Here is a comprehensive and technical deep dive into DEYE’s newest lineup of hybrid inverters and all-in-one energy solutions, based on the insights revealed at their recent All-Energy showcase.
The energy storage and hybrid inverter landscape is shifting rapidly from modular, decentralized components to highly integrated, all-in-one ecosystem architectures. DEYE, a manufacturer heavily embedded in the global solar market (often white-labeled under various brand names), has unveiled its next generation of hybrid energy systems.
Moving far beyond simple solar inversion and battery charging, DEYE’s new hardware operates as a holistic Energy Management System (EMS). Let’s break down the technical specifications and architectural advantages of their latest product suite.
1. Smart Load Integration & LoRaWAN Connectivity
Most traditional inverters focus purely on supply-side metrics—managing generation and storage. DEYE’s new generation flips this by actively controlling demand-side loads.
The new inverters feature a built-in EMS with natively integrated LoRaWAN (Long Range Wide Area Network) protocols.
Complete Wireless Control: Using LoRaWAN wireless dongles, the inverter can communicate with remote hardware—like EV chargers, smart relays, and smart meters—up to 200 meters away without requiring physical cable runs.
Network Independence: Unlike typical IoT smart home ecosystems, DEYE’s communication protocol does not rely on the customer’s local Wi-Fi router. The inverter creates its own self-contained mesh, ensuring uninterrupted load control (e.g., scheduled EV charging based on Time-of-Use tariffs or excess PV production) even during localized network outages.
2. The “All-in-One” Residential Solution: The Inverter is now built in to the stack
With Inbuilt Inverter
With External Hybrid Inverter
For residential applications, DEYE has introduced a highly stackable “All-in-One” unit that supports both on-grid and full off-grid topologies.
Inverter Ratings: The range supports single-phase models from 3.6 kW up to 8 kW, and three-phase models from 5 kW up to 12 kW.
Storage Density: The system utilizes low-voltage 5.12 kWh battery modules. A single stack can accommodate up to 6 modules (approx. 30 kWh).
Massive Expandability: You can parallel up to 6 of these battery clusters to a single inverter, pushing the maximum localized storage capacity to an impressive 180 kWh.
The “6-in-1” Architecture: DEYE classifies this as a 6-in-1 unit, most notably featuring direct diesel generator integration. The inverter can dynamically control a generator start/stop relay based on State of Charge (SoC) parameters, making it an ideal candidate for off-grid and rural properties.
A major pain point in standard whole-home backup installations is the requirement for a separate external gateway or Automatic Transfer Switch (ATS)—such as the Tesla Backup Gateway. These external units are necessary to physically decouple the home from the grid during blackouts to ensure compliance with anti-islanding regulations (zero export).
DEYE has built this gateway hardware directly into the inverter chassis.
Fewer Points of Failure: This native integration reduces installation time, minimizes required wall real estate, and eliminates the need for third-party ATS wiring.
4-Millisecond Transfer Time: In the event of a grid failure, the inverter detects the voltage drop and switches to off-grid backup mode in just 4 milliseconds [04:07]. This UPS-grade transfer time is fast enough to keep sensitive electronics, servers, and desktop computers running without rebooting.
4. Unmatched Phase Paralleling Architecture
Where DEYE truly flexes its engineering muscles is in its master/slave paralleling capabilities, which treat subsequent inverters as modular power blocks rather than isolated systems.
Single-Phase: Up to 16 inverters can be paralleled together.
Three-Phase: Up to 10 inverters can be paralleled together.
Crucially, the backup (EPS) ports can also be paralleled [06:01]. If an 8 kW single-phase inverter isn’t sufficient to handle the inrush current of a home’s HVAC system during a grid outage, you can parallel multiple units to stack their continuous backup output. The architecture allows you to easily expand the system’s power ceiling retroactively as site requirements grow.
5. C&I (Commercial & Industrial) Muscle
Scaling up from the residential sector, DEYE is rolling out heavy-duty solutions for the C&I market, maintaining the exact same modular philosophy.
BOS-G Pro- New Model
BOS-G Pro High-Voltage Batteries: Utilizing 5.12 kWh modules, these high-voltage batteries can be stacked up to 12 per rack. You can tie up to 16 racks together, bringing total storage capacity to just under 1 Megawatt-hour (MWh).
