Chapter 4
IN THIS CHAPTER
Understanding solar radiation
Seeing the effects of the sun’s path
Making the most of the solar resource with proper module placement
Akey consideration in the overall performance of any PV system is how the installed system can use the sun’s energy most effectively. For the array to perform at its best, you need to install it so that it has access to as much energy as possible. Because sunlight is the “fuel” for any PV array, you want to make sure your arrays have full access to as much of the solar resource (the sunlight striking your site) as possible. Having a fundamental understanding of the relationship between the sun and earth allows you to properly site the PV array.
In this chapter, I introduce you to the different forms of solar radiation and how they affect the production of a PV array. I also present you with the keys to understanding how the sun’s path affects your location. Finally, I give you language to use when describing the exact positioning of PV modules in relation to the solar resource.
Note: I don’t expect you to become an astronomer or dissect solar radiation into its different energy values after reading this chapter. I just want you to focus on the crucial concepts that’ll affect your everyday decisions when it comes to installing any PV array.
Solar radiation is the term I use to describe the energy that’s sent to the earth from the sun. Having a good understanding of solar radiation is vital because solar radiation is the driving force for all PV systems. In the following sections, I get you familiar with the various components of the radiation that affects PV modules and help you differentiate between the power and energy values that come from it. I also explain how you can use readily available tools to evaluate the amount of energy received from the sun in the area where you’re working.
The sun, that great nuclear reactor in the sky (and here you thought I wasn’t going to acknowledge nuclear energy’s role in the need to address the world’s power sources), is constantly hurling radiation toward earth. Approximately eight minutes after that radiation leaves the sun, the surface of the earth is assaulted by it. The exact amount of radiation and how you describe it depends on the planet’s atmospheric conditions. On a clear day, there’s little to interfere with the radiation; on a rainy day, the cloud cover greatly reduces the radiation that can reach you.
Diffuse radiation: The sun’s diffuse radiation takes a more roundabout path to the earth. Typically clouds, water vapor, dust, and other small airborne particles block and scatter the diffuse radiation’s path to the planet’s surface. The diffuse component of solar radiation therefore plays a minor role in the power output of a PV module. However, on days when clouds cover the sky, all the radiation is in the form of diffuse light without any direct radiation component.
Another form of diffuse radiation, albedo radiation (or reflectance), is part of the solar radiation at a site. It’s light that’s reflected from physical surroundings, such as a roof or the ground, and put back into the atmosphere as diffuse radiation.
The total global radiation received at a given site is the sum of the direct, diffuse, and albedo components.
After you know a little bit about the components of the radiation coming from the sun (which I share in the preceding section), you can throw some numbers into the mix. The term for the intensity of the solar radiation striking the earth is irradiance, and it’s a measurement of power over an area (power is the rate of the flow of energy; jump to Chapter 3 if you need a refresher on power and other electricity basics). The standard units associated with irradiance are watts per square meter (W/m2), but you can also easily refer to them as kilowatts per square meter (kW/m2).
The amount of irradiance striking a PV module at any given moment is affected by a number of factors, including the location of the module, its position relative to the sun, the time of year, and the weather conditions. I cover most of these factors later in this chapter; in the next sections, I explain the irradiance-related basics that you need to know.
Some common occurrences increase the irradiance levels striking PV modules:
One way to really tell the difference between irradiance on sunny versus cloudy days is to examine charts that measure all the irradiance values, like the ones in Figures 4-2 and 4-3 (the values shown are in W/m2).
PV modules produce current (the flow of electrons) and voltage (the pressure that makes electrons move) when exposed to sunlight and the electrons are given a path to flow in. Although voltage isn’t greatly affected by irradiance, current is directly dependent on irradiance. As soon as ambient light is present (at sunrise or even during a cloudy day), the PV module will have nearly full voltage present. Current, on the other hand, will vary throughout the day as the irradiance values increase and decrease.
