and film production, tissue paper production and maintenance areas, with the objective of identifying major energy uses, quantifying savings opportunities and defining a practical roadmap for implementation. Our approach combined data analysis, site investigations, equipment-level energy mapping, power-quality checks and techno-economic assessment in line with ISO 50002 and NF 16247-3 principles. The audit established a 2024 baseline electricity consumption of 5,823,000 kWh for an annual electricity cost of FCFA 554.6 million, and showed that the main energy drivers were motor systems, heating processes and compressed air. We then prioritised a set of high-impact measures including compressed-air leak reduction and pressure optimisation, improved HVAC settings, insulation of extruder heating zones, replacement of selected motors with premium-efficiency models, deployment of a 500 kWp self-consumption solar installation and implementation of a global metering system. Altogether, the recommended actions could generate annual savings of 2,051,760 kWh, equivalent to a 35% reduction in electricity consumption, deliver FCFA 194.97 million in yearly cost savings and avoid around 1,231 tCO2e per year. The project provided ACIPAC with a clear investment roadmap to improve industrial competitiveness while accelerating decarbonisation.

Mpamot commissioned us to assess the life-cycle carbon footprint and carbon-credit potential of the Tutuka Solar PV Project, a 28.93 MWp utility-scale installation near Standerton in Mpumalanga. The client’s challenge was to understand, at feasibility stage, where the main emissions would occur across the asset life cycle and how the project could be positioned for stronger environmental performance and future carbon value. Our mandate covered full GHG quantification, hotspot identification, sensitivity testing on operating life and recycling assumptions, and estimation of avoided emissions and indicative credit revenues. We carried out a cradle-to-grave LCA aligned with ISO 14040/14044 and the GHG Protocol, combining project-specific technical inputs with recognised LCA databases. The results showed total life-cycle emissions of 77,299 tCO₂eq and a carbon intensity of 56.3 gCO₂eq/kWh over 25 years. The raw material phase represented 64% of total emissions, driven largely by PV module production and steel mounting systems, while the use phase contributed 31% because of planned component replacement. A 40-year scenario increased total emissions to 90,496 tCO₂eq but improved carbon intensity by about 25%, reducing it to 42.4 gCO₂eq/kWh. The plant’s carbon payback was estimated at 1.5 to 2.8 years, and avoided emissions were projected at 743,914 to 1,433,606 tCO₂ depending on the future grid-emission pathway, with indicative carbon-credit revenues of USD 2.38 million to USD 11.87 million. The study provides Mpamot with a strong technical basis to optimise sourcing, extend asset life and strengthen circularity, while confirming the project’s meaningful contribution to South Africa’s clean-energy transition.

UNIDO commissioned this technical paper to understand how climate change is reshaping risk across South Africa’s agro-processing sector, where water dependence, energy intensity, and exposure to region-specific agricultural supply chains make industrial performance increasingly vulnerable to drought, heat stress, flooding, and infrastructure disruption. Our mandate was to identify the most climate-sensitive agro-processing subsectors, assess the resilience of their water and energy systems, and translate the findings into a practical adaptation agenda. To do this, we combined a review of more than 120 sources with climate hazard analysis using Climate Viz, scenario-based projections under SSP2-4.5 and SSP5-8.5, OCARA-based value chain risk screening, energy case analysis, and stakeholder interviews focused on industrial water resilience. The study showed that fruit and vegetable processing, beverages, and dairy should be prioritised for adaptation action because of their economic weight and high dependence on water and thermal energy, while poultry and sugar face severe localised risks in specific regions. It also highlighted the scale of systemic pressure: the sector consumes around 130 million m³ of water annually, South Africa is already using nearly all of its available water supply, and national water deficits could reach 2.7 to 3.8 billion m³ per year by 2030. The paper converted this diagnosis into an actionable roadmap centred on water efficiency, reuse and recycling, diversified supply systems, thermal and electrical efficiency, and climate risk integration into industrial planning. The result was a decision-ready resilience framework to help UNIDO and its partners prioritise investment, strengthen food-system security, and support more climate-resilient industrial development.

Ferney needed a credible net zero pathway for both its current operations and a future mixed-use territorial development in Mauritius, where tourism-related travel, imported construction materials, private mobility patterns and grid dependence all shape the carbon profile. Our mandate was to establish the present baseline, identify the main future emissions drivers, and translate the findings into a practical decarbonisation roadmap supported by monitoring tools. We combined a greenhouse gas inventory for existing operations, a life cycle assessment of the future development, an embedded carbon analysis across the main building typologies, an operational emissions review by phase and asset class, and energy scenario comparisons, while also supporting onboarding to the ORKI platform for long-term tracking. The work showed that the project’s carbon exposure is concentrated around a limited number of structural levers: procurement and specification of construction materials, building and infrastructure design choices, energy strategy, residential mobility and lifestyle assumptions, tourism positioning, and circular synergies between activities. A key strategic insight was that sourcing lower-carbon materials can be more decisive than design optimisation alone in the Mauritian context. The roadmap therefore prioritised low-carbon and EPD-backed materials, decentralised energy, residential right-sizing, ecosystem symbiosis, low-carbon mobility, regional tourism positioning, project-level LCA targets, and a carbon offset strategy aligned with Ferney’s broader vision. The result was a decision-ready net zero framework to guide design development, procurement standards, energy masterplanning, and implementation governance across the different phases of the project.

Biovea Energie needed to assess the carbon-credit potential of its 46 MW biomass project in Aboisso, understand carbon market trends, confirm project eligibility, and identify the most suitable certification pathway in a market facing tighter integrity requirements for renewable energy projects. We supported the client by reviewing carbon market dynamics, analysing the Africa and Côte d’Ivoire context, and comparing Verra, Gold Standard and S10X through a multi-criteria assessment based on reputation, cost-effectiveness, support and risk exposure. The analysis confirmed that the project uses biomass residues to produce grid-connected electricity, could supply around 1.7 million people, and is expected to reduce more than 340,000 tCO2e per year. It provided Biovea with an evidence-based certification strategy and positioned the project as a strong climate-finance opportunity.

Ferney needed a robust basis for selecting the most appropriate energy model for its future Smart City development, balancing long-term electricity demand, carbon performance, technical feasibility and urban integration. We supported Ferney in modelling the project’s energy needs across its 20-year build-out and in comparing renewable electricity strategies aligned with its climate and ESG ambitions. Our approach combined benchmark-based energy demand modelling by facility type and development phase, optimisation through thermal substitutions, and a multi-criteria assessment of two supply options: a centralised 10 MWp grid-tied PV plant and a decentralised building-by-building PV hybrid system with storage. The study covered residential typologies, eco-resort, healthcare, industrial, mixed-use, offices, leisure and support infrastructure. At full build-out, baseline electricity demand was estimated at 32,687 MWh/year, reduced to 26,196 MWh/year through demand optimisation and thermal substitution, while a high-demand sensitivity scenario exceeded 42,000 MWh/year. The centralised PV option significantly reduced grid dependence and emissions, but remained constrained by the absence of storage, land use requirements and limited adaptability to evolving demand. The decentralised hybrid option achieved an average self-generation rate of 92%, reduced grid reliance to below 10%, and outperformed the centralised model across most ESG-weighted criteria. This work gave Ferney a decision-ready energy roadmap to prioritise efficiency first, structure future solar investments, and align infrastructure choices with long-term carbon neutrality, resilience and sustainable urban development.

AfricInvest needed an independent view of how climate change could affect the resilience, margins and investability of a Moroccan fit-out and professional spaces company operating through short-cycle, procurement-driven projects. We supported the client in assessing climate-related operational, supply-chain and contractual exposure over a 5–7 year horizon, and in identifying practical mitigation measures to protect value creation. Our approach combined a TCFD-aligned governance review, a greenhouse gas screening, physical and transition risk analysis, climate scenario modelling, and a financial sensitivity assessment linked to actual operating performance. We also evaluated adaptive capacity across assets, workforce, logistics and procurement, then translated the findings into a targeted resilience programme. The assessment showed that climate exposure is primarily operational and contractual rather than structural, with heat stress identified as the most systemic physical risk, alongside episodic logistics disruption and imported material volatility. This work provided AfricInvest with a decision-ready climate due diligence, confirming that the business remains investable while highlighting clear priorities: strengthen contractual protections, formalise climate governance, improve supplier resilience, and reduce exposure to heat and procurement volatility.

The client needed to operationalise Côte d’Ivoire’s mandatory energy audit framework following Arrêté interministériel N°156 by creating practical tools to harmonise audit quality, improve compliance and strengthen public oversight. We supported GIZ, in coordination with the Direction Générale de l’Énergie (DGE), to structure and deliver a full toolkit for the implementation and monitoring of mandatory energy audits. Our approach combined regulatory review, stakeholder consultation, international benchmarking and tool design aligned with ISO 50002 and EN 16247, with adaptation to the Ivorian institutional and sector context. The assignment was organised in four phases: project scoping, diagnostic and consultations, tool development, and final validation and training. The output package included two ToR templates for industry and buildings, two sector good-practice guides, one tender dossier model, two audit report templates, two data-collection questionnaires, one or two thematic technical specifications, and an interactive Excel quality checklist for DGE. The mission also included participatory validation sessions and practical training for public authorities, approved auditors and companies subject to mandatory audits. The value created was the establishment of a standardised and scalable framework to improve audit consistency, reinforce governance, support local capacity building and prepare future digitalisation of quality control.

AfricInvest needed a clear view of how climate change could affect the resilience, margins and long-term investability of a Moroccan construction platform operating through site-based, multi-project execution. We supported the client in assessing climate-related operational, contractual and supply-chain exposure over a medium-term investment horizon, and in identifying practical actions to strengthen resilience. Our approach combined a TCFD-aligned governance review, a greenhouse gas screening, forward-looking physical and transition risk analysis, OCARA-based operational vulnerability mapping, scenario-based financial sensitivity testing, and a structured mitigation programme. The assessment showed that climate exposure is driven primarily by project execution rather than fixed assets, with heat stress emerging as the most systemic physical risk, followed by recurrent weather-related disruption and geographically concentrated flooding. On the transition side, the main vulnerabilities relate to construction material procurement, carbon-related cost pressures, and the integration of ESG and disclosure requirements into tendering and project costing. The review also confirmed that climate governance remains at an early stage, while resilience currently relies more on diversification and operational flexibility than on formalised protocols or engineered adaptation. This work provided AfricInvest with a decision-ready climate due diligence, highlighting clear priorities around contract structuring, supplier monitoring, climate-informed planning, heat adaptation, and stronger ESG governance, while confirming that the business model remains resilient if these measures are progressively embedded.

