2 MW Community Solar: Illustrative Design Example

Last updated: November 2026

A community solar project connects a shared generating asset with subscribers who receive benefits through a defined billing arrangement. The difficult work is aligning the physical plant, utility rules, customer agreements and cash flow. A capacity figure alone cannot explain household savings or investment returns.

This is an illustrative design and financial example, not a real project case study. The 2 MW, 400-household framework shows how to connect design assumptions with subscriber benefits. All project quantities and costs below are explicit assumptions or arithmetic, not observed market data.

The US Department of Energy’s community solar overview explains subscription and ownership participation with bill credits. Actual eligibility, credit values, billing and cancellation rules come from the applicable programme and contract.

SurgePV publishes this post and sells solar design software.

Project Overview: 2 MW Community Solar Serving 400 Households

The example assumes a 2.0 MWdc array and 1.6 MWac inverter capacity. It allocates the entire modeled output equally across 400 household shares. No real address, utility approval, construction date or operating record is asserted.

Project at a Glance

The module arithmetic exposes an unresolved design input: 6,800 x 295 W is 2,006 kW, not exactly 2,000 kW. The allocation and financial calculations use the nominal 2,000 kW case. A real design must reconcile the final module schedule, modeled capacity and subscriber allocation before release.

Why 2 MW and 400 Households?

These are chosen example values, not an optimum size or evidence of available feeder capacity. Dividing 2,000 kW by 400 gives a nominal 5 kW share. Actual programmes may size allocations differently and impose limits tied to consumption or customer class.

Grid feasibility: Obtain the utility’s accepted study basis and connection offer. A visible three-phase line or a hosting-capacity map cannot guarantee a 2 MW connection without upgrades. Record whether constraints refer to DC capacity, AC export or another defined quantity.

Land feasibility: Compare the usable surveyed area with the array, access, drainage, setbacks and environmental constraints. The 4.8-hectare allowance is not a minimum-land rule. Different equipment and site restrictions can change the required area.

Subscriber feasibility: Establish the eligible market, expected allocation sizes and customer-service process. Four hundred signed forms are not equivalent to four hundred active, correctly credited accounts. Track eligibility, enrollment, credit commencement and retention separately.

At the assumed energy and credit price, an equal share receives 7,875 kWh of annual allocation and $1,417.50 in gross credit value. A 12.5% discount produces $177.19 in annual subscriber savings and $1,240.31 in payment to the provider, rounded to cents. This discount applies to allocated credits, not automatically to the household’s entire electricity bill.

How Community Solar Works: Three Models Explained

Community solar describes shared benefits from a solar project; the commercial arrangement determines who owns the asset, pays costs and receives credits. The categories below are ways to organize the questions, not mutually exclusive legal structures or universal programme definitions.

Model 1: Subscription

A subscription can charge for allocated credits or output under agreed terms. This example assumes no upfront subscriber payment and a charge equal to 87.5% of allocated credit value. That is a chosen pricing rule, not a guaranteed offer available in any state.

The conceptual money flow is:

1. The project generates energy measured at the agreed boundary.
2. The utility applies eligible credits according to programme rules and allocation records.
3. The subscription charge is collected through the accepted billing arrangement.
4. The project pays operating expenses and its financing obligations.

Check whether billing is separate or consolidated. In New York, Department of Public Service guidance describes community distributed generation and net-crediting arrangements. Do not promise two bills or one bill without identifying the arrangement that applies.

Model 2: Ownership

An ownership arrangement may involve purchasing an interest or entitlement rather than paying a recurring subscription charge. Identify exactly what the participant owns and which operating, replacement and administrative costs remain payable.

Do not describe all credits after purchase as pure savings. The contract may allocate continuing costs or risks to participants. Review transfer, removal, resale, voting rights and what happens if the project underperforms or stops operating.

Model 3: Power Purchase Agreement

A power purchase agreement (PPA) defines the sale of energy under specified pricing and delivery terms. Its relationship to community-solar bill credits depends on the programme and contract. A fixed price per kWh is different from a fixed percentage discount on credit value.

