As a county utility, how do we add reliable clean baseload power over the next decade?

Adding reliable, clean baseload (or "clean firm") power as a county utility over the next decade requires navigating rising electricity demand , long interconnection queues, and strict reliability standards. Because traditional wind and solar are intermittent, and fossil fuels face regulatory and decarbonization pressures, a county utility must deploy a diversified strategy tailored to its size, geography, and access to capital.

The most viable technological and strategic pathways for a county utility over the next ten years include:

1. Next-Generation Geothermal (Enhanced Geothermal Systems - EGS / XGS)

• Why it works: Unlike hydrothermal power limited to specific surface geysers, new closed-loop or enhanced geothermal techniques use advanced drilling to tap hot rock nearly anywhere. It provides 24/7 zero-carbon baseload power with a tiny land footprint.
• Action: Partner with specialized next-gen developers or join a Joint Powers Authority (JPA) / Community Choice Aggregation (CCA) to aggregate procurement power, reducing individual financial exposure to exploratory drilling.

1. Advanced Small Modular Nuclear Reactors (SMRs)

• Why it works: SMRs offer factory-fabricated, scalable nuclear power ranging from 10 MW to 300 MW, fitting the smaller load profile of a county utility much better than massive gigawatt-scale traditional plants. They provide consistent, weather-independent carbon-free power.
• Action: Monitor Department of Energy (DOE) and early-adopter municipal utility partnerships. Consider regional consortium models to share the heavy initial capital expenditure and regulatory licensing costs.

1. Optimized Hydroelectric and Pumped Storage

• Why it works: If your county has existing water infrastructure, retrofitting or upgrading local small-dams or partnering on regional pumped storage hydro provides both traditional baseload stability and rapid-response flexibility to balance intermittent solar and wind.
• Action: Audit local water and sanitation districts. Treat wastewater effluent can also be repurposed to sustain local geothermal or cooling reservoirs.

1. Clean Firm Peakers & Gas with Carbon Capture / Hydrogen Readiness

• Why it works: While not purely zero-emission on day one, highly efficient combined-cycle gas turbines equipped with fast-start capabilities, or utilizing zero-emission green hydrogen/blended fuels and Carbon Capture, Utilization, and Storage (CCUS), act as a reliable bridge.
• Action: Ensure any new thermal generation investments feature fuel-flexible or modular designs so they can transition to net-zero fuels as regional supply chains mature.

1. Virtual Power Plants (VPPs) and Hybrid Pairing

• Why it works: While storage doesn't "generate" baseload energy, pairing utility-scale solar/wind with long-duration energy storage (4+ hours) alongside aggregated demand-response (VPPs) reduces the total amount of expensive clean firm capacity you need to build.
• Action: Implement smart rate designs and local distributed energy resource (DER) management on county-owned land or closed landfills to shave peak demand.

To help narrow down the best path for your specific utility, tell me:

• What is your approximate peak load (MW) and current generation mix?
• Are you operating as an independent balancing authority or tied to a larger RTO/ISO market?

Yes. For a county utility planning on a 10-year horizon (2026–2036), I would not treat “baseload” as one technology. I’d build a clean-firm portfolio: resources that can reliably serve load through nights, heat waves, winter storms, and prolonged renewable shortfalls.

DOE’s current definition of clean firm includes nuclear, hydropower, geothermal, and renewables paired with long-duration storage. Its recent modeling also finds that batteries and demand response are important but do not eliminate the value of clean-firm resources.

My recommended portfolio

1. Make nuclear your first serious clean-firm procurement

If your county has sufficient load—say 100+ MW of dependable demand—I'd investigate joining a multi-utility nuclear procurement rather than trying to build a reactor independently.

The nuclear market is moving toward the 2030s: DOE says recent programs are aimed at Gen III+ SMR deployment in the 2030s, while its 2026 supply-chain financing is supporting long-lead equipment for 10 large reactors.