You can measure irradiance on the job site to estimate the current value from the module or array and compare that to the actual current measurement you make with a digital multimeter (see Chapter 3 for details on measuring current). Irradiance measurements are used most often for data collection and in troubleshooting applications. Because the amount of current flowing from the array is directly related to the irradiance, by measuring and comparing both, you can quickly determine whether the PV array is performing to expectations. I show you how to make this comparison in Chapter 6.
To use a pyronometer, simply turn the device on, place the sensor in the same plane as the array, and read the meter. Keep in mind that the sensor consists of a small PV cell that has been calibrated at the factory. It may not be the most accurate tool, but it’s a handy device for what you need.
A successful PV system designer and installer not only knows how to track irradiance levels over the course of the day (I cover irradiance earlier in this chapter) but also how to calculate the energy values from the solar radiation at the site. These energy values are referred to as irradiation and are based directly on the irradiance levels received. You use irradiation values to help figure out how much energy a PV array will produce at a particular site.
As I explain in Chapter 3, energy is determined by multiplying power (measured in either watts or kilowatts) by a duration of time, typically an hour. Consequently, energy is typically measured in kilowatt-hours (kWh). The power received from the sun is measured in W/m2, but with a quick conversion (1,000 W = 1 kW) you can transform that into kW/m2. If you take that power value and multiply it by the number of hours that receive that much irradiance, the result is kWh/m2.
However, as you can see if you refer to Figures 4-2 and 4-3, irradiance values aren’t constant for hours at a time. In fact, they can change with the blink of an eye, which leads to the following question: If the irradiance values are only constant for seconds, or minutes at best, how am I supposed to take that information and turn it into kWh/m2, which is the energy value I really need?
Love it or hate it, the answer lies in calculus. What you’re really after is the area beneath the curve, and you can find it with a few quick calculations. If you’re a calculus-hater, you’re in luck — I don’t mess with any advanced math here. That’s because the good folks at the National Renewable Energy Laboratory (NREL) have done the hard work of calculating areas beneath curves and have broken down the results into a single number for easy use.
Take a look at Figure 4-4. It’s actually the same irradiance curve as the one I present in Figure 4-2 for a perfectly cloudless day, with the exception of a square box drawn over the curve. This box represents the equivalent area covered by the curve. In other words, the NREL has turned a curve into a box. As I show you later in this chapter, the NREL publishes this information for a number of locations for your reference.
With the area beneath the curve represented as a box, you have one irradiance value to use and an easily defined number of hours. Now you can simply take the irradiance value, multiply it by the number of hours, and find the energy value (yes, that’s right — irradiation). For example, if the top of the box intersects the irradiance line at 850 W/m2 and the number of hours is equal to 4, then you can calculate the energy received at this location as follows:
850 W/m2 × 4 hours = 3,400 Wh/m2 = 3.4 kWh/m2
Typically, irradiation values have an associated time period, such as the number of kWh/m2 over the course of a day, month, or year. As a PV designer, plan to look at all of these periods, but focus on the daily values.
The amount of solar energy received at a particular location each day is measured in terms of the energy per unit area per day (kWh/m2/day). The PV design lingo for this numerical value is the number of peak sun hours or insolation. In the sections that follow, I explain how to use peak sun hours to determine a PV array’s energy output and point you toward some handy charts and maps that list peak sun hours.
In the earlier “Relating current and voltage to irradiance” section, I tell you that the term peak sun refers to an irradiance value of 1,000 W/m2. Well, the number of peak sun hours describes the number of hours each day that the irradiance value equals 1,000 W/m2.
You probably don’t even have to refer to Figure 4-4 to remember that the sun doesn’t just pop up over the horizon, go to 1,000 W/m2, and sit there all day. At times, the irradiance values will be very low; other times, they’ll be very high. The number of peak sun hours is merely an estimation of the amount of time each day that the irradiance is equal to a peak sun. And because PV models are rated for their output under peak sun conditions, the number of peak sun hours each day indicates how many hours each day the PV array will operate at its full power output.