80 kW Three-Phase Hybrid Inverter: These massive storage arrays mate to DEYE’s pending 80 kW hybrid inverters. Mirroring the residential lineup, up to 16 of these 80 kW units can be run in parallel, easily pushing the system into the multi-megawatt operational tier [06:51].
Note: DEYE also noted that a massive 300 kW utility-scale inverter is currently navigating the compliance paperwork.
Summary
DEYE is aggressively targeting the pain points of modern solar installers and system architects. By bringing the EMS, grid gateway, and LoRaWAN communications inside the inverter casing, they are cutting down on physical clutter while offering an incredibly resilient, UPS-grade backup solution. Whether it’s an 8 kW off-grid cabin or a 1 MWh commercial facility, their paralleling architecture allows for virtually unlimited scaling.
REAL WORLD AUSTRALIAN INSTALLS
Check out what is coming with this video by the Smart Energy Lab
Integrating a JK BMS (specifically the PB-series Inverter BMS) with a Victron GX system (Cerbo GX, Ekrano, or Venus OS on Raspberry Pi) is the gold standard for DIY LiFePO4 builds. This setup enables DVCC (Distributed Voltage and Current Control), allowing the BMS to dictate exactly how much current the Victron MPPTs and Inverters should provide based on real-time cell data.
Step 1: Prepare the Hardware
To establish communication, you need a specific cable. Do not use a standard Ethernet cable; the pinouts are different.
Option A: Direct CAN Bus (Recommended) Use a Victron Type B RJ45 cable (or crimp your own).
JK End (CAN Port): Pin 4 (CAN-H), Pin 5 (CAN-L), Pin 6 (GND).
Option B: RS485 to USB (Alternative) If your CAN ports are occupied, use a Waveshare Industrial USB-to-RS485 converter to connect the BMS RS485 port directly to a USB port on your GX device.
Step 2: Configure the JK BMS Settings
Before plugging it in, you must tell the JK BMS to “speak” the Victron language.
Open the JK BMS App on your phone.
Go to Settings > Inverter Protocol Selection.
Select “Victron CAN” (often listed as Protocol #4).
Ensure the BMS ID/Address is set to 1 (for the Master battery).
Restart the BMS using the physical “RST” button or the app.
Step 3: GX Device Configuration
Once the cable is connected to the BMS-Can port on your Cerbo GX:
Navigate to Settings > Services > BMS-Can Port.
Set the CAN-bus speed to 500 kbit/s (this is the standard for JK and Victron).
Go back to the main device list. You should now see “JK-BMS” appearing as a connected device.
Step 4: Enable DVCC (The Critical Step)
For the BMS to actually control the charging process, DVCC must be active.
Go to Settings > DVCC.
Switch DVCC to ON.
Ensure “Limit Charge Current” and “Limit Managed Battery Voltage” are visible (they will be automatically populated by the JK BMS).
Set Shared Voltage Sense (SVS) to OFF (the BMS provides this data).
Troubleshooting FAQ
Q: The BMS isn’t showing up on my GX device.
Check the Port: Ensure you are using the BMS-Can port, not the VE.Can port (unless you have changed the VE.Can speed to 500k).
Check the Cable: 90% of issues are cable-related. Verify your Pin 4/5 (JK) matches Pin 7/8 (Victron).
Q: I have multiple batteries in parallel. How do I connect them?
Connect the batteries together via their RS485-2 ports using standard RJ45 cables.
Set Battery 1 to Address 1, Battery 2 to Address 2, etc.
Only the Master (Address 1) connects to the Victron GX via the CAN port.
Q: Can I use the Bluetooth driver instead?
Yes, for older non-inverter JK BMS models, you can install the dbus-serialbattery driver on Venus OS to connect via Bluetooth, though a wired CAN connection is significantly more stable for 48V power systems.
Lets use a Victron Multi RS Solar PMR482602020 as example
Report date: 11 February 2026 (Australia/Brisbane)
Scope: Whether the Victron PMR482602020 (Multi RS Solar 48/6000/100-450/100) can be legally/technically connected in parallel with the Australian distribution grid when it is not on the Clean Energy Council approved inverter list (“CEC-approved” in common installer shorthand). This report focuses on electricity-network connection rules and published DNSP requirements. Local council/planning rules are not assessed (unspecified; varies by council and local planning schemes).
General information only — not legal advice. Always confirm with the local DNSP and state/territory electrical safety regulator before purchasing or installing equipment.