As part of the expansion of its Youpougon plastics manufacturing plant, SIMPA wanted to anticipate a sharp rise in energy demand while reducing operating costs and environmental impact. We carried out a pre-feasibility study to assess a combined energy solution integrating self-consumption solar PV, a natural gas cogeneration unit and waste heat recovery for chilled water production. After extension, the site is expected to increase installed electrical capacity from 1 MW to 2.4 MW and reach annual consumption of around 20 GWh, with continuous 24/7 operation and a constant cooling demand of about 1 MWf. The proposed configuration combines a 1 MWp solar plant, a 2 MWe MWM gas generator and a 1 MWf lithium-bromide absorption chiller supplied by recovered engine and exhaust heat. The study confirmed that the generator’s available waste heat, estimated at 2,062 kWth, is sufficient to supply the absorption system under nominal operation, provided that a 25 m³ hot water buffer tank is installed to manage peak solar periods. A BROAD BDH-100 unit was identified as the most relevant technology choice. Compared with a conventional compression chiller, the absorption solution could reduce cooling-related electricity use by up to 80%. Financially, the combined PV and cogeneration scenario was estimated to reduce the site’s total energy cost by around 30%, with monthly savings of approximately CFA 41.1 million versus the baseline. The additional CAPEX for the heat recovery and absorption cooling package was estimated at about CFA 484 million. The result is a practical roadmap for resilient, lower-carbon industrial energy supply aligned with site growth.

PALMCI launched this assignment to strengthen the energy performance, operating resilience and cost competitiveness of its IBOKE palm oil mill and kernel press in southwestern Côte d’Ivoire. The audit covered the full industrial perimeter, including process lines, utilities and support buildings, with particular attention to the interaction between biomass cogeneration, grid electricity and diesel back-up generation. The study showed that the site consumed about 5.91 GWh of electricity in 2025, supplied mainly by the biomass turboalternator (63%), with the balance coming from the CIE grid (35%) and diesel generators (2%). The analysis also confirmed that motive power and pumping dominate the electrical load profile, representing more than 91% of installed capacity. Major opportunities for improvement were identified in boiler and steam-system efficiency, biomass storage, motor maintenance, power factor correction, feedwater pumping, deaerator operation and diesel generator optimisation. The resulting action plan estimated annual savings of 123 MWh of purchased electricity, 4,711 litres of diesel, 8,294 tonnes of biomass and significant reductions in water-treatment chemicals, for a total financial benefit of approximately FCFA 206 million per year against an investment of about FCFA 254 million. Priority actions included installing a biomass storage hangar, correcting power factor, fitting variable speed drives on feedwater pumps, repairing steam leaks and improving boiler-side thermal management. Beyond immediate savings, the audit highlighted a strong strategic upside: with better biomass valorisation and expanded use of the turboalternator, the site could sharply reduce its dependence on grid electricity and reinforce its energy autonomy.

We designed a solar-powered pumping solution for Nazareth House Johannesburg, with the objective of improving the reliability of water supply across the facility while reducing dependence on conventional backup power. The proposed system was sized following feasibility work and site visits to match the operating needs of two 3 kW submersible borehole pumps and one 5 kW pressure pump. The technical concept combines a 10 kWp solar PV array with a 12 kW three-phase inverter, three 5.1 kWh lithium phosphate batteries, and a 7.5 kW variable speed drive, creating an integrated pumping system capable of supporting both daytime and nighttime operation. The design philosophy prioritises solar production as the main source of power during the day, with surplus generation stored in batteries for later use. When solar energy is unavailable, the system is designed to switch to battery supply, then fall back to the grid at a defined battery state of charge, and finally to the onsite diesel generator under exceptional conditions. This hierarchy ensures continuity of pumping services while maximising the use of renewable electricity and maintaining resilience in the event of low solar availability or grid disruption. Overall, the proposal provides Nazareth House with a practical and robust pathway to secure essential water services through a cleaner, smarter and more resilient energy system.

SIBM PK 24 operates a 24/7 industrial site in Abidjan where rising electricity tariffs, grid instability and recurring voltage fluctuations were increasing operating costs and forcing greater reliance on backup generation. Our mandate was to assess the site’s energy performance, identify the main sources of consumption and build a practical, investment-ready action plan to reduce costs and improve operational resilience. We conducted a full energy audit aligned with ISO 50002 and NF EN 16247-3, combining data review, on-site measurements, equipment analysis and techno-economic evaluation of priority actions. The assessment showed that the main electricity uses were motive power, lighting, air conditioning and compressed air, and established a 2024 site baseline to support future monitoring and verification. We then prioritised high-impact measures including a site-wide metering system, replacement of halogen lighting with LED fixtures, twilight-based lighting controls and the progressive adoption of high-efficiency IE4 motors. Together, these measures represent an annual savings potential of 368,090 kWh, equivalent to a 43% reduction in electricity consumption, FCFA 38.4 million in yearly savings and around 221 tCO₂e avoided. Beyond the quantified savings, the project gives SIBM PK 24 a clear roadmap to strengthen energy management, reduce exposure to tariff volatility and improve the long-term efficiency of a critical industrial asset.

The Ridge School operates a large private educational campus in Johannesburg with a mixed energy profile combining grid electricity, solar PV with battery storage and diesel backup. We were mandated to analyse the school’s energy flows, review its tariff structure, benchmark performance, assess 12 months of historical utility data and identify practical energy conservation measures. Our approach combined utility bill analysis, on-site measurements, demand profiling, load inventory and targeted monitoring of significant energy users. The audit showed that electrical water heating is the site’s dominant energy use, with geysers representing roughly half of consumption, while lighting and plug loads make up the balance. We also found that the school’s overall energy intensity, at 21.6 kWh/m²/year, is well below the applicable SANS benchmark of 65 kWh/m²/year for educational buildings, indicating relatively satisfactory baseline performance. From this, we developed a prioritised optimisation roadmap focused on retrofitting remaining fluorescent lighting with LEDs, moving from the current Industrial Low Voltage tariff to a Time of Use tariff, deploying a Building Management System, improving solar PV battery cycling and strengthening the school’s energy governance. The most transformative opportunity identified was a centralised solar thermal hot water plant backed by a heat pump to replace dispersed electric geysers. The tariff migration alone is estimated to save about ZAR 78,417 annually, while the proposed solar thermal solution has an estimated installed cost of ZAR 2.553 million and a payback of just under four years. Overall, the project provides the school with a clear path to reduce operating costs, improve resilience and lower its carbon footprint.

Roman’s Pizza operates its head office and main warehouse in Centurion, Gauteng, where a fully electric site, refrigeration-heavy operations and strong time-of-use tariff exposure were driving high energy costs. We were mandated to review historical consumption and billing data, carry out on-site measurements and identify practical actions to reduce overall energy spend. Our approach combined invoice analysis, seasonal tariff review, on-site monitoring of the warehouse and refrigeration systems, and an opportunity assessment focused on both operational and technical measures. The audit showed that refrigeration is the dominant load, accounting for about 73% of daily electricity use, while warehouse lighting and office air conditioning plus lighting represent the balance. It also confirmed that winter tariffs have a disproportionate cost impact, with only 17% of electricity consumed during peak periods accounting for 45% of winter electricity cost. Based on this, we prioritised four actions: optimising the PV hybrid system through a smart controller, replacing legacy warehouse lighting with LED/CFL solutions, implementing preventive refrigeration maintenance, and installing timers for air conditioning, geysers and charging loads to avoid peak tariff periods. Together, these measures are expected to deliver annual savings of about R675,403 for an estimated CAPEX of R570,000, resulting in a simple payback of less than one year. Beyond the financial return, the project gives Roman’s a practical roadmap to reduce electricity and diesel dependence, improve operational resilience and embed stronger energy management practices across the site.

Nelson Mandela Bay Municipality | South Africa | Wastewater Treatment Plant EnPC Project Concept | 2025For Nelson Mandela Bay Municipality, we developed the concept and feasibility basis for an Energy Performance Contract at the Fish Water Flats Waste Water Treatment Plant, the city’s largest and most energy-intensive wastewater facility. Based on audits, billing analysis and site due diligence conducted up to January 2025, the project defined a first-phase package combining LED lighting retrofits, fine bubble aeration on lanes 1 and 2, and a 450 kWp ground-mounted solar PV system. The plant’s baseline electricity consumption was estimated at 21,397,953 kWh/year. The proposed package targets roughly 3.2 GWh/year of total energy impact, including 630,000 kWh/year of embedded renewable generation, with annual avoided emissions of about 2,980 tCO₂e. Total CAPEX is estimated at R49.84 million, including R44.0 million for aeration, R5.57 million for PV and R272,577 for lighting, for estimated annual savings of R6.04 million and an overall dynamic payback of 7.2 years. The concept also set out the institutional, procurement and M&V framework required for a shared-savings EnPC. A key conclusion is that fine bubble aeration is technically strong but not financially viable as a stand-alone EnPC measure; bundling with solar PV materially improves bankability. Critical enabling conditions before implementation include power factor correction, restoration of the SCADA system, and process stabilisation upstream of the aeration basins. The project is expected to support municipal decarbonisation, operational resilience and local job creation, with an estimated 60 direct and 30 indirect jobs.

