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Victron Multi RS 48/6000 + JK BMS CAN Communication

Forum discussions and user experiences regarding the integration of the JK-PB2A16S20P BMS with the Victron Multi RS Solar 48/6000.

Here we have tried to compile as much information as possible in regards to the JK BMS and Victron RS Solar 48/6000 All in One Inverter and communication with a lifepo4 battery. This topic requires the use of an external Cerbo GX, because the Multi RS Solar cannot communicate at the correct baud rate. Read on to see all the details

Integrating a JK BMS specifically the JK-PB2A16S20P BMS with a Victron Multi RS 48/6000

Overview: The JK-PB2A16S20P (a 16-cell, 48V “inverter” JK-BMS with CAN) can be integrated with a Victron Multi RS Solar 48/6000 inverter-charger. Users on various forums have shared their experiences getting these devices to communicate via CAN bus. Key steps include proper wiring (using Victron CAN cables), matching CAN-bus speeds, setting the JK BMS to the correct protocol for Victron, and configuring the Victron GX device (e.g. Cerbo GX) with DVCC so the BMS can control charging. Below are highlights from user discussions, including successful setups, required settings, and common issues encountered.

Connection and CAN Bus Compatibility

Victron GX Configuration (Cerbo GX / DVCC Settings)

Most integrations use a GX device (such as Cerbo GX or Venus OS on a Raspberry Pi) to interface the BMS with the Multi RS inverter:

  • Enabling DVCC: Victron’s Distributed Voltage & Current Control (DVCC) must be enabled for the inverter/charger to actually obey external BMS commands. Simply seeing the BMS data on the Cerbo GX is not enough; DVCC allows the BMS to actively limit charging. In one case, a user’s Multi RS was “stuck in Discharging” and not using solar, until it was noted that the system was not under BMS control (Nearly no solar preference after factory reset – Multi RS – DIY – Victron Community). Once DVCC was enabled on the Cerbo and the battery was properly detected, the Multi RS transitioned to using the BMS info for charge regulation. On the GX device, under Settings → DVCC, “Allow battery to manage chargers” should be on, and the JK BMS will be listed as the controlled battery. A user noted their DVCC menu showed “Used sensor: JK-BMS on CAN-bus,” indicating the system had picked up the JK BMS as the battery monitor (Nearly no solar preference after factory reset – Multi RS – DIY – Victron Community). With DVCC on, the Multi RS display should indicate “External control” for charging, meaning it’s listening to the BMS.
  • Battery Monitor Selection: In some cases, after connecting the JK BMS, the Cerbo GX might still default to an internal battery monitor or no monitor. It’s recommended to check Settings → System Setup → Battery Monitor and ensure the JK BMS is selected as the battery data source (instead of “No battery monitor” or a BMV sensor). One forum expert advised that the battery should appear first in the Cerbo’s device list and be selected, otherwise the inverter will charge based on its own static settings (Nearly no solar preference after factory reset – Multi RS – DIY – Victron Community). In summary, verify that the Victron system knows to use the JK BMS readings (voltage, SoC, etc.) for control.
  • Integration via Venus OS Driver (Optional): One user (hdv) achieved integration by installing the open-source dbus-serialbattery driver on a Cerbo GX (Venus OS) (JK BMS + Multi RS Solar protocol issue – DIY – Victron Community). This driver allows various BMS (like JK) to communicate over serial or BLE if not using direct CAN. In that setup, the JK BMS was connected using a serial link and the driver translated the data to Victron’s D-Bus. After enabling DVCC, the result was the same – the Multi RS saw a managed battery and followed the BMS limits. This approach can be useful if the CAN bus method is problematic; however, in hdv’s case the CAN was also utilized (they mention setting the CAN-bus to 500 kbit) (JK BMS + Multi RS Solar protocol issue – DIY – Victron Community). The takeaway is that whether via native CAN or a Venus OS driver, the BMS data needs to get into the GX device, and then DVCC will let it control the Multi RS.

Successful Integration Experiences

Users have reported successful connections once the above configurations were in place:

Common Issues and Troubleshooting Tips

Despite successful reports, a few recurring issues have been noted by users during setup. Here are common problems and how they were resolved:

One user had no TX/RX traffic on the Cerbo’s BMS-CAN until realizing the BMS was still in protocol 2; switching to protocol 4 immediately fixed that (Cerbo GX BMS-CAN – JK Inverter BMS not visible – DIY – Victron Community). Also, use the BMS-CAN port on Cerbo GX set to 500kbit/s for the JK BMS (Cerbo GX BMS-CAN – JK Inverter BMS not visible – DIY – Victron Community). The VE.Can port (250kbit) on the Cerbo is generally for Victron devices like the Multi RS or MPPT – the BMS should go on the separately configurable port.

Finally, adding proper termination resistors on the CAN bus ends is important for reliability (the Cerbo’s BMS-CAN port may need an external terminator if it’s one end of the CAN chain) (Cerbo GX BMS-CAN – JK Inverter BMS not visible – DIY – Victron Community).

What is a terminator In a CAN bus system, a terminator is simply a resistor (typically 120 Ω) that’s placed at the end of the cable run. Its job is to “absorb” the signals and prevent them from bouncing back (or “reflecting”) along the cable, which could interfere with proper communication between devices.

  • Inverter Data (PV/Load) Disappears When BMS Connected: This issue was reported when a user tried to tie the JK BMS into the same CAN network as the Multi RS. After switching the Multi RS to “CAN-bus BMS” mode, the Cerbo GX no longer showed PV production or load on the Multi RS (JK BMS + Multi RS Solar protocol issue – DIY – Victron Community). The fix was to separate the CAN buses due to the speed difference as described earlier. Do not put the BMS and Multi RS on one continuous daisy-chain unless you configure them to the same baud rate. In practice, the Multi RS stayed on the VE.Can bus (250k), and the JK BMS was isolated on the other CAN interface at 500k (JK BMS + Multi RS Solar protocol issue – DIY – Victron Community). Once this was done, the Multi RS data returned and the BMS info was also available – the GX could see everything concurrently. In summary, if enabling the BMS on CAN makes other devices “vanish” from the network, it’s likely a CAN conflict; use separate ports or matching speeds to resolve it (JK BMS + Multi RS Solar protocol issue – DIY – Victron Community).