This report was compiled with the help of Artificial intelligence on 11/02/2026, it should not be used other than to do your own research, to assist you in your own research, you must verify all claims made here, by the AI before proceeding, and you should be a qualified person to perform any electrical work.
Executive summary
In Australia, the entity that decides whether an inverter energy system may be connected to the distribution grid is the local distribution network service provider (DNSP) via the connection application/offer and connection agreement — not the Clean Energy Council (CEC). However, in practice, DNSPs overwhelmingly require inverters to be on the CEC Approved Inverter List (or equivalent “approved/onboarded” lists derived from it), because CEC listing is the most common way DNSPs verify compliance to the relevant inverter standards (especially AS/NZS 4777.2). Many DNSPs also build their application portals so that installers can only select inverters drawn from the CEC-supplied list.
Consistent with that, every major Australian DNSP reviewed in this report publishes a requirement that grid-connected inverters be CEC-listed (or “CEC approved”), with only two DNSPs (Ausgrid and Endeavour Energy) explicitly publishing a pathway for a “CEC unlisted inverter proposal” via written approval. Even under those “written approval” pathways, the inverter still needs to meet the technical requirements (AS/NZS 4777.2/4777.1 and DNSP-specific settings/controls), and DNSPs warn installers they may be required to replace non-compliant inverters at their own cost if installed without meeting requirements.
For the Victron PMR482602020 specifically, Victron’s own public documents for the Multi RS Solar show extensive international certifications, but do not show an AS/NZS 4777.2 certificate on the product’s certificate list, and the product datasheet’s standards list also does not include AS/NZS 4777.2. By contrast, Victron does publish AS/NZS 4777.2 certification for some other models (e.g., MultiPlus-II), demonstrating what an Australian certificate looks like. This strongly suggests the Multi RS Solar PMR482602020 is not presently certified/listed for Australian grid-parallel connections. (It may still be suitable for off-grid or generator-only use, but that is a different compliance pathway.)
Bottom line: if your PMR482602020 is not CEC-listed, you should assume it will be rejected for grid connection by most DNSPs. The only realistically arguable pathway is a case-by-case written approval with a DNSP that explicitly allows proposals for CEC-unlisted inverters (published only for Ausgrid and Endeavour Energy), supported by full third‑party compliance evidence and any DNSP communications/export-control requirements. For all other DNSPs, the published position indicates no non-CEC pathway for new grid-parallel connections (unless an exemption is explicitly published by a government technical regulator for a defined purpose, such as South Australia’s dynamic export regime — and those exemptions are time- and model-specific).
Legal and regulatory framework
Who has the “yes/no” authority to connect to the grid?
The practical permission to connect comes from the DNSP connection process: you apply (often via an installer portal), receive a connection offer/approval subject to conditions, and connect/commission in accordance with that agreement and the DNSP’s technical requirements. Some DNSPs state explicitly that approval is only granted after entering into a connection agreement, even for zero-export systems.
Where does the CEC “approved inverter list” fit?
The CEC is not the grid connection decision-maker, but its “Approved Inverter List” is the key reference dataset used across Australia. The CEC itself describes permitted API use cases including “Network Service Providers confirming that an inverter is listed on the CEC’s Approved Inverter List prior to connection”, which is an unusually direct statement of how the list is used in DNSP practice.
The CEC’s inverter listings are also structured around evidence of compliance: the CEC notes that model numbers with an “(AS4777-2 2020)” suffix indicate approval supported by an AS/NZS 4777.2:2020 certificate issued by a JAS‑ANZ accredited certifier or state electrical regulator. Separately, Energy Networks Australia notes that most DNSPs use the CEC approved inverter listing as their approved product list and many use it to populate their customer portals.
Why CEC listing matters even beyond DNSPs: STCs and the Clean Energy Regulator
If the installation is intended to create Small‑scale Technology Certificates (STCs) under the Small‑scale Renewable Energy Scheme, the federal Clean Energy Regulator states that newly installed small generation units must have their panels/batteries/inverters listed on the CEC list of approved components (among other requirements). So a non‑CEC inverter may not only jeopardise DNSP grid approval; it can also remove STC eligibility (which impacts economics and retailer finance).
AS/NZS 4777.2 and the National Electricity Rules context
The inverter behaviour standard at the centre of Australian grid‑connected DER is AS/NZS 4777.2. AEMO explains that AS/NZS 4777.2 specifies expected low‑voltage inverter performance/behaviour and compliance tests, and links compliance to secure operation under high DER penetration. AEMO also describes work with the Clean Energy Regulator and the CEC to incorporate inverter settings checks into CER inspections, reflecting enforcement attention on not just hardware certification but actual commissioning settings.
