Tracker vs Fixed Tilt Solar: Yield Gain and Break-Even

Last updated: November 2026.

Every ground-mount project faces the same early decision. Rack the modules at a fixed tilt and keep the simpler build, or add motors, controllers and moving-part maintenance in exchange for more energy. The “trackers add 20 percent” rule of thumb hides the answer, because the gain changes with the site and the cost does not.

This guide is for installers, EPC engineers and developers sizing ground-mount projects. It does not cover rooftop systems. The yield, cost and land-use figures come from three US government laboratory reports, each linked where it is used. They describe US plants. This page does not publish tracker figures for other countries because no primary source for them was read.

In this guide:

• Tracker vs fixed tilt side by side
• How the mounts work
• Yield gain by site
• Installed cost and O&M
• A worked break-even example
• Land use
• Where fixed tilt is still built
• A 7-question checklist
• When trackers do not pay back

Tracker vs Fixed Tilt Solar Side by Side

All figures are US data. Read the source column before you reuse a number, because the editions differ (2013, 2020 and 2023).

Sources: NREL Land-Use Requirements for Solar Power Plants in the United States (Ong et al., June 2013); LBNL Utility-Scale Solar, 2024 Edition (October 2024); NREL U.S. Solar PV System and Energy Storage Cost Benchmark, Q1 2020 (January 2021).

How the Two Mounts Work

A fixed-tilt racking system holds modules at one angle for the life of the plant. There are no motors or controllers. It is the mount used on most rooftops and carports, and it is still used on ground-mount sites where terrain or wind rules out tracking.

A horizontal single-axis tracker turns the modules about a north-south axis. The rows face east in the morning, lie flat near noon and face west in the evening, so the modules stay closer to square-on to the sun. LBNL’s 2023 US data counts this single-axis design as the standard for new utility-scale plants.

A dual-axis tracker also adjusts tilt through the year. NREL’s simulations show it adds energy at the sunniest sites, and its flat-panel plants needed 9.4 acres per MWac of direct land against 5.5 for fixed tilt. NREL’s survey found fixed-tilt and single-axis plants made up 96 percent of the PV projects it evaluated. Read the solar tracker glossary entry for the definition.

Trackers can lose energy to row-to-row shading when the sun is low. Controllers handle this with backtracking, which tilts the rows away from the sun to keep them out of each other’s shadow. See solar backtracking for how the algorithm works and how it interacts with row spacing.

Yield Gain by Site: NREL’s Seven US Locations

NREL simulated the same plant at seven US locations with fixed tilt, single-axis and dual-axis tracking. The table shows its results. These are model outputs from a 2013 report, not measurements from operating plants.

Source: NREL Land-Use Requirements for Solar Power Plants in the United States, Table 5 (Ong et al., 2013). The report takes the tracking gains from Drury et al. (2012).

Two points follow from the table. The single-axis gain is 12 to 22 percent, and five of the seven sites are below 20 percent, so a flat 20 percent is too high for most of them. And dual-axis tracking only pays off in energy terms at the highest-DNI sites: 39.6 and 43.7 percent in Phoenix and Alamosa, against 3.3 to 9.0 percent at the three lowest-DNI sites (Seattle, Newark and Jacksonville).

LBNL’s operating-fleet data points the same way. In its 2024 edition, tracking adds about 4 percentage points of capacity factor on average, and more than 5 points in the regions with the strongest solar resource. The edition’s sample is 1,253 plants totalling 61.4 GWac.

A tracker follows the direct beam, so a site with more diffuse light has less to gain. NREL’s Newark and Seattle results fit that pattern. Shading analysis of the actual site shows how much direct sun the array will see.

Installed Cost and O&M

Installed cost. In LBNL’s sample of 1,279 projects (66.5 GWac), 2023 tracking projects averaged 1.4 USD per watt AC (1.1 USD per watt DC) and fixed-tilt projects 1.2 USD per watt AC (0.9 USD per watt DC). LBNL notes that the premium has swung over time and was reversed in 2016, and that the averages do not control for project size, land or interconnection. Separately, LBNL found that 2023 projects over 50 MWac cost about 13 percent less per MW than 5 to 50 MWac projects. That comparison covers total project cost, not the tracker premium, so ask for quotes at your size.

