Playbook: Adopting Industrial heat & high-temp electrification in 90 days

Industrial heat accounts for roughly 10% of global greenhouse gas emissions and remains one of the hardest sectors to decarbonize. Processes requiring temperatures above 400 degrees Celsius, including steelmaking, cement production, glass manufacturing, and petrochemical cracking, have historically depended on fossil fuel combustion because no commercially viable electric alternatives existed at scale. That picture has shifted dramatically. Electric arc furnaces, industrial heat pumps capable of delivering temperatures up to 150 degrees Celsius, resistance heating elements rated to 1,800 degrees Celsius, and plasma torches reaching beyond 5,000 degrees Celsius have moved from laboratory demonstrations to commercial procurement catalogs. The question is no longer whether electrification of industrial heat is technically feasible but how quickly individual facilities can execute the transition.

This playbook provides a structured 90-day framework for moving from initial assessment to an operational pilot, drawing on documented deployments across steel, ceramics, food processing, and chemical manufacturing. The approach is designed for founders, plant managers, and sustainability leaders who need a concrete path forward rather than another technology survey.

Why It Matters

The urgency behind industrial heat electrification stems from converging regulatory, economic, and market forces. The EU Carbon Border Adjustment Mechanism (CBAM) began its transitional phase in October 2023 and will impose full carbon costs on imported steel, cement, aluminum, fertilizers, and electricity starting January 2026. For manufacturers exporting to Europe, the effective carbon price is projected to exceed 90 euros per tonne of CO2 by 2027, according to BloombergNEF analysis. Facilities that fail to decarbonize will face either direct carbon costs or loss of market access.

In the United States, the Inflation Reduction Act's Section 48C Advanced Energy Project Credit provides up to 30% investment tax credits for industrial decarbonization equipment, including electric heating systems. The Department of Energy's Industrial Demonstrations Program has allocated $6.3 billion for clean energy deployment in heavy industry. These incentives fundamentally alter the economics of electrification projects that would have been marginal even two years ago.

Electricity prices also favor the transition in many regions. Industrial electricity rates in the US averaged $0.073 per kilowatt-hour in 2025, while natural gas prices remained volatile, ranging from $2.50 to $6.80 per MMBtu depending on region and season. Electric heating systems typically achieve 90-98% energy conversion efficiency compared to 30-80% for combustion systems, meaning the effective cost per unit of delivered heat is increasingly competitive, particularly where facilities can access renewable power purchase agreements at $0.03-0.05 per kilowatt-hour.

Buyer pressure compounds the regulatory push. Major procurement organizations, including the US General Services Administration, the First Movers Coalition (representing over $12 billion in advance purchase commitments for green materials), and automotive OEMs with Science Based Targets, now require suppliers to demonstrate credible decarbonization pathways or risk disqualification from bidding processes.

Key Concepts

Process Heat Temperature Tiers categorize industrial heating requirements by temperature range, each associated with different electrification technologies. Low-temperature heat (below 150 degrees Celsius) covers applications such as drying, pasteurization, and space heating, addressable with industrial heat pumps achieving coefficients of performance (COP) of 3-5. Medium-temperature heat (150-400 degrees Celsius) serves steam generation, distillation, and certain chemical processes, increasingly covered by high-temperature heat pumps and electric boilers. High-temperature heat (400-1,000 degrees Celsius) encompasses ceramics, glass, and some metals processing, typically addressed through resistance heating or induction furnaces. Ultra-high-temperature heat (above 1,000 degrees Celsius) is required for steelmaking, cement clinker production, and certain chemical reactions, requiring electric arc furnaces, plasma torches, or concentrated solar thermal systems.

Thermal Energy Storage (TES) enables electrified facilities to decouple electricity consumption from production schedules, storing heat in materials such as molten salt, crusite bricks, or phase-change media during periods of low electricity prices and releasing it during production. Rondo Energy's commercial systems store heat at up to 1,500 degrees Celsius with round-trip efficiency exceeding 90%, allowing industrial facilities to arbitrage electricity prices and maximize renewable energy utilization.

Grid Connection and Power Density represent critical planning variables. Electric heating systems demand significantly more electrical capacity than the equipment they replace. A typical 10 MW natural gas furnace delivering 7 MW of useful heat requires replacement with an electric system drawing 7-8 MW from the grid. Facilities must assess available grid capacity, transformer sizing, and potential need for dedicated substations, a process that can take 12-18 months if grid upgrades are required.

Measurement, Reporting, and Verification (MRV) for industrial heat electrification involves documenting baseline emissions, tracking electricity consumption and source (grid mix versus contracted renewables), and reporting Scope 1 reductions under frameworks such as the GHG Protocol and SBTi. Credible MRV is essential for capturing the commercial value of decarbonization through green premiums, carbon credit generation, or regulatory compliance.

The 90-Day Framework

Days 1-15: Baseline Assessment and Stakeholder Alignment

The first two weeks focus on establishing the factual foundation for the project. Begin by mapping every thermal process in the facility, categorizing each by temperature requirement, duty cycle, annual energy consumption, and current fuel source. This thermal audit should produce a process heat map showing where energy enters and exits the production system.