Multiple DNSPs explicitly describe AS/NZS 4777.2 as “mandated by the National Electricity Rules” in their installer guidance. For example, Ausgrid and Endeavour Energy state that AS/NZS 4777.2:2020 (‘Inverter Requirements’) is mandated by the National Electricity Rules. SA Power Networks also references National Electricity Rules amendments commencing 18 December 2021 requiring grid-connected inverters to comply with AS/NZS 4777.2:2020.
AEMO DER Register: an additional compliance “paper trail”
Australia’s DER Register (operated by AEMO) is a national database of installed DER devices; AEMO explains it launched in March 2020 and that DER device information is typically requested from installers/contractors at installation time. DNSPs commonly require installers to submit DER details within 20 days of commissioning, and DNSP pages in NSW explicitly reference this requirement and provide installer contacts.
Verification of the Victron Multi RS Solar certification status
What Victron publishes for the Multi RS Solar
On Victron’s public Multi RS Solar product page, the “Certificates” section lists multiple country/region certifications (e.g., VDE‑AR‑N 4105, EN 50549 variants, IEC safety standards, etc.). The list shown does not include an Australian AS/NZS 4777.2 certificate for the Multi RS Solar.
The Multi RS Solar datasheet lists technical specifications and a “STANDARDS” line showing safety and EMC standards (e.g., IEC 62109, IEC 62040, IEC 62477) but does not list AS/NZS 4777.2 in that standards block. The datasheet also shows the unit’s PV characteristics (450 V open-circuit maximum, MPPT operating range up to 450 V, and PV input current limits), but these electrical specs do not substitute for Australian grid‑connection certification.
What an Australian AS/NZS 4777.2 certificate looks like for Victron (comparison)
Victron does publish an Australian certificate example for other products: a “Certificate of Suitability” (issued by SGS Australia under a JAS‑ANZ accredited scheme) for MultiPlus‑II models that explicitly lists compliance including AS/NZS 4777.2:2020 (and related standards). This demonstrates that Victron’s public documentation can include Australian certification where it exists.
Implication for grid connection
CEC listings commonly rely on recognised certification evidence (including JAS‑ANZ accredited certification or state regulator certification) and distinguish AS/NZS 4777.2:2020 compliant models via the “(AS4777-2 2020)” suffix. If the Multi RS Solar lacks AS/NZS 4777.2 certification evidence, it is difficult to see how it could be accepted for grid‑parallel connection under DNSP rules that require CEC listing.
DNSP implementation in Australia
Coverage and summary chart
The table below covers the standard electricity DNSPs for the ACT, NSW, VIC, QLD, SA, TAS, WA and NT (the same DNSPs consumers typically see on their network/distributor details). Chart: DNSP published requirement for CEC-listed inverters (Australia-wide, reviewed DNSPs) Total DNSPs reviewed: 16 ■ CEC required (no explicit non-CEC exception published): 14 (87.5%) ■ Conditional (CEC or explicit “written approval” pathway for unlisted inverter): 2 (12.5%) 14 2
Interpretation note: “Conditional” here means the DNSP’s published guidance explicitly offers a written-approval pathway for a “CEC unlisted inverter proposal”. It does not mean the DNSP accepts uncertified equipment; technical compliance still applies.
DNSP-by-DNSP table
DNSP
Published DG / connection policy (primary link)
CEC approval required?
Explicit wording / clause (excerpt)
Does DNSP allow non‑CEC inverters?
Contact / process to request approval
Typical technical conditions highlighted in policy
IES “shall comprise of inverters that are registered with CEC as approved grid connect inverters or multiple mode inverters”.
No (no published exception pathway found)
General DNSP contact details via Evoenergy website; ENA identifies contact email for embedded generation enquiries.
AS/NZS 4777.2 + accreditation number; CEC registered; Australia A settings tables; DNSP may require written approval before changing power quality settings.
Inverter must be AS/NZS 4777.2 compliant and either “be of a type approved by the Clean Energy Council” or “have written approval from Ausgrid… discuss your CEC unlisted inverter proposal”.
Yes — case-by-case written approval (published pathway)
Email published for “CEC unlisted inverter proposal”: [email protected]
Australia A settings; DNSP settings per NS194; warning that non‑compliant inverters may need replacement at installer cost; NSW Emergency Backstop (mid‑2026) expects CSIP‑AUS compliance and capability testing, with low-export fallback for poor internet.
