REGULATORY COMPLIANCE AND POWER PLANT ADVANCED CONTROL
Senergy CCI – Central Plant Controller
The Central Plant Controller (CCI) is a monitoring and control system installed at the point of delivery that allows DSOs to monitor and regulate the generation plant, enabling it to participate in grid balancing.
The CCI was introduced in Italy in 2022 with the V1 and V2 variants of the CEI 0-16 standard. The key requirements requested by the regulation include the PF1 (Monitoring), PF2 (Regulation and Control), and PF3 (Participation in Flexibility Markets and Plant Optimization) functions, which are essential to ensuring the security and stability of the national electricity system.
The Senergy CCI Higeco More solution is designed to fully meet all technical requirements, offering all the functionalities (PF1, PF2 and PF3) in a single device, with maximum reliability and ease of integration.
PF1, PF2 e PF3 features
Certified CEI 0-16
Cybersecurity
SENERGY CCI – CENTRAL PLANT CONTROLLER
Features and functionality
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HIGECO MORE ANSWERS THE MOST COMMON QUESTIONS ABOUT CCI
FAQ on the Central Plant Controller (CCI)
ARERA Resolution 385/2025/R/EEL 5 August 2025
In this section, we’ve collected the most frequently asked questions about CCI, which emerged during the dedicated webinar and subsequent discussions with our customers. Here you’ll find practical answers and regulatory references to clarify doubts and delve deeper into the operation of the Central Plant Controller.
Resolution 385/25/R/eel positively verifies revision 2 of Annex A72 to Terna’s Grid Code and consequently extends the scope of application of the CCI to photovoltaic and wind plants with a nominal power greater than or equal to 100kW, always connected to MT.
Systems with a nominal power greater than or equal to 100kW and less than 500kW will be considered EXISTING if connected to the grid before 31 March 2027, having submitted the connection request before 31 October 2025.
Power plants with a nominal power greater than or equal to 500kW and less than 1MW will be considered EXISTING if connected to the grid before 28 February 2027, having submitted the connection request before 6 August 2025.
Power plants with a nominal power greater than or equal to 1MW will be considered EXISTING if connected to the grid before 28 February 2026, having submitted the connection request before 6 August 2025.
Power plants not included in the above definitions are considered NEW.
For EXISTING systems, the Resolution requires UPGRADE, i.e., installation of the CCI, if not already present, and activation of the PF2 function for limiting Active Power upon external control by the DSO, by the deadlines listed above.
For NEW systems, the Resolution requires installation of the CCI and activation of the PF2 function for limiting Active Power upon external control by the DSO, by the time of grid connection.
For power plants with a nominal power greater than or equal to 1 MW connected to medium voltage, the obligation remains valid for all technologies, without distinction.
For power plants with a nominal power less than 1 MW, also connected to medium voltage, the obligation applies only to photovoltaic and wind technologies.
In the future, it will likely be extended to other technologies as well, and ARERA will define the modalities with a dedicated resolution.
If the system has a nominal power greater than or equal to 100kW, this is correct, as Resolution 385/25 extends the requirement for photovoltaic systems up to 100kW.
If, however, the system has a lower nominal power, it could be an error due to incorrect or outdated data on Gaudì. You can report this to the DSO by replying to the certified email received.
Resolution 385/25/R/eel establishes the provision of a bonus for the adjustment of existing plants, but only those with a nominal power of less than 1 MW.
Existing power plants with a nominal power greater than or equal to 100kW and less than 500kW will receive a financial contribution of:
– €7,500 if they submit the Compliance Declaration by March 31, 2026
– €5,620 if they submit the Compliance Declaration by July 31, 2026
– €3,750 if they submit the Compliance Declaration by November 30, 2026
– €1,875 if they submit the Compliance Declaration by March 31, 2027
Existing power plants with a nominal power greater than or equal to 500kW and less than 1MW will receive a financial contribution of:
– €1,000 if they submit the Compliance Declaration by February 28, 2026
– €7,500 if they submit the Compliance Declaration by June 30, 2026
– €5,000 if they submit the Compliance Declaration by October 31, 2026
– €2,500 if they submit the Compliance Declaration by February 28, 2027
Revision 4 of CEI 0-16, published in 2025, eliminated Annexes K and X, referring directly to the Terna Grid Code for HV-connected systems: Annex A68 for photovoltaic systems, A79 for storage systems, and A17 for wind systems. For MV-connected systems with a power greater than 6 MW, the same requirements apply as for smaller MV-connected systems.