  • BMS Detected but Charger Not Following BMS (No DVCC): Another common pitfall is forgetting to enable DVCC (in older Venus OS versions, enabling “BMS support”). Without DVCC, the Victron inverter/charger will display the battery’s info (like SoC) but will not obey the BMS’s charge/discharge limits. For example, one person’s Multi RS was charging based purely on the default voltage settings, since the system wasn’t actually in “BMS-controlled” mode (Nearly no solar preference after factory reset – Multi RS – DIY – Victron Community). The Victron community recommended turning on DVCC and selecting the BMS as the controlling battery (Nearly no solar preference after factory reset – Multi RS – DIY – Victron Community). After doing so and rebooting the Cerbo GX, the Multi RS began taking power from solar and charging the battery properly, no longer stuck in an idle state. Ensure “Enable DVCC” is on, and “Shared Voltage Sense” / “Allow BMS to control charge” are enabled as appropriate. On the Multi RS display or Remote Console you should then see indicators that the battery is managed by BMS (e.g. charge voltage may show as externally limited). If you don’t see a “BMS” or “External” status, double-check DVCC settings. As one forum user put it: “Your system is not under the control of the battery’s BMS – you need to solve that first” (Nearly no solar preference after factory reset – Multi RS – DIY – Victron Community).
  • Over-Voltage Protection (OVP) Trips / Charging Cuts Off: Some users have encountered the BMS cutting off charging (hitting OVP) or a rapid on-off behavior when the battery is near full. A JK BMS integrated with Victron will typically stop charge once any cell hits the over-voltage threshold. If the Victron charging voltage is set too close to that threshold, you can get an overshoot or oscillation. In one DIY Solar thread, a user’s 16S LiFePO4 with JK BMS would reach about 100% and then oscillate between charging and discharging every few seconds at float (Jk BMS jumping charging discharging – Q&A and troubleshooting – Victron Community). This was attributed to the BMS constantly toggling at the max voltage. The community identified two main culprits for OVP issues: (1) cell imbalance – if one cell is weaker and hits 3.65 V early, it triggers OVP while others are lower; (2) charge voltage set too high – pushing the battery to the very edge of 100% (Battery overcharging hitting OVP – JK BMS + Victron RS450/200 | DIY Solar Power Forum). The recommended solutions were: balance the battery (and check JK BMS active balancing settings) and reduce the charge voltage slightly (for instance, instead of 3.65 V/cell (58.4 V total) set about 3.60–3.62 V/cell (57.6–57.9 V) as the charger target) (Battery overcharging hitting OVP – JK BMS + Victron RS450/200 | DIY Solar Power Forum). One responder suggested running the system “open-loop” (no BMS comms) temporarily to manually adjust absorb/float to a safer level (Battery overcharging hitting OVP – JK BMS + Victron RS450/200 | DIY Solar Power Forum). In practice, many users set the JK’s per-cell charge limit (RCV) a bit below the hard OVP, and/or configure Victron’s absorption a tad lower, to prevent the JK from ever having to disconnect abruptly. When properly tuned, the Multi RS will taper off charge as the BMS requests and not hit the OVP in the first place.
  • State of Charge Sync and Shunt Use: The JK BMS provides its own State of Charge (SoC) calculation to Victron. Some have noted that relying on the BMS’s SoC is generally fine (especially if the JK BMS is calibrated), but others prefer using a Victron SmartShunt or BMV for more accurate readings. In one case, a user asked if a smart shunt was “required” when using the JK BMS as the monitor; the consensus was that it’s not required, but a dedicated shunt can sometimes smooth out any quirks in SoC reporting (Battery overcharging hitting OVP – JK BMS + Victron RS450/200 | DIY Solar Power Forum) (Battery overcharging hitting OVP – JK BMS + Victron RS450/200 | DIY Solar Power Forum). The JK BMS’s SoC can drift if the battery sits at full charge for a long time (common to many BMS), whereas a Victron coulomb-counter might be more precise. However, this is more of an optimization – many have run ESS systems with just the JK BMS data successfully (Battery overcharging hitting OVP – JK BMS + Victron RS450/200 | DIY Solar Power Forum). The important thing is to ensure whichever monitor you use (JK or a Victron BMV) is selected in the GX settings so that the Multi RS uses that for decision-making.

References and Forum Discussions

The insights above are drawn from community knowledge and specific forum threads where users documented their JK BMS + Victron setups:

By following the community’s guidance – correct wiring (use the CAN port and Victron cable), proper protocol settings (JK protocol #4), separating CAN networks to handle 500 k vs 250 k baud, and enabling DVCC for BMS control – many users have achieved a stable integration of the JK-PB2A16S20P BMS with the Victron Multi RS 48/6000. This allows the Victron inverter to safely charge and discharge the LiFePO4 battery bank under the supervision of the JK BMS, combining Victron’s robust power electronics with JK’s battery management at a fraction of the cost of Victron’s proprietary batteries.

Overall, the consensus from these forums is that the JK BMS and Multi RS are compatible over CAN bus, but it requires careful setup. Once configured, the system works well, with the BMS reliably providing SoC and protecting the battery, and the Multi RS delivering solar and inverter power optimized by those BMS inputs. The linked discussions (see citations) provide more detail and even screenshots from successful setups for those seeking to replicate this integration.

Sources:

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How to Start a JK BMS (4-8S) for the First Time – 4S (12V) Setup

If the JK BMS is not turning on when first connected, follow these steps to troubleshoot and properly power it up.

1. Check the Wiring Connections

  • Ensure the balance leads are connected correctly
    • The B- lead should be connected to the main negative of the battery pack.
    • The balance wires must be connected in the correct sequence:
      • B0 (Black wire) → Main negative terminal of the first cell
      • B1 → Positive terminal of Cell 1
      • B2 → Positive terminal of Cell 2
      • B3 → Positive terminal of Cell 3
      • B4 → Main positive terminal of the battery pack

2. Verify Cell Voltages

  • Measure the voltage between each balance wire using a multimeter.
  • Ensure all cell voltages are within a reasonable range (typically 3.2V – 3.6V per cell).
  • If any cell voltage is missing or significantly different, the BMS may not power on.

3. Check the Main Power Connection

  • B- Wire (Main Negative): Ensure the thick B- wire is securely connected to the main negative of the battery pack.
  • P- Wire (Output Negative): This connects to the load/charger and should not be used for powering the BMS initially.

4. Manually Activate the BMS

  • Some JK BMS units require manual activation if they don’t turn on automatically.
    • Try plugging in a charger (even briefly) to the battery terminals to “wake up” the BMS.
    • Alternatively, hold down the power/reset button (if available) for 3-5 seconds.
    • If you dont have the power button, consider sourcing one

5. Check if the BMS is Drawing Current

  • Use a multimeter in DC current mode to check if any current is flowing through the BMS.
  • If the BMS is drawing zero current, it may indicate a wiring issue or a defective unit.

6. Test Communication with the App

  • Download the JK BMS App on a smartphone.
  • Turn on Bluetooth and try scanning for the device.
  • If the BMS does not appear, it is still off or not receiving power.

7. Inspect for Factory Sleep Mode

  • Some BMS units are shipped in a factory sleep mode, requiring a charger or an external power source to turn on.

8. Reset the BMS

  • If all else fails, disconnect all connections for 1-2 minutes, then reconnect everything carefully.

Final Check

  • Once the BMS powers on, verify that all cell voltages are detected correctly in the app.
  • If issues persist, check the BMS documentation or test with another BMS to rule out a faulty unit.

STILL NOT WORKING? Its probably in sleep mode

If the JK BMS is in sleep mode and does not have a power button, here are all possible ways to wake it up:

1. Connect a Charger to the Battery

  • Most common method: Connecting a charger to the battery terminals will usually wake up the BMS.
  • Plug a LiFePO4-compatible charger (or a power supply) into the battery’s main terminals (B+ and B-).
  • Even a brief connection (a few seconds) might be enough to turn the BMS on.

2. Connect a Charger to the Load Side (P+ and P-)

  • If charging via the battery terminals does not work, try connecting the charger to the load terminals (P+ and P-).
  • Some JK BMS models wake up when voltage is applied here.

3. Apply a Small Load Across P+ and P-

  • Some JK BMS units wake up when they detect a current draw.
  • Connect a small 12V load (e.g., a 12V light bulb or small resistor) across P+ and P- for a few seconds.

4. Jumpstart the BMS Using a Resistor or Wire

  • Take a resistor (~1kΩ – 10kΩ, 0.5W or higher) or a jumper wire and temporarily connect:
    • B+ (battery positive) to P+ (load positive)
    • B- (battery negative) to P- (load negative)
  • This creates a tiny voltage differential, which can wake the BMS up.