Roman’s Waterkloof operates a grid-supplied restaurant in Tshwane with a 100 kVA diesel generator used during load shedding, creating a cost structure heavily exposed to municipal tariffs and backup fuel use. We were mandated to assess the site’s electricity profile, power quality, load composition and technical options to reduce operating costs while securing at least four hours of backup capacity. Our analysis combined a consumption survey, equipment review, tariff analysis and concept design for a right-sized hybrid solar solution. The study found that the restaurant consumes about 468 kWh/day on weekdays and 583 kWh/day on weekends, with ovens accounting for roughly 40% of the theoretical maximum load, followed by refrigeration and air conditioning at 30%. We also found that winter tariffs increase costs by about 25% for the same consumption, the hot water heat pump was not functioning, and operational behaviour such as leaving an oven on overnight was contributing avoidable waste. Because the pizza ovens drive sharp daytime peaks, we concluded that installing hybrid solar without first addressing the oven load would be expensive and inefficient. We therefore recommended switching the pizza ovens to gas and then implementing a hybrid system comprising 40 kWp of rooftop PV, a 50 kW inverter and 80 kWh of battery storage to provide four hours of backup and enable peak shaving. The proposed solution has an estimated CAPEX of R1.9 million, expected net savings of about R405,000 per year and a return on investment of 4.7 years, while materially reducing diesel dependence and exposure to future electricity price escalation.

For InVivo’s greenfield malt production project in South Africa, we delivered both the concept study and the FEL2 feasibility phase for a low-carbon industrial energy system combining gas, heat pumps and solar PV. The concept study screened and compared eight hybrid, off-grid and low-carbon energy system configurations through a multi-criteria assessment covering CAPEX, OPEX, footprint, technology maturity, GHG reduction potential, lead time, NPV, IRR and risks. This first phase reviewed seven core technology families, including thermal solar, biogas generation, heat storage, solar PV with battery storage, combined heat and power, heat pumps and gas boilers, to identify the most robust 24/7 energy architecture for the site. Building on this work, the FEL2 study developed the selected concept into a more detailed technical and financial basis for decision-making for a 132,000 t/year malt plant requiring 224 MWh of heat and 41 MWh of power per day. The feasibility phase included equipment sizing, preparation of P&IDs for pre-heating and building heating systems including heat pumps, development of the bill of materials and bill of quantities, CAPEX estimation to around +/-10%, OPEX estimation, and financial modelling under different commercial scenarios including PPA versus outright purchase. The combined studies provided the client with a structured pathway from technology screening to implementation-ready feasibility, while supporting an energy strategy expected to deliver annual savings of around ZAR 14 million, 4.5 MWp of additional renewable power, 4.4 MWhth of additional renewable heating and cooling, annual emissions reductions of about 12,000 tCO2e, an estimated CAPEX of ZAR 150 million and a payback period of around 6 years.

PESCA, a food and beverage client operating a frozen products storage and food factory in South Africa, appointed us to deliver an energy efficiency audit, a Scopes 1 and 2 carbon audit, and EPCM support for a 275 kWp rooftop solar PV system combined with batteries and inverter infrastructure for a 6,000 m² facility consuming about 90 MWh per month. The audit findings directly informed the design of the hybrid solar solution and helped optimise its CAPEX before implementation. The project delivered major operational and environmental benefits, including a 50% reduction in energy consumption, 65% cost savings and a 50% reduction in Scopes 1 and 2 GHG emissions. Beyond the solar hybrid project itself, the study also identified a broader decarbonisation and efficiency roadmap, including staff training, replacement of the kitchen cold production system with newer technology, hot water production for ablutions, lighting upgrades to CFL or LED, and digital monitoring of energy consumption through an EMS. Key outcomes included annual energy cost savings of ZAR 1.47 million, renewable capacity addition of 275 kWp, annual emissions reduction of 587 tCO2e, total CAPEX of ZAR 7.2 million and a payback period of 5.4 years.

East London Industrial Development Zone SOC Ltd | South Africa | Smart Street Lighting Business Case and Delivery Model | 2026The East London Industrial Development Zone developed this business case to support the conversion of its conventional high-pressure sodium street lighting network to a smart LED-based system as part of a broader strategy to reduce operating costs, lower energy demand and carbon emissions, and strengthen its positioning as an eco-industrial and innovation-led zone. The proposed project covered 364 street poles and 415 light fittings, replacing existing 150W HPS lamps with 32W LED units fitted with smart controllers and supported by an on-premise management platform. Beyond direct lighting efficiency, the concept was designed to create a connected infrastructure layer with functions such as remote diagnostics, lumen failure alerts, runtime tracking, energy reporting, programmable lighting schedules, event-based lighting increases for security, and future integration with cameras, air quality sensors and other smart city systems. The business case built on earlier UNIDO/NCPC work and a pilot conducted with Trilliant, then translated the opportunity into a practical implementation and procurement model in which a service provider would finance the project and be remunerated through a share of achieved savings until payback. Based on the pilot modelling, the project was estimated at R1.712 million excluding VAT, or R1.969 million including VAT, with annual operating costs of about R228,672, approximately 80% electricity savings, and a significantly longer lamp life for LED compared with HPS. The project also included installation, testing, commissioning, staff training and a requirement that ELIDZ retain ownership of operational data through locally hosted systems. Strategically, the initiative was positioned not only as an energy efficiency measure, but also as a first step toward a Smart Park platform that could support localisation, ICT skills development, data-driven infrastructure management and potential future smart city service expansion across the metro and province.

Soufflet Malt is developing a new 93,000 t/year malt plant south of Johannesburg to supply Heineken, with commissioning targeted for the end of 2026 and a long-term ambition aligned with carbon neutrality objectives. In a South African context marked by both high grid carbon intensity and electricity supply instability, we previously supported the concept and feasibility studies that led to the selection of a hybrid energy solution based on gas engines with heat recovery. Building on this, we were mandated to support procurement of Packages 2 and 3 through successive tender analysis phases, reviewing proposal completeness, scope alignment, constructability, technology choices, pricing structures, execution assumptions and delivery risks. Across both rounds, the work highlighted that equipment selection was a major value driver, with the supply portion representing a substantial share of total cost and boiler choice alone accounting for a large part of the investment. The analysis also identified several optimisation levers before award, including reducing Phase 1 to one 150 m³ hot water storage tank with provision for future expansion, optimising piping lengths and layout, refining storage tank material strategy, and reassessing the backup boiler philosophy. It further clarified the relative merits of boiler, pump, heat exchanger and air-heating options in the South African market, while helping narrow the project to a limited number of credible implementation pathways. The outcome was a clearer procurement roadmap that strengthened scope definition, improved cost-performance trade-offs and de-risked the delivery strategy for a strategic lower-carbon industrial energy system.

For eThekwini Metropolitan Municipality, we developed the project concept and technical, institutional and financial basis for an Energy Performance Contract covering a first bundle of seven priority public buildings under the Energy Efficiency in Public Buildings and Infrastructure Programme. Drawing on audits and due diligence undertaken between 2019 and 2025, the work consolidated a package of demand-side and on-site generation measures including LED lighting retrofits, HVAC upgrades, water-heating modernisation through solar thermal, and behind-the-meter solar PV. Across the seven facilities, the project established an estimated baseline electricity consumption of 1,688,855 kWh/year and identified a pathway to reduce grid consumption to about 660,040 kWh/year through 745,154 kWh/year of energy-efficiency savings and 283,661 kWh/year of embedded renewable generation. The proposed investment envelope totals R18.15 million, including R14.85 million for energy-efficiency measures and R3.30 million for solar PV, with estimated gross savings of R3.38 million per year, a simple payback of 5 years and 4 months, and annual avoided emissions of 945 tCO₂e. Beyond the technical intervention design, the project also set out the implementation architecture for a shared-savings EnPC, including ESCO participation, metering and M&V requirements, legal and procurement pathways, risk management, municipal capacity building and a phased delivery roadmap. The analysis highlighted City Fleet as the strongest economic anchor of the package, confirmed embedded solar PV as a key profitability driver, and positioned the programme as a scalable municipal retrofit model aligned with eThekwini’s Climate Action Plan, local economic development goals and South Africa’s Just Energy Transition agenda. The concept further estimated a job-creation potential of about 20 direct and 30 indirect jobs, while supporting local content development and long-term municipal energy management capability.

South Africa’s emerging green hydrogen market requires catalytic PtX projects to demonstrate compliance with robust technical, environmental and social criteria before they can credibly access grant support and progress toward bankability. The client needs an independent audit framework to assess whether selected projects meet minimum requirements related to renewable electricity additionality, carbon intensity, water use, sustainable carbon sourcing, land use, biodiversity and relevant certification schemes, while also supporting the country’s broader decarbonisation objectives. We support IDC, under the KfW-funded Promotion of Green Hydrogen in South Africa Programme, to structure and deliver an independent technical audit and advisory approach for selected PtX projects before financial close and after commercial operation. In partnership with TÜV SÜD, we combine hydrogen certification expertise with local environmental, regulatory and stakeholder knowledge to review project documentation, assess permitting and E&S risks, validate key technical assumptions, model energy and mass balances, verify compliance against KfW/IDC criteria and relevant certification frameworks, and conduct post-COD monitoring and site-based verification. This assignment helps establish a transparent, credible and investment-ready foundation for South Africa’s green hydrogen economy while aligning project development with climate, inclusion and sustainability objectives.

The client needs to address a structural gap in social housing retrofit planning across South African cities: municipalities are under pressure to improve affordability, energy security and decarbonisation outcomes, but often lack standardised and defensible tools to assess, prioritise and structure interventions at scale. We support C40 Cities Climate Leadership Group to develop a decision-grade framework for five metropolitan municipalities that helps cities and social housing institutions move beyond fragmented pilots toward scalable and bankable retrofit programmes. The framework is portfolio- and precinct-based rather than building-by-building and integrates technical, financial, regulatory, institutional and social dimensions into one practical decision tool. It includes Global South benchmarking, social housing typologies, energy baseline analysis, energy-efficiency retrofit options, rooftop solar PV suitability, financial and affordability logic, operations and maintenance planning, and delivery and procurement pathways. The approach is designed to provide clear go/no-go/further-study thresholds, prioritise energy efficiency before solar, address split incentives between landlords and tenants, and account for tariff structures, procurement constraints, affordability impacts on low-income households and municipal revenue implications. The result is a scalable framework intended to help municipalities identify priority clusters, define typology-based intervention packages and build procurement-ready retrofit pipelines aligned with Just Energy Transition principles.