Yes. The scope of application is defined based on the nominal power of the system, calculated as defined by the CEI 0-16 standard, not on the maximum grid feed-in power.
Specifically, for photovoltaic systems, the nominal power must be calculated as the sum of the lower of the AC and DC power of each inverter.
Yes, in the transitional phase, that is from the publication of the Resolution until the deadlines indicated for the definition of existing plants, it is necessary to install both.
In general, for existing systems, it is necessary for the remote disconnection modem to remain functional until the completion of the upgrade, in particular until the functional checks of the DSO have been passed.
Yes, as indicated in the TIDE, but only for the portion of energy sold. Any incentive will not be reimbursed, as it is allocated to the energy PRODUCED, which in this case was not generated.
Yes, it is. For hybrid systems, i.e., systems with multiple technologies, the definition of a system in the TICA is considered for applicability: a system is defined as a group of generators, of the same technology, connected under the same POD.
The CCI is mandatory if under a MT POD there is at least one system with a nominal power greater than or equal to 1MW, or if there is a photovoltaic or wind system with a nominal power greater than or equal to 100kW. In this second case, the PF2 Active Power Limitation function must also be activated upon external command from the DSO.
Yes, to be compliant with CEI 0-16, the CCI must have all the functionalities defined in Annexes O and T: the functional performances PF1, relating to observability, PF2, relating to controllability by the DSO, and PF3, relating to controllability by the aggregator/bsp.
Arera Resolutions 540/21 and 385/25 establish whether or not the activation of various functions on systems is mandatory.
Resolution 385/25 establishes the mandatory activation of the PF2 Active Power Limitation function upon external command from the DSO for photovoltaic and wind systems connected to medium voltage with a nominal power greater than or equal to 100 kW.
Yes, in addition to the PF2 Active Power Limitation function upon external DSO command, which must be activated on all MV-connected photovoltaic and wind power systems with a nominal power greater than or equal to 100kW, when defining the Operating Regulations, the DSO can request the activation of other specific PF2 functions. The Producer can always refuse, but these functions are not mandatory.
No, it remains invalid as previously.
Annexes O and T state that the time synchronization function can be performed by a GPS receiver integrated into the CCI, or it can be provided via a local communications network service, using the NTS protocol, the secure version of NTP.
The DSO, as required by Resolution 540/21.
The battery limit, between the DSO’s scope of supply and that of the Manufacturer, is the optical cassette that the DSO installs in the measurement compartment of the Secondary (exchange) cabin.
It better be. In fact, the CCI must use a PKI (Public Key Infrastructure) for the management of security certificates (See CEI 0-16 T.3.3.4.9). According to Annex T there are 3 ways to do it:
1 – Manual Management (temporary solution only): Installations, updates, revocations, replacements, of DSO certificates and any BSPs must be done manually on each plant. Challenging and error-prone if there are many CCIs to manage.
2 – Local PKI in the plant and OCSP protocol: Installing and managing a local PKI is very expensive and difficult. It is neither convenient nor secure.
3 – External PKI in CLOUD: The CCI uses an external PKI in #cloud, through the internet connection. Secure, centralized and automatic management of the certificate life cycle.
In addition, a CCI connected to the internet is easier to update – mandatory updates are already planned in the coming years – to reach and consult – through our portal – to replace in case of failure – automatic backup of configurations and data.
The data to be collected by the CCI remains essentially unchanged from the past.
For Delivery Points, the CCI must directly measure P, Q, V, and optionally I, and acquire the status of the DG and DI.
For Single Generators, the CCI must acquire the P measurement and the status of the DDG (or equivalent).