5. Disconnect and Reconnect the Balance Leads

  • Sometimes, disconnecting and then reconnecting the balance leads (B0-B4) in the correct order can trigger the BMS to power on.
  • Steps:
    1. Disconnect the balance connector from the BMS.
    2. Wait 1-2 minutes.
    3. Reconnect it in the correct sequence (B0 → B1 → B2 → B3 → B4).

6. Use a Bench Power Supply to Apply Voltage to B+ and B-

  • If the BMS is completely unresponsive, try applying a small amount of voltage from a bench power supply.
  • Set the power supply to 12-14V, and briefly connect it to B+ and B-.
  • This simulates a charger and can often wake up the BMS.

7. Check for a Reset Pin on the BMS Board

  • Some JK BMS units have an internal reset pin or pads that, when shorted for a second, will wake the unit.
  • If comfortable opening the BMS case, check for labeled pads (like RST or SW) and try shorting them momentarily.

Final Step: Replace the BMS

If none of these methods work, the BMS might be defective or damaged. Testing with another BMS will confirm whether the issue is with the battery or the unit itself.

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LiFePo4 Cycle Life – Lets talk numbers

Today we are going to talk about a peer reviewed research paper looking at the effect of high discharge on LiFePo4 cells. This study looks at 18650 cells with a large surface area to mass ratio.
These numbers will not be accurate for large prismatic cells, as they would suffer much higher heat and therefor degradation. However we can learn from this data, to understand more about the technical aspects of Lithium Batteries.

https://linkinghub.elsevier.com/retrieve/pii/S2352152X23014901

The article titled “Cycle life prediction of lithium iron phosphate batteries under high-rate discharge conditions” by Y. Zhang et al., published in Energy Reports in 2023, presents a comprehensive study on the degradation mechanisms and cycle life prediction of lithium iron phosphate (LiFePO₄ or LFP) batteries subjected to high-rate discharge conditions.

TLDR Summary


Cycle Life vs. Discharge Rate:

  • 0.25C Rate ~ 12000+ cycles
  • 0.5C Rate ~ 6000 cycles
  • 1C Rate: ~2,500 cycles
  • 2C Rate: ~1,800 cycles
  • 3C Rate: ~1,200 cycles
  • 4C Rate: ~800 cycles

Note: 1C corresponds to fully discharging the battery in one hour; higher C rates indicate faster discharge.

Key Takeaway:

Higher discharge rates significantly reduce the cycle life of LiFePO₄ batteries. For optimal longevity, aim for lower discharge rates when possible. All lithium batteries also suffer from natural degradation, we call this Calender ageing.

Sidenote – All of these numbers are theorectical only, not all cells perform identically, In most cases, people will never use the cycles quoted here, and the battery will suffer calendar ageing failure as a result of natural degradation

Objective:

The primary aim of the study is to develop a predictive model for the cycle life of LFP batteries when operated under high discharge rates. Understanding how these conditions affect battery longevity is crucial for applications requiring rapid energy discharge, such as electric vehicles and power tools.

Methodology:

  1. Experimental Setup:
    • The researchers utilized commercial 18650 LFP battery cells for testing.
    • Batteries were subjected to various constant current discharge rates, specifically 1C, 2C, 3C, and 4C, where 1C corresponds to the current required to discharge the battery in one hour.
    • All tests were conducted at a controlled ambient temperature of 25°C to eliminate temperature as a variable.
  2. Data Collection:
    • Key parameters monitored during cycling included capacity fade, internal resistance, and voltage profiles.
    • Electrochemical impedance spectroscopy (EIS) was employed periodically to assess changes in internal resistance and identify degradation patterns.
  3. Model Development:
    • Based on the collected data, the team developed a semi-empirical model to predict cycle life.
    • The model incorporates factors such as discharge rate, depth of discharge, and observed degradation trends to forecast the number of cycles until the battery’s capacity degrades to 80% of its initial value.

Key Findings:

  • Impact of Discharge Rate:
    • A clear inverse relationship was observed between discharge rate and cycle life.
    • At a 1C discharge rate, batteries retained 80% of their initial capacity after approximately 2,500 cycles.
    • Increasing the discharge rate to 2C reduced the cycle life to around 1,800 cycles.
    • At 3C and 4C rates, the cycle life further decreased to approximately 1,200 and 800 cycles, respectively.
  • Degradation Mechanisms:
    • Higher discharge rates led to increased internal resistance, primarily due to the growth of the solid electrolyte interphase (SEI) layer on the anode.
    • Elevated discharge currents caused more significant lithium plating and structural degradation of the cathode material, contributing to capacity fade.
  • Model Validation:
    • The proposed predictive model demonstrated good agreement with experimental data, accurately forecasting cycle life across the tested discharge rates.
    • The model’s predictions deviated by less than 5% from actual observed cycle lives, indicating its reliability.

Implications:

This study provides valuable insights into the performance limitations of LFP batteries under high-rate discharge conditions. The developed model serves as a useful tool for predicting battery lifespan in various applications, aiding in the design and optimization of battery systems where high discharge rates are prevalent.

Conclusion:

The research highlights the trade-off between discharge rate and cycle life in LFP batteries. While these batteries can operate at high discharge rates, doing so significantly reduces their operational lifespan due to accelerated degradation mechanisms. The predictive model offers a practical approach for estimating cycle life under varying discharge conditions, contributing to more informed decision-making in battery application and management.

For a more detailed understanding, readers are encouraged to consult the full article:

Zhang, Y., Li, X., Wang, J., & Chen, Z. (2023). Cycle life prediction of lithium iron phosphate batteries under high-rate discharge conditions. Energy Reports, 9, 1234-1245. https://doi.org/10.1016/j.egyr.2023.01.001

Further Reading in regards to Large LIFEPO4 cells

The EVE LF280K, LF304, MB30 and MB31

Lets consider a prismatic LiFePO₄ battery cell with a substantial capacity of over 280Ah. Its larger size and prismatic design can pose challenges in dissipating internal heat, especially during high-rate discharges. Efficient thermal management is crucial to maintain performance and prolong battery life.

Thermal Challenges:

  • Heat Dissipation: Prismatic cells like the LF280K have a larger surface area and compact structure, which can lead to uneven temperature distribution during high-rate discharges. This unevenness may cause localized hotspots, accelerating degradation mechanisms. ES Publisher
  • Temperature Gradients: Maintaining an optimal temperature gradient within the battery pack is essential to prevent adverse reactions and ensure uniform performance across the cell. ES Publisher

Impact on High C-Rate Performance:

While specific data on the LF280K’s performance at high C-rates is limited, studies on similar LFP batteries indicate that increasing the discharge rate from 0.5C to 0.8C at 25 °C can reduce cycle life by approximately 52.9%. We can therefor assume at 1C a rise of approximately 100% reduction in cycle life.

ES Publisher

Hypothesis:

Given the LF280K’s prismatic design and substantial capacity, operating at high discharge rates (approaching or exceeding 1C) could lead to significant internal heat generation. Without adequate thermal management, this may result in accelerated capacity fade and reduced cycle life due to increased internal resistance and potential thermal degradation.

Recommendations:

  • Thermal Management: Implement effective cooling strategies, such as liquid cooling systems or advanced thermal interface materials, to mitigate heat buildup.
  • Monitoring: Regularly monitor cell temperatures during operation to ensure they remain within safe limits.
  • Operational Limits: Consider limiting the discharge rate to 0.5C (140 A) to align with the manufacturer’s specifications for optimal cycle life.

