Every solar farm moves through the same sequence, and each stage gates the next. The timeline is driven mostly by the utility and the permitting authority, not by construction. For a shorter walk-through written for first-time owners, read our guide to developing a solar farm from raw land to revenue.
1. Site control
Development starts with the legal right to use land: an option to lease or purchase, usually with a study period before the lease term begins. Site control is what lets a developer file an interconnection request and spend money on studies. We look first at distance to three-phase distribution or transmission lines, parcel size and shape, slope, wetlands, flood zones, and title encumbrances before anyone signs. Landowners should read how to lease your land for a solar farm before accepting an option.
2. Feasibility and desktop screening
A solar farm feasibility study begins at the desk: hosting capacity maps and utility circuit data, GIS layers for wetlands, habitat, prime farmland, and floodplain, topography, zoning, and a preliminary layout that yields a realistic MW-AC figure. We add an energy model, a rough interconnection cost range, and a pro forma so the go or no-go decision is made on numbers rather than acreage. Most sites that fail, fail here, cheaply.
3. Environmental review and permitting
Solar farm permitting varies more by town and state than any other stage. Typical elements are wetland delineation, a stormwater management plan, endangered species and cultural resource screening, glare and visual studies where required, a local site plan or special permit, and a decommissioning plan with financial surety. State siting boards take jurisdiction above certain size thresholds. We prepare permit-ready civil and electrical drawings so the application answers the questions a planning board or conservation commission will ask.
4. Interconnection studies and the queue
Solar farm interconnection is the schedule. Distribution-connected projects apply to the local utility and move through screening, impact, and facilities studies, increasingly in group or cluster studies. Larger projects enter a regional queue (ISO-NE in New England, ERCOT in Texas). Lawrence Berkeley National Laboratory's Queued Up 2026 Edition reports a median of more than five years from interconnection request to commercial operation for projects built in 2025, and that only 13 percent of capacity requesting interconnection between 2000 and 2020 had reached commercial operation by the end of 2025. Study results set network upgrade costs, which can move a project from strong to unfinanceable, so we model upgrade exposure before a deposit is posted.
5. Engineering
Engineering converts studies into a buildable plant: geotechnical and pile load testing, civil grading and stormwater, array layout and row spacing, string and DC design, inverter selection, AC collection, medium-voltage equipment, and the point-of-interconnection design the utility must approve. We iterate the design against the energy model and the cost model at the same time, because ground coverage ratio, DC to AC ratio, and pile embedment all trade production against capital.
6. Procurement, including trackers vs fixed tilt
Procurement covers modules, inverters, racking, transformers, switchgear, and long-lead utility equipment. Two decisions dominate. The first is supply chain compliance, including domestic content and the foreign entity of concern rules that now affect credit eligibility. The second is racking:
- Single-axis trackers. Rotate east to west through the day, increasing annual energy yield, and are the dominant choice in new US utility-scale construction per LBNL. They cost more, use more land per MW, and add moving parts to maintain. They pay back best at lower latitudes with high direct irradiance, as in Texas and Florida.
- Fixed tilt. Lower capital cost, simpler O&M, better tolerance of irregular parcels, slopes, and heavy snow loads. Often the better answer on smaller Northeast community solar sites where land is constrained and the yield gain from tracking is smaller.
We run both options through the energy model and the offtake price shape before recommending one. Under an as-generated PPA the answer is often different than under a fixed-shape hedge.
7. Construction
Solar farm construction follows a predictable sequence: mobilization and erosion controls, clearing and grading, access roads, pile installation, racking, module installation, DC wiring, trenching and AC collection, inverter and transformer pads, and the utility interconnection facilities. Our construction team self-performs the core scopes and reports progress against a resource-loaded schedule, which is what lenders and their independent engineer track.
8. Commissioning and the ASTM E2848 capacity test
Commissioning proves the plant does what the contract says. Beyond insulation resistance, IV curve, and inverter startup testing, bankable EPC contracts require a capacity test under ASTM E2848, which compares measured output to the modeled output at reporting conditions (ASTM E2939). As a public reference point, the Entergy Arkansas Solar BOT scope book sets a guaranteed capacity ratio of 97.0 percent and requires at least 750 cumulative minutes of valid data across three or more days within a 15-day window. A shortfall triggers remediation or liquidated damages, not a conversation.
9. Permission to operate
PTO is the utility's written authorization to energize and export. It follows witness testing of protection settings, the utility's own upgrades, and final metering. PTO is also the date most offtake contracts and state incentive tariffs start the revenue clock, so we schedule backward from it and coordinate utility milestones weekly during the final months.
10. Operations and maintenance
Solar farm O&M protects the production number the project was financed on: monitoring and alarm response, inverter and tracker service, vegetation management, module cleaning where soiling justifies it, thermal imaging, and availability reporting to owners and lenders. LBNL's Utility-Scale Solar 2025 Edition reports median empirical O&M costs falling from about $40 per kW-AC per year in 2012 to about $11 per kW-AC per year in 2024. See our solar O&M service for scope detail.