Quantify the baseline: total annual fuel consumption (in MMBtu or GJ), associated Scope 1 emissions (in tonnes CO2e), fuel costs, and maintenance expenditures for combustion equipment. Include the age and remaining useful life of existing burners, boilers, and furnaces. Equipment approaching end-of-life represents the highest-value electrification targets because replacement costs are already budgeted.

Simultaneously, engage the facility's electrical utility to understand available grid capacity at the point of connection. Request a load study or interconnection pre-screening to identify whether existing infrastructure can accommodate the additional electrical demand. Document the current electricity tariff structure, including demand charges, time-of-use rates, and any available industrial incentive programs.

Convene a cross-functional alignment meeting with plant operations, engineering, finance, procurement, and sustainability leadership. Present the baseline data and secure agreement on project objectives: target processes for electrification, acceptable payback period, and required production continuity during transition. This meeting should produce a signed project charter with explicit executive sponsorship.

Lhoist, a global lime and minerals producer, completed this baseline phase across three European plants in under two weeks by deploying portable energy monitoring equipment on all combustion assets simultaneously, generating comprehensive heat maps without interrupting production.

Days 16-40: Technology Selection and Vendor Engagement

With the baseline established, match each target process to available electrification technologies. For processes below 200 degrees Celsius, evaluate industrial heat pumps from manufacturers such as Vattenfall, MAN Energy Solutions, and Siemens. For 200-1,000 degrees Celsius, assess electric resistance heating from Kanthal (Sandvik), induction systems from Inductotherm, or infrared heating from Heraeus. For temperatures above 1,000 degrees Celsius, consider electric arc furnace solutions from Tenova, plasma heating from PyroGenesis, or thermal storage from Rondo Energy and Antora Energy.

Issue a structured request for information (RFI) to at least three vendors per temperature tier. The RFI should specify: process temperature and tolerance, thermal duty (in MW or kW), duty cycle and ramp rate requirements, available electrical supply (voltage, phases, and capacity), physical space constraints, and required integration with existing process controls. Request reference installations with verified performance data, not marketing materials.

Evaluate responses against five criteria: technical fit (can the system meet process specifications), capital cost (total installed cost including balance of plant), operating cost (electricity consumption at projected rates), implementation timeline (from order to commissioning), and vendor track record (number of comparable installations and years of commercial operation).

SSAB, the Swedish steelmaker, selected Tenova's electric arc furnace technology for its HYBRIT initiative after a six-week evaluation process involving site visits to three reference installations, thermal modeling of the specific steel grades required, and detailed grid capacity analysis with the local utility Vattenfall. The evaluation phase invested approximately 400 engineering hours but avoided a potential $15 million stranded asset risk from selecting an unsuitable technology.

Days 41-65: Pilot Design and Procurement

Design the pilot around a single process or production line that is representative of broader facility operations but not on the critical path for customer deliveries. The pilot should run long enough to capture at least two full production cycles and ideally span different seasonal conditions affecting electricity prices and grid load.

Define success metrics before procurement. At minimum, track: delivered heat quality (temperature stability, uniformity), energy consumption per unit of output, product quality compared to baseline (dimensional accuracy, material properties, surface finish), system reliability (uptime percentage), and total cost per unit of output including electricity, maintenance, and amortized capital.

Secure financing and incentives in parallel with equipment procurement. In the US, file for Section 48C tax credits, which require DOE allocation but can reduce effective capital cost by 30%. In the EU, access the Innovation Fund, which has allocated 40 billion euros for industrial decarbonization through 2030. State and regional incentives vary substantially; the Database of State Incentives for Renewables and Efficiency (DSIRE) provides a searchable catalog of US programs.

Place equipment orders with clear delivery and commissioning milestones. Negotiate performance guarantees tied to the success metrics defined above. Include liquidated damages clauses for delays and performance shortfalls, with bonus provisions for exceeding targets.

Bormioli Pharma, an Italian glass packaging manufacturer, designed its pilot around a single glass melting furnace, running the electric system in parallel with the existing gas furnace for 60 days. This approach allowed direct performance comparison under identical production conditions while maintaining supply continuity for pharmaceutical customers who required uninterrupted delivery.

Days 66-90: Installation, Commissioning, and Operational Learning

Installation timelines vary by technology and complexity. Industrial heat pumps for low-temperature applications can be installed in 2-3 weeks. High-temperature resistance heating systems typically require 4-6 weeks including electrical infrastructure modifications. Electric arc furnaces and major process changes may need 8-12 weeks, potentially extending the 90-day framework.

Commission the system in stages: electrical connectivity verification, no-load testing, partial-load operation, and full-load production trials. Document performance against baseline metrics at each stage. Record all anomalies, adjustments, and operator observations in a structured commissioning log.

During the first two weeks of operation, maintain the previous heating system as backup. This dual-running period provides a safety net while operators develop familiarity with the new equipment's control characteristics, ramp rates, and response to process disturbances.