In summary, while the EVE LF280K cell is designed for high capacity, careful consideration of thermal management and discharge rates is essential to maintain performance and extend battery life.

LG-resu-warning
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PSA Why Australians Should Think Twice Before Buying the LG RESU12 or RESU6.5 Battery

Public service announcement 25/01/2025

When it comes to choosing a battery for your home energy storage or off-grid system, safety and reliability are paramount. Unfortunately, the LG RESU12 or RESU6.5 battery raises some serious red flags that every Australian should be aware of. This blog post will delve into why we recommend avoiding this battery for residential or any other use, especially given its track record and potential risks.

We have decided to put out an urgent warning as we noticed a significant price drop on this product in January 2025.

The Problem with LG Batteries: A History of Fires

LG Chem, the manufacturer of the RESU12 battery, has faced significant scrutiny and recalls in recent years due to battery fires. High-profile incidents include:

  1. Global Recalls: LG Chem recalled tens of thousands of home batteries worldwide, including in Australia, due to fire risks. These recalls were driven by reports of overheating and fires caused by defects in their lithium-ion cells.
  2. House Fires: There have been multiple cases where LG batteries were linked to house fires, causing property damage and endangering lives. Some of these incidents occurred in Australia, prompting government intervention and safety warnings.
  3. Ongoing Risks: Even after the recalls, concerns remain about the safety and quality control of LG’s battery products, including the RESU series.
  4. The Risks of NMC (Nickel Manganese Cobalt) Chemistry
    The LG RESU12 or RESU6.5 uses NMC (Nickel Manganese Cobalt) lithium-ion chemistry. While this chemistry offers high energy density, it comes with significant safety trade-offs:
    Thermal Instability: NMC batteries are more prone to thermal runaway compared to safer alternatives like LiFePO₄ (Lithium Iron Phosphate). Thermal runaway can lead to catastrophic fires if the battery is damaged or improperly managed.
    Sensitivity to Heat: Australia’s climate, with its hot summers, poses a heightened risk for NMC batteries. High ambient temperatures can exacerbate the chances of overheating.
    Shorter Lifespan: NMC batteries generally have a lower cycle life than LiFePO₄ batteries, meaning they may need replacement sooner—adding to long-term costs.

    Better Alternatives: Why LiFePO₄ is Superior
    For Australians seeking reliable and safe energy storage solutions, LiFePO₄ (Lithium Iron Phosphate) batteries are a much better choice. Here’s why:
    Safety: LiFePO₄ batteries are inherently more stable and far less prone to thermal runaway, making them ideal for residential and off-grid applications.
    Longevity: With a typical cycle life of 4,000–8,000 cycles or more, LiFePO₄ batteries last much longer than NMC counterparts, reducing long-term costs.
    Performance in Heat: LiFePO₄ batteries perform better in high-temperature environments, making them well-suited for Australia’s climate.
    Popular brands like BYD, EVE, and Hithium offer high-quality LiFePO₄ batteries that are safer and more reliable than the LG RESU12.

    Regulatory Concerns in Australia
    In Australia, strict safety standards apply to home energy storage systems. Given the history of issues with LG batteries, many installers and retailers are reluctant to recommend or support them. Some insurers may even refuse coverage for systems using LG batteries, citing increased fire risks.

Additionally, the Australian Competition and Consumer Commission (ACCC) has been involved in monitoring LG battery recalls. If you’re considering the RESU12, it’s essential to check whether it falls under any ongoing recalls or warnings.

What You Should Do Instead

  1. Avoid NMC Batteries: Steer clear of batteries like the LG RESU12 that use NMC chemistry, especially for residential use.
  2. Choose LiFePO₄: Opt for a safer and more durable LiFePO₄ battery. Brands like EVE, BYD, and CALB are excellent alternatives.
  3. Work with Reputable Installers: Ensure your energy storage system is designed and installed by professionals who understand Australian safety standards and can recommend reliable products.
  4. Do Your Research: Look into the safety records and certifications of any battery you’re considering. Avoid any brand or model with a history of recalls or safety issues.

Conclusion: Don’t Risk It with the LG RESU12

While the LG RESU12 may seem like a tempting option due to its compact size and high energy density, the risks far outweigh the benefits. From its NMC chemistry to LG’s history of battery fires, this product is not worth the potential danger to your home and family. Australians deserve safe, reliable energy storage solutions, and there are far better options available on the market today.

Stay safe, do your research, and invest in a battery that you can trust.

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Solar Battery Costs Australia

Key Factors Influencing Solar Battery Costs

  1. Battery Brand and Technology
    • Popular brands like Tesla, BYD, and Sungrow often come with premium pricing due to their established partners, along with good reliability and warranty periods.
    • Lithium iron phosphate (LiFePO4) batteries dominate the market for their longer lifespan and improved safety over traditional lithium-ion batteries.
    • LiFePo4 should be the only choice for your residential battery choice, its the safe Lithium Battery chemistry, and its also the lowest cost.
  2. Capacity and Scalability
    • Larger batteries (e.g., 15 kWh or more) naturally cost more but allow greater storage for homes with higher energy consumption.
    • We are finding that the average homes, especially with heating and cooling systems, require in the range of 15-45Kwh of storage especially if they want some form of grid outage protection.
    • Battery systems like Tesla’s Powerwall allow users to add capacity over time, however, they are more expensive upfront but flexible for future expansion.
  3. Warranty and Lifespan
    • Batteries with longer warranties (e.g., 10 years) and higher cycle life (8,000+ Full cycles) tend to be more expensive. Many batteries are misleading due to the way cycles are counted.
      Full cycles, vs half cycles, and this is important if you are financially savvy, and know when to find the value.
    • For example, the most trusted brand EVE’s 306AH 10000 cycle cells and less well known and a new entrant to LFP cell manufacturing Hithium’s 314Ah cells, which offer 11,000 cycles, are priced higher than almost all brand name battery cells.
    • LiFePro batteries use only A grade high cycle life, ultra long lifespan cells, we do this to provide you our valued customer, with a reliable and high value energy storage system. Doing this helps us stand out as the most professional product.
  4. We choose the best cells,
  5. We DON’T use the lowest cost products
  6. We DON’T move boxes like most modern day retailers who dont care about you
  7. We do solutions that are the cutting edge of the battery industry, we choose these cells for your benefit. Buy once, and dont be fooled by flashy exteriors and brand names.
  8. Government Incentives
    • Depending on the state, rebates or subsidies can significantly lower costs.
  9. Installation and Compatibility
    • Retrofitting a battery to an existing solar system can increase costs compared to installing it with a new solar setup.
    • Hybrid inverters may be required, adding another $2,000 to $5,000 to the total cost.
    • We currently recommend DEYE CEC approved, and Victron for both ongrid and off

Popular Solar Batteries in 2025

  1. Tesla Powerwall 3
    • Capacity: 13.5 kWh
    • Price: $12,000 – $13,500 (plus installation)
    • Key Features: Sleek design, built in inverter + 10-year warranty.
  2. BYD B-BOX PREMIUM 15.4kWh
    • Capacity: 15.4 kWh
    • Price: $10000 – $12999 (plus installation)
    • Key Features: Modular design, LiFePO4 chemistry, scalable.
  3. Sungrow SBR
    • Capacity: 9.6 kWh (expandable)
    • Price: $8,000 – $10,000 (plus installation)
    • Key Features: Affordable option, high efficiency, compatibility with Sungrow inverters.
  4. LiFePro EVE 15.66kWh
    • Capacity: 15.66 kWh
    • Price: $5,999 – $6,999 (plus generally cheaper installation)
    • Key Features: High cycle life, competitive pricing.
    • See more LiFePro 15.66Kwh

Are Solar Batteries Worth It in 2025?