Assign production, pricing, curtailment and collection risks explicitly. Paying for actual energy does not automatically transfer all production risk to the developer. A participant can still receive less benefit when generation or credit value is lower.

Model Comparison

This is an editorial comparison based on the participation models described by DOE and the billing distinctions in the New York guidance above. Obtain legal and commercial advice for the actual arrangement; this table is not a contract template.

Site Selection and Land Acquisition

Site selection should bring land, grid and subscriber feasibility into the same decision. The example assumes a candidate parcel; it does not claim that a developer screened real sites or completed an environmental investigation.

Site Selection Criteria

Use a screening record with evidence and unresolved conditions. Weighted scores can help compare preferences, but a high score cannot cancel a fatal legal, environmental or connection constraint.

Record why a site remains under consideration and which evidence must arrive before spending more. Distinguish a screening assumption from a completed study. The next stage should close the controlling uncertainty rather than generate more polished drawings from an unverified location.

Illustrative Land Lease Structure

Assume rent of $800 per acre annually over approximately 11.9 acres. That gives $9,520 in year-one rent. It is not a regional market quotation. If a model includes 2% annual escalation, calculate each year’s cash flow from the contract rather than entering an unrelated terminal value.

The example budget also carries a $25,000 upfront land allowance and a $50,000 decommissioning-security allowance. A real agreement must determine whether security is cash collateral, a bond premium or another instrument, since those have different cash-flow effects.

Have counsel review access, construction rights, drainage, vegetation, assignment, lender protections, removal and restoration. Coordinate the lease term with project life and financing, and identify the obligations that survive termination. Do not assume a purchase option or an unrestricted right to remove trees.

Environmental and Geotechnical Assessment

Identify the investigations required for the actual parcel and approval route. Potential subjects include wetlands, ecology, contamination, flood risk, ground conditions, drainage and cultural resources. Their applicability and scope need professional review.

Keep findings and reliance limits with the design inputs. A report saying one surveyed area is suitable cannot automatically be extended to an expanded array or new access road. If the layout changes, ask the relevant specialist whether further work is required.

Define stop conditions before fieldwork and construction. Unexpected fill, groundwater, habitat or buried infrastructure should trigger the agreed review process. Neither a generic soil capacity nor an assumed absence of wetlands belongs in a construction package without evidence.

System Design: Ground-Mount 2 MWdc / 1.6 MWac

The technical framework below identifies the records a real 2 MWdc / 1.6 MWac design would need. It is not an engineered equipment schedule, a simulation run or a construction specification.

Module Selection

The assumed schedule of 6,800 nominal 295 W modules gives 2,006 kWdc. It illustrates why module count and nameplate capacity must reconcile. No manufacturer, efficiency, warranty or certification is claimed for that hypothetical module.

For a real project, obtain the exact datasheet and installation instructions. Check dimensions, electrical characteristics, temperature coefficients, approved clamping and warranty conditions. Use the selected model consistently in the layout, electrical calculations, yield model and procurement schedule.

Inverter Configuration

The nominal AC design target is 1,600 kW. Select the number and rating of actual inverters through the electrical design. Reconcile their total nameplate capacity with the modeled AC basis and utility export limit; those quantities need not be identical.

Using nominal capacity, the DC/AC ratio is 2,000 / 1,600 = 1.25. This ratio alone cannot determine clipping, efficiency, equipment stress or economic suitability. Those require the selected equipment, weather inputs and a reviewed model.

Racking and Tracking

Tracking is a configuration to evaluate against fixed tilt using the actual site. A real layout must identify the exact tracker, row geometry and structural limits. Reconcile modules per row and row counts with the equipment schedule before comparing modeled output.

Compare tracking and fixed tilt using the same site and financial basis. Include maintenance, control requirements, foundations and inter-row shading. Keep structural and geotechnical design under qualified review; an energy model does not approve tracker operation or foundation capacity.

Electrical Design

String length, operating voltage, protection and transformer ratings need equipment documents and a project-specific electrical design. Keep each selected value traceable to the design basis, calculation and responsible reviewer.

