Understanding the Purpose of the Feasibility Study

A feasibility study for a solar array project in a remote location is not a simple go/no-go gate. It is a structured decision-support tool that quantifies risks, validates assumptions, and aligns stakeholder expectations before significant capital is committed. The study evaluates five interrelated pillars: technical viability, economic sustainability, environmental stewardship, regulatory compliance, and social acceptance. In remote settings, logistical factors such as seasonal access, extreme weather, and supply chain fragility add layers of complexity that demand rigorous upfront assessment. A well-executed study helps project sponsors avoid costly overruns, equipment failures, or community opposition that could kill a project during construction or early operation.

Phase 1: Preliminary Site Screening

Before diving into detailed analysis, a high-level screening filters out obviously unsuitable locations. This phase leverages satellite imagery, existing solar resource maps, and desktop reviews to identify two or three candidate sites worth deeper investigation. Key screening criteria include minimum annual solar irradiation (often above 4.5 kWh/m²/day for economic viability), land slope below 10% to avoid expensive grading, and absence of protected ecosystems. Screening also flags proximity to transmission lines or microgrids—even 5 km of new transmission can double project costs in remote areas. The output of this phase is a shortlist that justifies the expense of on-site visits and detailed modeling.

Using Remote Sensing and Public Data

Free tools such as the NREL Solar Prospector and the Global Solar Atlas provide initial irradiation data. LiDAR datasets from national geological surveys reveal topography, while satellite thermal imagery can indicate dust or snow load patterns. These resources reduce the need for expensive aerial surveys at the earliest stage.

Step 1: On-Site Assessment

Once candidate sites pass screening, a physical inspection validates desktop assumptions. The on-site team collects data that no satellite can provide: soil bearing capacity, microclimate variations, access road conditions, and local security risks. In remote locations, site visits may be limited to dry seasons or require helicopter or boat logistics, so planning the survey window is critical.

Solar Resource Measurement

While satellite-derived data offers long-term averages, local microclimates (fog, dust from mining, or orographic clouds) can deviate significantly. Installing a temporary pyranometer or reference cell for at least three months—ideally a full year—captures seasonal variability. For projects above 1 MW, IRENA’s feasibility guidelines recommend a correlation analysis between on-site measurements and nearby meteorological stations to estimate long-term interannual variability, typically ±5-10% for most arid regions.

Topography and Geotechnical Conditions

Gentle south-facing slopes (northern hemisphere) optimize panel orientation and reduce civil works. A geotechnical survey checks for permafrost, expansive clays, or loose sand that could undermine foundations. In regions with high seismic activity, spectral analysis of the soil informs racking design. The survey also identifies drainage patterns to prevent flooding or erosion around arrays.

Accessibility and Logistics

Transport of solar equipment to remote sites often represents 15–25% of total installed cost. Evaluate road conditions (width, load-bearing capacity, seasonal closures), airstrip or helipad availability, and port proximity if ocean transport is needed. For island or polar projects, offloading large containers may require specialized equipment. The feasibility report should include a logistics plan with estimated lead times for each component.

Step 2: Technical Evaluation

The technical evaluation moves beyond generic assumptions to a system-specific design that matches site conditions. This includes selection of module technology, mounting structure, inverter architecture, and energy storage if required.

Module and Inverter Selection for Harsh Environments

Remote arrays often face extreme temperatures, salt spray, sand abrasion, or high UV exposure. Bifacial modules on single-axis trackers work well in high-albedo deserts but add mechanical complexity and maintenance. Conversely, fixed-tilt polycrystalline panels with robust frames are preferred in cyclone-prone zones. Inverters should have a wide MPPT voltage range and conformal coating for humidity. For off-grid systems, battery chemistry (lithium iron phosphate vs. lead-carbon) must balance cycle life against the difficulty of replacement. Each decision should be supported by manufacturer reliability data and accelerated aging test results.

Energy Simulation and System Sizing

Professional software like PVsyst, HOMER, or Helioscope processes site-specific irradiation, temperature, albedo, and shading from terrain or vegetation. Simulations produce annual energy yield, performance ratio, and capacity factor. For remote locations without grid backup, the system must include a conservative oversizing margin (typically 10–20%) to account for module degradation, soiling, and unplanned downtime. If the array will supply a load with seasonal peaks (e.g., mining camp or tourist lodge), hourly load profiles must be matched against PV output—a mismatch often reveals the need for storage or a hybrid diesel backup.

Grid Integration vs. Standalone

When a weak grid exists, a feasibility study must analyze fault levels, harmonic limits, and voltage regulation. In many remote regions, the local utility requires a detailed interconnection study that may take longer than the project itself. For off-grid systems, the design must consider a charge controller that can handle dump loads if batteries are full, and a battery management system that prevents thermal runaway. The technical report should explicitly state the type of installation (grid-tied, off-grid, or hybrid) and the control logic.

Step 3: Economic Analysis

Economic feasibility transforms technical metrics into financial language that investors, lenders, and internal stakeholders understand. The analysis must treat remote-specific cost drivers that differ sharply from urban or rooftop projects.

Capital Expenditure (CAPEX) Breakdown

Major CAPEX categories include: modules, inverters, mounting hardware, BOS (balance of system including wiring, combiner boxes, switchgear), freight, installation labor (often higher remote premiums), and civil works (roads, foundations, fencing). In remote areas, import duties, bonding for temporary workers, and demobilization costs can add 20–35% over baseline pricing. Use vendor quotes validated against recent similar projects (e.g., mining or oil & gas solar installations).

