Frequently asked questions

We assess sites and design the commercial structure. We compare equipment, construction, and financing terms to find the combination that works best, manage the permitting and construction schedule, and collate the quality inspection results. After commissioning we stay on for operations, and for expansion into ESS and VPP.

GRIDAEND Co., Ltd. is an energy project development company founded in June 2026. The work centers on solar (PV and BIPV), alongside ESS, VPP, energy consulting, and real estate development. The head office is in Dongtan, Hwaseong, Gyeonggi-do.

It joins three words: Grid, And, End. The intent is to tie energy projects into a single grid (Grid), to stay alongside you (And), and to keep the energy maintained from the beginning through to the end (End).

We assess sites anywhere in Korea. The head office is in Dongtan, Hwaseong, Gyeonggi-do, and our partner network handles construction and operation nationwide.

We publish the process and the deliverables first. The contents page of the assessment report, and the output of each of the seven stages, are published on this site in full. The initial feasibility assessment is free of charge, so you can judge us on the work itself.

Construction is carried out by partner firms vetted in their own discipline. GRIDAEND compares terms, manages the construction schedule, and collates and reports the inspection findings from the supervisor and the contractor. We don't push a particular firm on you, and the final choice is yours.

The initial feasibility assessment is free of charge, and the report comes back within about five business days. Detailed work that carries an external cost, such as a structural review or a survey, is quoted first and proceeds only once you agree.

No. We put the terms from our affiliate and partner consortiums side by side and show all of them. The final choice is yours.

No. Energy yield, prices, and the regulatory regime all move, so no developer can guarantee a return. We give you a conservative, a base, and an optimistic scenario, and publish the assumptions and the basis behind each one.

Rent varies widely with area, irradiation, grid conditions, and the contract structure, so we do not quote a standard figure. We calculate it from the conditions at your site and put it in the assessment report.

Yes. In the roof lease model you provide the land or the roof and invest nothing. If you want the owner-invested model, we look at combining government support programs with financing to bring the upfront burden down.

Mainly from development and management services, and from fees arising when we bring partners into a project. Before any contract, we set out which costs fall on you, at which stage, and how they arise.

It depends on your capital and your goal. Steady income without investing usually points to the roof lease model; maximizing the return usually points to the owner-invested model. The assessment report compares the 20-year cash flow of both.

It depends on the class of farmland, the land-use zoning designation, and the local government's ordinance. A farmland conversion permit or consultation is required, and if you want to keep farming while generating, agrivoltaics is the route to examine. We check it against your land parcel number (jibeon) in the initial assessment.

A structural safety review comes before installation, and the contract states who is responsible for waterproofing and leaks. An older roof may need reinforcement or replacement first, and if so we settle who carries that cost in advance.

A rule requiring generating equipment to sit a minimum distance back from housing or roads. Under the renewable energy act and its enforcement decree, effective 18 September 2026, a local government may set a setback only within 200 m of a housing cluster (five homes or more). It does not apply to community-participation projects, rooftop systems, or systems for self-consumption.

Send us the parcel number. We check the land-use zoning designation, the municipal setback ordinance, the prospects for a development activity permit, and the headroom for grid connection, then tell you whether a project stands up. There is no charge.

The lease is normally written so that it passes to the new owner. If a sale is a possibility, pin down the succession clause and the early termination terms while the contract is being drafted.

Anywhere from a few months to more than a year, depending on size, location, and grid conditions. The usual order is the electricity business licence, the development activity permit, the construction plan filing, the pre-use inspection, and the notice of commencement of business. The assessment report gives an expected schedule for the specific site.

The report comes back within about five business days. If material is missing, or the site needs further checking, we contact you and give you a revised date.

A parcel number or building address and a way to reach you are enough to start. A certified copy of the property register, a cadastral map, electricity bills, and a roof drawing make the assessment more precise, but none of them are required.

When applications to connect plants to the network pile up, projects wait their turn to be connected. As of July 2026 the volume waiting nationwide was reported at about 8.9 GW, and it varies sharply by region. It has to be checked before construction starts.

No. The initial assessment exists to help you decide and carries no obligation to contract. You are free to read the result and walk away.

The Green Premium, or buying RECs. Both put a record in place immediately, with no equipment to build. The cost repeats every year, though, so over a longer horizon a mix of self-generation and PPAs that brings the unit price down is often the stronger combination.

Which programs apply depends on your industry, your region, and the type of installation. Through our partner network we check eligibility, timing, and requirements with you. Most programs open for applications only once a year, so the calendar matters.

It depends on your load profile, your tariff, and the capacity that fits. Send us the last 12 months of bills and we calculate it for your site. We do not quote savings figures we cannot support.

It depends on the space you have, how much power you use, and what you can invest. With space and heavy consumption, self-generation comes out ahead; with little space, or large volumes to procure, a PPA is the one to examine. Most companies end up using both.

The module costs more. But it replaces cladding you were going to buy anyway, so the comparison has to be made on total cost. Add the value of meeting the ZEB requirement, plus subsidies and generation income, and the real burden looks very different.

Since January 2025, public buildings with a gross floor area of 1,000 m² or more must be certified at ZEB grade 4 or above, and public buildings of 500 m² or more at grade 5. In the private sector, since December 2025, buildings with a gross floor area of 1,000 m² or more, and multi-unit housing of 30 units or more, must meet design standards at the level of ZEB grade 5.

It depends on the purpose and the conditions. At a site with a pronounced peak, the bill saving is usually clear. Where storage is paired with a generating plant, the outcome swings widely with the rules and the prices on offer. We run the economics first, then make a recommendation.

It is a battery installation, so safety design is not optional. Siting requirements, fire protection, the battery management system, and continuous monitoring go into the design from the start, and we check the insurer's underwriting conditions alongside them.

Check the plant's capacity and its metering and communications requirements, then contract with a power trading operator to take part. GRIDAEND assesses whether participation is possible, introduces operators, and compares their contract terms.

Now is exactly when the assessment should start. The bill converting the RPS into a contract market passed the National Assembly on 20 August 2026, and according to the government's materials, REC issuance for new installations stops from 2027. The commissioning date and the contract route change the revenue structure for 20 years, so the schedule has to be designed site by site.

New installations earn from the price awarded in the competitive-bid contract market, or from a direct PPA price, instead of from RECs. Installations commissioned by 2026 with a record of REC issuance have a grace period to 2029 under the government proposal.

The government proposal points toward a separate bidding track for small operators. Raising the small-scale threshold to somewhere below 1 MW has been discussed, but the specific threshold will be fixed in subordinate legislation.