O&M. NREL’s Q1 2020 benchmark lists 16.32 USD per kWdc per year for utility-scale fixed tilt and 17.46 USD for single-axis tracking. That is a difference of 17.46 - 16.32 = 1.14 USD per kWdc per year. A later edition, the Q1 2023 benchmark, lists 16.12 USD per kWdc per year (2022 dollars) for single-axis tracking and gives no fixed-tilt value, so the 2020 pair is the only side-by-side comparison read for this page. This page quotes no motor-failure, wind-stow or terrain-loss figures because none was available from a primary source.

Sources: LBNL Utility-Scale Solar, 2024 Edition; NREL Cost Benchmark Q1 2020; NREL Cost Benchmark Q1 2023.

Worked Example: How Much Extra Energy Must a Tracker Deliver?

Use a simple levelised cost to find the break-even. The inputs are a mix of sources and vintages, so treat the result as a screening test, not a forecast.

Inputs.

• Installed cost: 900 USD per kWdc fixed tilt and 1,100 USD per kWdc tracking (LBNL 2023, rounded to 0.1 USD/W in the source).
• O&M: 16.32 and 17.46 USD per kWdc per year (NREL Q1 2020).
• Energy: the kWh/kW figures from the NREL table above (Phoenix and Seattle).
• Our assumptions: 6 percent discount rate and 25-year life, no degradation, no land cost, no tax credits.

Step 1, capital recovery factor. 0.06 x 1.06^25 / (1.06^25 - 1) = 0.0782.

Step 2, yearly cost per kWdc.

• Fixed tilt: 900 x 0.0782 + 16.32 = 70.40 + 16.32 = 86.72 USD.
• Tracker: 1,100 x 0.0782 + 17.46 = 86.05 + 17.46 = 103.51 USD.

Step 3, break-even gain. 103.51 / 86.72 = 1.194. The tracker needs about 19 percent more energy than fixed tilt to cost the same per MWh.

Step 4, cost per MWh at two sites.

The result is sensitive to the inputs. LBNL rounds costs to 0.1 USD per watt. At the rounding extremes (0.95 and 1.05 USD/Wdc) the break-even gain falls to about 10 percent. At the other extremes (0.85 and 1.15) it rises to about 30 percent. Replace the 900 and 1,100 USD figures with real quotes before you rely on the result. Also, the yield figures are 2013 simulations and the O&M figures are from 2020.

The most useful conclusion is the method. Divide the tracker’s total yearly cost by the fixed-tilt cost, and compare the answer with the site’s simulated energy gain. Generation and financial modeling in SurgePV is where you would set up the energy and cost inputs for a specific site.

Land Use: Acres per MWac and per GWh

NREL surveyed built and proposed US plants. Trackers use more land per MWac. Per GWh of yearly output the picture depends on plant size.

Source: NREL Land-Use Requirements for Solar Power Plants in the United States, Tables 4 and 8 (Ong et al., 2013). The plant samples are small for the 2-axis rows (4 plants).

From these inputs, the 1-axis plants use 6.3 / 5.5 = 1.15 times the land per MWac of fixed tilt under 20 MW (about 15 percent more), and 9.0 / 5.8 = 1.55 times over 20 MW (about 55 percent more). The over-20 MW sample is seven plants for each mount type, so treat that ratio as indicative. NREL reports no significant size effect on land per unit of capacity overall, yet the tracker figure rises from 6.3 to 9.0 acres per MWac between the two size classes.

Tracker rows need wider spacing than fixed rows so that they do not shade each other as they rotate, and that is the reason for the extra land. Where land is expensive, price it into the comparison from the start. Use the solar land area calculator to estimate the acreage a given capacity needs.

Where Fixed Tilt Is Still Built: The Fixed-Tilt Solar PV Market

In the US, fixed tilt is now the minority choice at utility scale. LBNL’s 2024 edition covers 1,504 projects totalling 80.2 GWac. It reports that single-axis tracking dominated again in 2023, with 96 percent of all new capacity (89 percent of new projects) using tracking, the highest share ever.

LBNL also describes where fixed tilt still wins. It says fixed-tilt projects are increasingly built on particularly challenging sites (for example terrain or wind loading) or in the least-sunny regions of the northeast. It lists fixed-tilt exceptions in windy regions (Florida), on brownfields and landfill sites, and on particularly challenging terrain.