I think an example, complete with numbers, would be a good idea here. To start, divide your insolation value by peak sun to get a number of hours per day. Check out the example in the earlier “Calculating solar radiation energy: Irradiation” section, where the box in Figure 4-4 intersects the irradiance line at 850 W/m2 and the amount of time is 4 hours. The result of the equation is 3,400 Wh/m2 of energy (or 3.4 kWh/m2). Because this measurement was taken during a single day, it’s actually an insolation value (3.4 kWh/m2/day). By dividing that value by one peak sun (1,000 W/m2, which is equal to 1 kW/m2), you get the number of hours each day that the PV array will operate at its rated output.
3.4 kWh/m2/day ÷ 1 kW/m2 = 3.4 hours/day
You then multiply this number of hours by the power value of a given array to figure out the expected maximum energy output. So if I have a 3 kW array on my house and the number of peak sun hours today is 3.4, I can calculate the expected energy output by multiplying the two together.
3 kW array × 3.4 peak sun hours = 10.2 kWh of energy
Note: The number of peak sun hours varies with a number of factors, most notably the time of year and your position on the globe. I show you more details on these effects later in this chapter.
After you know how to make calculations using peak sun hours, how do you know precisely what peak sun hour numbers to use for your client’s area? NREL to the rescue! You can find peak sun hours data for more than 200 U.S. locations on the NREL Web site at rredc.nrel.gov/solar/pubs/redbook
. Granted, other sources of peak sun hours data are out there and you can spend a lot of time dissecting all of them, but I show you the NREL data so you can acquire a fundamental understanding.
In Figure 4-5, you see an example of the data set NREL publishes in its Solar Radiation Data Manual for Flat-Plate and Concentrating Collectors. (Nicknamed “the NREL Redbook,” this resource also has a good introduction to help you better understand all the terms the Redbook uses in its charts.) Although all the values shown are based off of arrays that point true south, these tables also list multiple solar resource values based on the tilt of a PV array that’s positioned on a horizontal surface rather than a vertical one. On the left-hand side of Figure 4-5, you see 0°, Latitude –15°, Latitude, Latitude +15°, and 90°. Latitude –15° means the tilt angle of the PV array off of the horizontal is equal to the local latitude minus 15°. (I get into the details of these values later in this chapter. For now, just focus on the fact that the PV array is moving from flat to vertical as you look down the far-left column.)
As you move horizontally across any of these different tilt-angle designations, you see numerical values for the number of peak sun hours for each month. The unit for these values is kWh/m2/day, or peak sun hours. Think of it as the average number of hours each day of that month when your PV array will operate at its rated output.
You can get an idea of the peak sun hours available across the United States in Figure 4-6. As you can see, the greatest amount of peak sun hours occurs in the southwest, and the numbers decrease as you move north. This chart can help you generalize and compare your location to others, but you should only use it to create a rough estimate of your location. You always need to look up the specific site you’re working in to make an accurate energy-production estimate.
To succeed as a PV system designer and installer, you need to have a firm grasp on the relationship of the sun and the earth, particularly in terms of how they’re positioned relative to each other throughout the calendar year. For someone in northern Alaska, these changes are much more dramatic than for someone in Hawaii, but you need to understand the concepts regardless.
In the following sections, I describe general seasonal effects based on the earth’s movement, the sun’s relationship to your client’s specific location, and solar time; I also explain how to analyze sun charts and introduce the solar window.
The number of daylight hours each day has an obvious effect on a PV array’s production: More sun means more solar energy. As a PV installer, you need to be able to visualize how the position of the sun changes with each season and the effect that has on the arrays you’re designing and installing. In other words, you need to be able to take seasonal effects into account.
One important factor to consider is the motion of the earth around the sun. Earth takes an elliptical path around the sun, meaning that on the summer solstice (approximately June 21), the earth is actually at its farthest point from the sun. On this day, the Northern Hemisphere is tilted toward the sun, and that half of the world has its longest day (and shortest night) of the year. Time moves on, and the earth continues to orbit the sun. On the winter solstice (approximately December 21), the planet is as close to the sun as it’ll ever get; on this day, the Northern Hemisphere is tilted away from the sun, creating the shortest day and longest night.
