Evaluating Electrification Project Feasibility

Renewable-Powered Battery Swaps: Unlocking Ship Electrification At Global Canals When discussing maritime electrification, the idea of mid-ocean recharging frequently emerges. It's a good notion except for everything about its feasibility, costs and operations, but there is a variant that makes sense. Full article: https://lnkd.in/guSKaB9r The Maersk McKinney Moller Center's recent analysis correctly concluded that battery-electric ships are viable and increasingly competitive, driven by falling battery prices, rising energy density, and easy integration of containerized battery packs onto vessels. However, their assumptions were already outdated. They used battery costs of $300 per kWh, whereas current grid-scale battery packs in China are available for $51 per kWh, dramatically improving the economics and expanding where hybridization will take hold to transoceanic ships. The recharging concept that was mooted again by several commenters when I published on the Maersk study suggests placing large wind farm and charging facilities in mid-ocean locations, allowing ships to carry smaller battery packs. Though attractive in theory, the harsh economic reality of offshore infrastructure quickly sets in. Marine engineering costs escalate exponentially. My rule of thumb is that infrastructure that costs $1 onshore typically rises to about $10 offshore, $100 subsea, and potentially over $1000 for deep ocean locations. Offshore projects only succeed under highly favorable or strategically critical conditions, such as offshore wind near dense energy demand centers or over high-value oil reserves, not in isolated, storm-prone regions like the Aleutians or mid-Atlantic. However, the broader concept of intermediate charging shouldn't be dismissed entirely. There's significant practical and economic potential for containerized battery exchanges at existing maritime choke points like the Panama Canal, Suez Canal, Strait of Malacca, and possibly Gibraltar. These locations offer strong renewable resources, existing port infrastructure, predictable ship stops, and operational simplicity. Containerized battery swaps could easily integrate into routine ship operations, drastically cutting onboard battery requirements, vessel weight, and costs. The maritime industry should prioritize developing standardized containerized battery exchange solutions at these established chokepoints rather than chasing economically unfeasible mid-ocean charging stations. Collaboration among maritime stakeholders — ship operators, port authorities, regulators, investors, and suppliers — is essential. Pilot projects at locations like the Suez or Panama canals could rapidly prove the economic and operational case, paving the way for wider adoption and accelerated maritime decarbonization.

Building Simulation cover article Informing electrification strategies of residential neighborhoods with urban building energy modeling Electrifying end uses is a key strategy to reducing GHG emissions in buildings. However, it may increase peak electricity demand that triggers the need to upgrade the existing power distribution system, leading to delays in electrification and needs of significant investment. There is also concern that building electrification may cause an increase of energy costs, leading to further energy burden for low-income communities. This study uses the urban scale building modeling tool CityBES to assess the electrification impacts of more than 43,000 residential buildings in a neighborhood of Portland, Oregon, USA. Energy efficiency upgrades were investigated on their potential to mitigate the increase of peak electricity demand and energy burden. Simulation results from the calibrated EnergyPlus models show that electrification with heat pumps for space heating and cooling as well as for domestic water heating can reduce CO2e emissions by 38%, but increase peak electricity demand by about 9% from the baseline building stock. Combining electrification measures and energy efficiency upgrades can reduce CO2e emissions by 48% while reducing peak electricity demand by 6% and saving the median household energy costs by 28%. City and utility decision makers should consider integrating energy efficiency upgrades with electrification measures as an effective residential building electrification strategy, which significantly reduces carbon emissions, caps or even decreases peak demand while reducing energy burden of residents. Details of the research can be found at https://lnkd.in/gSCi-W3k The article is co-authored by Tianzhen Hong, Sang Hoon Lee, Wanni Zhang, Han Li, Kaiyu Sun & Joshua Kace             #BuildingSimulation #CityBES #decarbonization #electrification #cover