CIPREL sought to improve the energy performance, operational efficiency and electricity generation capacity of its 543 MW thermal power plant in Vridi, while reducing internal energy consumption and operating costs. We conducted a comprehensive energy performance review covering six gas turbines, one steam turbine, heat recovery steam generators, air-cooled condensers and auxiliary electrical systems. Our assessment combined site inspections, electrical and combustion measurements, thermodynamic analysis, energy balances, heat-rate calculations and evaluation of turbine efficiencies, using a 2024 baseline of approximately 3.3 TWh of annual electricity generation. The study identified performance losses associated with fouled heat exchangers, compressor inefficiencies, turbine air-intake restrictions and inefficient auxiliary motor operation. We developed seven prioritised improvement measures, including cleaning heat recovery boilers, air-cooled condensers and turbine compressors; installing waste-heat-driven absorption cooling for gas turbine inlet air; introducing variable-speed drives on pumps and fans; and optimising lighting and air-conditioning systems. Our mandate also covered techno-economic assessments, investment prioritisation, identification of instrumentation anomalies and preparation of an energy performance improvement plan with a measurement and verification framework. The proposed measures are estimated to increase annual electricity generation by approximately 251,600 MWh (8%) while reducing internal electricity consumption by 18,093 MWh (29%), subject to implementation and performance verification.

SOTACI sought to reduce energy consumption and operating costs across its steel-processing facilities in Yopougon while identifying opportunities to improve energy performance and reduce greenhouse gas emissions. We conducted a comprehensive industrial energy audit covering the production units and administrative facilities, using 2025 consumption data representing approximately 13.1 GWh of grid electricity and 4.4 GWh of natural gas annually. Our assessment combined site inspections, electrical measurements, thermal imaging, energy balances and identification of significant energy uses across electrical distribution, compressed-air networks, gas and electric furnaces, chilled-water production, ventilation and lighting. We identified opportunities to optimise subscribed electrical capacity, eliminate compressed-air leaks, improve compressor control, strengthen furnace insulation, optimise cooling systems and introduce comprehensive energy monitoring. The study also assessed gas-fired cogeneration integrated with absorption cooling and a proposed 2 MWp solar photovoltaic installation for self-consumption. We developed a prioritised energy performance improvement plan covering operational adjustments, equipment upgrades and larger capital investments, supported by techno-economic assessments, estimated energy and financial savings, and a measurement and verification framework. The proposed measures aim to improve industrial energy efficiency, reduce operating expenditure and lower associated carbon emissions.

The client needs to accelerate implementation of energy-efficiency measures in Botswana by moving beyond policy intent toward practical action across public and private sectors. This requires stronger stakeholder awareness, improved technical capacity, better energy-data systems and a pipeline of actionable audits, retrofit studies and pilot projects. We support the ASPIRE Botswana programme to implement Outcome 2 by combining strategic, technical and market-oriented interventions. Our mandate includes assessing the national energy-efficiency context, organising awareness-raising campaigns for priority stakeholder groups, delivering knowledge-sharing workshops for specialists and supporting creation of a web-based energy-data collection and analysis system for the national energy balance. We also contribute to the definition of investment-focused scopes of work for distribution-loss reduction, delivery of retrofitting studies for pilot public buildings, promotion of ESCO-led energy audits in large energy-consuming facilities and implementation of pilot energy-efficiency actions. Through this assignment, we help translate energy-efficiency ambitions into practical, scalable and inclusive interventions that strengthen institutional capacity, unlock investment-ready opportunities and support Botswana’s sustainable energy transition.

The client needs to unlock large-scale energy-efficiency investment in South Africa’s public sector, where ageing infrastructure, limited technical capacity and constrained access to finance have slowed development of viable projects despite significant savings potential. We support SANEDI to help public-sector entities transform energy-efficiency and climate-resilience ambitions into bankable projects under a performance-contracting model with Energy Service Companies. Our mandate covers project conceptualisation, technical and institutional due diligence, preparation of Concept Business Cases, development of MFMA-aligned tender documentation, financial structuring and support through tender implementation. We also help identify concessional and blended-finance pathways, integrate renewable-energy options, assess greenhouse-gas reduction and job-creation potential and strengthen institutional capacity through workshops, tools and methodological guidance. By combining transaction advisory, procurement support and capacity building, the assignment helps public institutions move from fragmented project ideas to structured, finance-ready and performance-based investment programmes that can accelerate implementation and improve public-sector energy performance at scale.

The client needs to address high post-harvest losses, unreliable electricity supply and the high cost of cold storage in rural agricultural areas, all of which constrain food preservation, agro-processing and local income generation. We support Rwanda Energy Group to develop the GeoFridge concept: a pilot cold-storage solution designed for the Bugarama-Ruhwa region that combines geothermal energy, solar thermal and photovoltaic power to deliver low-carbon refrigeration for agricultural products. Our mandate covers functional definition of the cooling system, detailed studies, fabrication, installation and commissioning of the demonstrator, as well as training for the beneficiary and analysis of operational feedback to improve the prototype. The project also includes optimisation of the business model, impact assessment and preparation of a regional deployment plan and East Africa opportunity mapping. By integrating three mature technologies into a single rural cold-chain solution, the project aims to reduce electricity consumption significantly compared with standard refrigerated containers while improving food preservation, strengthening resilience in off-grid or weak-grid contexts and creating a scalable pathway for renewable cooling in agricultural value chains.

The Energy Efficiency in Public Buildings and Infrastructure Programme (EEPBIP) was established to accelerate large-scale energy efficiency investment across South African municipalities, provincial governments and State-Owned Entities, using Energy Service Companies (ESCOs) and Energy Performance Contracts to overcome capacity, project-development and financing barriers. The transaction advisory assignment was structured to support public-sector institutions from project conceptualisation through development of bankable business cases, tender preparation and ESCO procurement. The technical scope included review of energy audits, electricity billing data and energy baselines; identification and quantification of bankable efficiency measures; high-level assessment of small-scale embedded generation, including solar PV; and preparation of technical specifications. Financial analysis covered CAPEX, operating and maintenance costs, NPV, IRR, dynamic payback, energy-cost savings and greenhouse-gas reductions, together with identification of complementary funding sources and advice on project financing structures. The scope also incorporated socio-economic analysis, Measurement and Verification and programme monitoring arrangements, preparation and adaptation of Invitations to Tender and Energy Performance Contracts, and technical, financial, legal and socio-economic backstopping during bidder clarifications, evaluation, funding review and contract negotiations. Capacity development was embedded through institutional workshops and training, with the assignment scheduled from July 2024 to June 2025.

EUROFIND seeks to strengthen energy performance across its five Ivorian sites through a structured programme focused on controlling overall energy consumption, reducing operating costs and identifying high-impact optimisation opportunities. For EUROLAIT, Manergy-Iroko, in partnership with EDF Power Solutions, proposes an energy-efficiency audit aligned with EN 16247-3 and ISO 50002. The assignment will assess energy uses, consumption patterns, influencing factors and key energy-performance indicators, supported where required by instrumented measurements of electricity, temperature and flow to improve the reliability of the analysis and savings calculations. The methodology includes analysis of historical energy data, equipment inventories, detailed energy modelling and benchmarking, followed by identification and techno-economic assessment of improvement measures. Each opportunity will be prioritised on the basis of expected energy savings, investment requirements and return on investment, resulting in a practical action plan to support sustained efficiency improvements and informed investment decisions.

MIoD seeks to establish a common transition-planning architecture that enables Mauritian organisations to convert material climate and sustainability exposures into governed actions, investment decisions, measurable targets and credible Corporate NDC Pledges. Iroko Africa proposes to develop a practical Core Transition Planning Framework integrating governance, strategy, risk management, targets, implementation, financing, monitoring and disclosure, while translating Mauritius’ NDC 3.0, the Green Taxonomy and relevant international standards into actionable guidance. The framework is structured around three cumulative application tiers—Foundational, Developing and Advanced—to provide proportionate requirements for organisations of different sizes, maturity levels and climate exposure. Our proposed scope also covers interoperability with topic-specific toolkits, common definitions and evidence requirements, action prioritisation incorporating CAPEX, OPEX and financing needs, alignment with climate- and sustainable-finance pathways and mapping of relevant metrics to the Corporate NDC Pledge Platform. The proposed eight-week programme includes framework inception, coordination with topic-specific consultants, development of the draft toolkit and editable application tools, three tier-based consultation sessions, refinement and final handover.

MIoD is developing a Climate and Sustainability Transition Planning Toolkit Suite to help Mauritian companies translate climate ambition into credible, implementable and finance-ready transition plans aligned with Mauritius’ NDC 3.0 and relevant international frameworks. Iroko Africa proposes to develop two Mauritius-specific Application Toolkits covering Energy, Emissions & Transport and Climate Resilience & Disaster Risk. The first will address energy consumption, Scope 1, 2 and relevant Scope 3 emissions, efficiency, renewable energy, transport and low-carbon mobility, enabling organisations to establish reliable baselines and develop costed, monitored decarbonisation roadmaps. The second will translate physical climate risks—including cyclones, flooding, coastal and sea-level risks, drought and water stress—into prioritised resilience, preparedness, adaptation and recovery measures. Our proposed scope combines tiered implementation pathways for Foundational, Developing and Advanced organisations, sector guidance, editable assessment and action-planning tools, targets and financing guidance, metrics and reporting frameworks, and interoperability with the Generic Transition Plan and Corporate NDC Pledge Platform. The planned eight-week programme includes inception and common architecture design, standards and evidence crosswalking, development of both toolkits, technical quality review and platform mapping, three tier-based user sessions, refinement and final handover.