There is also a potentially attractive strategy: brownfield nuclear sites. DOE estimates roughly 60–95 GW of new nuclear capacity could potentially be developed at existing or recently retired nuclear sites.

For a county utility, I'd therefore explore:

• joining an existing reactor consortium;
• taking a minority ownership position;
• signing a 15–25-year nuclear PPA;
• evaluating an existing nuclear-site redevelopment;
• or reserving capacity in a credible SMR program.

I would not make an unproven reactor design the centerpiece of the county's reliability plan.

2. Treat geothermal as the wildcard worth investigating now

Geothermal is unusually attractive because it can provide the characteristic you actually want: high-capacity-factor, dispatchable, zero-carbon generation.

Conventional geothermal depends heavily on geography, but enhanced geothermal systems (EGS) could greatly expand the geography. DOE is currently funding EGS pilots and explicitly describes geothermal as a source of firm, flexible power.

So I'd commission a county/regional geothermal resource assessment immediately.

If the geology works, a 50–200 MW geothermal project could be much more strategically valuable to you than another tranche of intermittent generation.

3. Build lots of cheap energy—but don't confuse energy with reliability

I'd still procure substantial solar and wind.

But I'd change the procurement question from:

“How many megawatts of renewable energy can we buy?”

to:

“How many MW can you guarantee us at 7 p.m. during a 10-day regional weather event?”

That's a very different contract.

Pair renewable generation with storage of different durations:

• 2–4 hours: daily solar shifting and peak shaving
• 8–12 hours: evening/overnight reliability
• 24–100+ hours: multi-day renewable droughts and extreme events

The point isn't to make batteries provide all your baseload. It's to prevent your expensive firm generation from having to chase every short-duration fluctuation.

4. Preserve a reliability backstop

I'd be reluctant for a county utility to eliminate its last dispatchable thermal capability before it has replacement firm capacity.

Instead, establish a shrinking reliability reserve.

For example:

2026–2030:
Renewables + storage + existing dispatchable fleet

2030–2033:
Add nuclear/geothermal/hydro contracts; retire the least-efficient thermal units

2033–2036:
Clean-firm resources become the backbone; retain a small amount of thermal capacity for rare emergencies

That gives you insurance against technology, permitting, transmission, and construction delays.

5. Procurement matters more than technology

I'd create a Clean Firm RFP rather than an RFP for nuclear, geothermal, or storage.

Require bidders to demonstrate:

• guaranteed MW availability;
• maximum outage duration;
• performance during extreme weather;
• fuel/resource security;
• 10-, 20-, and 30-year cost;
• transmission requirements;
• construction schedule;
• permitting risk;
• emissions;
• black-start capability;
• ancillary-service capability;
• and penalties for failing reliability commitments.

Then compare technologies on $/MW-year of dependable capacity, not merely $/MWh of energy.

A plausible county strategy

For every 100 MW of new dependable load, I would initially investigate something like:

30–50 MW nuclear/firm generation

• 10–20 MW geothermal/hydro
• 100–200 MW renewable generation
• 50–100 MW / 8–12+ hour storage
• demand response equivalent to 10–20 MW
• 50–100 MW emergency backup

Those aren't prescriptions—the right ratios depend heavily on your existing generation, transmission, load shape, and regional market. But the architecture is important: don't try to make one resource do everything.

The biggest strategic mistake to avoid

Don't wait until 2031 to start looking for firm capacity.

Nuclear and geothermal have long development cycles, and transmission can take years. DOE's nuclear commercialization analysis explicitly argues that waiting until the mid-2030s to begin deployment could create serious decarbonization and supply-chain problems.

I'd therefore spend 2026–2027 doing three things simultaneously:

1. Lock down 2030–2036 clean-firm options — nuclear, geothermal, hydro and regional PPAs.
2. Build the renewable + storage pipeline — these are generally faster.
3. Plan transmission and interconnection around the firm resources, rather than treating transmission as an afterthought.

