DIYrich
Solar Wizard
How do you get 120v from 208v 3-Phase?No need to convert.
Everything that works on 240v will work on 208v.
How do you get 120v from 208v 3-Phase?No need to convert.
Everything that works on 240v will work on 208v.
208v 3-phase is a 3-phase WYE system.How do you get 120v from 208v 3-Phase?
This is typically because power supplies in most appliances have a wide 100v-240v range, correct?No need to convert.
Everything that works on 240v will work on 208v.
Isn’t that a partnered system where Victron and Fronius advertise some secret sauce? I would put that in the same class as Enphase PLC, except maybe with less theoretical capability for on grid operation since you can’t shift any parameters in that situation while you can still modulate PLCI guess you haven't seen a Victron/Fronius AC coupled system operating, have you?
Major appliances are more like 180-240V, to cover shitty grids, Japan’s lower voltage, and U.S. + EUThis is typically because power supplies in most appliances have a wide 100v-240v range, correct?
No. Victron can communicate via LAN with the Fronius to do zero export. But in an off-grid setup that function is not used. The Victron and the Fronius systems are really just individually configured, and there is no "communication" other than frequency shift.Isn’t that a partnered system where Victron and Fronius advertise some secret sauce? I would put that in the same class as Enphase PLC, except maybe with less theoretical capability for on grid operation since you can’t shift any parameters in that situation while you can still modulate PLC
Just in the SunSink videos.Makes me want to get a 30k or 60k at my next house, just for fun. Lol
Has anybody seen one installed?
Yes, had I known that I was going to end up with a SolArk when I designed my initial system in 2021 I might have planned for more DC coupled solar to give me more flexibility. As it turns out my initial install of 8kW of micros was a lot easier because RSD was built in. I also encountered fewer long term grid down situations and those have lasted only a few hours so not having the benefit of all my AC coupled micros in my current scenerio is not an issue. If I do have a long grid down situation I have a 14-30 receptacle which can put 5.7 kWs of load on my system and when I testedd that the AC coupled micros were able to produce even though my battery was at 95% SOC. I do have 3kW of DC coupled solar and the smoothness of that control allows my system to function well during situations where there is little load on just the DC coupled solar.AC coupling works best if there's also DC PV connected.
It's a much smoother control.
The secret sauce I meant is, the two companies worked together to ensure that it worked, and it’s a supported combination. To me this means they tested it and were willing to release it together. And there is commitment on Fronius side to guarantee that the specified Microgrid profile will either never be changed in behavior, change is within agreed upon limits, or change is tested for regressions.No. Victron can communicate via LAN with the Fronius to do zero export. But in an off-grid setup that function is not used. The Victron and the Fronius systems are really just individually configured, and there is no "communication" other than frequency shift.
100v-240v are power supplies that rectify to low voltage dc.This is typically because power supplies in most appliances have a wide 100v-240v range, correct?
@DIYrich - Thanks for the detailed response. Much appreciated.
2. I've been told this by 2 separate Sol-Ark technicians - the frequency change goes from 60.0 to 62.0 within a matter of a few seconds. There is no modulation in between. So there is no graceful ramp down of AC coupled inputs on the GEN port. They are either ON or OFF. At least that is what I was told. If so, this isn't ideal. And it's surprising to me, coming from a quality company like Sol-Ark
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3. I agree that it doesn't make sense for the frequency on the AC-coupled GEN port to be different than the LOAD port. The on-grid inverters are synced with the GRID frequency. I would think that in Off-grid mode, the frequencies on both the GEN and LOAD ports would be the same. But maybe Sol-Ark does something different here? I also believe that frequency shifting doesn't take place unless you put the AC PV on the GEN port, but not 100% certain of this.
Actually, the biggest thing is to have the frequency range where the GT inverter goes from 100% to 0% output correct. In the Victron inverters you set those parameters (with a little room for error, e.g. 0% Frequency is set slightly higher than where 0% is on the GT inverter) and you tell the Victrons how many kW of PV there is connected, then they work off of that. And I'm pretty sure it would work quite well with any GT inverter that does proper frequency shift curtailment that isn't just on/off. The SMA that I had used at first shut off at 60.5Hz IIRC. The Fronius starts throttling around 60.5Hz or maybe 60.8Hz is at 0% somewhere around 62Hz, which I believe is a pretty standard range on new GT inverters.The secret sauce I meant is, the two companies worked together to ensure that it worked, and it’s a supported combination. To me this means they tested it and were willing to release it together. And there is commitment on Fronius side to guarantee that the specified Microgrid profile will either never be changed in behavior, change is within agreed upon limits, or change is tested for regressions.