One of the most interesting papers on electric mobility you will read this year, I promise. A preprint (not yet peer reviewed) by my student Joshua Sello, titled "Agent-Based Simulation of Electric Minibus Taxis: Framework and Application to Stellenbosch Paratransit" https://lnkd.in/diKMPpXk In short, he modelled minibus taxi drivers and their decision making to try to understand the impacts of electrification. He assesses different charging strategies and evaluates the impact on mobility and charging infrastructure. My favourite two figures from the paper are shown below, indicating for different charging scenarios and different adoption levels, the impact on passenger waiting times, failed trips, and seat-distance-utilisation. The other shows EV and ICE km driven. Other figures in the paper show waiting times at chargers, grid impact, and emissions impact. Abstract: The electrification of minibus taxis in sub-Saharan Africa holds promise for reducing greenhouse gas emissions and improving urban air quality, yet its success depends on understanding the behavioural and infrastructural realities of informal paratransit. This paper introduces a modular, agent-based simulation framework that integrates discrete choice and opportunity cost into driver decision-making, calibrated with empirical data from Stellenbosch, South Africa. The model is used to evaluate electrification scenarios across varying electric vehicle adoption rates, depot connector counts, charging power levels, and the presence of home charging. Results show that while limited depot capacity leads to steep increases in passenger waiting times and reductions in trips serviced, the introduction of home charging consistently alleviates depot congestion and maintains service quality even at high adoption levels. Beyond 22 kW per-connector, however, additional charging power yields diminishing returns. Grid impacts reveal contrasting load profiles: depot-only charging concentrates demand during operating hours, whereas home charging shifts load to the evening peak, underscoring the importance of managed charging strategies. Environmental benefits are substantial but contingent on a cleaner electricity grid. The findings demonstrate that electrification is operationally feasible without structural reform of paratransit, provided that charging strategies balance service quality, infrastructure cost, and grid sustainability. Electric Mobility Lab #electricvehicle #ev #paratransit #populartransportation #sustainabledevelopment #charging #charginginfrastructure

Electrification only works if it lowers cost per ton. Mining doesn’t buy powertrains. Mining buys $/Ton reduction. At Sigma Powertrain, we start at the top of the design “V”: $/Ton = f (Mechanical Efficiency + Cycle Time + Fuel Cost + Service Life + Payload Impact) Everything we engineer maps back to that equation. 1️⃣ 11–15% Higher Mechanical Efficiency Compared to conventional mechanical drivetrains. No torque converter losses. No friction clutch wear components. Hardened steel power path. More energy reaches the ground — especially under load and on grade. Efficiency isn’t a headline. It’s a compounding advantage. 2️⃣ 15 KPH Sustained Hill Climb Grade performance defines cycle time. High torque at zero speed. Sustained pulling power uphill. Controlled regenerative braking downhill. We don’t claim universal savings — every haul profile is different. But faster, controlled cycles increase production capacity. 3️⃣ Lower Fuel Burn Hybrid or full BEV architecture. Regenerative capture on descent. Reduced diesel peak loading. Higher efficiency in loaded segments. Fuel remains one of the largest variable cost inputs in open pit mining. 4️⃣ 30,000+ Hour Service Life Typical overhaul intervals: ~12,000 hours. Target design life: 30,000+ hours. All hardened steel gearing. No consumable clutch packs. Designed for true mining duty cycles. Longer service life = fewer rebuilds = improved uptime = lower TCO. 5️⃣ Net Zero Impact to Payload Electrification should not compromise revenue tons. No dead weight penalty. No payload reduction. Infrastructure Reality Not every mine is ready for full BEV charging infrastructure. That’s why modularity matters. Our architecture supports: • Full BEV • Serial hybrid • Parallel hybrid Mines can reduce fuel consumption and emissions without rebuilding their entire energy infrastructure on day one. Electrification is a transition — not a binary switch. Every mine is different. Fuel costs vary. Grades vary. Duty cycles vary. But the physics don’t change. Higher efficiency. Faster cycles. Longer service life. Those levers consistently move $/Ton in the right direction. CAT 777 through 793 class. Built for owner-operators focused on long-term operating cost. If you're modeling the next 15–20 years of fleet strategy, we’re ready to run the numbers with you.

Landed for Impact — We Ask Farmers to Be Environmentally Responsible. Then We Make It Financially Impossible. This week I took a hard look at converting diesel powered irrigation pump stations to electric in North Carolina. It sounds straightforward. It. Is. Not. A comparable electric installation accounting for utility hookup, line runs, transformer upgrades, and permitting can vary by hundreds of thousands of dollars per station depending on where you are. Not because the equipment costs more, but because the utility landscape has not caught up to the opportunity. In my experience, larger investor owned utilities and electric cooperatives approach these projects very differently. Cooperatives tend to move faster, engage more directly with farm operators, and treat conversions as a priority. There is a real model there worth scaling. The gap is getting larger utilities to the same table with the same urgency. The variation is not just state to state; it’s county to county, district to district. Two farmers twenty miles apart can face dramatically different costs for an identical project. Closing that gap requires utilities, regulators, and farm operators working from the same playbook. We completed a project in Florida that took more than a year. Hundreds of emails and dozens of phone calls. The equipment and farmer were ready. Better coordination and prioritization between project developers and utilities would cut that timeline in half and make these conversions viable for far more operations. Diesel is at $5.61 per gallon nationally and large operations can spend well into six figures annually on fuel that also produces emissions. The economics of going electric are clear. The missing piece is a faster, more consistent path to get there. The emissions piece is only part of it. Diesel stations carry real risk to land and waterways; spills, leaks, and runoff move into soil, drainage systems, and the water table. Electrification removes that risk entirely. This is part of the capex conversation on every project because protecting land and waterways is not a soft benefit; it’s a measurable risk reduction and belongs in the financial case for conversion. Food security is national security. The cost of food is a pressure point for every American farmers and households. Utilities, regulators, and policymakers have a direct role to play in making farm electrification faster and more affordable. The infrastructure case is strong; the policy and collaboration just need to match it.