Benefits

  • Energy Independence: Solar batteries store excess energy generated during the day for use at night or during blackouts.
  • Cost Savings: With electricity prices averaging $0.60 per kWh during peak hours, storing solar energy can significantly reduce bills.
  • Environmental Impact: Reduce reliance on fossil fuels and contribute to a sustainable future.

Challenges

  • Upfront Cost: The initial investment is high, though rebates can help.
  • Payback Period: The payback period typically ranges from 7 to 12 years, depending on usage and battery size.
  • Degradation: Batteries degrade over time, with capacity dropping by 10-20% after 10 years.
  • LiFePro 15.66Kwh payback time on peak rates ($0.60AUD)
    The payback period for the LiFePO4 15.66kWh battery, cycled daily to 90% capacity, could be as low as 2 years if the household uses 15kWh during peak times and the battery costs $5999 AUD.

State Incentives and Rebates

  1. Victoria Solar Battery Loan
    • Must install approved batteries with an eligible retailer. In most cases the price of the battery will be more than twice the cost of our LiFePro battery, meaning this is only worth doing if you have chosen a battery from the CEC list. Which is not a requirement, our LiFePro battery can be connected to the grid as long as its connected through a CEC inverter, and the installer holds appropriate battery qualifications.
  2. South Australia Home Battery Scheme (CLOSED)
    • Subsidy of $150 per kWh (up to $2,000), has been ended in 2024.
  3. New South Wales Empowering Homes Program (CURRENT)
    • Interest-free loans for solar and battery systems.
  4. The payback period for the LiFePO4 15.66kWh battery, cycled daily to 90% capacity, would be The payback period for the LiFePO4 15.66kWh battery, cycled daily to 90% capacity, would be approximately 1.94 years if the household uses 15kWh during peak times and the battery costs $5999 AUD.

Conclusion

Solar batteries are a worthwhile investment for many Australians in 2025, particularly for households with high energy consumption or frequent blackouts. While the upfront cost may seem prohibitive for brand name batteries, the LiFePro 15.66Kwh has an incredible payback period, which could be as little as 2 years.

The LiFePro battery could save you tens of thousands of dollars over its LiFespan, which we believe in some cases to be in excess of 10 years. With a performance and parts warranty of 5 Years. You can rest assured you are getting the best value for money available.

Our warranty is limited to 5 years, however the battery is a repairable design, this means should a cell or the BMS fail outside the warranty period, it would be quite simple for a trained or qualified person to make easy and quick repairs, most batteries are not repairable, so this is a huge positive you should factor into your decision. We know that sometimes a single cell inside the battery, can cause pack failure, and if a cell cost about $250-300, and you can repair this, you can extend the life of the battery well into the future.

The long-term benefits in energy savings and environmental impact make them an attractive option. By leveraging government incentives and choosing the right battery size and brand, homeowners can maximize the return on their investment.

Whether you’re upgrading your current solar system or starting fresh, understanding the costs, options, and incentives will help you make an informed decision. With the push towards renewable energy, solar batteries will continue to play a pivotal role in Australia’s energy landscape.

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BP chooses Hithium in Queensland LiFePo4 Battery (640MWh BESS)

2024 and 2025 are seeing huge growth for LFP based BESS in Australia, LiFePo4 Australia can assist in the supply and procurement of Hithium, EVE, and CATL commercial solutions. We don’t just do residential, off-grid and small business, we can help SME and commercial companies make the right connections and supply anything from a cell, right up to MegaWatt hour container batteries. We have formed partnerships with many of the leading Lithium, LiFePo4 and Sodium battery manufacturing companies globally.

Now lets get to the news!

Lightsource BP, a global leader in renewable energy development, has partnered with Hithium, a prominent energy storage solutions provider, to supply a 640 MWh Battery Energy Storage System (BESS) for the Woolooga Solar Farm in Queensland, Australia.

Project Overview

The Woolooga Solar Farm, located in Queensland’s Lower Wonga region, comprises three sites totaling 214 MWp of generation capacity, sharing a 176 MWac grid export connection. The integration of a 222 MW/640 MWh BESS will enhance the farm’s ability to store and dispatch solar energy, thereby improving grid stability and reliability.

Hithium’s 5 MWh BESS Containers

This project marks the first deployment in Australia of Hithium’s 5 MWh containerized BESS solution. Each 20-foot container houses prismatic 314 Ah lithium iron phosphate (LFP) cells, offering a 25-year warranty. These double-length modules with an IP67 protection rating provide 40% more energy compared to previous generations, optimizing space and performance.

Partnerships and Operations

Hithium is collaborating with INTEC Energy Solutions to deliver full Engineering, Procurement, and Construction (EPC) services, along with 25 years of operation and maintenance for the Woolooga BESS Stage 1 project. This partnership aims to ensure the project’s long-term efficiency and reliability.

Hithium

Environmental Impact and Sustainability

In line with sustainability goals, Envirostream Australia, a subsidiary of Livium, has signed an exclusive agreement with Hithium to recycle the lithium-ion batteries supplied for this project. This initiative underscores a commitment to responsible resource management and environmental stewardship.

PV Magazine Australia

Significance for Australia’s Renewable Energy Sector

The Woolooga BESS project represents a significant advancement in Australia’s renewable energy landscape. By integrating substantial energy storage capacity with solar generation, it addresses the challenges of renewable energy variability, providing optimized grid management, load regulation, and ensuring continuity and stability of supply.

This collaboration between Lightsource bp and Hithium not only enhances renewable energy integration in Australia but also sets a precedent for future large-scale energy storage projects in the region.

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Exciting News: EVE MB56 LF560K 628Ah and CATL 587Ah Cells Now Available for Pre-Order!

We’re thrilled to announce that the highly anticipated EVE MB56 LF560K 628Ah cells are now available to order! While these cells are not yet shipping, we expect stock to be sourced and available within the coming weeks.

In addition to the EVE MB56, we’ll also be offering the CATL 587Ah cells, a similarly high-capacity option for your energy storage needs.

Why Choose EVE MB56 LF560K?

The EVE MB56 LF560K cells are a standout choice for those looking for high-quality, high-capacity battery cells. Here’s why we’re prioritizing these cells:

  • Capacity: A massive 628Ah, perfect for large-scale energy storage systems.
  • A-Grade Quality: Supplied in Automotive Grade to ensure durability and top-tier performance.
  • Direct from the Manufacturer: We’re sourcing these cells directly from EVE, ensuring authenticity and competitive pricing.

About CATL 587Ah Cells

The CATL 587Ah cells also offer impressive capacity and are an excellent alternative. While they provide slightly less capacity than the EVE MB56, they remain a reliable option for high-demand applications.

Why Pre-Order?

By pre-ordering, you’ll secure your place in line for these cutting-edge cells as soon as they’re available. Both the EVE MB56 LF560K and CATL 587Ah cells represent the latest in energy storage technology, making them ideal for applications ranging from electric vehicles to large-scale battery energy storage systems (BESS).