Inverter must either be “approved by the Clean Energy Council” or have “written approval… to use the make and model… (contact us to discuss your CEC unlisted inverter proposal)”.
Yes — case-by-case written approval (published pathway)
Endeavour instructs “please contact us” for unlisted inverter proposal; ENA provides DNSP contact email list for general enquiries.
Australia A settings; NS194 set-up; DER Register reporting within 20 days; warning that non‑compliant inverters may need replacement.
Defines “Approved Inverter” as AS/NZS 4777 compliant and listed on Clean Energy Council tested/approved inverters; also states all EG systems require a Connection Agreement (even zero export).
No (no published “unlisted inverter” exception pathway found)
Pre-approvals/connection via AusNet processes; ENA provides pre-approvals email contact.
Connection agreement required even for zero export; limited export control accuracy requirements; commissioning test reports for limited export; capability testing / utility-server interactions and fallback export limits in some cases.
“The inverter selected must be on the Clean Energy Council list of compliant inverters” and (from 1 July 2025) must also be on Jemena’s approved list; non-listed inverters “cannot connect and commission”.
No (must be on CEC list and Jemena list)
Jemena connection process and “approved list” pathway; ENA provides contact email for generation enquiries.
Emergency backstop: active comms link; CSIP‑AUS compliant inverter; internet connectivity.
Factsheet: “Ensure the inverter… is Clean Energy Council (CEC) approved.” Also: “Our validation steps check that a CEC approved inverter has been used.”
No
Factsheet publishes embedded generation contact email; ENA provides DNSP emails for basic/negotiated connections.
Australia A settings; export cap to pre-approval (typical 5 kW); internet connection; for export, systems under 200 kW must be CSIP‑AUS compatible and connected to utility server; only onboarded devices eligible to export.
Standard: “The inverters should be registered with CEC as approved grid connect inverters.” Dynamic Connections page: generating products “will need to be listed with the Clean Energy Council” and connected to utility server via Wi‑Fi internet.
No (no published non-CEC pathway found)
Energex connection process; ENA provides Energex contact email.
Australia A settings; DNSP connection agreement; export limits; for dynamic exports: utility-server communications and fallback export limits if comms fail.
entity[“company”,”Ergon Energy Network”,”qld electricity distributor”]
Installer guidance includes: “Confirm the equipment you are installing is CEC approved.”
No (no published non-CEC pathway found)
Ergon connection portal/process; ENA provides Ergon contact email.
Emergency Backstop Mechanism in QLD applies from 6 Feb 2023 for selected systems (GSD requirement); technical standards referenced and listed for installers.
entity[“company”,”SA Power Networks”,”sa electricity distributor”]
SA Power Networks: uses the CEC “Approved Inverter” listing to verify inverter compliance; select AS/NZS 4777.2:2020 compliant inverter from the list for applications.
Generally no for new export-capable systems. Government dynamic export regime notes time‑limited transitional/exemption arrangements; after 1 April 2024, certification and CEC listing mandatory for prescribed dynamic export equipment.
SA Power Networks publishes contact email for new energy services; government OTR contact details also published for dynamic export guidance.
Dynamic export capable equipment (for export-capable connections) and capability testing; zero-export sites exempt from dynamic export compliance but still must meet general connection rules; government/policy timelines matter.
IES must include inverters “registered with CEC as approved grid connect inverters” and included on the SGD compatible inverter list; CEC listing must not have expired.
No (must be CEC-listed and SGD-compatible)
Horizon Power installer processes; ENA provides renewables contact email.
Secure Gateway Device (SGD) and hardwired ethernet requirements; DERMS control; Australia C setting; export limits and operating envelopes; compatible inverter list governance.
entity[“company”,”Power and Water Corporation”,”nt electricity distributor”]
IES must include inverters “registered with the Clean Energy Council (CEC) as approved grid connect inverters.”
No
Power and Water “connect me” email listed by ENA.
Australia A setting; inverter certification to AS/NZS 4777.2 with accreditation number; (Power & Water appears in both region A and region C mapping guidance depending on network context); plus commissioning form requirements.