Victron has numerous writeups that are easy to find on Google for how to set this up.
That said, I can sort of believe that AC couples retrofit companies are willing to take on the testing load themselves for the most common customer situations (EG IQ7 and IQ8, or SEDG), in the absence of cooperation from the GTI vendor
Ok, but upthread in post #18 i shared the grid response speed required by my POCO:And I'm pretty sure it would work quite well with any GT inverter that does proper frequency shift curtailment that isn't just on/off.
And of course the GEN port relay is the ultimate failsafe off/on mechanism.the Sol-Ark can shift it's frequency all the way to 65hz to shutdown non 1741SA inverters. But this works more as a off/on kind of thing.
Whenever you are in a grid-interactive (I.e. net metering/selling to the PoCo) type of scenario, you are of course, subject to the grid-interactive requirements of said PoCo. The one thing that I'm not sure on in regards to that 5 second response time requirement is if that is "the" time frame, or if it is the maximum response time allowable. I would expect that when curtailing "down" (dropping output power level) you would be allowed to respond instantaneously, as an instant drop to 0% would be desirable in a grid-down scenario. I would expect that the 5 second requirement is to avoid PV production to go from 0% to 100% instantly, as that could cause grid instability, especially right after coming back online from a power outage scenario. Now, there is a 5 minute delay on re-connection when grid comes back on, but imagine 20 homes with 10kW of solar connected and grid comes back on, then 5 minutes later the full 200kW of PV starts dumping onto the grid lines at the same time.Ok, but upthread in post #18 i shared the grid response speed required by my POCO:
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1547-2018 defines open loop response time as
“The duration between a control signal input step change (reference value or system parameter) until the controlled output changes by 90% of its final change, before any overshoot.”
What is the response parameter on the off-grid code that you posted earlier?The one thing that I'm not sure on in regards to that 5 second response time requirement is if that is "the" time frame, or if it is the maximum response time allowable.
There's also ride-through provisions in 1741SA to avoid destabilizing the grid when there is a blip. 1741 classic was too trigger happy with disconnecting. You don't want the grid to get wrecked if, during a brownout or other blip, the grid tie inverters decide to peace out and withdraw their power.I would expect that the 5 second requirement is to avoid PV production to go from 0% to 100% instantly, as that could cause grid instability, especially right after coming back online from a power outage scenario. Now, there is a 5 minute delay on re-connection when grid comes back on, but imagine 20 homes with 10kW of solar connected and grid comes back on, then 5 minutes later the full 200kW of PV starts dumping onto the grid lines at the same time.
For reference: discharging a 10kWh battery bank at a rate of 10kW (pretty high discharge rate there...) for 5 seconds = 13.9WattHours which is 0.14%.
So, discharge any size bank at a 1C rate for 5 seconds (until GT inverter ramps back up power output) and you have lost only 0.14% of that banks storage! 5 minutes of 1C discharge would drop 8.3%. So as you can see, unless you are going to have massive load swings, to the tune of nearly a 1C discharge, having a few seconds, or even a few minutes, of discharge until PV GT inverter ramps back up won't be anything terrible at all.
I'm actually not sure. I'll see if I can find that.What is the response parameter on the off-grid code that you posted earlier?
Do you know if the ride-through provisions are both V and Hz based? Or are they only voltage based? (I think frequency is used as well, if I remember correctly.) If frequency is involved as well, do you know what the upper limits are for Hz? (I mean specifically for ride through.)There's also ride-through provisions in 1741SA to avoid destabilizing the grid when there is a blip. 1741 classic was too trigger happy with disconnecting. You don't want the grid to get wrecked if, during a brownout or other blip, the grid tie inverters decide to peace out and withdraw their power.
I'm pretty sure 5 min delay is required any time you are grid-tied. But in an off-grid setup you could bump that time down to 5 or 10 seconds.To clarify, you are only talking about grid tied with the 5 min delay? AC coupling is supposed to avoid that (and that's what I'm happy with, as I've beaten to death a few times already)
What I am referring to is when the grid former/battery based inverter has frequency shifted up to throttle back GTI because batteries are full or nearly full, with low loads. Then a large load kicks in (let's say electric dryer). When that happens, the battery based inverter drops the frequency, in order to allow GTI to ramp up again on production in order to have PV directly power that load.These violate standard design rules. You are supposed to have grid former inverter AC-out = GTI AC out (sustained, not surge), so that it can always fill in. And they are supposed to be able to ramp up quickly enough.