The other factor to consider when it comes to seasonal effects is the tilt of the earth’s axis. When viewed from space, the earth’s axis has a tilt of 23.5 degrees. Because of this tilt, during the times between the spring equinox (approximately March 21) and the fall equinox (approximately September 21), the Northern Hemisphere is actually pointing toward the sun, whereas the Southern Hemisphere is pointed away from it (see Figure 4-7). As the earth’s orbit continues toward winter, the hemispheres swap their positions, so the Northern Hemisphere points away from the sun, and the Southern Hemisphere points toward the sun. On the equinoxes, the earth isn’t pointing toward or away from the sun; instead, it’s directly perpendicular with it.
Take a look at Figure 4-8 and pretend that your perspective of earth is the same as the sun’s (doing so helps you visualize how the tilt of the earth affects the amount of sunlight striking any part of the earth). Notice how the tilt during the winter and summer restricts the sun’s access to the hemispheres that are pointed away from the sun and how the sun has full access to the entire globe on the equinoxes.
As I show you in the preceding section, the motion of the sun across the sky is due to the tilt of the earth in relationship to the sun and the path the earth takes around the sun. (Yes, I know the sun is the stationary object, and the earth is actually orbiting the sun. But for simplicity’s sake, I refer to the sun moving across the sky and how the sun’s position changes.) In the next sections, I show you how these facts relate to where you sit on earth because as a PV system designer and installer, that’s what you really care about.
You’re probably well aware that the angle of the sun off the horizon varies throughout the year. The amount of variation is consistent across the globe, with the exact measurement dependent on the time of day and your specific latitude on the earth.
To view the changes in the solar altitude, picture yourself standing on the equator for an entire year (I suggest picturing yourself with your favorite cold beverage in hand because a year can be a long time). On the spring equinox, the sun is directly overhead, or 90 degrees from your perspective. As the earth continues to orbit the sun, it moves toward the summer solstice. When it gets to June 21, the sun is no longer directly over your head; it has actually moved 23.5 degrees to the north. As the earth continues its path, it comes back around to the fall equinox, and the sun is directly overhead once again. And as you can probably figure out by now, when the earth moves to the winter solstice position, the sun is now 23.5 degrees to the south of your location on that day. By the time the earth gets back to March 21, your year is over, and the sun is again directly overhead.
Just as the sun has a position in the sky based off of the horizon (altitude), it also has a position in the sky that moves from east to west. This position is known as the solar azimuth, and it has a steady movement on a daily basis.
The earth rotates around its own axis once every day, or once every 24-hour period. Because a full rotation of the earth measures 360 degrees, the motion of the sun is 360 degrees divided by 24 hours, which equals 15 degrees per hour. So over the course of an hour, the motion of the sun from east to west is 15 degrees.
One point worth noting is the difference between solar time and clock time because the two very rarely match. When looking at your client’s location, you care about locating the array based on solar time, not necessarily the time on your watch. The sun (and lucky ol’ Arizona and Hawaii) doesn’t have a clue about daylight saving time; it operates solely on solar time.
Sun charts allow you to figure out how the sun’s path looks on paper. You can use them to pinpoint the sun’s location at any time of day and any time of year, which is helpful when you’re evaluating a particular site for potential shading issues. The sun charts in this section are the basis for the shading-analysis tools I describe in Chapter 5, so don’t skip over this material.
Figure 4-10, the sun chart for 30 degrees north latitude shows a typical sun path. The curves represent the path of the sun across the sky for various times of the year. The tallest curve is the path of the sun on the summer solstice, the middle curve represents the equinox paths (March 21 and September 21), and the lowest curve is the path on the winter solstice.
Notice that at solar noon on the equinox dates, the altitude of the sun is equal to the zenith minus the latitude (90 degrees – 30 degrees = 60 degrees). You can further evaluate the sun chart to see that the altitude difference between summer solstice and the equinox at solar noon is 23.5 degrees.