The required design record should include equipment identity, environmental basis, string calculations, input allocation, conductor and protection schedules, grounding and bonding, collection routes and the utility interface. Check the applicable standards and manufacturer instructions rather than borrowing values from a generic example.

Annual Energy Assumption

The energy figure is a scenario input, not a PVsyst result or a New York yield benchmark. A real estimate needs identified weather data, equipment models, geometry, losses and uncertainty treatment. Preserve the full input and result files so a reviewer can reproduce the estimate.

Financial Structure: Tax Equity, Debt, and Subscription Revenue

Separate project cash flow from subscriber savings and financing distributions. This illustrative model uses subscription receipts and explicit operating allowances. It does not claim an executed debt agreement, tax-equity partnership or eligible federal credit.

Capital Sources and Tax Review

A real capital plan can combine sponsor funds, debt and other eligible sources. Obtain terms covering drawdown, interest, reserves, security, covenants and distributions. The timing of funding matters as much as the nominal share of project cost.

The IRS Clean Electricity Investment Credit page is a starting point for current federal credit review. A qualified adviser must determine the applicable provisions, dates, conditions and eligible basis. This example assumes no tax credit, depreciation benefit, grant or tax-equity proceeds in its revenue arithmetic.

Tax eligibility and investor allocation depend on the project and transaction. Record each assumption with its legal basis, effective date and adviser. A project modeled for a historical date needs the law and evidence applicable to that date.

Revenue Model

Assume all 3,150,000 kWh receive a credit value of $0.18/kWh and all allocated subscriber charges are collected. Those assumptions produce $567,000 in gross credit value. At a 12.5% discount, subscriber savings total $70,875 and provider receipts total $496,125.

For New York, NYSERDA’s Value Stack explanation identifies location- and time-dependent bill-credit components. Do not assume a retail tariff is the credit rate or add separate environmental and capacity income if that value is already included in compensation.

The example assumes full allocation and collection solely to make the arithmetic transparent. A real model must include unallocated energy, enrollment delays, payment performance, credit timing and any rules governing unused credits. Do not call those items zero simply because the input is missing.

Operating Expenses

The following allowances are hypothetical annual costs, not signed contracts or market benchmarks. The reserve is included as a cash allocation and should not automatically be treated as an accounting expense.

Project Cash Margin

The simplified year-one difference is $496,125 minus $128,270, or $367,855 before debt service, income tax and other omitted items. It is not distributable cash or a bankable return metric.

Dividing the detailed capital allowance of $2,849,500 by this unchanged annual margin gives approximately 7.75 years. This is a static ratio, not a forecast payback: it excludes escalation, degradation, financing, changes in credit value, major replacements and tax effects.

No internal rate of return (IRR), net present value (NPV) or levelized cost of energy (LCOE) is asserted. Those require a complete time-series model with a defined perspective and cash-flow boundary. A project can have a positive first-year margin while still failing its financing requirements.

Cost Breakdown and Economics

The following illustrative capital allocation is a budgeting exercise, not evidence of construction costs. Amounts are USD; per-watt values use the nominal 2,000,000 Wdc basis and are rounded. Reconcile taxes, refundable security, working capital and financing fees before comparing a real quotation.

Total Project Cost Breakdown

Subscriber Economics

Under the equal-share and full-allocation assumptions, the household calculation is:

Rounding each household amount can create small differences from aggregate totals. Calculate the aggregate from unrounded values and apply the billing programme’s rounding method at the appropriate stage. Do not independently round several intermediate values and then describe the mismatch as lost revenue.

A subscriber’s remaining utility bill depends on actual consumption, fixed charges, tariff rules and the treatment of credits. The example cannot support a claim that a household’s whole bill falls by 12.5% or that a fixed percentage of its electricity use is offset.

Community Solar and Rooftop Cost Comparison

Compare the customer’s decision and the developer’s investment separately. A subscription discount is not equivalent to ownership of a rooftop system, and project construction cost per watt is not the same as a subscriber’s annual payment.

For the customer, compare upfront payment, net benefit, obligations, transfer terms and cancellation. For the developer, compare complete capital and operating cost, eligible compensation and risk. Use consistent dollars per watt or dollars per kilowatt and identify the scope behind every quoted amount.