Interpretation notes on the table: 1) “CEC approval required” means the DNSP’s published guidance requires selection of a CEC‑listed inverter (or defines “approved inverter” as one listed on the CEC list), or requires the inverter be CEC‑registered/approved as a grid‑connect inverter. In Victoria, several DNSPs additionally require the inverter to be “onboarded” to the DNSP’s utility server (CSIP‑AUS / IEEE 2030.5 context). 2) “Conditional” is used only where the DNSP explicitly publishes a “written approval” pathway for a CEC‑unlisted inverter proposal (Ausgrid and Endeavour Energy). 3) Some technical documents use the word “should” for CEC registration; however, DNSP portals, related installer guidance, STC rules, and emergency backstop/dynamic export regimes frequently make CEC listing a practical prerequisite to approval and commissioning.
So can PMR482602020 be grid-connected if it’s not CEC-approved?
For a grid-parallel connection (exporting or capable of exporting in normal operation), the published DNSP position across Australia is effectively “no”, unless a DNSP explicitly grants an exception. Most DNSPs state their inverter must be CEC-approved/registered, and their portals and commissioning regimes (CSIP‑AUS onboarding, utility server capability tests, export limiting, regional settings) are built around that assumption.
In NSW, Ausgrid and Endeavour Energy are notable because they explicitly publish a written‑approval pathway to propose a CEC‑unlisted inverter. That pathway is not automatic approval: it simply means the DNSP is willing to assess the proposal. If assessed and rejected (or if installed without meeting requirements), the installer may be required to replace the inverter at their own cost. Given the Multi RS Solar’s apparent lack of AS/NZS 4777.2 certification evidence in Victron’s public materials, obtaining approval would likely require strong third‑party certification evidence and DNSP-compatible control/communications.
For non-export / off-grid configurations: Many standards and DNSP rules treat systems as “grid connected” if they can operate in parallel with the distribution system; true off-grid or break-before-make changeover arrangements may fall outside embedded generation connection rules, depending on design. This is highly technical and jurisdiction-dependent — if the intent is any form of grid interaction, assess it with the DNSP and a suitably licensed electrician/engineer before purchase.
Practical steps for installers and system owners
Before you buy or install (the “don’t get stuck with an unconnectable inverter” checklist)
Identify the DNSP first (your distributor). Use regulator resources (AER) or check the electricity bill.
Confirm the inverter is on the CEC Approved Inverter List (and check the listing is current/not expired). Also confirm the correct AS/NZS 4777.2 standard version and regional setting apply.
Confirm state/DNSP-specific mandatory controls:
Victoria: emergency backstop / CSIP‑AUS utility server onboarding requirements are explicit for several DNSPs.
Queensland: emergency backstop mechanism / Generation Signalling Device requirements are documented for certain systems.
South Australia: dynamic export capable equipment/commissioning tests and timelines are governed by government technical regulator guidance and SA Power Networks processes.
Western Australia (SWIS): Western Power requires Australia Region B settings; CEC listing is used to deem compliance.
Horizon Power: SGD compatibility list and hardwired comms to DERMS are mandatory for relevant connection classes.
Confirm STC / rebate implications early: if STCs are part of the commercial model, check the Clean Energy Regulator eligibility rule requiring CEC-listed components.
If you still want to pursue a non-CEC inverter grid connection
In practice, this only makes sense where the DNSP explicitly allows an “unlisted inverter proposal” pathway (published for Ausgrid and Endeavour). For those DNSPs, engage before purchase and be prepared to supply:
Independent certification evidence to AS/NZS 4777.2 (current applicable version) and anti-islanding evidence (IEC 62116), plus installation compliance to AS/NZS 4777.1. DNSPs commonly require an accreditation number and/or recognised test evidence.
Evidence that the unit can be configured to the DNSP required regional settings (Australia A/B/C) and that those settings are locked/verified.
Evidence of compliance with communications/export control obligations if applicable (CSIP‑AUS/IEEE 2030.5, utility server connectivity, capability tests, fallback export behaviour).
A clear single-line diagram and export-limiting method (where limited export applies), plus any commissioning test report required by the DNSP.
If you cannot supply the above, the probability of approval is low, and installing anyway risks forced replacement and/or inability to legally energise/export.
Post-install obligations that commonly apply
AEMO DER Register submission (commonly within 20 days of commissioning), either by the installer or via DNSP-integrated workflows depending on jurisdiction.
Commissioning evidence: many DNSPs require commissioning sheets/capability test results and validate certificates of electrical safety before enabling metering / export.