The client needs to modernise SIMPA’s industrial site in Yopougon, optimise its energy mix and reduce operating costs by valorising waste heat from a 2 MWe natural-gas generator to meet chilled-water needs. We support ADEMAT on the thermal engineering and owner’s engineering scope of the SIMPA project, from detailed design through works supervision and commissioning support. Our mandate covers the initial energy audit, integration of the existing waste-heat recovery system on the gas engine and flue gases, sizing of a 110°C hot-water storage system, integration of an absorption chiller for chilled-water production, design of chilled-water buffer storage, HAZID analysis and preparation of layout and civil-engineering input data. We are also assisting during procurement and construction through technical bid analysis, review and approval of execution documents, site monitoring, supervision of pressure, tightness and performance tests, and verification of regulatory controls related to gaseous emissions, including NOx. The mission is structured over a planned nine-month period and mobilises a multidisciplinary team for 89 person-days, with key milestones covering audit and preliminary design, thermal execution design, site supervision, thermal commissioning and final DOE handover.

EUROFIND intends to improve the energy performance of its Ivorian industrial sites through detailed assessment of consumption, operating practices and opportunities for technically and economically viable optimisation. For CIE CACAOYERE, Manergy-Iroko, in partnership with EDF Power Solutions, proposes an energy-efficiency audit based on EN 16247-3 and ISO 50002. The proposed work will establish the audit perimeter, review historical energy consumption and available system information and undertake on-site investigations supported by calibrated measurement equipment where additional data are required. The diagnostic approach can include electrical-network analysis, thermal measurements, combustion analysis and compressed-air leak detection depending on the relevant site uses and available data. Findings will be consolidated into a detailed energy balance and a prioritised portfolio of improvement measures, with energy savings, investment requirements and return on investment assessed to support a practical energy-performance action plan and informed investment decisions.

AFD and AFPG needed a strategic view of geothermal-development pathways in Kenya, Tanzania and Uganda in a context of demographic growth, urbanisation, climate pressure and changing energy technologies. We were mandated to assess these pathways while distinguishing geothermal power generation from direct-use applications for heating and cooling. Our approach combined megatrend analysis with an assessment of urban growth, geothermal-resource geography, grid dynamics, climate pressures and technology trends. The study found that Kenya shows the strongest integrated geothermal profile, Tanzania presents regional power clusters and direct-use opportunities, and Uganda shows greater potential for localised direct use, shallow geothermal and geo-cooling. The report provided AFD and AFPG with a framework for comparing geothermal pathways by geography, application and market readiness.

Ferney sought an evidence-based view of the sustainability issues most significant to the project from both impact and financial perspectives, to support ESG prioritisation, strategic decision-making and future reporting development. Our team carried out a double materiality pre-assessment combining stakeholder salience analysis, an employee questionnaire structured around impact and financial materiality, semi-structured stakeholder interviews and thematic analysis, followed by GRI mapping, stakeholder prioritisation and an initial double materiality matrix. The work identified a concentrated set of priority themes, with biodiversity, employment, local communities and economic performance emerging as Tier 1 issues, while energy, water and effluents, indirect economic impacts and environmental compliance remained material supporting themes. The assessment also highlighted key delivery tensions around preserving a low-density, nature-led model while maintaining financial viability, strengthening community inclusion, managing climate and water resilience, and translating ESG commitments into measurable execution. The resulting framework provides a basis for strengthening sustainability governance and reporting architecture, defining KPIs and targets, quantifying priority financial effects where feasible, integrating sustainability risks into management processes and progressing towards a more mature disclosure framework aligned with investor and financing expectations.

IUCN and Ipieca sought to develop a practical resource to help renewable energy developers, business leads and sustainability teams identify and assess opportunities to combine solar and wind generation with other productive land and infrastructure uses, improving land productivity while increasing potential environmental, social and economic value. Our team supported the development of the compendium through desktop research, a co-creation workshop and targeted interviews and questionnaires with project developers, NGOs and specialist organisations. The research examined four principal co-use categories — agriculture, nature-based activities, urban and rural infrastructure, and mining — with a primary focus on onshore solar and wind projects. The work assessed technical configurations including agrivoltaics, solar grazing, wind and agriculture, pollinator habitats, ecosystem restoration, nature-based solutions and renewable energy integration with existing infrastructure and rehabilitated mining land. It also evaluated common technical, environmental, social, regulatory and financial risks and opportunities, supported by international project case studies. The resulting guidance sets out practical considerations for stakeholder co-design, integrated planning, monitoring and evaluation, financial viability and responsible scaling, while identifying knowledge gaps and actions needed to strengthen evidence, investment and replication of co-use approaches globally.

At the SABS Groenkloof facility in Pretoria, we assessed the modernization of a centralized hot water plant serving two main buildings and currently relying on four aging 2 MWe electric resistance boilers. As part of an Energy Performance Contracting initiative, the study analysed 30 months of high-resolution operating data to identify the most technically viable and energy-efficient replacement pathway. The analysis confirmed a highly inefficient system with a COP of around 1, a peak aggregated demand close to 3.0 MW, uneven boiler usage, and a thermal requirement now aligned with hot water production rather than steam, making industrial heat pumps a suitable alternative. Two options were evaluated: a centralized industrial heat pump plant and a hybrid heat pump plus solar thermal configuration. The recommended solution was a centralized plant based on two 1.7 MW high-temperature industrial air-to-water heat pumps in parallel, providing 3.4 MW of thermal capacity and a 10% redundancy margin over the observed peak. This configuration is expected to reduce electrical input from around 3.0 MW to about 0.85 MW, cut hot water energy consumption by 60% to 75%, significantly lower maintenance costs, and provide a robust platform for a future solar thermal phase if required. The work also defined the technical basis for the next delivery stages, including financial modelling, EnPC measurement and verification, tender preparation, and site survey activities, positioning the project as a low-risk, high-impact decarbonisation and OPEX reduction opportunity for the facility over the next 15 to 20 years.

Dalkia and EDF wanted to assess whether seawater thermal energy from the Mediterranean could support a localized low-carbon network delivering heating, cooling and domestic hot water in La Seyne-sur-Mer. We carried out the feasibility and preliminary design study, analysing local energy demand, available marine resources, plant sizing and configuration, and comparing two scenarios: a fully renewable option and a hybrid option with limited gas backup. Our work also covered environmental impact, subsidy eligibility, CAPEX and operating risk, including specific attention to marine biodiversity. The study demonstrated two viable pathways: a first scenario reaching a 73.1% renewable share with 7,300 MWh/year of renewable production and up to 1,149 tCO2e/year avoided, and a second scenario reaching 71.4% renewable energy with 7,125 MWh/year and only 1.8% gas use at peak load. Total project CAPEX was estimated between €4.6 million and €5.65 million, with potential subsidies of up to €3.5 million. The study gave the client a clear technical and financial basis for decision-making and next-stage engineering.

Constellium sought to improve the energy performance of an aluminium production site manufacturing 5,000 tonnes per year and consuming around 20,000 MWh/year of gas and 22,000 MWh/year of electricity. We supported the client through a FEL2 study focused on waste heat recovery and cooling circuit optimisation, analysing the site’s thermal balance, cooling capacities and future resilience needs in a context of rising temperatures and more frequent heatwaves. The study assessed resizing scenarios for the cooling system, additional cooling uses such as workshop air conditioning through adiabatic cooling, and both internal and external heat valorisation opportunities. It confirmed that the most relevant measures could generate annual energy savings of €218k, reduce emissions by 122 tCO2e/year, and be implemented with a CAPEX of €868k and a 4-year payback period. The assignment gave the client a practical roadmap to improve cooling efficiency, recover low-carbon heat and strengthen industrial resilience while preparing potential synergies with a neighbouring facility.

For a new cement production plant in Saint-Maximin, Neocem needed a low-carbon energy master plan consistent with its ambition to produce cement with significantly lower emissions than a conventional facility. We supported the client through a FEL2 study covering a 200,000 t/year plant based on flash calcination technology and heat recovery, with initial energy needs estimated at 54 GWh/year of gas and 12 GWh/year of electricity. Our analysis reviewed the main decarbonisation levers, including dryer electrification, rooftop and parking-lot solar self-consumption, geothermal potential for future thermal needs, and broader energy efficiency and heat recovery strategies. The study showed that electrifying the dryer was the only option capable of significantly reducing CO2 emissions at process level, despite higher initial investment and operating costs, and that complementary measures could deliver around 9% energy cost savings with a payback period of about 1.9 years. This work enabled the client to prioritise the most effective decarbonisation pathway and anticipate the electrical infrastructure implications of a lower-carbon production model.

AFD and AFPG required a first-level assessment of how climate change could affect geothermal power generation and associated infrastructure in Kenya, Tanzania and Uganda. Our mandate covered the physical climate risks affecting cooling systems, civil works, access infrastructure and grid interfaces. We combined international literature, regional climate projections, technology benchmarking and subsystem-level vulnerability analysis across heat stress, drought, flooding, storms and geomorphological instability. The assessment found deep geothermal reservoirs to be broadly resilient, while surface and near-surface systems represent the principal sources of vulnerability. It also identified cooling-system selection as an important design variable, with different trade-offs between water dependence and hot-day performance. The work developed a 4R resilience framework covering Readiness, Redundancy, Resourcefulness and Recovery.

Djera Production needed an assessment of the climate risks affecting forage production, livestock, milk processing and business continuity at its dairy operation in the Bélier region. Our mandate covered climate vulnerability, operational resilience and the development of an adaptation roadmap. We applied the OCARA methodology, aligned with IPCC concepts and ISO 14091, combining process mapping, site visits, stakeholder interviews, questionnaires and climate-scenario analysis. The assessment identified 14 vital or major processes, five low-resilience processes requiring priority action, and four climate-shock scenarios covering flooding, drought, bushfire and extreme heat. Thirty-six adaptation measures were prioritised, including weather monitoring, stronger water and drainage infrastructure, cold-chain efficiency, preventive maintenance and continuity planning.