Feasibility of a utility-scale BESS project: 1. Site Selection Location Suitability: Evaluate the site for physical space, accessibility, and proximity to the grid connection point. Consider factors like land ownership, zoning regulations, potential for expansion. 2. Grid Connection and Integration Interconnection Requirements: Analyze the technical requirements for connecting the BESS to the grid, including voltage levels, power capacity, and grid stability. Grid Compatibility: Ensure the BESS can handle grid dynamics, such as fluctuations in voltage and frequency, and assess the system’s ability to provide ancillary services like frequency regulation or reactive power support. 3. Battery Technology Selection Technology Suitability: Compare different battery technologies (e.g., lithium-ion, flow batteries, solid-state) based on energy density, cycle life, efficiency, and response time to ensure the project’s needs. Thermal Management: Consider the thermal management requirements of the selected battery technology, including cooling systems and potential for thermal runaway. 4. System Sizing & Scalability Energy & Power Requirements: Determine the optimal size of the BESS based on the project's storage and power output. This includes peak load demands, duration of energy discharge, and frequency of cycling. Scalability: Assess the potential for future expansion and whether the system design can be scaled up to accommodate increased demand or additional storage capacity. 5. Performance and Reliability Cycle Life & Degradation: Evaluate the expected cycle life of the batteries and their degradation rate over time, considering the impact on performance and maintenance costs. System Reliability: Analyze the reliability of the entire system, including power conversion systems, inverters, and control systems. Ensure redundancy and fail-safes are in place to maintain continuous operation. 6. Control & Communication Systems EMS: Evaluate the control systems responsible for managing the charge/discharge cycles, ensuring optimal performance, and integrating with the broader energy management strategy. Communication Protocols: Ensure compatibility with existing grid communication protocols and consider the need for secure, real-time data exchange between the BESS and grid operators. 7. Energy Efficiency & Losses Round-Trip Efficiency: Calculate the round-trip efficiency of the BESS, considering losses during charging, discharging, and energy conversion. This impacts the overall economic feasibility of the project. Self-Discharge Rate: Evaluate the self-discharge rate of the batteries and how it affects long-term storage efficiency, especially for applications requiring extended storage. 8. Integration with Renewables Renewable Energy Compatibility: If the BESS is intended to integrate with renewable energy sources (e.g., solar, wind), assess the compatibility of the system in terms of variability in generation and storage. #BESS #Powersystem #renewable