The detailed budget includes hard costs, development expenses and reserves. Some reserves may remain assets, while spent development fees do not. Ask the finance team to classify each item before calculating investment returns or presenting the cost breakdown to a lender.

Regulatory and Permitting Challenges

Create an approval register for the actual project. This illustrative example has no permits, incentive award or legal determination. The responsible advisers must identify the federal, state, local and utility requirements that apply.

Federal Review

Do not assume indirect connection to the interstate grid automatically triggers a federal environmental review. Have counsel identify any federal action, funding, land interest or other applicable requirement. Record the responsible agency and determination where relevant.

Likewise, do not apply an airport-distance rule from this article. Evaluate any aviation submission from the project’s actual location, dimensions and agency requirements. Land enrolled in conservation programmes requires its own review of obligations and proposed changes.

The useful project record is a list of triggers, evidence, responsible advisers and required decisions. A generic checklist cannot prove that environmental, aviation or land-programme approval has been obtained.

New York Siting and Incentives

The New York ORES FAQ describes its Article VIII framework for large-scale renewable generation of 25 MW or larger. A 2 MW example should not be presented as having passed that process.

Have local counsel identify the actual siting, environmental and permit route. Do not treat being below the cited large-scale threshold as exemption from all review. Record the lead authority and required approvals for the specific parcel.

No NY-Sun award is assumed here. Check the current programme, capacity availability, eligibility and reservation conditions with NYSERDA. Include an incentive in committed financing only when the project has the evidence required to rely on it.

Local Requirements

Ask the municipality and relevant authorities for the site-plan, zoning, building, electrical, drainage, access and restoration requirements. Identify required engineering seals and inspection stages. The example does not claim by-right zoning or a particular permit fee.

Coordinate road use and construction access with the responsible authority and landowners. If security or a restoration agreement is required, distinguish refundable collateral from an expense. Keep the approval conditions visible to the contractor.

Low-Income Participation and Consumer Protection

Programme-specific rules determine eligibility, documentation, allocation and required benefits. Have the programme administrator identify the provisions applicable to the project before setting participation targets or advertising discounts.

Use NYSERDA’s community solar information and the actual programme documents as starting points. Confirm what evidence may be collected, how consent is obtained and who can access it. Do not assume a platform may query benefit databases automatically.

Design enrollment around clear terms and an accessible complaint route. Explain billing, cancellation, moving, seasonal variation and when credits begin. Evaluate service quality from actual records rather than asserting that one income group has better payment behavior or lower churn.

Grid Connection and Interconnection

Interconnection is a separate development workstream with its own evidence and milestones. No queue duration or upgrade cost is established for this hypothetical site. Obtain the utility’s process and any site-control requirements before deciding when to apply.

Interconnection Milestones

A real project may use different stage names or combine steps. Track its actual process rather than forcing it into a fourteen-month calendar. A submitted application is not evidence that capacity is reserved or energization is approved.

Illustrative Interconnection Allowance

The budget uses $171,000 as an allocation, not a utility quote. It includes a $25,000 refundable-security assumption, which should be treated separately from permanent expense in a detailed cash-flow model.

Replace these values with the utility offer and professional scopes. Identify cost responsibility, refunds, securities, milestone payments and exposure to later changes. Do not classify a broad allowance as evidence that a particular recloser or substation upgrade is sufficient.

Agreement and Operating Requirements

The agreement must define the permitted export, connection point, voltage, metering, protection, communications and operating obligations. The nominal 1.6 MWac target in this example is not an accepted export limit.

Have qualified electrical and utility specialists establish the applicable standards and settings. This guide gives no power-factor, ride-through or protection value. Keep the final utility requirements aligned with the equipment configuration and commissioning record.

Subscriber Management Platform

Subscriber operations need reliable allocation, billing, consent and support records. The example does not identify an installed platform or claim that SurgePV provides subscriber billing or utility-data integration.

Platform Requirements

Demonstrate the workflow with synthetic or permissioned data. Include a duplicate account, a move, an allocation change, a delayed utility credit and a canceled subscription. A successful invoice export alone cannot prove the process handles exceptions.