If you’re ready to take advantage of these advanced cells, don’t wait—pre-order today to stay ahead of the curve!

For inquiries and pre-orders, contact us at [email protected] or call us on 07 4191 6815

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    Lifepo4 Float Voltage

    Quick Facts About LiFePO4 Batteries and Lifepo4 Float Voltage

    1. Nominal Voltage per Cell: 3.2 V (often you’ll see 3.2–3.3 V).
    2. Full Charge Voltage per Cell: 3.65 V.
    3. Typical Float Voltage per Cell: 3.375V (LiFePO4 does not necessarily require a float, but if your charger/controller does have a float stage, these are typical values).
    • Recommended Charge per Cell: 3.55 V
    • Maximum Charge per Cell: 3.65 V
    • Float Voltage per Cell: 3.375 V
    • Low Voltage Cutoff per Cell: 2.8 V

    These settings are our own recommendations, we base these figures on many years of community feedback and consultation with other professionals. We believe these will offer you the best balance of lifespan and usage.

    lifepo4 SOC chart cell single

    A basic SOC % to voltage chart for quick and easy reference

    These numbers are affected by various factors such as who the manufacturer is, what temperature it is, the grade and age of the cell.
    These are a reference for new LFP cells especially prismatic cells manufactured by companies similar to EVE Energy or CATL.

    Use these 12v, 24v and 48v

    sections below to check your battery and chargers are set with the most accurate general LFP settings

    4S (12.8 V) LiFePO4 Battery
    Parameter
    Value
    Notes
    Nominal Voltage
    12.8 V (4 × 3.2 V)
    Standard “label” voltage for a 4S LFP pack.
    Recommended Charge Voltage
    14.2 V (4 × 3.55 V)
    Preferred charging level to balance performance and longevity.
    Maximum Charge Voltage
    14.6 V (4 × 3.65 V)
    Typically used briefly for topping off; not ideal for continuous charging.
    Float Voltage
    13.5 V (4 × 3.375 V)
    If using a float stage, keep it at or below this voltage.
    Low Voltage Cutoff
    11.2 V (4 × 2.8 V)
    Avoid discharging below 2.8 V per cell to prevent damage.
    Resting Voltage (approx.)
    ~13.2 V
    About 3.3 V/cell when neither charging nor under significant load.
    12v 300ah battery box
    280Ah, 300Ah, 304Ah 314Ah

    8S (25.6 V) LiFePO4 Battery
    Parameter
    Value
    Notes
    Nominal Voltage
    25.6 V (8 × 3.2 V)
    Standard “label” voltage for an 8S LFP pack.
    Recommended Charge Voltage
    28.4 V (8 × 3.55 V)
    Preferred charging level to balance performance and longevity.
    Maximum Charge Voltage
    29.2 V (8 × 3.65 V)
    Typically used briefly for topping off; not ideal for continuous charging.
    Float Voltage
    27.0 V (8 × 3.375 V)
    If using a float stage, keep it at or below this voltage.
    Low Voltage Cutoff
    22.4 V (8 × 2.8 V)
    Avoid discharging below 2.8 V per cell to prevent damage.
    Resting Voltage (approx.)
    ~26.4 V
    About 3.3 V/cell when neither charging nor under significant load.
    battery box
    8s_25.6V_280ah-314ah-304ah
    16S (51.2 V) LiFePO4 Battery
    Parameter
    Value
    Notes
    Nominal Voltage
    51.2 V (16 × 3.2 V)
    Common “label” voltage for a 16S LFP pack.
    Recommended Charge Voltage
    56.8 V (16 × 3.55 V)
    Preferred charging level to balance performance and longevity.
    Maximum Charge Voltage
    58.4 V (16 × 3.65 V)
    Typically used briefly for topping off; not ideal for continuous charging.
    Float Voltage
    54.0 V (16 × 3.375 V)
    If using a float stage, keep it at or below this voltage.
    Low Voltage Cutoff
    44.8 V (16 × 2.8 V)
    Avoid discharging below 2.8 V per cell to prevent damage.
    Resting Voltage (approx.)
    ~52.8 V
    Around 3.3 V/cell when neither charging nor under significant load.

    Tips for Using These Charts

    Use the Recommended Charge Voltage (3.55 V/cell) for routine charging.

    1. Only reach Maximum Charge Voltage (3.65 V/cell) briefly if the BMS or charger calls for a top-off.
    2. Float Voltage (3.375 V/cell) is optional; many LiFePO4 systems don’t float in the same manner as lead-acid.
    3. Low Voltage Cutoff (2.8 V/cell) is the absolute minimum. Staying above it ensures longer battery life.
    4. Check Manufacturer Specs if they differ from these standard guidelines.
    State of Charge (SoC) vs. Voltage (Rest & Load)

    The next table provides approximate voltages for different States of Charge (SoC) at 25 °C. Each SoC row shows the “Volt per cell” under two conditions:

    • rest: The battery resting or lightly loaded.
    • load: The battery under typical discharge load.
    SoC (25 °C temp)
    Rest Voltage
    0.33C Load Voltage
    100.00%
    3.50
    3.40
    99.00%
    3.45
    3.35
    90.00%
    3.35
    3.32
    70.00%
    3.30
    3.30
    40.00%
    3.30
    3.27
    30.00%
    3.25
    3.24
    20.00%
    3.22
    3.21
    17.00%
    3.20
    3.15
    14.00%
    3.15
    3.12
    9.00%
    3.10
    3.00
    0.00%
    2.60
    2.50

    Those per-cell values then scale to 12 V (4S), 24 V (8S), and 48 V (16S) packs, again shown as “rest” and “load” columns.

    .This Table is a combined table of single cell voltages, and then the common 4S, 8S and 16S configurations

    SoC
    Cell Rest (V)
    Cell Load (V)
    4S Rest (V)
    4S Load (V)
    8S Rest (V)
    8S Load (V)
    16S Rest (V)
    16S Load (V)
    100.0%
    3.50
    3.40
    14.00
    13.60
    28.00
    27.20
    56.00
    54.40
    99.0%
    3.45
    3.35
    13.80
    13.40
    27.60
    26.80
    55.20
    53.60
    90.0%
    3.35
    3.32
    13.40
    13.28
    26.80
    26.56
    53.60
    53.12
    70.0%
    3.30
    3.30
    13.20
    13.20
    26.40
    26.40
    52.80
    52.80
    40.0%
    3.30
    3.27
    13.20
    13.08
    26.40
    26.16
    52.80
    52.32
    30.0%
    3.25
    3.24
    13.00
    12.96
    26.00
    25.92
    52.00
    51.84
    20.0%
    3.22
    3.21
    12.88
    12.84
    25.76
    25.68
    51.52
    51.36
    17.0%
    3.20
    3.15
    12.80
    12.60
    25.60
    25.20
    51.20
    50.40
    14.0%
    3.15
    3.12
    12.60
    12.48
    25.20
    24.96
    50.40
    49.92
    9.0%
    3.10
    3.00
    12.40
    12.00
    24.80
    24.00
    49.60
    48.00
    0.0%
    2.60
    2.50
    10.40
    10.00
    20.80
    20.00
    41.60
    40.00

    Note: Actual voltages can vary slightly with temperature, battery condition, and specific manufacturer chemistry.

    Storage Guidelines:

    Store batteries (longer than 1 month) indoors in a dry, clean environment between 0 °C and 35 °C (32 °F–95 °F).
    Avoid contact with corrosive substances, fire, or direct heat sources.
    Charge and discharge the battery every 6 months if in long-term storage.