𝐄𝐱𝐩𝐥𝐨𝐫𝐢𝐧𝐠 𝐄𝐕 𝐄𝐦𝐩𝐥𝐨𝐲𝐦𝐞𝐧𝐭 𝐚𝐭 𝐃𝐢𝐚𝐦𝐞𝐫 𝐁𝐚𝐬𝐡𝐚 𝐃𝐚𝐦 𝐏𝐫𝐨𝐣𝐞𝐜𝐭 ⚡🚜 At Diamer Basha Dam, our fleet includes Volvo FX400/440 dump trucks, Hyundai 40Ton excavators, Volvo front-end loaders, telescopic handlers, drilling machines (DTH, TH), and a range of utility vehicles. Currently, around 40% 𝒐𝒇 𝒐𝒖𝒓 𝒐𝒑𝒆𝒓𝒂𝒕𝒊𝒐𝒏𝒂𝒍 𝒆𝒙𝒑𝒆𝒏𝒅𝒊𝒕𝒖𝒓𝒆 𝒊𝒔 𝒄𝒐𝒏𝒔𝒖𝒎𝒆𝒅 𝒃𝒚 𝒅𝒊𝒆𝒔𝒆𝒍/𝒃𝒊𝒐𝒇𝒖𝒆𝒍– c̳o̳s̳t̳l̳y̳ ̳a̳n̳d̳ ̳e̳n̳v̳i̳r̳o̳n̳m̳e̳n̳t̳a̳l̳l̳y̳ ̳c̳h̳a̳l̳l̳e̳n̳g̳i̳n̳g̳.̳ We have been evaluating how 𝐞𝐥𝐞𝐜𝐭𝐫𝐢𝐜 𝐯𝐞𝐡𝐢𝐜𝐥𝐞𝐬 (𝐄𝐕𝐬) can transform our operations. The benefits are clear, but the key question remains: 👉 How do we sustainably charge these EVs? Charging through diesel or HFO generators is not a real solution. Instead, we are exploring a complete ecosystem: ·       𝐇𝐲𝐛𝐫𝐢𝐝 𝐫𝐞𝐧𝐞𝐰𝐚𝐛𝐥𝐞 𝐜𝐡𝐚𝐫𝐠𝐢𝐧𝐠 (solar + wind integration at site) ·       𝐁𝐚𝐭𝐭𝐞𝐫𝐲-𝐬𝐰𝐚𝐩 𝐬𝐲𝐬𝐭𝐞𝐦𝐬(already proven in large mining operations worldwide) ·       𝐇𝐢𝐠𝐡-𝐜𝐚𝐩𝐚𝐜𝐢𝐭𝐲 𝐛𝐚𝐭𝐭𝐞𝐫𝐢𝐞𝐬 balanced against financial feasibility Our fleet operate 20-𝐡𝐨𝐮𝐫 𝐝𝐚𝐢𝐥𝐲 𝐬𝐡𝐢𝐟𝐭𝐬 (10 + 10) making 𝐜𝐡𝐚𝐫𝐠𝐢𝐧𝐠 𝐭𝐢𝐦𝐞 𝐚𝐧𝐝 𝐫𝐚𝐧𝐠𝐞 𝐩𝐞𝐫 𝐜𝐲𝐜𝐥𝐞 critical. While a 60-minute charge could fit into break time, if one cycle cannot cover haulage of 8-9 trips/dump truck, we face operational constraints. This opens a larger discussion: ·       𝐁𝐚𝐭𝐭𝐞𝐫𝐲 𝐜𝐡𝐚𝐫𝐠𝐢𝐧𝐠 via 𝐫𝐞𝐧𝐞𝐰𝐚𝐛𝐥𝐞 𝐞𝐧𝐞𝐫𝐠𝐲 𝐬𝐨𝐮𝐫𝐜𝐞 vs 𝐫𝐞𝐧𝐞𝐰𝐚𝐛𝐥𝐞 𝐩𝐨𝐭𝐞𝐧𝐭𝐢𝐚𝐥 within 𝐣𝐨𝐛 𝐬𝐢𝐭𝐞? ·       Is 𝐛𝐚𝐭𝐭𝐞𝐫𝐲 𝐬𝐰𝐚𝐩𝐩𝐢𝐧𝐠 the viable path forward for continuous operations? ·       How do we balance 𝐡𝐢𝐠𝐡𝐞𝐫 𝐛𝐚𝐭𝐭𝐞𝐫𝐲 𝐜𝐚𝐩𝐚𝐜𝐢𝐭𝐲 𝐯𝐬 𝐜𝐨𝐬𝐭 𝐟𝐞𝐚𝐬𝐢𝐛𝐢𝐥𝐢𝐭𝐲? ·       What 𝐥𝐞𝐬𝐬𝐨𝐧𝐬 can 𝐭𝐮𝐧𝐧𝐞𝐥𝐢𝐧𝐠, 𝐦𝐢𝐧𝐢𝐧𝐠, 𝐚𝐧𝐝 𝐦𝐞𝐠𝐚 𝐝𝐚𝐦 𝐩𝐫𝐨𝐣𝐞𝐜𝐭𝐬 learn from each other on 𝐄𝐕 𝐢𝐧𝐭𝐞𝐠𝐫𝐚𝐭𝐢𝐨𝐧?

A feasibility study is a systematic assessment conducted before starting a project to determine whether the project is viable, practical, and worth investing in. It helps decision-makers answer the key question: “Should we proceed with this project or not?” A feasibility study evaluates potential strengths, weaknesses, opportunities, risks, costs, and benefits of a proposed project. Key Components of a Feasibility Study #Market_Feasibility Examines whether there is sufficient demand for the product or service. *Target market *Customer needs *Competition *Pricing strategy #TechnicalFeasibility Assesses whether the required technology, equipment, and skills are available to implement the project. #Organizational_Feasibility Determines whether the organization has the management capacity, structure, and human resources to run the project successfully. #FinancialFeasibility Evaluates the financial viability of the project. *Startup costs *Revenue projections *Profitability *Cash flow analysis #EnvironmentalFeasibility Assesses the environmental impact of the project and compliance with environmental regulations. #EconomicFeasibility Analyzes the broader economic benefits & costs to society (cost-benefit analysis). #Socio_CulturalFeasibility Examines whether the project aligns with community values, beliefs, and social norms. #PoliticalFeasibility Assesses government support, policies, regulations, and political risks that may affect the project.