Operating Expenditure (OPEX) Projection

Annual OPEX includes routine cleaning (frequency depends on dust accumulation), preventive maintenance, insurance, security, and remote monitoring fees. In remote sites, technician travel, accommodation, and spare parts logistics inflate OPEX by 50–100% compared to accessible locations. The model should include an Escalation factor for inflation and a contingency reserve for unplanned repairs (e.g., module replacement after hailstorm).

Revenue and Savings Estimation

For grid-connected systems, revenue comes from exported electricity at the tariff rate (PPA or feed-in tariff). For behind-the-meter installations, savings are valued at the avoided cost of displaced diesel or grid electricity. Monetize additional benefits such as reduced price volatility, carbon credits, or improved reliability (avoided lost production). Use a discounted cash flow (DCF) model to calculate:

  • LCOE (Levelized Cost of Energy) – Total lifecycle cost divided by total energy delivered. Compare against the current cost of generation (e.g., diesel at $0.35–0.50/kWh).
  • Net Present Value (NPV) – Sum of discounted cash flows; positive NPV justifies investment.
  • Internal Rate of Return (IRR) – Acceptance threshold typically 8–12% for infrastructure projects, higher for riskier remote ventures.
  • Payback Period – Should align with battery warranty or financing term; typically 5–10 years.

Sensitivity Analysis

Run scenarios on key variables: irradiation level (±10%), CAPEX overrun (15% contingency), diesel price (±20%), and inflation. Identify which variable most affects returns; often the diesel price (or avoided cost) is the largest leverage point. A sensitivity tornado chart included in the feasibility report helps decision-makers focus risk mitigation efforts.

Financing and Incentives

Explore grants from climate funds, development banks (e.g., World Bank, Green Climate Fund), or national renewable energy agencies. Many remote projects in indigenous or conservation areas qualify for concessional loans. Tax incentives such as accelerated depreciation or investment tax credits can improve IRR by several percentage points. List all applicable programs with application deadlines and award probabilities.

Environmental and legal due diligence is often the gating factor that determines if construction can begin. In remote locations, regulations may be less stringent but enforcement can be unpredictable, requiring extra caution.

Environmental Impact Assessment (EIA)

An EIA evaluates effects on local flora, fauna, water resources, and cultural heritage. For solar arrays, key concerns include land clearing (habitat fragmentation), stormwater runoff, bird collision risk, and visual intrusion. Conduct baseline surveys during two seasons to capture migratory species. Mitigation measures—e.g., wildlife corridors, native grass seeding, or micro-siting panels away from sensitive areas—should be costed and included in the OPEX. The World Bank’s environmental frameworks offer guidance for projects in developing countries.

Permitting and Land Rights

Identify required permits: building permits, electrical permits, environmental clearance, land-use change authorization, and water rights (if using water for cleaning). In many jurisdictions, solar projects over a certain size require a public hearing. Land tenure clarity is critical—disputed ownership or communal land without formal titles can stall projects for years. Engage a local legal consultant to review lease or purchase agreements, especially regarding expropriation risk or indigenous land rights.

Climate Resilience and Decommissioning

The feasibility study should include a climate risk screening. For coastal or island sites, sea-level rise and storm surge may affect low-lying arrays. For arctic projects, increased snowfall from climate change could alter load calculations. Conversely, for decommissioning, estimate costs to remove foundations, recycle modules, and restore the site. Many lenders now require a decommissioning bond, which should be set aside annually as part of OPEX.

Step 5: Social Impact and Community Engagement

Remote locations often have close-knit communities that can make or break a project. Social license to operate is earned through genuine engagement, not one-way information sessions.

Stakeholder Identification and Consultation

Map all stakeholders: local residents, tribal councils, businesses, environmental NGOs, government officials, and nearby industries. Design consultation methods that respect cultural norms—for example, town hall meetings may not work in cultures where decisions are made by a council of elders. Hire local facilitators who speak the language and understand local power dynamics. Document concerns and how they will be addressed.

Local Benefits and Employment

Quantify the number of local jobs during construction (typically 2–5 person-years per MW) and ongoing operation (0.1–0.2 FTE per MW for cleaning and maintenance). Commit to local hiring targets and skills training. For off-grid projects, community energy cooperatives or profit-sharing models build long-term goodwill. Also consider secondary benefits: reliable power for schools, clinics, or telecom towers.

Managing Expectations and Avoiding Conflict

Be transparent about construction noise, dust, and temporary road closures. In regions with strong opposition, an independent mediator can facilitate dialogue. The feasibility report should include a social risk matrix and a community engagement plan with milestones (e.g., quarterly updates during construction). If the project triggers resettlement, follow IFC Performance Standard 5 for land acquisition and involuntary resettlement.

Integrating Findings into a Decision Framework

After collecting and analyzing data across all five pillars, the feasibility study should converge into a clear recommendation with risk-adjusted confidence levels. A decision matrix scores each alternative site against weighted criteria (e.g., 30% technical, 25% economic, 20% environmental, 15% legal, 10% social). The highest-scoring option becomes the primary recommendation. The final deliverable includes an execution roadmap with: pre-construction milestones, required studies (e.g., detailed geotechnical), financing triggers, and a risk register with mitigation strategies.

Conclusion

A comprehensive feasibility study transforms a promising idea into a bankable project. By rigorously evaluating solar resource, logistics, system design, economic returns, environmental constraints, and community dynamics, stakeholders can de-risk the development of solar arrays in remote locations. While the upfront investment in the study often runs 1–3% of total project cost, it pays dividends by preventing costly mistakes and building the confidence needed to secure financing and permits. In an era where remote communities and industries seek energy independence and decarbonization, a well-executed feasibility study is the foundation upon which resilient solar projects are built.