Subscriber Acquisition Budget

The channel counts below form an illustrative planning exercise. They are not campaign results or acquisition benchmarks. Multiplying each assumed count by its assumed unit cost gives:

The capital budget’s $97,500 acquisition allowance is broader than this direct-channel arithmetic. The $15,295 difference remains an unallocated planning allowance, not a claimed spend or proven saving. A real budget should identify staffing, verification, systems and other costs before approval.

Track eligible, enrolled, credited and retained accounts separately. Acquisition cost per signed form can look attractive while the cost per active subscriber is much higher. Choose the measurement boundary before comparing channels.

Churn and Retention

Define churn, collection performance and complaint metrics before collecting them. Record the denominator, reporting period and treatment of moves or re-enrollment. Do not invent a customer-satisfaction score for a project with no operating record.

Use support contacts to find misunderstandings in the customer disclosure. Seasonal credit variation, delayed credits and allocation changes need clear explanations. Evaluate the effect of communication from actual complaint and retention records rather than promising a percentage improvement.

Environmental Impact

Environmental impact requires a defined accounting method, generation profile and geographical basis. This example has no verified emissions study, lifecycle assessment or ecological certification.

Avoided Emissions

Define the emissions question before selecting a factor. Keep pounds and metric tons distinct, identify the relevant region and reporting year, and document any conversion. Capacity and annual energy alone cannot supply a credible avoided-emissions result.

The EPA AVERT resource provides a starting point for avoided-emissions analysis. Select the method appropriate to the question and retain the dataset, region, year, units and calculation. Average grid intensity and marginal displaced emissions answer different questions.

Do not multiply one annual factor across the full project life without explaining changes in generation and grid assumptions. If environmental attributes are sold or allocated elsewhere, review who may make which claims. Keep the claim boundary consistent across investor reports and subscriber marketing.

Lifecycle Assessment

A lifecycle calculation needs manufacturing, transport, construction, operation and end-of-life assumptions. Carbon payback and energy payback are different metrics. Neither follows directly from nameplate capacity or one year’s production.

Obtain the relevant equipment and construction data before making a numerical claim. Identify exclusions and uncertainty, and use the same lifetime assumptions as the financial and energy models where appropriate. No lifecycle payback value is asserted here.

Biodiversity and Land Use

A vegetation plan can be part of the design, but habitat benefits need site-specific ecological advice and implementation records. Do not claim certification, pollinator outcomes or reduced mowing costs without evidence.

Coordinate vegetation with access, drainage, electrical safety and the selected tracker. If grazing is considered, review animal welfare, fencing, cable protection and operating responsibilities. An illustrative land-use concept is not proof that the final installation supports those activities.

Keep a management plan with tasks, owner, inspection criteria and the response to failed establishment or invasive species. Environmental commitments should remain funded obligations in the operating plan rather than decorative language in a proposal.

Social and Community Benefits

Report community benefits as measured outcomes or explicit commitments, not assumptions borrowed from another project. This example’s only calculated household benefit is the $70,875 aggregate annual discount under its stated full-allocation assumptions.

Local Economic Impact

A real project can track local procurement, construction hours, ongoing service work and payments to landowners or authorities. Define local geography and avoid confusing temporary full-time-equivalent work with permanent jobs.

The illustrative $9,520 rent and $28,500 tax allowance are budget inputs, not evidence of payments to a particular community. Do not call an allowance a signed payment-in-lieu-of-tax agreement or assume it creates the same public benefit in every jurisdiction.

Energy Equity

Community solar can offer participation to people unable to host rooftop panels, as DOE explains. Access still depends on programme availability and eligibility. Avoid implying that every renter or low-income household can subscribe on identical terms.

Measure participation and benefit using authorized data and clear definitions. Do not publish invented income, renter or environmental-justice demographics. Protect personal information and explain the purpose of any eligibility evidence requested.

If household energy burden is reported, calculate it from actual energy spending and income under a stated method. Use the example’s calculated $177.19 annual saving per equal share only within its stated credit-price and allocation assumptions. A different household benefit needs its own calculation.