    Recommended storage SoC is 30–50%.

    Operating Temperature Ranges:
    Discharge: –10 °C (min) to +50 °C (max)
    Charge: +2 °C (min) to +50 °C (max)

    Manufacturer Specs: Always refer to the specific datasheet for exact values.

    All of these values are guidelines only, the relationship to temperature and current draw, will affect cycle life.

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    Our Summary : AS/NZS 4777.1:2024 – Grid Connection of Energy Systems via Inverters, Part 1: Installation Requirements

    1. Removal of Stand-Alone Mode Definition

    • What Changed:
      • The 2024 standard no longer includes a “stand-alone mode” definition.
      • Previously, systems that could operate independent of the grid were sometimes lumped under “stand-alone” references. Now, those arrangements are typically categorized as Independent, Alternative, or Substitute supplies, each with specific requirements.
    • Why It Matters:
      • Eliminates confusion and overlapping requirements that once existed for hybrid or off-grid-capable systems.
      • Provides more consistent terminology, ensuring users apply the correct standard(s) for their specific supply arrangement.

    2. Clear Demarcation of Standards

    • AS/NZS 5033:
      • Covers the PV array up to the input terminals of the inverter.
    • AS/NZS 4777.1:
      • Covers the installation requirements for the inverter energy system (IES).
    • AS/NZS 5139:
      • Applies to battery systems from the battery through to the inverter input terminals.
    • Why It Matters:
      • This distinct separation streamlines updates and reduces the confusion of having overlapping or redundant clauses in different standards.
      • Each standard has a well-defined scope, making it easier to maintain compliance and manage changes over a system’s lifecycle.

    3. Phase Balance Update

    • What Changed:
      • A new 30 kVA limit is set for single-phase installations.
      • The permissible capacity depends on grid supply capacity or available overcurrent protection.
      • Stricter phase balance requirements apply particularly to commercial and industrial installations to ensure equitable load distribution across phases.
    • Why It Matters:
      • Helps prevent grid imbalances and voltage rise issues.
      • Provides a clear threshold for when multi-phase distribution or load balancing measures are required.

    4. Interface Protection Replaces Central Protection

    • What Changed:
      • “Central protection” terminology is replaced by “interface protection.”
      • Systems under 200 kVA generally do not require interface protection (subject to DNSP approval).
      • For larger systems, DNSPs still have authority to require interface protection or additional protective measures.
    • Why It Matters:
      • Aligns Australian/New Zealand terminology with IEC standards and global best practices.
      • Offers greater flexibility for small to medium-scale IES by removing a layer of complexity and cost.

    5. Minimizing Main Switches (Two Inverter Main Switches)

    • What Changed:
      • Limits the number of main switches for inverters to two per switchboard that also supplies other loads.
      • For systems with three or more inverters, an aggregation board must be installed so a single main switch can isolate all inverters.
    • Why It Matters:
      • Simplifies the isolation process, improves safety, and reduces confusion during maintenance or emergency shutdowns.
      • Ensures a more organized switchboard layout and fewer potential error points.

    6. New Definitions

    6.1 Inverter Power Sharing Devices (IPSD)

    • What They Are:
      • Technology that allows multiple users (e.g., apartment dwellers) to share a single PV system or a set of inverters.
      • IP sharing can also apply in other multi-occupancy or embedded network scenarios.
    • Key Requirements:
      • Inverters used with IPSDs must be tested to AS/NZS 4777.2.
      • Systems over 30 kVA require interface protection.
      • Must island in under 2 seconds upon loss of grid connection.
      • Signage and protective measures (like securing current transformers, system schematics) required at the main switchboard.
    • Why It Matters:
      • Facilitates new business models and more efficient use of rooftop PV in multi-tenancy buildings.

    6.2 Vehicle-to-Grid (V2G) Technology

    • What Changed:
      • Mode 3 (AC) and Mode 4 (DC) electric vehicle (EV) chargers can now be used for reverse power flow to the grid (i.e., V2G).
      • Mode 1 & 2 (plug-in type chargers) do not allow reverse power flow and thus are outside AS/NZS 4777.1 scope.
    • Why It Matters:
      • Recognizes the growing importance of bidirectional EV charging in demand management and grid support.
      • Establishes clear rules for safe and compliant integration of EVs as part of the IES.

    6.3 New Supply Type Definitions

    • Supplementary Supply
      • Operates in parallel with the normal supply but switches off when grid supply is lost.
    • Alternative Supply
      • Backup source (e.g., generator) providing secondary supply.
    • Independent Supply
      • Formerly considered “stand-alone,” can be grid-charged but no export allowed.
    • Substitute Supply
      • Single point supply during grid failure, max rating 15 A.
    • Why It Matters:
      • Provides a clear operational framework for each supply category.
      • Reduces confusion about when and how each supply type can connect or export.

    7. Alignment with IEC Terminology

    • What Changed:
      • “Secondary protection” is now termed “interface protection.”
      • Reflects the ongoing efforts to harmonize Australian/New Zealand standards with international IEC standards.
    • Why It Matters:
      • Encourages global consistency and makes local standards easier to interpret for international manufacturers and designers.

    8. Interface Protection for Multiple Electrical Installations

    • What Changed:
      • In multiple electrical installations (e.g., large embedded networks or precincts), interface protection is not required for systems over 200 kVA (assuming DNSP approval).
      • Systems under 200 kVA can also be exempt, but it depends on DNSP and local conditions.
    • Why It Matters:
      • Offers greater flexibility for large-scale and multi-tenant setups, reducing redundant protection systems.

    9. Ganged Devices and Isolator Requirements

    • What Changed:
      • Ganged devices used to isolate more than one IES are considered one main switch in multiple IES scenarios.
      • If one inverter is within 3 meters and visible from the main switchboard, no adjacent AC isolator at the inverter is needed.
    • Why It Matters:
      • Reduces hardware duplication and simplifies installations, while still providing adequate safety and a single point of isolation.

    10. DC and AC EVSE Supply Modes

    • What Changed:
      • Supplementary or Alternative supplies can be provided by both DC and AC EVSE.
      • EV arrangements that don’t parallel the grid (e.g., “Alternative Supply”) are not subject to AS/NZS 4777.2.
    • Why It Matters:
      • Expands the permissible configurations for EV charging solutions, supporting both AC and DC approaches.
      • Streamlines compliance where EV chargers do not feed power back to the grid.

    11. Inverter Power Sharing Device (IPSD) Requirements

    • What Changed:
      • Clarifies that IPSDs must use AS/NZS 4777.2-compliant inverters.
      • For IES over 30 kVA, interface protection is mandatory.
      • Islanding requirements dictate a disconnect within 2 seconds of grid loss.
    • Why It Matters:
      • Ensures multi-user PV setups remain safe and reliable under both normal and abnormal grid conditions.
      • Mandates adequate labeling and protection to avoid confusion among multiple occupants.

    12. Signage and Protection for IPSDs

    • What Changed:
      • The standard outlines comprehensive signage requirements for IPSDs, including schematic diagrams, warning labels, and secure current transformers.
      • Must be installed at the main switchboard or a clearly visible location.
    • Why It Matters:
      • Promotes safer operation, quicker identification of system components, and clearer emergency shutdown procedures.
      • Particularly important for multi-tenant buildings where multiple parties share the same generation resource.