If you tell me the county/state, current peak load, annual MWh, existing generation/PPAs, and expected 2035 peak, I can turn this into a specific 10-year resource plan with MW targets, procurement sequence, reliability logic, and rough capital/PPA economics.

If the objective is reliable, clean baseload power over the next decade, the answer is unlikely to be a single technology. The lowest-risk strategy for most county or municipal utilities is to build a portfolio of "clean firm" resources while aggressively improving system flexibility.

A practical roadmap looks like this:

1. Treat "baseload" as "clean firm capacity"

Many utilities are shifting away from planning around "baseload" and instead procure clean firm capacity—resources that can operate at high availability regardless of weather while providing grid stability. DOE identifies advanced nuclear, geothermal, hydropower upgrades, and fossil generation with carbon capture as examples, while noting that these projects require long lead times and should begin planning now if they are expected to be online within the next decade.

2. Make next-generation geothermal your first technology to evaluate

If your geology is suitable—or if regional power purchases are possible—next-generation geothermal deserves serious consideration.

Advantages include:

• 90–95% capacity factors
• Zero fuel price risk
• Minimal land footprint
• 24/7 dispatchability
• Uses drilling expertise already common in the oil and gas industry

Recent utility procurements in California specifically targeted clean firm resources, resulting in geothermal contracts because they complement wind and solar well. Costs and drilling timelines have been improving rapidly.

3. Don't wait for SMRs—but keep them in the plan

Small modular reactors (SMRs) could become an excellent county-scale clean baseload option, but most deployments remain later in the decade.

For planning purposes:

• Reserve potential sites
• Preserve transmission access
• Participate in regional SMR partnerships
• Avoid assuming commercial operation before the early-to-mid 2030s unless a specific project is well underway

Many utilities are modeling SMRs today as a long-term option rather than relying on them for near-term capacity.

4. Build lots of renewables—but don't expect them to replace firm power alone

Solar and wind reduce fuel costs dramatically.

However, during:

• winter storms
• cloudy weeks
• calm weather
• evening peaks

you still need dependable generation.

The emerging consensus is that renewables should be paired with:

• 4–8 hour batteries
• long-duration storage
• clean firm generation

rather than viewed as a complete substitute for firm resources.

5. Invest in long-duration storage

Most batteries today cover only a few hours.

Future reliability increasingly depends on storage capable of:

• 10–100+ hours
• shifting renewable energy across multiple days
• reducing the amount of firm generation that must be built

This won't replace firm generation entirely, but it can substantially reduce how much is needed.

6. Upgrade the grid before building more generation

Many county utilities can defer expensive generation by improving:

• transmission utilization
• reconductoring existing lines
• advanced power-flow controls
• substation modernization
• demand response
• industrial load flexibility

Recent utility plans increasingly include these measures because they often deliver reliability faster and at lower cost than new power plants.

7. Procure portfolios instead of individual plants

Rather than asking, "Should we build a geothermal plant or solar farm?", leading utilities ask:

"What combination provides the lowest cost while meeting reliability targets?"

A representative portfolio for a county utility in the 2030–2035 timeframe might look like:

• 35–45% solar
• 10–20% wind (where available)
• 15–25% batteries
• 20–35% clean firm generation (geothermal, hydro, nuclear, or similar)
• demand response and efficiency equivalent to several percent of peak demand

The exact mix depends on local resources, load shape, transmission, and policy goals.

Bottom line

For a county utility planning over the next decade, the most resilient strategy is likely to be:

1. Build solar and conventional batteries aggressively where economical.
2. Modernize transmission and distribution to unlock existing capacity.
3. Procure at least one source of clean firm power—preferably next-generation geothermal where feasible, with SMRs, hydropower upgrades, or other firm low-carbon options evaluated in parallel.
4. Add long-duration storage as it becomes commercially competitive.
5. Use demand-side flexibility to reduce required generation capacity.