Recovering waste heat from the biogas plant is technically feasible and can significantly increase electricity generation. An ORC system is likely the more practical and cost-effective option for this application. However, a thorough feasibility study is crucial before making any investment decisions. • Waste Heat Potential Gas engines, produces a great quantity of heat. To give an order of magnitude, these engines produce a very high percentage of its fuel energy in the form of heat. Estimating recoverable heat as a percentage of the engine's fuel input is complex, but it can be in the area of 30-50% in the form of recoverable waste heat. • Electricity Generation With an ORC system, might expect to recover 5-15% of that waste heat as additional electricity. A waste heat boiler system, if the exhaust temperature is high enough, could recover slightly more. Considering the engine specifications, the ability to generate another 10% on top of the existing electricity generation from a well designed waste heat recovery system, is a reasonable target. This would mean that the plant could produce further electricity. • Cost An ORC system for this size of application could range from RM 2 million to RM 5 million, depending on the specifications. A waste heat boiler and small steam turbine system would likely be more expensive, possibly exceeding RM 5 million. • Timeline Project planning and engineering 6-12 months. Equipment procurement 6-9 months. Installation and commissioning 6-12 months. Total estimated timeline 1.5 - 3 years. • Technical considerations The quality and consistency of the biogas fuel is very important, because it impact the exhaust gas temperature. The placement of the heat recovery equipment, is very important to keep the piping heat losses to a minimum. The correct selection of heat exchangers are a vital part of the design. • Scope Engineering design, equipment supply, installation, testing, and commissioning of the waste heat recovery system. Integration with the existing electrical grid. Necessary permitting and approvals. Key Considerations A detailed feasibility study is essential to determine the precise waste heat potential and optimize the system design. Waste heat recovery systems require regular maintenance to ensure optimal performance. The existing grid connection must be capable of handling the additional electricity generation. Perak | Mac 2025 | 1314hrs

I'm seeing industrial operators and data centers commission feasibility studies that don't answer the right questions. And with NERC's 2025 Long-Term Reliability Assessment flagging 13 of 23 regions at resource adequacy risk through 2030, the stakes just got higher. MISO, PJM, Texas ERCOT, WECC-Northwest, WECC-Basin, SERC-Central. High-risk regions. The same regions where data center and industrial load growth is heaviest. That's not a coincidence. The grid reliability problem isn't just about capacity. It's about the type of capacity. Coal retirements are accelerating. Solar and batteries are coming online fast. But when you model dispatch during tight hours (winter peaks, extreme weather), the reliability attributes aren't the same as the baseload capacity they're replacing. Layer surging peak demand from data centers and electrification on top of that, and the gap widens between what the grid can reliably deliver and what industrial operators need to run 24/7. Which brings us to behind-the-meter generation and microgrids. Legal since the 1970s. What's changed: the economics now justify it as a competitiveness strategy, not just a resiliency backup. Most industrial teams commission a feasibility study. It comes back with a topline number: "Yes, on-site generation is possible. Here's the estimated cost." That's not enough. You need to know: • What's the optimal configuration for the best price per megawatt? • How does on-site generation compare to utility rates over 10+ years, including rate escalation? • Which combination of assets (gas, solar, battery, hybrid) delivers the best economics under high growth, low growth, and base case scenarios? • How does this hold up if fuel costs spike or equipment costs come in higher? Most feasibility studies don't model that. They give you a snapshot, not a stress test. In the microgrid space, we do feasibility analysis, but it's a techno-economical study. We model your load. Simulate multiple generation configurations. Run sensitivity analysis across different futures. Compare on-site vs. utility economics even if you already have grid access. The result: you know the optimal price per megawatt configuration and whether the economics hold up when the assumptions change. That's the difference between making an informed decision and hoping the utility can keep up. —— Evaluating behind-the-meter generation or microgrid solutions for your data center or industrial facility? Let's talk. I'll walk you through what a proper techno-economical study covers and what the numbers look like for your site. Grab time on my calendar or give me a call. 🗓️ https://t2m.io/mMoKxRy | 📱 1-888-218-6001 Image Source: NERC LTRA 2025