The data is US-only. This page does not state market shares for Europe, India or other regions, because no primary source for them was read.

The 7-Question Checklist

Use this list on a first client call. It has no scoring formula. It points you to the facts you need before you request quotes.

If question 2 or 3 is a no, price fixed tilt first. If all seven are yes, request quotes for both mounts and run the break-even test with your own numbers.

When Trackers Do Not Pay Back

The sources above support three conditions where a tracker is hard to justify.

1. Less sunny sites. In NREL’s simulations, Newark and Seattle gained 12.1 and 13.5 percent, below the 19 percent break-even in the worked example. Seattle’s fixed-tilt cost per MWh came out lower.
2. Challenging terrain or wind loading. LBNL reports that fixed tilt is still chosen for these sites.
3. Expensive land. A tracker plant used 15 to 55 percent more land per MWac in NREL’s sample, so land cost can erase the energy gain.

Project size may also matter, but none of the three sources measures how the tracker premium changes with size. Collect quotes at your project size.

For the ground-mount design steps that sit around this choice, such as row pitch, ground coverage ratio and foundations, read ground-mount solar design.

Conclusion

Three actions follow from the sources:

• Replace the flat “20 percent” rule with a site result. NREL’s single-axis gains ranged from 12.1 to 21.9 percent.
• Compare cost per MWh, not yield. Divide the tracker’s yearly cost by the fixed-tilt cost to get the break-even gain, then check it against the site’s simulated gain.
• Get quotes at your project size before you commit. LBNL’s cost averages are rounded and do not control for project size or land.

To run these comparisons on a live site, book a demo or see how solar design software handles ground-mount layouts.

Frequently Asked Questions

Is a solar tracker worth it compared to fixed tilt?

It is worth it when the extra energy is larger than the extra yearly cost. Using LBNL 2023 US costs and NREL O&M benchmarks, a tracker needs about 19 percent more energy than fixed tilt to match its cost per MWh. NREL’s simulations give 22 percent in Phoenix and 12 to 14 percent in Newark and Seattle. Get quotes for both mounts at your project size before you decide.

How much more energy does a solar tracker produce vs fixed tilt?

NREL simulated a single-axis tracker at seven US sites and found 12.1 to 21.9 percent more annual energy than fixed tilt. The gain was 21.9 percent in Phoenix and 21.3 percent in Alamosa, but 12.1 percent in Newark and 13.5 percent in Seattle. A dual-axis tracker gave 3.3 to 43.7 percent more, depending on the site.

What is the cost difference between a tracker and fixed tilt?

In LBNL’s 2023 US sample, tracking projects cost about 1.1 USD per watt DC and fixed-tilt projects about 0.9 USD per watt DC, so about 0.2 USD per watt more. NREL’s Q1 2020 benchmark put utility-scale O&M at 17.46 USD per kW DC per year for single-axis tracking and 16.32 USD for fixed tilt, a difference of 1.14 USD.

Do solar trackers need more land than fixed tilt?

Per megawatt of AC capacity, yes. NREL’s survey of US plants found direct land use of 6.3 acres per MWac for single-axis tracking and 5.5 for fixed tilt in plants under 20 MW. In plants over 20 MW it was 9.0 and 5.8. Per GWh of yearly output the result flips for small plants (2.9 vs 3.2 acres) but not for large ones (3.5 vs 2.8).

Are fixed-tilt solar plants still being built?

Yes, but rarely at US utility scale. LBNL reports that 96 percent of new US utility-scale capacity in 2023 used single-axis tracking. Fixed tilt is increasingly built on challenging terrain, in windy regions, on brownfield and landfill sites, and in the least-sunny parts of the northeast.

Do solar trackers work for residential rooftops?

No. This guide covers ground-mount projects only. The sources used here (NREL and LBNL) describe ground-mounted utility-scale plants, and they contain no rooftop tracker data.

What is the payback period for a solar tracker?

No source used here publishes a tracker payback period, so this page does not give one. Use the break-even test instead: divide the tracker’s total yearly cost per kW by the fixed-tilt cost. The result is the extra energy the tracker must deliver. With the inputs on this page it is about 19 percent.