This approach avoids overreliance on any single technology while improving reliability, reducing emissions, and limiting exposure to future fuel-price volatility.

Adding reliable, clean baseload (or "clean firm") power over the next decade as a county or municipal utility requires balancing strict local accountability, long-term capital budgeting, and evolving grid realities (like surging industrial and data center demand).

Traditional baseload is shifting away from unmitigated coal and gas toward 24/7 carbon-free resources. A strategic, step-by-step roadmap tailored for a county utility over the 2026–2036 timeframe involves the following key pathways and actions:

• Enhanced Geothermal Systems (EGS): No longer limited to volcanic regions, next-generation EGS uses advanced oil and gas drilling techniques to tap consistent underground heat anywhere. Partnering with developers utilizing closed-loop binary generators provides a zero-emission, weather-independent 24/7 resource.
• Advanced Nuclear & Small Modular Reactors (SMRs): SMRs and microreactors offer factory-built, scalable nuclear power suited for smaller footprints. While upfront capital costs remain a hurdle, county utilities can monitor or participate in regional nuclear innovation hubs or pursue joint-action agency contracts to share financial exposure.
• Biogas, Biomass, and Waste-to-Energy (WtE): Capturing methane from local county landfills, wastewater treatment plants, or utilizing localized organic waste streams via mass-burn or advanced conversion allows a county to turn local waste into firm, localized electrons while reducing fugitive emissions.
• Clean Peaking and Firming via Microgrids / VPPs: Instead of massive centralized builds, combining localized high-efficiency natural gas assets paired with future carbon capture readiness, or deploying modular Virtual Power Plants (VPPs) and long-duration energy storage (LDES), helps bridge reliability gaps without breaking municipal credit ratings.
• Strategic Procurement via All-Source RFPs: Rather than owning everything outright, leverage All-Source Competitive Bidding through your regional generation and transmission (G&T) cooperative or joint action agency to let private developers take construction risk on clean firm power purchase agreements (PPAs).

To help narrow down the best technological and financial mix for your specific county, could you share:

• What is your approximate peak load (MW) and current ownership vs. purchase mix?
• Are you part of a Joint Action Agency or G&T cooperative , or do you operate independently within an RTO/ISO market?

For most county or municipal utilities, the question is less "What single technology should we build?" and more "What portfolio provides reliable, affordable, low-carbon electricity 24/7?" Over the next decade, the strongest strategies combine clean firm generation, storage, demand flexibility, and transmission rather than relying on any one resource.

A practical roadmap looks something like this:

The realistic clean baseload options

1. Existing hydro (if available)

• Excellent clean baseload
• Long asset life
• Usually expansion opportunities are limited

2. Geothermal One of the few truly clean baseload technologies operating today.

Advantages:

• 90–95%+ capacity factor
• Dispatchable
• Very low emissions
• Complements wind and solar well

Limitations:

• Resource dependent
• Multi-year development
• Exploration risk

Enhanced geothermal is expanding the number of viable locations, but commercial deployment is still scaling.

3. Nuclear (SMRs or large reactors) Advantages:

• Carbon-free
• Very high reliability
• Excellent for growing loads

Challenges:

• Long permitting
• High capital cost
• Commercial SMRs are still emerging in the U.S.

For projects entering service by the mid-2030s, planning generally needs to begin well before 2030.

What probably should not be considered baseload

Modern utility planning increasingly focuses on resource adequacy or clean firm capacity rather than traditional "baseload." Solar and wind can supply a large share of annual energy, but they generally need storage, transmission, flexible demand, or firm resources to maintain reliability during periods of low renewable output.

Long-duration storage is becoming a major piece

Instead of sizing clean firm generation to meet every hour of demand, many utilities are adding:

• pumped hydro
• iron-air batteries
• flow batteries
• compressed-air storage
• thermal storage

These technologies help bridge multi-day renewable shortfalls while reducing the amount of firm generation required.