See how the sun rises north of east and sets north of west during the summer and just the opposite during the winter? All of these parts of sun charts help you understand the path of the sun and describe the solar window, which is the basis of your solar site assessments; I introduce you to the solar window in the next section.
If you think about the motion of the sun across the sky at your location, you can imagine it appearing at various positions over the course of a year. In fact, this movement is very predictable and relatively easy to represent with the sun charts described in the preceding section. All the points between the solstices can be defined as the solar window. Figure 4-11 shows the portion of the sky considered in the solar window.
The path of the sun on each solstice date defines the extreme sun paths for a location. By defining these two paths, you know that the sun will always be within that “window” every day of the year. (The solar window is represented by the half gray, half clear arc in Figure 4-11.) As you design a PV system, your goal is to keep as much of that window open for the PV array as possible. If a tree or building is inside that window, the PV array will be shaded for some amount of time, reducing the energy output.
After you know how the sun moves at your client’s location, you need to relate that movement to the placement of the PV modules. The angle off of the horizon on which the modules are mounted and the direction they’re pointed in reference to true north are the key factors for your installation. I explain some basics to know in the sections that follow; flip to Chapter 5 for full details on performing a site-survey analysis for a PV system.
Tilt angle is the number of degrees the PV modules are mounted off of the horizon. It’s a critical consideration in any PV system installation. Installations vary from nearly flat on some large commercial roofs (called low-slope roofs) to a very slight tilt (5 to 10 degrees) in some applications to vertical walls (which are at a 90-degree angle) and everything in between.
Knowing about the tilt of the earth’s axis (which is 23.5 degrees) relates to tilt angle. How? Refer to Figure 4-5 for a refresher on the solar radiation data sets. In particular, look at how the tilt angle of the modules is represented in terms of the number of degrees off the horizontal in relation to latitude. The tilt angles in relation to the site’s latitude are affected in the following ways:
The idea behind varying the tilt angle is to maximize the PV array’s energy production by pointing the array perpendicular to the sun as much as possible. So if your client needs to maximize energy production in the summer months (perhaps because she’s running a water pump), you should mount the array so the tilt is equal to a value of latitude minus 15 degrees. On the opposite end, if the client wants more energy production in the winter, the array should have a tilt angle of latitude plus 15 degrees.
The reason for the magical 15-degree value is the fact that the sun moves 23.5 degrees between the equinox date and the solstice date and then back again. By adjusting the tilt angle by 15 degrees rather than the full 23.5, you allow the array to be perpendicular to the sun for the days and weeks surrounding the time of year you’re optimizing for.
Note: If you read almost any older textbook on the subject of PV module mounting and how best to determine tilt angle, you’ll see a nearly universal answer: Tilt the PV array at an angle equal to the latitude for maximum annual energy production. Although this would be an absolutely correct statement if your client’s site were always free of cloud cover and other weather variations, such as a lot of fog in the fall and winter, it may not be an absolute truth for your client’s location. In Chapter 5, I show you how to use some commonly available tools to help you determine the tilt angle that’ll serve your client best.
Another major component to consider when planning the array location to maximize energy output is the orientation with respect to true north, or the azimuth. The best way to refer to the azimuth of an array is to refer to the number of degrees the array is facing with reference to true north, exactly the same as you refer to the sun’s position.
With this notation, the array has an azimuth of 90 degrees if it faces true east, 180 degrees if it faces true south, and 270 degrees if it faces true west. Bear in mind that true east, true south, and true west don’t refer to compass directions; instead, they take magnetic declination into account. (Magnetic declination is the difference between true north and magnetic north; flip to Chapter 5 to discover how to account for magnetic declination.) For an example of what I mean, look at Figure 4-12. It shows a PV module that has an azimuth that’s east of south. You could also say that this module has an azimuth of approximately 165 degrees based on how far it is from true north.
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