Alternative compliant ways to achieve a Victron-based system
If the goal is “Victron ecosystem + legal grid connection”, the simplest path is to choose a CEC-listed inverter/charger or hybrid inverter suitable for your topology and DNSP requirements, and confirm listing status before purchase. Victron has published AS/NZS 4777.2 certification for some products (e.g., MultiPlus‑II certificate shown), and many other mainstream brands are listed on the CEC approved inverter list used by DNSPs and STC eligibility rules.
Important: “CEC-approved” can mean different things in casual conversation (installer accreditation vs product listing). Here it means the product is listed on the CEC approved inverter list used by DNSPs and STC eligibility rules.
Primary sources linked in this report
entity[“organization”,”Clean Energy Council”,”australian clean energy body”] — Approved inverter list and product program pages: CEC approved inverters and Products program FAQ.
entity[“organization”,”Clean Energy Regulator”,”australian government renewable regulator”] — STC eligibility and CEC list requirement: Small-scale renewable energy systems.
entity[“organization”,”Energy Networks Australia”,”australian energy networks industry body”] — DNSP region settings mapping and “most DNSPs use CEC list” note: FAQ: Changes to Inverter Standards.
entity[“organization”,”Australian Energy Regulator”,”australian energy regulator”] — Distributor identification: Who is your distributor?.
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How Lithium Prices Influence ESS-Grade LFP Cell Costs Lithium iron phosphate (LiFePO₄ or LFP) is the chemistry of choice for stationary energy storage systems (ESS) thanks to its safety, cycle life, and cost stability. But battery-grade lithium carbonate (Li₂CO₃) prices can move sharply. The big question: does this heavily impact the final cost of an ESS battery? The answer: it has a surprisingly small effect — even when prices double.
1. Real-World LFP Cell Examples
Two widely used prismatic LiFePO₄ cells from EVE Energy are great case studies:
EVE MB31 – 314 Ah large-format cell (~1 kWh, ~5.6 kg)
EVE LF100LA – 100 Ah cell (~0.326 kWh, ~1.98 kg)
Exact lithium content is proprietary, but we can calculate it closely using LiFePO₄’s chemistry.
2. Lithium Carbonate Content in LFP Cells
Lithium makes up about 4.4% of LiFePO₄’s cathode mass, and lithium carbonate is 18.8% lithium by weight.
From this, manufacturing each 1 kWh of LFP storage capacity needs ~0.47 kg of lithium carbonate.
This means:
MB31 (≈1 kWh) → ~0.47 kg Li₂CO₃ per cell
LF100LA (≈0.326 kWh) → ~0.153 kg Li₂CO₃ per cell
3. Price Change: USD $10,000/t → USD $20,000/t
Let’s compare the impact of lithium carbonate doubling from USD $10/kg to USD $20/kg.
Per cell:
MB31 314 Ah:
$10/kg → USD $4.70 lithium cost
$20/kg → USD $9.40 lithium cost
Increase: USD $4.70 (~AUD $7)
LF100LA 100 Ah:
$10/kg → USD $1.53 lithium cost
$20/kg → USD $3.06 lithium cost
Increase: USD $1.53 (~AUD $2.30)
4. Effect on a 51.2 V Battery Pack (16 Cells)
Most 51.2 V ESS batteries are built from 16 cells in series:
Using MB31 cells (314 Ah / ~1 kWh each):
16 × USD $4.70 increase = USD $75.20 (~AUD $112) more if Li₂CO₃ doubles in price.
Using LF100LA cells (100 Ah / ~0.326 kWh each):
16 × USD $1.53 increase = USD $24.48 (~AUD $36) more if Li₂CO₃ doubles in price.
5. Why the Impact Is So Small
Even a 100% jump in lithium carbonate prices adds less than AUD $120 to a large 51.2 V / 314 Ah battery, and under AUD $40 to a smaller 100 Ah version.
That’s because:
Lithium carbonate is only a small fraction of the cell’s mass.
The rest of the cost comes from iron, phosphorus, graphite, copper, aluminium, electrolyte, casings, BMS, labour, testing, logistics, and installation.
6. Key Takeaways
Doubling lithium carbonate from USD $10k/t → USD $20k/t adds:
~USD $75 (~AUD $112) to a large 51.2 V 314 Ah pack
~USD $24.50 (~AUD $36) to a smaller 51.2 V 100 Ah pack
Other materials, manufacturing, and installation dominate ESS battery costs.
Lithium price swings are important, but they don’t make or break ESS battery affordability.