Don't overlook "virtual power plants"

A county utility often gains more reliability per dollar by controlling load than by building generators.

Examples include:

• smart water heaters
• managed EV charging
• commercial HVAC control
• industrial interruptible loads
• distributed batteries

These resources can reduce system peaks, defer infrastructure upgrades, and improve resilience.

If I were advising a county utility today

For a 10-year planning horizon, I'd target something like:

• 20–30% demand reduction through efficiency and demand response
• Significant solar deployment
• 4–8 hour battery storage for daily balancing
• Long-duration storage for resilience
• A firm clean resource (geothermal if feasible, otherwise participation in a regional SMR or other clean-firm project as it becomes commercially available)
• Expanded transmission or regional power purchases to improve access to diverse resources

This diversified approach avoids betting the utility's future on any single technology while improving reliability, lowering emissions, and managing costs.

If you tell me:

• your state,
• the utility's peak load (MW),
• annual energy sales (GWh),
• and whether you're part of a regional transmission organization (such as PJM, MISO, SPP, CAISO, or ERCOT),

I can outline a resource mix that is realistic for your service territory and estimate the capacity additions needed over the next decade.

Adding reliable clean baseload power as a county utility over the next decade requires a diversified portfolio approach , blending proven clean technology with emerging "firm" power sources to meet 24/7 demand, rather than relying on a single technology.

Key strategies for a county utility:

1. Adopt "Clean Firm" Power Technologies
Unlike intermittent wind or solar, clean firm power provides consistent energy.

• Geothermal Energy: Provides reliable, 24/7 power with a low land footprint, suitable for areas with high heat flow.
• Advanced Nuclear / Small Modular Reactors (SMRs): Offers consistent, high-capacity power with smaller footprints and improved safety, ideal for replacing retiring coal or large gas units.
• Biomass/Waste-to-Energy with CCS: Utilizing organic waste or forestry residues to produce power while capturing carbon (CCS) provides consistent electricity and negative emissions.
• Existing Hydro Upgrades: Modernizing existing local hydropower facilities to increase capacity.

2. Implement Long-Duration Energy Storage (LDES)
To bridge gaps when renewables are not producing, invest in storage that lasts longer than standard four-hour lithium-ion batteries.

• Pumped Hydro Storage: If geography permits, this is the most established long-duration solution.
• Flow Batteries & Thermal Storage: Developing new storage technologies that can discharge for 10+ hours.

3. Develop "Clean Repowering" of Existing Assets
As fossil fuel plants are retired, use existing site interconnection points for clean energy, which speeds up deployment and saves on infrastructure costs.

• Gas to Hydrogen: Transitioning existing natural gas turbines to run on clean hydrogen.
• Retrofit with CCS: Adding carbon capture and storage (CCS) to existing natural gas plants.

4. Enhance Transmission and Grid Flexibility

• Grid-Enhancing Technologies (GETs): Using advanced conductors and power flow controllers to increase the capacity of existing lines, offering a faster and cheaper alternative to building new lines.
• Virtual Power Plants (VPPs): Aggregating distributed resources (residential solar, batteries, electric vehicle charging) to act as a reliable, centralized generator.

5. Leverage Financial Incentives and Planning

• IRA Funding: Utilize federal incentives like the Energy Infrastructure Reinvestment program before they expire.
• Diversify Risk: Instead of a single large plant, develop multiple, smaller, diverse clean projects to mitigate supply chain or technology failures.

To provide a more tailored roadmap, could you tell me:

• What is your primary source of power today?
• What is the current peak demand and anticipated growth (e.g., new data centers)?
• Are you located in a region with specific resources (e.g., high wind, high solar , or geothermal potential)?

If I were advising a county utility board today, I would shift the discussion away from "baseload" as the objective and toward "24/7 clean firm capacity and system reliability." Traditional baseload (plants that run continuously) is one way to achieve reliability, but modern utilities increasingly value resources that can provide dependable capacity when needed while integrating lower-cost renewables.