Netcare needed to assess lower-energy cooling options at Waterfall City Hospital, where chilled-water production represented 22% of total electricity consumption and up to 40% during summer. We were mandated to evaluate the partial replacement of two existing 261 kW vapour-compression chillers with solar-thermal and lithium-bromide absorption cooling. Our approach combined technology and supplier screening, roof-area assessment, equipment sizing, hydraulic integration, risk analysis and CAPEX/OPEX modelling across three implementation scenarios. The study identified approximately 800 m² of usable roof area, with the proposed collector configuration providing 315 kWp of thermal output. The preferred base case was estimated to save R495,260.9 per year with a 9.7-year payback. An enhanced configuration incorporating domestic hot water was estimated to save R740,604.4 per year, with a 7.8-year payback and 318 tCO₂e per year of avoided emissions.

EDF South Africa needed an assessment of energy consumption and cost-reduction opportunities at the Gautrain Marlboro and Midrand stations. Our mandate covered half-hourly electricity data, tariffs, demand profiles, site measurements and the identification of significant energy uses. The audit found average monthly electricity consumption of 84,737 kWh at Marlboro and 42,077 kWh at Midrand. Security lighting alone was estimated to account for 28% of Marlboro's daily consumption. We prioritised LED replacement, occupancy-based lighting controls and a hybrid 250 kWp solar PV and battery-storage system. The hybrid system was estimated to avoid approximately 501,000 kWh per year of grid consumption and generate around R825,000 per year in savings.

AGL needed to assess energy costs at its 10,087 m² Plumbago warehouse in Kempton Park. This included the performance of an existing landlord-owned PV installation and the site's dependence on diesel during load shedding. Our mandate covered utility and diesel data, tariff exposure, site inspection and the identification of practical cost-reduction measures. The audit found daily consumption of approximately 1,500–1,700 kWh, with lighting estimated to represent 65% of total electricity use. The proposed action plan included LED lighting, timers for office air conditioning and geysers, improved forklift-charging management and battery-storage integration with the existing PV system. These measures were estimated to deliver approximately R971,329 per year of savings against R1.58 million of investment, with a simple payback of 1.63 years.

The project required a reliable off-grid electricity solution for a rural site in Belobaka. We covered the detailed design, works supervision and commissioning of a hybrid solar installation. The delivered system comprises an 80 kWp solar PV plant integrating battery storage and generator backup. The project provided a decentralised electricity-supply configuration designed to improve continuity of service while reducing reliance on fuel-based generation.

The project required a hybrid power solution for the Total Old Road service station in Monrovia to reduce diesel-related energy costs and strengthen continuity of electricity supply. We covered the detailed design, works supervision and commissioning. The delivered configuration comprises a 15 kWp solar PV installation integrated with batteries and generator backup. The project established a hybrid electricity-supply system adapted to the operating requirements of the service station.

Lekedi Park required an off-grid electricity solution capable of supporting both general site demand and water-pumping requirements. We covered the detailed design, works supervision and commissioning. The delivered system comprises a 67 kWp solar PV installation combined with battery storage and generator backup. The project established a hybrid off-grid electricity configuration sized for the site's operational and pumping requirements.

Aviniger Farm required a self-consumption solution to reduce energy costs and improve continuity of electricity supply at its Niamey site. We covered the feasibility study, detailed design and commissioning. The delivered configuration comprises a 250 kWp solar PV installation coupled with diesel generation and grid supply. The project established a hybrid power architecture combining onsite solar production with existing backup and grid infrastructure.

The PROVES programme required decentralised electricity solutions for multiple rural communities. We covered the detailed design and commissioning of a portfolio of rural electrification installations. The programme comprises 12 solar plants, each rated between 30 and 40 kWp and incorporating battery storage. The project established a multi-site electrification configuration based on decentralised solar generation and storage adapted to local service requirements.

The CABOPLAST site in Praia required a hybrid solar PV solution with generator backup. We covered the feasibility study, detailed design and commissioning. The system comprises a 70 kWp solar PV installation combined with generator backup.

TotalEnergies required a hybrid solar PV solution coupled with diesel generation for its head office in Lagos. We covered the feasibility study, owner's engineering and project management, and PV-diesel integration. The system comprises a 120 kWp solar PV installation coupled with diesel generation.

TotalEnergies required an assessment of rooftop solar PV potential at its industrial site in Pointe-Noire. We covered the PV feasibility study, PV/diesel/grid integration and technical project structuring. The study assessed a rooftop PV capacity of up to 2 MWp.

Mena Solar required an assessment of ground-mounted solar PV potential for an industrial site in Bamako. We covered the PV feasibility study, PV/diesel/grid assessment and technical project structuring. The study assessed a ground-mounted PV capacity of up to 4 MWp.

Médecins Sans Frontières required a hybrid solar PV solution with battery storage for its clinic in Moissala. We covered the feasibility study, detailed design and commissioning. The system comprises a 30 kWp solar PV installation combined with a battery energy storage system (BESS).

AFD and AFPG needed an assessment of Kenya's readiness for geothermal direct-use heat in industrial applications, with particular focus on the conditions required to turn opportunities into financeable projects. Our approach combined project-level microeconomic analysis, stakeholder interviews, international benchmarking, resource-demand mapping, market-readiness screening and bankability assessment. The study identified opportunities across agribusiness, food and beverages, FMCG and chemicals, construction materials, and transport and storage. It highlighted Nakuru, Menengai and Longonot as particularly promising areas for future industrial clustering. It also identified key constraints, including regulatory support, last-mile infrastructure, site accessibility and financing costs. To address these, we proposed enabling mechanisms including demand aggregation, long-term heat-offtake agreements, industrial parks and SEZs, and targeted public and DFI support.

As part of Phase 2 of the KTUF geothermal partnership, supported by the Agence Française de Développement (AFD) and the French Treasury, the assignment addressed how a defined geothermal direct-use project can identify, structure and secure the capital required for implementation. We developed a repeatable Project-to-Finance Framework for agri-food applications. It sets out four steps: defining the financing case, determining the capital strategy, identifying eligible funding routes and executing the financing plan. We applied the framework to the proposed GeoFridge/GeoDry pilot at Kiejo-Mbaka, Tanzania, for which Iroko Africa is developer and EPC contractor. The pilot uses an existing 233 m well delivering fluids at approximately 70–75°C to provide around 100 kWth of continuous thermal output. This supplies three GeoFridge absorption-refrigeration units and two containerised GeoDry units, supported by solar thermal, PV and batteries for off-grid operation. The analysis identified commercial validation of the pay-as-you-go service model, rather than geothermal exploration, as the principal risk. We therefore recommended a catalytic-capital-led structure, combining capital, viability-gap and preparation grants, with concessional and commercial debt reserved for later phases once cash generation is demonstrated. Carbon finance was treated as potential supplementary revenue outside the base case. The work concluded with a prioritised fundraising plan, identifying GET.invest, PREO Technical Assistance and UNDP Energy for Growth in Africa as immediate preparation routes and develoPPP Classic as the priority deployment-finance route.

OLAM needed an assessment of alternative power architectures for an industrial site operating two continuous production lines, with a combined demand of approximately 96 MWh/day. We compared three options: grid-tied solar PV, a hybrid solar PV and battery micro-grid with control systems, and a solar-diesel micro-grid without battery storage. Our analysis covered operational continuity, islanding, frequency stabilisation, micro-cut protection, renewable integration and economics. The grid-tied PV option required approximately CFA 1.1 billion of investment for estimated annual savings of CFA 335 million. The hybrid micro-grid required approximately CFA 2.5 billion for estimated annual savings of CFA 710 million. The solar-diesel configuration produced the shortest modelled payback, at 2.9 years, based on CAPEX of CFA 1.175 billion and annual savings of approximately CFA 375 million.

ERIUM needed an assessment of gas-fired cogeneration as an alternative to its existing boiler-only configuration for CO₂ production in Abidjan. Our mandate covered electrical-load analysis, process integration, thermal balances, risks and a preliminary CAPEX/OPEX evaluation. We also assessed the potential to combine onsite electricity generation, exhaust-gas recovery and process cooling. A 1 MW gas engine was selected as the preferred option based on payback, implementation simplicity, production stability and usable exhaust flow. The unit was assessed as capable of operating for approximately 80% of the year. The proposed configuration was estimated at CFA 792.3 million, with annual savings of CFA 416.4 million and a modelled emissions reduction of 39%, equivalent to approximately 2,490 tCO₂e/year.

Henwil Chickens needed a detailed assessment of energy costs across its Lichtenburg abattoir, feed mill and rendering plant. Our approach combined a review of bills, tariffs and metering data with site investigations and measurement of significant energy users. The audit found that annual electricity, coal, diesel and paraffin expenditure totalled approximately R50 million, of which electricity represented R31.1 million. The abattoir accounted for 52% of measured electrical consumption, the feed mill 34% and the rendering plant 14%. We recommended measures including chiller and compressor heat recovery, solar thermal, insulation, power-factor correction, variable-speed drives, peak-period rescheduling and hybrid PV systems. Several of the identified operational measures had modelled payback periods below one year. Larger renewable and storage measures formed part of the longer-term investment roadmap.

Mainland Group needed an energy audit of its Duékoué rubber-processing plant, which operates entirely on onsite diesel generation. Our mandate covered production processes, utilities and support buildings. We combined operational-data analysis, field measurements, thermographic inspection and techno-economic assessment. During the July 2024–June 2025 baseline period, the plant consumed 21.69 GWh of electricity, while eight diesel generators produced 22.83 GWh, with specific diesel consumption of approximately 0.31 L/kWh. The action plan identified potential annual savings of 19.2 GWh and approximately FCFA 2.84 billion, against estimated investment of FCFA 3.29 billion, with approximately 10,776 tCO₂e/year of avoided emissions. Priority measures included a 2.4 MWp solar plant, diesel-generator optimisation, exhaust-heat recovery for drying and comprehensive energy metering.

The City of Pau needed feasibility and engineering support to redevelop a former landfill as a ground-mounted solar PV asset. Our mandate included review of an earlier feasibility study, management and procurement options, and environmental, topographical and geotechnical investigations. It also covered contract preparation, negotiations, and performance monitoring during construction and operation. The project provided approximately 3–3.5 MWp of additional renewable capacity, with estimated CAPEX of €2.3 million. The development was also planned in relation to future electricity demand from adjacent wastewater, methanisation and methanation facilities.