Sources:
EVE datasheets of 100ah and 314ah cells.
Lithium content calculations based on LiFePO₄ molecular composition.
Victron MultiPlus-II Range Gains Expanded CEC Approval
The Clean Energy Council (CEC) has updated its approved inverter list to include additional Victron MultiPlus-II models under the AS/NZS 4777.2:2020 standard, valid until 2027–2028.
Now certified for residential & commercial use in:
On-grid installations — with no power export back to the grid, single or three-phase. (No Battery Rebate available on grid)
Off-grid installations — with up to 4 units per phase in parallel. Battery rebate is available, when installed by an OFFGRID licensed CEC/SAA installer (to be clear, this is a very uncommon license even for Solar installers)
Model
Approval Expiry
MultiPlus-II 48/8000/110-100 230V
Jul 10, 2028
MultiPlus-II 48/10000/140-100 230V
Jul 10, 2028
MultiPlus-II 48/15000/200-100 230V
Jul 10, 2028
Existing Approved Models
The 3 kVA & 5 kVA models (including GX versions) remain approved under:
Stand-Alone Inverter with Generator Input – Battery Only
Stand-Alone Inverter with Grid Input – Battery Only (-AU models)
EVE Energy’s new MB56 (also known as LF560K) battery cell is potentially going to make waves in the world of energy storage, promising to revolutionize everything from home solar systems to large-scale grid infrastructure. This LiFePO4 (LFP) prismatic cell boasts an impressive blend of high capacity, extended lifespan, and enhanced safety, setting a new benchmark for the industry.
EVE MB56 seen next to the EVE MB30 cell. Cycle life can be as high as 12000 cycles, but for residential non thermally managed battery cells, EVE has given them a cycle life of 8000 cycles according to the datasheet they have released. – Source EVE BATTERY USA WEBSITE
At its core, the MB56 offers a nominal capacity of 628Ah and a nominal voltage of 3.2V. What truly sets it apart, however, is its ultra-long cycle life, ranging from 8,000 to an astonishing 12,000 cycles to 70% of its original health. This longevity is a result of EVE’s innovative manufacturing techniques and improved material composition for both the cathode and anode.
Beyond its impressive lifespan, the MB56 prioritizes safety and efficiency. It features very low internal resistance, minimizing energy loss and maximizing performance. The cell is designed with robust safety features, including an explosion-proof and leak-free construction, and excellent thermal stability. EVE is even integrating “smart cell” technology for real-time monitoring of crucial parameters like temperature and gas levels.
The MB56 is a true workhorse, designed for a wide array of applications. Its primary focus is large-scale energy storage systems, encompassing utility-grade grid storage, commercial building solutions, and seamless integration with renewable energy sources. It’s also an ideal candidate for off-grid systems, providing reliable power for homes and remote setups. Furthermore, its “Automotive Grade” designation makes it suitable for electric vehicles, particularly buses, heavy-duty trucks, and commercial fleets, as well as marine applications. For the DIY enthusiast, its high capacity, pre-welded studs, and included busbars make it an attractive option for building custom battery packs.
EVE Energy began pilot production of the MB56 around December 2024 at its state-of-the-art “Super Factory” in Jingmen, China. This highly automated facility is designed for precision and efficiency, with the capacity to produce a remarkable 1.5 cells per second.
In essence, the EVE MB56 represents a significant leap forward in battery technology. Its combination of high capacity, exceptional cycle life, and advanced safety features not only drives down overall system costs but also simplifies integration, paving the way for a more efficient and sustainable energy future.
Limited stock is available, but they are now in production for available to purchase in limited quantities, we also have
Further news, we may be moving away from the JK BMS for some of our higher end batteries. We have already started using a PACEBMS on our LiFePro 51.2v 100ah batteries, and the software is great, the touchscreen is really easy to set the required protocol and the ability to connect to the BMS remotely is ideal, featuring both Wifi and Bluetooth.
The new models just recently annouced now feature 2A Active cell balancing, which is a really great feature, it not only extends the pack life, when the cells begin to fade with age, it also makes the balancing function, must faster than traditional energy storage BMS.
The new PACE BMS offers OTA (over the air) updates, a cleaner and nicer software setup, on Tier 1 grade hardware with 2A active balancer built into the board. This is significant, and allows us to be able to remotely update any BMS that is connected to the WIFI network at the installed location, firmware brings new features in particular inveter support and updates.