A practical portfolio over the next decade could look like this:

For the clean firm generation piece, the leading options are:

1. Advanced geothermal (highest near-term potential where resources exist)

The U.S. Department of Energy views geothermal as one of the few renewable technologies capable of providing continuous, high-capacity-factor generation that complements wind and solar. Enhanced geothermal systems are expanding the number of viable locations beyond traditional geothermal regions.

Pros:

• 24/7 operation
• Very low emissions
• Small land footprint
• High capacity factor

Challenges:

• Site-specific geology
• Exploration and drilling risk

2. Existing or new nuclear (best long-term firm resource)

Small modular reactors (SMRs) are promising for municipal and cooperative utilities, but widespread deployment at scale is more likely in the early 2030s than immediately. Nuclear provides carbon-free, around-the-clock generation but requires long planning horizons and substantial capital.

Pros:

• Excellent reliability
• Zero operational CO₂ emissions
• Long asset life

Challenges:

• High capital cost
• Licensing and construction timelines

3. Hydroelectric (where available)

If your utility has access to hydro resources or regional contracts, hydro remains one of the best clean firm resources.

4. Long-duration storage

Multi-hour and multi-day storage will become increasingly important for replacing fossil peakers, although economics remain highly dependent on region and technology maturity.

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Don't overlook the "virtual power plant"

Many utilities can defer hundreds of megawatts of new generation by investing in:

• Smart thermostats
• Water heater controls
• Commercial load management
• EV managed charging
• Time-of-use rates

These programs often cost much less than building new power plants while improving reliability.

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A balanced resource mix

Rather than relying on a single technology, many planners favor something like:

• 40–60% wind and solar
• 20–30% clean firm generation (geothermal, nuclear, hydro)
• 10–20% storage
• Flexible demand and transmission enhancements throughout

This combination balances cost, emissions, and resilience under a wide range of operating conditions.

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For a county utility

If you're responsible for serving local customers rather than operating a large regional generation fleet, I would prioritize:

1. Strengthen transmission and substations.
2. Expand demand response and distributed energy resources.
3. Build solar with 4–8 hour batteries where economical.
4. Secure long-term contracts for clean firm power (geothermal, hydro, or nuclear) rather than owning every asset.
5. Evaluate participation in future SMR or advanced geothermal projects if they become commercially viable in your region.

That approach adds reliable clean capacity incrementally, limits financial risk, and preserves flexibility as technologies mature and demand evolves. It also aligns with growing industry emphasis on maintaining adequate dependable capacity as electricity demand increases.

Adding reliable, clean baseload power—electricity that is available 24/7 without carbon emissions—requires a diversified portfolio approach, rather than relying on a single large power plant.

Over the next decade, utilities can build this capacity by utilizing technologies that complement renewable energy, upgrading infrastructure, and employing advanced firm power sources.

1. Invest in Clean "Firm" Generation Technologies

• Advanced Geothermal Energy: Unlike traditional geothermal, new systems can be located almost anywhere, providing continuous, 24/7 power.
• Small Modular Reactors (SMRs) or Advanced Nuclear: While requiring significant planning, small-scale nuclear provides reliable, carbon-free baseload power.
• Biomass/Waste-to-Energy: Systems that transform organic waste into electricity can provide 24/7 consistency while capturing carbon.
• Hydrogen/Green Hydrogen: Used for energy storage or to replace natural gas in turbines, providing a cleaner firming capacity.

2. Deploy Long-Duration Energy Storage (LDES)

• Pumped Hydro & Advanced Compressed Air: Utilize hard rock storage systems to store energy from wind and solar and release it during high demand, providing 8+ hours of power.
• Battery Energy Storage Systems (BESS): Utility-scale batteries help manage peak demand and store excess solar/wind energy for immediate use.