As part of EUROFINS’s five-site energy-efficiency programme in Côte d’Ivoire, the proposed SCCI assignment aims to establish a robust understanding of site energy performance and identify practical opportunities to reduce consumption and operating costs. The wider programme is designed to evaluate key energy uses and indicators, improve energy management and develop a structured group-level improvement plan. Iroko Africa, working with EDF Power Solutions, proposes to conduct the audit in accordance with EN 16247-3 and ISO 50002, beginning with scope definition and review of historical consumption and technical documentation. On-site investigations will incorporate instrumented measurements where required, followed by preparation of a detailed energy balance and comparison with sector performance ratios. Identified efficiency measures will then be quantified and prioritised through assessment of anticipated savings, CAPEX and return on investment. The final output will provide SCCI with a prioritised energy-performance improvement plan designed to support operational decision-making and future investment planning.

The client needs flexible technical support to help structure, launch, monitor and coordinate health infrastructure projects across multiple regions while also integrating cross-cutting technical considerations such as energy performance. We support AFD, as part of a consortium with AP-HP International and Insuco, to provide technical assistance throughout the project cycle, from project identification and technical review to project or programme appraisal, start-up support, transitional project-management assistance and ongoing monitoring of projects and programmes. Our mandate also includes transversal technical inputs, notably measures aimed at improving energy performance. Designed as a framework for repeated assignments across diverse geographies and thematic contexts, this support enables targeted mobilisation based on regional and sector expertise. The assignment helps strengthen preparation and implementation of health-infrastructure investments while improving delivery quality, coordination and long-term operational performance.

The client sought a clear evidence base on the environmental performance of geothermal power, to support development of the geothermal sector in East Africa. We prepared a Life Cycle Assessment (LCA) drawing on scientific literature, including a review of 46 LCA studies conducted between 1995 and 2020. The assessment compared four representative technologies: flash, dry steam, closed-loop Organic Rankine Cycle (ORC) and Enhanced Geothermal Systems (EGS). It used three indicators: greenhouse-gas emissions, water consumption and fossil resource use. The methodology applied a cradle-to-grave boundary covering drilling, construction, operation, maintenance and well closure. It used a functional unit of 1 kWh of net electricity delivered to the grid, a 30–35-year lifetime and IPCC GWP100 metrics, supported by industrial data and recognised databases including Ecoinvent. The analysis found that binary ORC systems deliver the lowest impacts, with emissions of 1.2–36 gCO₂-eq/kWh, water use of 100–300 L/MWh and fossil energy use of 0.1–0.25 MJ/kWh. Flash and steam systems ranged up to 110 gCO₂-eq/kWh and 3,000 L/MWh. We also benchmarked geothermal against other power technologies and extended the assessment to critical-mineral dependency and supply-concentration risks. The study concluded with recommended measures to reduce the footprint of geothermal power, including maximum fluid reinjection (reducing direct emissions by up to 90% in some systems), air cooling, low-carbon auxiliary power, optimised well design and cogeneration.

The study was initiated to assess whether capabilities developed in oil and gas can support geothermal power development in Kenya, Tanzania and Uganda, and where dedicated workforce development is required. We carried out a pre-screening workforce and capability assessment covering the geothermal asset lifecycle, from exploration, drilling and reservoir assessment through power-plant delivery, commissioning, grid integration and operations. Our approach combined national geothermal pipeline scenarios, available workforce and supplier evidence, training capacity and occupation-by-occupation competency mapping. Each priority capability was classified by response: transfer, bridge, build or temporarily mobilise external expertise. Against a FEXTE 2050 planning case of approximately 10.4 GW of incremental geothermal capacity, the study estimated labour requirements of around 860,900 job-years across manufacturing, construction and installation using an Africa-adjusted benchmark. It also clarified how alternative methods produce materially different results. The assessment found that oil and gas is a material feeder sector for project management, drilling, well engineering, surface facilities and maintenance, but not a volume solution. Resource geoscience, reservoir engineering, steamfield design and generation operations require dedicated geothermal or power-sector pathways. We recommended a regional, phased and demand-led response, including a five-year capability programme and a regional Capability Gap Dashboard to link project demand, available capability and delivery responses

Botswana’s ASPIRE Programme aims to strengthen the national Rooftop Solar (RTS) Programme by improving its regulatory framework, technical requirements, financial sustainability and accessibility to consumers. We are supporting the European Union and the Government of Botswana through a comprehensive review of the programme, combining regulatory, technical, economic and financial assessments with stakeholder engagement. Our mandate covers the evaluation of existing net-metering arrangements, potential net-billing mechanisms, export tariffs, capacity limits, approval procedures and third-party commercial models. The technical assessment addresses distribution-grid hosting capacity, solar PV interconnection standards, bidirectional metering, battery storage integration, curtailment requirements and installer accreditation. We are also undertaking economic and financial modelling to assess the impact of rooftop solar deployment on Botswana Power Corporation’s revenues, consumer electricity costs and cross-subsidies, alongside the evaluation of incentives and financing mechanisms, including green loans and concessional finance. The assignment incorporates international benchmarking, consumer protection, equitable access to solar energy and institutional capacity-building recommendations. The mission is structured over approximately six months, from October 2026 to March 2027, mobilising four specialists for 120 person-days. Planned deliverables include diagnostic and benchmarking assessments, financial modelling, consolidated recommendations, revised national RTS Guidelines and a stakeholder validation workshop. The project aims to establish a practical regulatory and implementation framework supporting the sustainable expansion of distributed solar energy across Botswana.

WEPA needed to significantly reduce CO2 emissions from steam production at its Bousbecque paper site while maintaining reliable industrial supply and meeting all regulatory and logistical requirements. We supported ENGIE Solutions through a FEL2 study for an 8 MW biomass steam production unit using forest chips and wood pellets to partially replace natural gas. The assignment covered boiler room sizing, wood storage and transport technologies, utility connections, site layout, fire risk management, regulatory changes, and CAPEX/OPEX assessment. The proposed system was designed to supply steam at 17 barg over 8,000 operating hours per year and to meet a demand of about 67,700 MWh. The study showed that the biomass boiler could produce 109,300 tonnes of steam per year, cover 88% of the site’s needs, reduce emissions by about 13,950 tCO2e/year, and be implemented with a CAPEX of approximately €10.5 million. It also confirmed compliance with ICPE and DREAL requirements and gave the client a robust basis for implementation planning, fuel logistics and decarbonisation investment.

Lesaffre wanted to transition from a fully gas-based steam production system to a greener and more efficient configuration at its LIS industrial site in Cérences, while preserving supply security and remaining fully compliant with environmental regulations. We supported the client through a FEL2 study for a new biomass-and-gas boiler plant designed to supply industrial processes with up to 12.5 t/h of dry saturated steam at 20 bar. Our analysis covered the integration of a biomass boiler with two gas boilers used for support and backup, alongside wood storage and conveying systems, flue gas treatment, economizers, degassing water treatment and associated safety and control systems. The study validated the technical feasibility of the new steam plant, confirmed that it could provide 56,100 MWh/year of additional heating capacity, and estimated emissions reductions at 12,300 tCO2e/year for a CAPEX of €7 million. It also demonstrated that the installation could be implemented safely below the 20 MW thermal threshold and integrated effectively with the site’s utilities, including water treatment, compressed air and heat recovery systems.

The French Energy Regulatory Commission sought to assess the extent to which coupling electricity, gas, heating and cooling networks could become a credible lever for accelerating the urban energy transition. We conducted a techno-economic study to evaluate the relevance, viability conditions and systemic impacts of these solutions at urban infrastructure scale. Our approach was based on the identification of 16 coupling solutions, grouped into three main categories: the valorisation of new energy sources, the improvement of inter-network flexibility and efficiency, and the opening of networks to new energy uses. The analysis combined case review, techno-economic modelling, business model reconstruction and an applied case study focused on Bordeaux Métropole Energies. The study showed that the most robust opportunities lie on the heat side, particularly through waste heat recovery, district heating and cooling networks, and selected local flexibility mechanisms, while solutions such as power-to-gas or hydrogen appear, at this stage, to have more limited relevance in dense urban environments. It also highlighted the need to anticipate the evolution of gas network uses and to adapt certain planning and regulatory frameworks. This assignment helped inform the regulator’s decision-making, structure a multi-network vision for urban decarbonisation, and identify practical levers to improve resilience, energy performance and territorial value creation.

Pays de Gex Agglomeration set out an ambitious objective: to become a positive energy territory by 2050 by cutting energy consumption by 50% and covering most of its needs with local renewable energy sources. In this context, we delivered an Energy Master Plan and integrated Energy-Climate roadmap to support long-term decision-making and structure the territory’s transition pathway. Our work began with a comprehensive territorial diagnosis, developed mainly through cartographic and GIS-based analysis and carried out in collaboration with more than 25 public and private local stakeholders. This phase covered the socio-economic profile of the territory, the analysis of the PLUiH, energy demand assessment, renewable and recovered energy potential, district heating networks, governance dynamics and the main energy challenges facing the area. Building on this foundation, we facilitated stakeholder workshops to co-develop three energy transition scenarios and define quantified, realistic targets for the deployment of local renewable solutions and energy renovation measures. The roadmap identified concrete opportunities including waste heat recovery from CERN, photovoltaics, geothermal energy, biomass and district heating networks. Delivered in partnership with two local consulting firms selected for their strong understanding of the local territory and its cross-border relationship with Switzerland, the assignment provided Pays de Gex with a robust strategic framework, a shared territorial vision and an actionable basis for planning its energy transition.