The battery based inverter will use either closed loop comms info or measured battery volts and amps to adjust frequency shift off of. My personal system does not have closed loop comms. Therefore the Victrons are looking at battery amps (measured by Victron SmartShunt) and battery volts, and also looking at charge voltage for current charge state. When battery volts rises above absorb voltage setpoint, the Victrons begin to shift frequency up. I believe they have a PID loop of some sort in their algorithm, and how fast the voltage is rising will play into how quickly the frequency shifts up. Once Absorb voltage has been reached, they will "hold" it there until Absorb time has been reached (I have mine set to 1hr to allow top balancing of cells to happen.) then frequency shifts all the way to 62.4-62.6Hz until battery volts drops to Float setpoint, then PID loops resumes "playing" with frequency to maintain Float volts.What are your thoughts on the ramp-down constraints? I think they're determined by the charge current available at a particular SoC %. Depending on how good the BMS communications is, this may be set more or less conservatively. Also, the AC coupling may not be willing to use the surge charge current offered by the BMS to push it further.
On my personal system (I am of course running "openloop"), I only have AC coupled PV and I am able to get my batteries completely full. (E.g. 100% SOC.) I think the biggest issue that people might run into is with batteries that do not have active balancing, and only passive balancing in the BMS. I have seen so many batteries with only passive balancing run into cell imbalance issues after 4 or 5 years of operation in off-grid setups! What happens then is that battery volts comes up close to your Absorb voltage target, then one cell (or cell pack) suddenly has voltage spike causing BMS shutdown. If there are a few batteries in parallel, the other units receive unit A's charge current when it shuts down. This causes higher C rate, which causes imbalanced cell voltage spikes in another one...... which dumps ore charge current.... until all units have shut down. That in turn causes battery based inverter to see battery overvoltage (when last unit shuts off, charge current spikes DC voltage) and shut down.If you have a really large battery to inverter ratio, you might even be able to charge at very high SoC %, if the CC/CV taper still allows enough charge current. Now, I'm not sure if the charger logic is actually smart enough to predict the available charge current at that part of the curve.
So classic cascade failure. I get that one solution appears to be active balancing to keep the batteries from getting out of balance and starting the chain reaction above, but wouldn't closed-loop comms also solve/avoid the issue? [I get that you don't want/have closed loop, just wondering if it's another solution.]What happens then is that battery volts comes up close to your Absorb voltage target, then one cell (or cell pack) suddenly has voltage spike causing BMS shutdown. If there are a few batteries in parallel, the other units receive unit A's charge current when it shuts down. This causes higher C rate, which causes imbalanced cell voltage spikes in another one...... which dumps ore charge current.... until all units have shut down. That in turn causes battery based inverter to see battery overvoltage (when last unit shuts off, charge current spikes DC voltage) and shut down.
It would depending on how the BMSs communicate. I have several rack batteries which communicate through a master. I don't know how an inverter would respond in the above situation. If it reduced the charging current the cascade could be stalled.but wouldn't closed-loop comms also solve/avoid the issue?
So classic cascade failure. I get that one solution appears to be active balancing to keep the batteries from getting out of balance and starting the chain reaction above, but wouldn't closed-loop comms also solve/avoid the issue? [I get that you don't want/have closed loop, just wondering if it's another solution.]
Reducing charging current can help, but honestly, active balancing is by far better long term! I have seen/worked with batteries that were so far out of balance (after 5 years of use with only passive balancing) that in order to balance cells AFTER ADDING AN ACTIVE BALANCER WITH 1A BALANCE CURRENT that I had to set all charge voltages to ~3.375V/cell (27V/54V for 24V/48V nominal respectively) and hold the voltage there for a whole week before bumping up the voltage gradually until I got it up to ~3.55V/cell. Anything higher than that resulted in cell overvoltage spikes!It would depending on how the BMSs communicate. I have several rack batteries which communicate through a master. I don't know how an inverter would respond in the above situation. If it reduced the charging current the cascade could be stalled.