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As of May 7, 2026, China’s household rooftop solar capacity stands at 205 gigawatts — a scale that makes the country an unavoidable case study for Canada. Energy researcher Anders Hove says the Chinese experience shows how to bring down installation costs while also exposing the grid limits that can slow everything down.
Hove, a senior research fellow at the Oxford Institute for Energy Studies, told Energi Media that China’s residential rooftop market went from almost nothing before 2020 to roughly 17 percent of the country’s total solar capacity. The growth was fast, but it was not uniform, and the lessons are not limited to China’s ability to manufacture cheap panels.
One common mistake is to treat all distributed solar as rooftop solar. Hove is careful to separate the two. Distributed solar — roughly half of China’s installed solar capacity — also includes commercial and industrial projects, and ground-mounted systems built close to electricity consumers.
The distinction matters for policy. A residential program faces customer acquisition costs, small-scale permitting and neighborhood-level grid constraints. Commercial and industrial projects have different load profiles and can often absorb more of the power they generate on site.
For Canada, that means residential rooftop targets should not be designed the same way as broader distributed-generation targets. If the goal is to put panels on homes, the policy tool must address household-level barriers: marketing, contracts, inspections and substation capacity. If the goal is distributed generation broadly, then sites with large loads and more manageable interconnection issues can move faster.
China’s “Whole County” rooftop program, launched in 2021, was an answer to one very practical problem: finding homeowners one by one is expensive.
“Procuring them one by one tends to add a lot of costs,” Hove said. Even in a country with very low equipment prices, marketing, customer contact, site assessment and contract signing still add up. By aggregating rooftops across a county, officials and developers could organise installations at a scale that reduced transaction costs per household.
That approach is directly relevant to Canada. Communities do not need to replicate China’s administrative structure. Instead, they can bundle rooftops and run a competitive procurement process, then repeat that process over several years. Hove says the key is to avoid treating community solar or rooftop aggregation as a one-time campaign and to build a repeatable pipeline.
Bundling also helps because one successful project creates case studies for the next one. Neighbourhoods become familiar with the process, installers develop local supply chains, and utilities can better anticipate the locations and timing of new generation.
The hardest obstacle is not panel price or installer capacity. It is the distribution network. Rural grids in China were built for low electricity use, not for hundreds of households exporting power at the same time. When reverse power flows reach a substation, the network can hit its limit.
Chinese authorities responded by drawing maps of local “absorption capacity” and placing restrictions on new connections in constrained areas. The approach made planning more predictable, but Hove said the problems appeared early in the rooftop programme and are still only partially resolved.
The Canadian parallel is visible in many provinces. Distribution utilities are designed for one-way power flows, and adding rooftop solar at scale requires new transformers, reconductoring or advanced inverters. The financial responsibility for those upgrades is often contested, which means project approvals slow down even when the solar itself is cost-effective.
China can build transmission and distribution infrastructure at lower cost than most countries. Hove argues that this engineering strength is not enough to solve the institutional side of the puzzle.
Grid companies, regulators and local governments have different incentives. State ownership does not automatically align those incentives or remove disputes over who pays for upgrades and who earns the return. “I don’t think that China has the magic recipe for overcoming some of those political obstacles,” Hove said.
That observation is important for Canada and the United States. A utility that earns a return on new substations may view solar differently from one that loses revenue from customer-generated power. Provincial and state regulators set the rules, and those rules determine whether distribution investments happen in time.
Hove’s point is that China’s centralized system still experiences coordination failures. Democratic systems with multiple jurisdictions will need explicit incentive reform, not just technology roadmaps.
Hove also warns against blaming solar or wind for every increase in system costs. China benefits from large industrial electricity demand, significant hydro resources and falling battery prices, yet it continues to add coal capacity.
Part of the cost burden comes from keeping that surplus coal capacity available. Plants that are used less often still need compensation, and those payments are ultimately passed on to consumers. That is a policy choice, Hove says, not an unavoidable consequence of solar generation.
The takeaway for Canada is to separate costs caused by renewable variability from costs caused by how the system is operated. A grid designed for flexibility — with storage, interprovincial trade and demand response — can integrate solar at much lower cost than a system that preserves inflexible baseload capacity.
Hove notes that electricity now covers about 30 percent of China’s energy use, with the share rising by roughly one percentage point each year. The drivers are electric vehicles, industrial restructuring, services, heat pumps and induction cooking.
But electrification does not automatically solve rooftop export bottlenecks. Even if households use more electricity, the peak export moment can still overwhelm a local transformer. The solution is coordinated planning: knowing where solar will be built, where demand will grow, and where distribution upgrades are needed.
For Canada, this means rooftop programs should be planned together with building electrification and utility investment. Panels and heat pumps belong on the same roadmap. So do electric vehicle chargers and storage.
The Chinese rooftop boom is not a clean template. Its success depended on state-backed programmes, low-cost manufacturing and a willingness to restrict new connections where grids are weak. Those conditions do not transfer directly to Canada.
What does transfer is the overall lesson: reduce customer acquisition costs through bundling, plan distribution upgrades in advance, align utility incentives with electrification, and do not treat residential rooftop solar as just a generation project.
For North American policymakers, Hove’s research reinforces a simple idea. Cheap panels are necessary but not sufficient. The real work is in procurement design, grid coordination and utility reform.