The City of Nîmes commissioned a Greenhouse Gas Emissions Assessment (BEGES) for its municipal activities in 2023, together with a transition plan designed to reduce emissions through to 2050. With around 2,700 municipal staff and a broad range of departments and public service delegations, the key challenge was to build a robust emissions baseline and translate it into a practical decision-making framework for long-term climate action. Our assignment was structured in five stages: defining the assessment perimeter, collecting data across 21 municipal services and departments, calculating emissions in line with ADEME methodology, co-constructing a reduction action plan, and presenting the results through both regulatory reporting and accessible decision-support materials. The action plan was developed through workshops with city staff on mobility, energy and buildings, and procurement, and included quantified impacts as well as a reduction trajectory for 2026, 2030, 2040 and 2050. The study established a 2023 baseline of 29,110 tCO2e and identified a pathway to reduce emissions by 14% by 2030 and 24% by 2050 based on the selected measures. By combining a rigorous carbon inventory with collaborative planning and operational tools transfer, the mission provided the City of Nîmes with a structured roadmap to prioritise actions, monitor progress and embed climate strategy into its broader municipal transition agenda.

Les Fermes Debout needed a reliable, low-carbon and cost-controlled heating solution for its future greenhouse development in Lisses, while reducing exposure to fossil fuel price volatility. Manergy was mandated to assess the technical, energy, environmental and economic feasibility of recovering waste heat from the nearby CloudHQ data centre and transferring it to the agricultural site through a buried heat network. Our approach followed ADEME and AMORCE/ADEME feasibility-study guidance and combined greenhouse thermal modelling, multi-year climate analysis, load-duration assessment, hydraulic predesign, route and utility-constraint analysis, and scenario-based techno-economic optimisation. The study covered four greenhouses of about 2.7 ha each, a 2,330 m² central agricultural building, and an estimated 1.28 km connection between the data centre and the site. Key results showed a reference annual heat demand of about 17.0 GWh, a peak load of about 7.5 MW, and a 6 MW design covering around 97% of call hours. Three development scenarios from 6 MW to 12 MW were assessed, with CAPEX estimates ranging from about €2.6 million to €3.3 million for connection to building 1. The preferred concept confirmed the technical relevance of direct waste heat recovery without a heat pump in the base case. The project could avoid about 3,069 tCO₂e/year net and generate around €918k/year net cash flow in year 1, with a simple payback of about 4.5 years without subsidies and 2.7 years with estimated support. This study established a credible pathway for local industrial-agricultural energy symbiosis.

Terres de Saint Malo needed to secure the future of its positive-temperature cold storage facility for vegetables, where the existing 900 kW refrigeration system operated with R404A, by identifying a long-term replacement solution not affected by F-Gas constraints. We supported the client in assessing the site’s actual cooling needs, comparing replacement scenarios, and building a technical, economic and financial decision basis. Our approach combined a diagnostic of the existing installation, operational tests with three and then two compressors, cooling-demand analysis, and a comparison of retrofit and replacement options, including R1234ze retrofit and new outdoor chillers using R290 or NH3, supported by supplier consultations. The study confirmed a target cooling capacity of 600 kW with a safety margin. The two-compressor test demonstrated 470 kW without alarms, while maintaining a supply air temperature of around 2°C. The retrofit option was estimated at approximately €561k with no expected electricity savings, whereas the new central plant option was estimated at €620k, with annual OPEX savings of €46k, €48k in CEE support, and a 1.3-year payback compared with retrofit. Additional optimisation opportunities were also identified for distribution pumps, with an investment of €8.5k and annual savings of €4k. Overall, the assignment enabled investment prioritisation, ruled out low-value options such as standalone ice-bank replacement, and prepared a robust works roadmap.

The feasibility study covered a geothermal district heating and cooling network supporting a 600,000 m² urban development in Southeastern France, planned to accommodate 30,000 new residents together with major public amenities including a swimming pool, schools and a hospital. We assessed the technical and energy framework of the DH/DC system, defining a concept sized at 16 MW cold for 28 GWh with 68% renewable energy, and 15 MW heat for 24 GWh with 72% renewable energy. The scheme was based on 11 boreholes and four piping systems. The study provided the client with a structured basis for integrating low-carbon heating and cooling into a major urban expansion project.

The Centre Hospitalier du Sud Seine et Marne needed to structure its response to the Éco Énergie Tertiaire requirements across three hospital sites in Fontainebleau, Montereau-Fault-Yonne and Nemours, representing a combined 135,832 m². We supported the hospital through a coordinated programme combining regulatory energy-data consolidation, energy audits, multi-site renovation planning and assessment of technical installations. The work included identifying the entities subject to the regulation, analysing ten years of energy consumption to determine the reference year and reference consumption, and submitting data to ADEME’s OPERAT platform. We then assessed building and technical-system deficiencies, analysed usage and technical data, quantified opportunities to improve energy efficiency and comfort, and developed several renovation scenarios. A site-wide strategy was prepared to programme works in line with the 2030, 2040 and 2050 regulatory milestones. The assignment also included a comprehensive diagnostic of existing HVAC systems to assess the condition of networks and technical equipment. The resulting work provided a common energy-performance framework across the three sites and a basis for prioritising future renovation measures.

La Celle-Saint-Cloud needed to assess the energy performance of the Jules Ferry and Pierre & Marie Curie school complexes and define improvement measures aligned with current regulatory requirements. The two primary and nursery school sites, built in 1961 and 1957 respectively, comprise multiple interconnected buildings, school restaurants and staff accommodation, with floor areas of 5,099 m² and 3,697 m². We supported the ongoing audits through stakeholder consultation, collection and analysis of energy-consumption data, assessment of the existing building fabric and thermal performance of façades and structures, and inspection of heating, domestic hot-water and ventilation systems. The scope also included summer-comfort assessment, energy modelling and comparison with regulatory objectives. Improvement measures considered include insulation of external walls, roofs and floors, together with optimisation of heating and lighting systems and development of intervention scenarios. The study identified potential savings of 631,055 kWh/year, €121,000/year and 153 tCO₂/year for Jules Ferry, and 113,881 kWh/year, €21,000/year and 28 tCO₂/year for Pierre & Marie Curie.

The City of Arles needed to assess the technical and economic feasibility of developing a district heating and cooling network in the Barriol neighbourhood as part of its urban-renewal programme. The study area includes private and social housing, commercial premises, schools and cultural infrastructure, with the city seeking to integrate renewable and recovered energy into its wider urban-development strategy. We supported the assignment through analysis of current and future heating and cooling demand, assessment of locally available renewable and recovered energy resources, development of technical, energy and environmental scenarios and economic and tariff analysis of the shortlisted options. Two network perimeters were assessed: one focused on the NPNRU redevelopment zone and a wider scenario incorporating both the NPNRU area and a future ZAC to the east. Hydrogeological studies were undertaken with Strategeo to assess groundwater geothermal potential. The wider scenario was found technically viable, with renewable and recovered energy contribution exceeding 65% and reaching up to 69%. Key parameters include approximately 16,890 MWh/year of heat demand, 4,387 MWh/year of cooling demand and around 5 km of network in the stated second-scenario configuration.

Safran needed to replace the centralized gas heating system serving its 96-hectare Villaroche site and 110 buildings with a more sustainable, lower-carbon solution. We carried out a FEL1 concept study to compare renewable heating pathways, focusing on geothermal energy from the Dogger aquifer and biomass heating, while assessing the technical and economic implications of each option. Our work compared four scenarios through a multi-criteria decision process based on CAPEX, OPEX, regulation, carbon footprint and technology maturity. Two solutions emerged as the most relevant: a biomass-plus-gas configuration using local wood residues, and a geothermal option coupled with a high-efficiency heat pump. The selected scenario reached a 76% renewable energy share and an 82% reduction in annual Scope 1 CO2 emissions, with an estimated CAPEX of €24.5 million and an 11-year payback period. The study provided Safran with a clear decision-making framework and highlighted that substantial renovation of the site’s heat distribution systems would be required to enable the transition.

MAT Friction sought to establish a voluntary energy management system at its Noyon site and work towards ISO 50001 certification. We supported the ten-month assignment by first carrying out an energy audit to establish the site’s energy baseline and identify improvement opportunities. This was followed by a gap assessment against ISO 50001 requirements to determine the site’s position relative to the standard and define priority actions. The implementation support included training workshops covering the different sections of the standard, assistance in preparing the energy performance review, weekly project follow-up, support with drafting and reviewing required documented information, and a mock audit ahead of the certification audit. The assignment identified nine energy-saving actions and 970 tCO₂ of potential avoidable carbon emissions. The site subsequently obtained ISO 50001 certification. The work also established a structured energy-consumption map and regular follow-up process to support ongoing monitoring of energy performance and corrective actions.

Mayoly needed to define a low-carbon pathway for its industrial sites while accounting for projected production growth of 15% by 2030 and an ambition to reduce greenhouse-gas emissions by 55% in 2030 compared with a 2019 reference. The work covered the sites at Dammarie-les-Lys, Dreux and Isle-sur-la-Sorgue and focused on Scopes 1 and 2. We supported the six-month assignment by establishing the roadmap framework and calculating projected 2030 CO₂ emissions while incorporating anticipated changes in site activity and production. The scope included an energy and carbon study and an assessment of financing options, taking account of available subsidy mechanisms and alternative financing solutions to evaluate opportunities beyond exclusive use of the client’s own funds. We also supported the definition of the final roadmap through a jointly developed multi-criteria matrix used to select and prioritise actions. More than 80 actions were studied and costed, with the roadmap indicating a projected 2030 greenhouse-gas reduction of 2.5 ktCO₂ compared with the 2019 reference.

The client needed to assess the implementation of a 35 t/h biomass steam plant as part of an industrial decarbonisation project in the Vosges. The scale of the proposed installation required specific technical solutions, including round biomass silos and non-standard boiler technology. We supported the project through the detailed preliminary design phase, developing the technical basis required to validate equipment layouts and the principal solutions selected for the future plant. The engineering scope covered electrical systems and control-command architecture, hydraulic routing, flue-gas systems, biomass handling arrangements and boiler selection. The assignment therefore brought together the principal mechanical, electrical, process and utility interfaces needed to define the proposed biomass steam installation before subsequent implementation stages. We also prepared the project budget with an accuracy of ±5%, providing the client with a cost basis aligned with the level of definition reached during the detailed preliminary design phase.