Community Engagement

Plan outreach early enough to inform the design and disclosures. Provide a clear route for questions about land use, construction, billing and project ownership. Record commitments and who is responsible for delivering them.

A public meeting does not guarantee approval or quantify avoided legal costs. Track questions, responses and changes made rather than claiming a fixed return on engagement spending. Communicate unresolved conditions honestly, especially before enrollment or construction dates are firm.

Illustrative Year-One Performance Sensitivity

There is no observed year-one performance for this example. The following sensitivity uses 3,087 MWh as an assumed 2% reduction from the 3,150 MWh base case. It is not a weather record, equipment-failure report or P90 result.

Production and Revenue Sensitivity

The sensitivity isolates energy while holding credit price, allocation, collection and operating allowances constant. Real conditions can move several inputs together. Do not interpret a one-variable scenario as a statistical probability or a complete downside case.

Operating-Cost Sensitivity

Consider an assumed $3,200 maintenance increase. If that increment is applied to the lower-energy scenario, cash costs and reserves become $131,470 and the simplified margin becomes $354,732.50. No actual tracker failure or cleaning event is claimed.

A full model should separate scheduled maintenance, unplanned repairs, warranty recovery and lost generation. Record the timing of payments and downtime rather than treating every repair as an equal annual charge. Do not count the same lost energy twice in both production and a separate cash penalty.

Performance Review for a Real Project

Compare measured and modeled outputs at the same boundary and time basis. Retain meter records, weather evidence, outage logs, curtailment and billing data. Investigate differences before attributing them to a particular cause.

Customer enrollment and collection are separate from plant availability. Reconcile the active allocation register to utility credits and receipts. A functioning plant can still have a cash shortfall if credits are delayed or allocated incorrectly.

Debt coverage requires the actual loan terms and lender’s cash-flow definition. The simplified margin above excludes debt and tax, so it cannot prove covenant compliance. Have the finance reviewer connect the operational report to the accepted financing model.

Lessons Learned

The following lessons are review actions drawn from the illustrative workflow, not conclusions from a completed development or an operating team’s experience.

Lesson 1: Establish the Interconnection Path Early

Identify the utility process, application prerequisites and site-control requirements before setting the development schedule. Track the evidence needed for each milestone and the exposure to upgrade costs. Do not advise applying without land control when the utility may require it.

Action: Keep a connection-risk register and a spending decision tied to the next utility result. If the offer changes the project economics, reconsider the site or configuration before committing further construction funds.

Lesson 2: Separate Subscriber Interest from Active Allocation

An inquiry, signed agreement, approved account and credited subscriber are different stages. Plan staffing and systems for the entire path. Confirm programme eligibility and consumer disclosures before collecting commitments.

Action: Reconcile enrollment records with the utility’s accepted allocation list. Assign ownership for rejected accounts and delayed credits so customers receive a clear explanation and correction route.

Lesson 3: Price Tracker Maintenance Explicitly

A tracking option needs a maintenance scope and operating assumptions consistent with the chosen hardware. Do not use an unsupported universal percentage premium over fixed tilt. Review warranty coverage, response obligations and exclusions.

Action: Compare actual service proposals and incorporate their cash timing into the model. Keep warranty recoveries separate from expenses until the right to recover is established.

Lesson 4: Explain Seasonal Credits Before Enrollment

Annual averages do not promise equal monthly benefits. Use a supported monthly model or observed record and label it accurately. Explain the billing cycle and any credit delays separately from seasonal generation.

Action: Have the customer-service team review a sample high-production and low-production statement. Ensure both use the same pricing rule and show the customer’s net benefit clearly.

Lesson 5: Keep Tax and Financing Assumptions Under Review

Tax benefits, debt terms and investor allocations depend on the actual project and transaction. The example cannot supply those terms. Legal and accounting review should occur before an assumed benefit is used to support a commitment.

Action: Maintain an assumption register with source, date, owner and acceptance status. Update the financial model when a term changes and record which investment or customer decisions need reconsideration.