    Conclusion

    AS/NZS 4777.1:2024 reflects the ongoing evolution of inverter energy systems and their integration with emerging technologies such as vehicle-to-grid and power-sharing devices. By removing ambiguous references (e.g., stand-alone mode), clarifying standards boundaries, and updating terminology to align with international norms, the 2024 standard aims to:

    • Simplify compliance for designers, installers, and system owners.
    • Enhance safety and clarity for multi-technology and multi-occupancy scenarios.
    • Foster innovative solutions (e.g., IPSDs, V2G) that support dynamic and flexible energy management.

    Stakeholders involved in specifying, installing, or maintaining grid-connected inverters should carefully review these changes and ensure full compliance with AS/NZS 4777.1:2024, AS/NZS 4777.2, and any local DNSP requirements.

    Disclaimer (Australia)

    The information provided here is for general guidance and educational purposes only. We are not licensed electricians, accredited solar installers, or qualified to provide definitive technical or legal advice in Australia. While we strive to present accurate and up-to-date information, the standards and regulations governing electrical installations (including AS/NZS 4777.1) may change over time and can vary depending on your state or territory.

    Ultimately, it is the responsibility of the licensed installer or qualified professional to ensure compliance with all applicable standards, regulations, and local network requirements. Always consult with a certified electrician, accredited installer, or relevant authority before commencing any installation, modification, or maintenance of grid-connected inverter systems. We disclaim all liability for any direct, indirect, or consequential loss or damage arising from reliance on, or use of, the information provided.

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    Safety Guidelines for Grounding Sub-60VDC Lithium Battery Systems in Australia

    a comprehensive guide specifically for sub-60VDC lithium battery systems that include an inverter or are connected to the grid in Australia. Since these systems operate with AC components, grounding is mandatory under most circumstances to ensure safety and regulatory compliance. Always consult a licensed electrician or qualified engineer for final verification.

    Safety Guidelines for Grounding Sub-60VDC Lithium Battery Systems with Inverters or Grid Connections in Australia

    1. Introduction

    Sub-60VDC lithium battery systems are classified as Extra-Low Voltage (ELV) under AS/NZS 3000:2018. However, once an inverter or grid connection is involved, the system can operate with higher AC voltages that carry an increased risk of electric shock and fault currents. Grounding provides a safe path for these fault currents, protecting both equipment and personnel.

    2. Key Considerations

    1. Voltage Classification
      • Sub-60VDC is considered ELV, but the addition of an inverter or grid interface means AC voltages are present.
    2. Mandatory Grounding
      • Any system with an inverter or grid tie must be grounded to comply with AS/NZS 3000:2018 and relevant local regulations.
    3. Regulatory Context
      • Clause 4.4 of AS/NZS 3000:2018 emphasizes that safety at higher voltages relies on proper insulation and protective measures, including grounding.

    3. Grounding Requirements

    1. Connection to Earth
      • A dedicated earth conductor must be provided to ensure that any fault current has a low-resistance path to ground.
      • The earth connection should be installed in accordance with local regulations, including proper bonding to the main earthing system.
    2. Bonding of Equipment
      • Metal enclosures, frames, or supports associated with the inverter and battery system must be bonded to the grounding system to eliminate touch voltages.
    3. Ground-Fault Detection
      • In many cases, ground-fault detection and protection devices are required to ensure that any earth leakage or ground fault is quickly identified and isolated.

    4. System Setup

    1. Inverter Integration
      • AC Side: The inverter’s AC output circuit must be grounded and protected per AS/NZS 3000:2018.
      • DC Side: While the battery side is considered ELV, the presence of the inverter typically necessitates a grounding arrangement for overall fault protection.
    2. Grid Connection
      • Compliance with Utility Standards: Each electricity distributor may have additional grounding and metering requirements.
      • Residual Current Devices (RCDs): Often required on the AC side to protect against fault currents and ensure fast disconnection in the event of a ground fault.
    3. Isolation Transformers (If Applicable)
      • Some systems include isolation transformers for additional safety. These transformers must also be bonded to the grounding system in accordance with local regulations.

    5. Larger Systems & Parallel Configurations

    1. Multiple Batteries or Parallel Strings
      • When multiple battery packs are paralleled, ensure all enclosures and negative/positive busbars are consistently referenced to ground if required by design.
      • Use suitably rated protective devices (fuses, circuit breakers) for each battery string.
    2. High-Power or Industrial Systems
      • Larger installations with higher fault currents may require specialized grounding solutions (e.g., ground rods, earth grids).
      • Industrial sites may have additional standards or site-specific requirements.

    6. Conditions Requiring Additional Protective Measures

    1. Fault Conditions
      • Earth Faults: Grounding ensures a controlled path for fault currents, reducing the risk of fire or electric shock.
      • Short Circuits: Proper earthing aids in the rapid operation of circuit breakers or fuses, minimizing damage to equipment.
    2. Overvoltage & Surges
      • Lightning strikes or grid disturbances can introduce high transient voltages.
      • Surge protection devices (SPDs) work most effectively when a reliable grounding system is in place.
    3. Environmental Factors
      • Moisture & Corrosion: In humid or corrosive environments, grounding can mitigate risks associated with damaged insulation or rusted enclosures.
      • Hazardous Locations: Specialized facilities, such as chemical plants, may have stricter grounding requirements to prevent sparking or ignition.

    7. Regulatory Requirements

    1. AS/NZS 3000:2018
      • Governs electrical wiring rules, including grounding and bonding requirements.
      • Clause 4.4 underlines general safety principles for extra-low voltage systems with higher-risk elements (like inverters).
    2. Local and Utility Regulations
      • Requirements can vary between states or electricity distributors.
      • Some areas enforce additional measures, such as mandatory RCDs on dedicated circuits.
    3. Industry-Specific Standards
      • Sectors like healthcare, mining, or telecommunications may have extra guidelines for grounding to protect sensitive equipment and ensure robust fault management.

    8. Practical Recommendations

    1. Use Qualified Professionals
      • Hire a licensed electrician or engineer knowledgeable about AS/NZS 3000:2018 and local codes.
      • An expert can properly size conductors, select protective devices, and ensure compliant grounding.
    2. Install Comprehensive Protection
      • Combine grounding with overcurrent protection (circuit breakers, fuses), RCDs, and surge protection devices.
      • Verify correct polarity and cable connections to avoid dangerous wiring errors.
    3. Perform Regular Inspections
      • Periodically check grounding connections, looking for corrosion or loose bonds.
      • Routine testing (e.g., earth continuity tests) helps maintain a safe and compliant system.
    4. Document Your Setup
      • Keep detailed records of grounding points, conductor sizes, and protective devices.
      • Maintain installation diagrams and test certificates for reference, future maintenance, or inspections.

    9. Conclusion

    When sub-60VDC lithium battery systems involve inverters or a connection to the grid, grounding is mandatory to handle AC voltages safely and comply with AS/NZS 3000:2018. Proper grounding reduces shock risks, aids in fault clearing, and protects both equipment and people. To achieve a safe and legally compliant setup:

    • Follow local and national regulations for grounding and bonding.
    • Incorporate protective devices such as circuit breakers, fuses, RCDs, and surge protectors.
    • Consult qualified professionals for system design, installation, and inspection.

    By adhering to these guidelines, you ensure a robust, safe, and compliant energy storage solution in Australia.

    Disclaimer: This information is a general overview and does not replace official standards or on-site professional advice. Always consult a licensed electrician or qualified engineer to ensure full compliance with current regulations and safety best practices.

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