3. Optimize Existing Infrastructure & Grid Upgrades

• Reconductoring & Grid-Enhancing Technologies (GETs): Upgrading existing transmission lines with advanced materials can increase capacity by 10-30% in just a few years without new lines.
• Virtual Power Plants (VPPs): Aggregating rooftop solar, home batteries, and electric vehicles into a virtual plant to stabilize the grid and manage demand.
• Streamline Permitting: Actively work to shorten the timeline for permitting and interconnecting new projects, which is crucial for delivering new supply within 10 years.

4. Portfolio Diversification and Hybrid Systems

• Hybrid Projects: Pair large-scale solar or wind with onsite battery storage to create a more consistent, pseudo-baseload supply.
• Demand-Side Flexibility: Implementing smart grid technologies to incentivize customers to shift energy use to off-peak hours, reducing the need for new, expensive baseload generation.

Recommended Strategy: Focus on accelerating the deployment of geothermal and LDES while leveraging federal investments to upgrade transmission lines for a "mixture" of renewables, storage, and clean firm sources.

To provide a more tailored roadmap, could you share:

• What is the current energy mix (e.g., % coal, % gas, % renewables)?
• What is the primary goal (e.g., fastest deployment vs. lowest cost vs. absolute 24/7 reliability)?
• Are there local resources like existing transmission lines, hydro resources, or land availability?

For most county-owned utilities, the question is less "What single technology should we build?" and more "What portfolio delivers reliable, affordable, low-carbon power with manageable execution risk?"

Over the next decade, a practical strategy is to separate firm clean capacity from low-cost clean energy:

1. Preserve every megawatt of existing firm generation

The cheapest reliable megawatt is often the one you already own.

If your utility has:

• hydro,
• biomass,
• landfill gas,
• waste-to-energy,
• existing gas turbines,

keep them reliable while planning replacements. Retiring dispatchable assets before replacement capacity exists is one of the largest reliability risks.

2. Add as much inexpensive renewable energy as the grid can absorb

Solar and wind reduce fuel costs and emissions, but they are not baseload by themselves.

A county utility should aggressively pursue:

• utility-scale solar
• community solar
• long-term renewable PPAs
• distribution-level solar where it avoids feeder upgrades

These resources provide inexpensive energy, allowing your firm resources to run fewer hours.

3. Invest heavily in storage—but recognize its limits

Four-hour batteries solve:

• evening peaks
• frequency regulation
• reserve requirements
• renewable smoothing

They do not replace week-long firm generation.

Long-duration storage (10–100+ hours) is becoming increasingly important as renewable penetration grows, although costs and technology maturity vary. DOE identifies long-duration storage as a key requirement for highly renewable grids.

4. Pursue geothermal wherever geology allows

Among commercially available clean technologies, geothermal is one of the strongest baseload options.

Advantages include:

• 90%+ capacity factors
• dispatchability
• no fuel price volatility
• very small land footprint

The DOE considers geothermal a firm, flexible renewable resource capable of balancing intermittent generation, and sees significant potential from enhanced geothermal systems (EGS).

Even if your county lacks conventional geothermal resources, advanced geothermal may become increasingly viable over the next decade as drilling costs fall. Recent investment from major electricity buyers is accelerating commercialization.

5. Consider advanced nuclear—but plan conservatively

Small modular reactors (SMRs) could eventually provide excellent clean baseload power:

• high capacity factors
• zero operational carbon emissions
• long operating lives
• relatively small footprints

However, for most county utilities, SMRs are unlikely to provide meaningful capacity before the early-to-mid 2030s because of licensing, financing, supply chain, and construction timelines. They are worth monitoring or participating in regional consortia, but they should not be the sole plan for meeting reliability needs within the next decade.

6. Expand demand flexibility

The cleanest "generator" is often load that can move in time.

