Community and shared solar: models and EU policy

Not every household or business has a roof suited to solar - shaded, rented, north-facing, or simply absent, as with apartment dwellers. Community and shared solar schemes exist to let these people access solar generation and its financial benefits without hosting a system themselves. In the EU this is no longer a niche experiment; it is a defined legal category with binding transposition obligations for member states.

This article is for local authorities, cooperative organizers, housing associations, and individuals evaluating whether to join or set up a shared solar scheme. It explains the EU legal framework, the main allocation and billing models, and the practical economics of participation.

We focus on the EU because Renewable Energy Directive (RED II, and its RED III amendment) provisions on "renewable energy communities" and "citizen energy communities" set a common baseline that shapes national schemes across member states, even though implementation details differ by country.

The EU legal framework

RED II (Directive (EU) 2018/2001) introduced the legal concept of a Renewable Energy Community (REC): a legal entity based on open and voluntary participation, effectively controlled by members who are natural persons, SMEs, or local authorities located near the projects, whose primary purpose is to provide environmental, economic, or social community benefit rather than financial profit. The related Internal Electricity Market Directive (EU 2019/944) defines a parallel concept, the Citizen Energy Community (CEC), with a similar member-control principle but without the same geographic proximity requirement and covering more than just renewables.

RED III (Directive (EU) 2023/2413), which entered into force in 2023, strengthens these provisions, requiring member states to conduct an assessment of the potential for renewables self-consumption and energy communities, and to remove undue regulatory and administrative barriers to their formation, including for cross-border and multi-site setups. Member states retain significant discretion in transposition, so the specific rules on capacity caps, allowed member types, and grid-fee treatment vary considerably by country.

Allocation models

Virtual net metering / net billing

The most common structure for multi-member schemes without private wire connections. Generation from a shared or "anchor" solar installation is measured centrally, and credits are allocated to participating meters according to a predefined key - typically a fixed percentage share proportional to each member's financial contribution or historical consumption. The distribution system operator (DSO) or supplier applies these credits against each member's own metered consumption, usually on a monthly or quarterly settlement cycle.

Direct physical supply via private wire

Where the generator and consumers are close enough (e.g. a solar array serving several units in the same building or industrial park), electricity can be supplied directly over a private line without passing through the public grid for that portion of flow. This avoids public network tariffs and losses for the shared volume but requires the participants to be electrically adjacent, and typically still requires a grid connection for import/export balancing.

Cooperative ownership

Members buy shares in a cooperative that owns and operates the generation asset; returns come as a mix of reduced electricity bills (via one of the above allocation methods) and/or a dividend on the cooperative shares. This model dominates in countries with a strong energy cooperative tradition (Germany, Denmark, Netherlands) and typically requires the highest degree of member governance participation.

Comparing the models

Worked example: virtual allocation for a 10-member scheme

A 100 kWp rooftop array on a school produces 105,000 kWh/year (1,050 kWh/kWp specific yield). Ten households each buy a 10% allocation share by contributing EUR 1,800 to the capital cost (total capex EUR 90,000, i.e. EUR 900/kWp, with the remainder covered by a municipal grant). Each household is credited with 10,500 kWh/year against its own consumption.

If the applicable virtual net billing tariff credits each kWh at EUR 0.16 (a typical avoided retail rate net of unavoidable network charges), each household's annual credit is 10,500 kWh x EUR 0.16/kWh = EUR 1,680/year. Simple payback on the EUR 1,800 contribution is roughly 1.1 years, which looks unusually fast, and in practice most real schemes see a lower credit rate (EUR 0.08-0.12/kWh is common once network and supplier margins are deducted) and/or a higher per-member capital contribution once a market-rate module price rather than a subsidized capex is used - always model with the specific credit rate and cost basis quoted by the scheme operator, not a generic assumption. Members should also budget for annual O&M and insurance costs typically pooled at 1-1.5% of capex, deducted from the pool before allocation.