Train operations and maintenance staff on the new equipment before full handover. Electric heating systems require different maintenance competencies than combustion equipment: high-voltage safety, element replacement procedures, and power electronics diagnostics replace burner tuning, flame detection, and flue gas analysis.

Conduct a formal 90-day review with all stakeholders. Present measured performance against the success metrics established during pilot design. Quantify actual energy savings, emissions reductions, product quality outcomes, and total cost of ownership. Use this data to build the business case for full-scale rollout across remaining processes and facilities.

Action Checklist

• Complete a facility-wide thermal process audit mapping every heat source by temperature, duty cycle, and annual energy consumption
• Request a grid capacity assessment and interconnection study from the local utility
• Identify processes approaching end-of-life for combustion equipment as priority electrification targets
• Issue structured RFIs to at least three vendors per temperature tier with detailed process specifications
• File for applicable tax credits and incentive programs before equipment procurement
• Design a pilot around a non-critical production line with defined success metrics
• Negotiate performance-guaranteed contracts with vendors including commissioning milestones
• Train operations and maintenance staff on electric heating equipment before system handover
• Conduct a formal 90-day review with measured performance data to inform full-scale rollout decisions

FAQ

Q: What is the typical payback period for industrial heat electrification projects? A: Payback periods range from 2-7 years depending on the temperature tier, local electricity and gas prices, and available incentives. Low-temperature heat pump installations in regions with favorable electricity rates often achieve payback within 2-3 years due to their high COP. High-temperature applications such as electric arc furnaces have longer payback periods of 5-7 years but can be significantly accelerated by carbon pricing (each $50 per tonne CO2 shaves approximately 1-2 years off payback) and investment tax credits. With the 30% Section 48C credit in the US, many projects shift from marginal to clearly economic.

Q: How do I handle grid capacity constraints if the utility cannot supply additional power? A: Three strategies address grid constraints. First, deploy on-site thermal energy storage to flatten demand profiles, drawing power during off-peak periods and storing heat for production use. Second, install on-site renewable generation (rooftop or ground-mount solar, or behind-the-meter wind) to offset a portion of grid demand. Third, phase the electrification across multiple grid upgrade cycles, converting low-power processes first while the utility invests in infrastructure for larger loads. Some facilities combine all three approaches.

Q: Will product quality change when switching from gas-fired to electric heating? A: In most applications, electric heating delivers equal or superior quality compared to combustion. Electric systems provide more precise temperature control (typically plus or minus 1-2 degrees Celsius versus plus or minus 5-10 degrees Celsius for gas burners), more uniform heat distribution (eliminating hot spots from flame impingement), and a cleaner process atmosphere (no combustion gases contacting the product). Glass, ceramics, and metals producers consistently report improved product consistency after electrification. The primary exception is processes that rely on combustion atmosphere chemistry, such as certain direct-fired drying applications, which may require reformulation.

Q: Can I electrify only part of a process while keeping gas for the rest? A: Hybrid approaches are common and often represent the most pragmatic path. Many facilities electrify preheating stages (which operate at lower temperatures and benefit most from heat pump COPs) while retaining gas for the highest-temperature steps. This can capture 40-60% of available emissions reductions at 30-50% of the capital cost of full electrification. The hybrid approach also reduces grid capacity requirements and provides operational flexibility during the transition.

Q: What happens to my Scope 1 emissions if I switch to grid electricity that still includes fossil generation? A: Switching from on-site combustion to grid electricity converts Scope 1 (direct) emissions to Scope 2 (purchased electricity) emissions. The net emissions impact depends on the grid's carbon intensity. In regions with carbon-intensive grids (above 600g CO2/kWh), the emissions benefit may be modest without contracted renewable electricity. However, facilities can eliminate this issue by procuring 24/7 carbon-free energy through power purchase agreements, renewable energy certificates, or on-site generation. Under GHG Protocol market-based accounting, facilities purchasing 100% renewable electricity report zero Scope 2 emissions regardless of grid mix.

Sources

• International Energy Agency. (2025). Electrification of Industrial Heat: Technology Readiness and Deployment Status. Paris: IEA Publications.
• BloombergNEF. (2025). Industrial Decarbonization Outlook: Heat Electrification Economics and Market Sizing. New York: Bloomberg LP.
• US Department of Energy. (2025). Industrial Demonstrations Program: Project Portfolio and Lessons Learned. Washington, DC: DOE Office of Clean Energy Demonstrations.
• European Commission. (2025). Innovation Fund: Large-Scale Industrial Decarbonization Projects, Annual Report. Brussels: EC Directorate-General for Climate Action.
• McKinsey & Company. (2025). The Net-Zero Transition in Heavy Industry: Technology Pathways and Investment Requirements. New York: McKinsey Global Institute.
• Rondo Energy. (2025). Commercial Deployment Data: Industrial Heat Storage Performance Across Five Installations. Oakland, CA: Rondo Energy Inc.
• SSAB. (2025). HYBRIT Initiative: Progress Report on Fossil-Free Steel Production. Stockholm: SSAB AB.