Comparing Community Solar Projects Across Markets

A comparison across Minnesota, Colorado and Massachusetts needs identifiable project records and programme documents. The questions below help organize that research; they do not describe completed projects or assert current programme terms.

Minnesota Comparison Questions

Identify the actual programme, utility, project vintage and subscriber classes. Check how credits are valued, which customers may participate and who manages billing. Do not carry a rule or capacity limit from an older programme into a new project without verification.

For a comparable project, obtain the design capacity basis, annual metered energy, capital-cost boundary and customer agreement. If the provider cannot share confidential costs, label them unavailable rather than estimating a precise installed price.

Colorado Comparison Questions

Separate grant-supported economics from the unsubsidized project case. Verify the funding award, eligibility, reporting obligations and who receives the benefit. A deep customer discount does not reveal the construction cost or investor return by itself.

Compare the customer population only where definitions and permissions support it. Avoid borrowing local poverty statistics to characterize actual subscribers. Retain evidence of achieved enrollment and net benefits if those are used in a public case study.

Massachusetts Comparison Questions

Identify the applicable incentive programme, tariff and project qualification date. Incentive availability and compensation should be established from current documents and the project’s acceptance record. Do not assume adders combine or that a published programme guarantees an allocation.

Check whether reported revenue includes energy, credits, incentives and environmental attributes. Normalize the boundary before comparing it with a New York Value Stack project. Otherwise the same benefit may appear in one project’s base price and another project’s separate revenue line.

Comparison Record

Use the community solar design guide for the wider planning workflow. A comparison becomes useful when it explains differences in scope and evidence, even if that means some fields remain unavailable.

Conclusion

This illustrative 2 MW example shows how physical capacity, allocations and credit pricing connect. At 3,150 MWh and an assumed $0.18/kWh credit price, a 12.5% discount yields $70,875 in aggregate annual subscriber savings under full-allocation assumptions.

The result is arithmetic, not a project forecast. The model still needs a reconciled equipment schedule, site-specific yield estimate, accepted utility compensation, real quotations and tax and financing review before it could support investment.

1. Resolve site and interconnection feasibility before treating the capital allowance as committed cost.
2. Make customer savings and billing terms traceable to the programme and contract.
3. Keep operating, credit-price and enrollment sensitivities separate, then combine them in a reviewed financial model.

Bring the accepted design basis to a SurgePV modeling demonstration to discuss energy and financial workflow support. Subscriber billing, tax-equity structuring and utility integration require separate scope and evidence.

For related modeling context, see generation and financial scenarios and the array-layout workflow.

Frequently Asked Questions

Is this a real 2 MW community solar case study?

No, this is an illustrative design and financial example. Its project quantities and costs are assumptions or arithmetic, not operating records. A real investment case needs site, utility, equipment, cost and financing evidence.

How many households can a 2 MW community solar project serve?

The number depends on eligible allocation sizes and programme rules. This example divides a nominal 2,000 kWdc into 400 equal 5 kW shares. That arithmetic does not prove the shares match actual household usage or eligibility.

How much does a 2 MW community solar project cost?

A reliable price requires a defined site and complete quotations. This example uses a detailed $2,849,500 budget allowance, not a market benchmark. Interconnection, civil work, development costs and financing can materially change the total.

How are community solar subscriber savings calculated?

Subtract the subscription charge from the allocated bill-credit value under the contract. In this example, $1,417.50 of annual credit value at a 12.5% discount gives $177.19 of savings per equal share. That is not a 12.5% reduction in the entire utility bill.

Does community solar always qualify for a federal tax credit?

Eligibility must be established for the actual project under applicable law and timing rules. This example includes no federal credit or depreciation benefit in its arithmetic. Have a qualified adviser review the project before relying on an incentive.

How long does community solar interconnection take?

The timeline depends on the utility process, studies, upgrades and completed milestones. This example has no actual queue or energization record. Obtain the utility schedule and track unresolved conditions separately from construction progress.

How should a community solar project report emissions savings?

Use a documented method appropriate to the location, generation profile and claim being made. Retain the dataset, units, calculation and treatment of environmental attributes. This example makes no numerical avoided-emissions or lifecycle claim.