Grid tariffs and the "double payment" problem

A recurring policy tension is whether shared and self-consumed energy should still bear the full standard network tariff, which is normally calculated to recover the fixed costs of the shared distribution grid regardless of who generates the electrons. RED II and RED III direct member states to ensure renewable energy communities are not subject to discriminatory or disproportionate fees, but do not mandate a full exemption; several countries apply a reduced network charge for community-shared or self-consumed volumes to reflect that these still use the local grid, while a smaller number of pilot private-wire schemes get closer to full exemption for genuinely bypassed segments of network. Prospective members should check the specific tariff treatment in their jurisdiction before assuming grid fees are avoided (see /calculators/self-consumption for the underlying self-consumption calculation this depends on).

Practical barriers in transposition

• Interconnection queue delays for the shared generation asset, no different from any other grid-connected PV system (see /blog/mppt-explained for underlying system design considerations that affect approval).
• Legal entity setup costs and governance overhead disproportionate to small community projects, an issue RED III explicitly asks member states to address via simplified one-stop-shop administrative processes.
• Capacity caps on individual REC projects in some jurisdictions, which can force oversubscribed schemes to either expand physically or turn away members.
• Metering infrastructure: virtual allocation requires smart meters at each participating site capable of the settlement interval used (commonly 15- or 30-minute), which is not yet universal in every member state.

Common mistakes

• Assuming the credit rate a member receives equals the retail electricity price; it is usually a net-of-network-charges rate that is materially lower.
• Underestimating governance time commitment in cooperative models, which rely on volunteer boards for auditing, member communication, and regulatory compliance.
• Ignoring degradation and O&M reserve when modeling long-term member returns, treating year-one output as flat for 20-25 years.
• Not confirming what happens to a member's allocation if they move house or sell the property - transferability rules differ by scheme and jurisdiction.
• Overlooking capacity caps and queue position, which can delay commissioning well beyond the timeline assumed at signup.
• Conflating "community solar" marketing offered by commercial third parties with the legally defined REC/CEC structures that carry specific member-control and proximity requirements under EU law.

Frequently asked questions

Do I need to live near the solar installation to join a scheme?

It depends on the model. Virtual net billing schemes often allow participation anywhere within the same DSO or bidding zone, while private-wire and some national REC rules impose stricter geographic proximity requirements.

Is community solar cheaper than installing my own rooftop system?

Not automatically. Community solar avoids the need for a suitable roof and large upfront capital, but a well-sited private rooftop system with full self-consumption typically delivers a lower cost per kWh than a shared allocation once network charges are applied to the shared credit.

Can a commercial business join a Renewable Energy Community?

Yes, SMEs can be members under RED II's REC definition, but member control must remain effectively with natural persons, SMEs, or local authorities, and the primary purpose must remain community benefit rather than pure commercial profit.

What happens to my share if the scheme's asset underperforms?

This depends entirely on the scheme's legal structure and risk allocation; cooperative members typically share the shortfall proportionally, while some commercially operated shared-solar products offer a performance guarantee, so check the specific contract.

Does RED III change anything for existing community schemes?

RED III mainly obliges member states to remove administrative barriers and assess community energy potential going forward; existing schemes are generally grandfathered under the rules in force when they were established, but future capacity expansions may fall under updated national transposition rules.

Standards and references

Relevant legislation and standards: Directive (EU) 2018/2001 (RED II), Directive (EU) 2023/2413 (RED III amendment), Directive (EU) 2019/944 (Internal Electricity Market Directive), and IEC 61724-1 for performance monitoring of the underlying generation asset that any allocation model depends on.

Sources: European Commission Joint Research Centre (JRC) reports on energy communities; IEA PVPS Task 1 national survey reports covering shared ownership models; IRENA "Innovation landscape" briefs on community-based renewable energy; national energy regulator guidance documents on net billing tariff design.

Related reading: /calculators/self-consumption for modeling shared allocation outcomes, /calculators/payback for scheme-level payback modeling, and /glossary for definitions of terms such as REC and CEC used throughout this framework.