Examples include:

• water treatment pumping
• wastewater facilities
• thermal storage
• municipal buildings
• EV charging
• industrial interruptible tariffs

A few percent of flexible demand can significantly reduce required peaking capacity.

7. Strengthen regional partnerships

County utilities often gain more reliability by sharing resources than by building everything themselves.

Consider:

• regional transmission upgrades
• capacity-sharing agreements
• joint ownership of firm resources
• coordinated reserve markets
• long-term clean energy PPAs

A balanced 10-year portfolio

A representative target for a county utility aiming for high reliability and low emissions might look like:

• 35–50% solar and wind
• 20–30% hydro (where available)
• 10–20% geothermal or other firm clean generation
• 10–20% battery and long-duration storage
• Demand response equivalent to 5–10% of peak load
• Existing dispatchable generation retained as a declining reliability reserve until clean firm resources are fully operational

This approach avoids relying on any single technology while reducing fuel-price exposure and maintaining reliability.

The key planning principle is that reliable clean power is achieved through a portfolio. Over the next decade, the technologies most likely to deliver dependable 24/7 service are existing hydro, geothermal where available, expanding storage, flexible demand, and regional coordination. Advanced nuclear has strong long-term potential but, for most county utilities, should be treated as a strategic option beyond the immediate 10-year planning horizon rather than the primary near-term solution.

Adding reliable, clean baseload power—electricity that is produced 24/7 with zero or low carbon emissions—requires a portfolio approach over the next decade, blending advanced technology with existing infrastructure upgrades . As a county utility, the strategy should focus on dispatchable (controllable) clean energy, firm renewables, and energy storage.

Here is a structured approach for adding reliable clean baseload power over the next decade:

1. Develop Firm Clean Generation

• Geothermal Energy: Utilize geothermal for true 24/7 baseload power, as it is unaffected by weather conditions and provides consistent electricity and heat.
• Advanced Nuclear (Small Modular Reactors - SMRs): Invest in modular nuclear, which offers consistent, carbon-free power at a smaller scale, ideal for local utility needs.
• Biomass/Biogas with CCS: Utilize organic waste (brush, crop residues) to generate electricity combined with Carbon Capture and Storage (CCS) to ensure zero-net emissions.
• Hydropower: Maximize existing or add new small-scale hydro projects where available.

2. Modernize Existing Dispatchable Infrastructure

• Hydrogen Retrofits: Repurpose existing natural gas plants to run on clean hydrogen or blend hydrogen with natural gas to lower emissions.
• Carbon Capture on Gas Units: Retrofit natural gas plants with carbon capture technology, allowing them to remain dispatchable while significantly reducing their carbon footprint.
• Coal-to-Clean Repurposing: Repurpose retiring coal plants into modern natural gas, hydrogen, or storage facilities to leverage existing grid connections.

3. Deploy Long-Duration Storage (LDS)

To make renewable energy behave like baseload, invest in technology that stores energy for days or weeks rather than hours.

• Pumped Storage Hydropower: A proven, long-duration method to balance intermittency.
• Advanced Batteries & Iron-Air Batteries: Implement long-duration battery technologies for grid stability, allowing solar/wind to bridge the gaps during low generation.

4. Accelerate Infrastructure & Policy

• Accelerate Permitting & Interconnection: Streamline local permitting for new, clean power projects to reduce development time from decades to years.
• Implement Grid-Enhancing Technologies (GETs): Utilize advanced conductors, transmission, and software to increase the capacity of existing lines to move clean power, increasing capacity by up to 30%.
• Virtual Power Plants (VPPs): Develop VPPs that aggregate residential storage, EVs, and smart appliances to reduce demand during peak times, acting as a "virtual" baseload.

Summary Table for 10-Year Plan

For immediate, actionable steps to increase your grid's capability, you might look into Grid Enhancing Technologies (GETs) as mentioned in the Department of Energy analysis.

Would you like to explore financing options for these projects or look into specific state incentives for clean baseload?