Individual generator data is required only for new systems with a power output greater than or equal to 1 MW, and only if the generators have a nominal power greater than:
– 170kW for static converters (e.g., photovoltaic inverters)
– 250kW for traditional generators
– 50kW for storage
Furthermore, among the simplifications introduced by the CEI for power plants with a nominal power of less than 500 kW, it is established that:
– for fully sold and single-source plants only, the aggregate generated power can be assimilated to the power fed into the grid, measuring only the latter.
– the maximum allowable error for measurements increases from 2.2% to 5%.
The CEI 0-16 standard requires that MV measurements must be taken at the point of delivery directly by the CCI using its measurement unit.
The standard recommends using a Class 0.2 or better Measurement Converter and Class 0.5 or better CTs and VTs, with a rating of 5 VA or 10 VA. The CTs and VTs can be shared with other systems, excluding the fiscal measurement group, without creating interference.
Measurement systems with different characteristics are also acceptable, provided they comply with the accuracy required by Annex A.6 of the Terna Network Code, table 5: maximum error in the measurement of P, Q and V less than 2.2%, which increases to 5% for systems with nominal power less than 500kW.
The CEI 0-16 standard specifies that the measurements and statuses of individual generators, and the measurements of the aggregate generated power, can also be acquired by the CCI via communication with other system elements, using standard communication protocols, provided that the required accuracy is guaranteed.
For delivery point measurements, however, the law establishes that they be acquired directly from the CCI.
No, because the protectors use protective CTs, which cannot guarantee the required accuracy.
As indicated in paragraph O.14 and in figures O.1 and O.7 of CEI-016 2025-04, monitoring of the status of the DG and all the DIs is required, through direct acquisition (clean contact) or by communicating with other system elements (e.g. SPI).
Yes, as indicated in the interpretative note published by the CEI in July 2023.
Resolution 540/21/R/el establishes that DSOs that do not intend to carry out data collection and regulation activities may use a third-party distributor, “such as, for example, the reference distribution companies or, in the case of SDC, the concessionary distribution companies in the territory in which they operate“. Alternatively, the DSO could submit a communication of motivated renunciation to Terna by 31 January 2022, which will evaluate alternative solutions. Ultimately, Terna will carry out the data collection directly, via the IEC 60870-104 protocol.
Yes, CTs are not the only measurement system available. You can also use Rogowski probes, but be careful because they are not as precise as CTs, and the CEI 0-16 standard requires that a total measurement error on P and Q be guaranteed to be less than 2.2%!
If you choose CTs measuring in class 0.5, as indicated in CEI 0-16, you will be able to avoid additional tests and compliance problems.
Yes. The CEI 0-16 standard establishes that the TVs for measuring the Minimum Homopolar Voltage must always be installed in MV at the connection point, and can be equipped with a double secondary (one for protection and one for measurement), or a single secondary with a double class (protection and measurement).
In the first case, the CCI can be connected to the measurement windings, even in parallel with other systems already connected.
In the second case, the CCI can be connected to the secondaries already connected in open delta to the Interface Protection, creating a separate connection to each VT. This way, it is always possible to take the three Phase-Earth voltages, without interfering with the measurement of the Minimum Homopolar Voltage.
In any case, the requirement regarding the maximum measurement error must always be respected, which must be less than 2.2%, or 5% only for systems with a nominal power of less than 500kW.
The CCI control functions are based on closed-loop regulators, which read the measurements at the delivery point, compare them with the set points, received (servo mode) or calculated (autonomous mode), calculate the set points to be sent to the generators/converters and send them. Consequently, the CCI must be able to communicate reliably and quickly with the generators/converters, which must implement a standard communication interface and protocol that includes the possibility of receiving commands in P and Q (or equivalent, for example PF or PHI). If the communication is based on serial protocols, such as RS485 or CANBUS, and not Ethernet, it is more difficult to respect the prescribed response times, and it is necessary to evaluate the feasibility on a case-by-case basis.
Many photovoltaic inverter models, even older ones, are already designed to be controlled by an external control system, meaning they support receiving commands via standard communication protocols to regulate active and reactive power. Sometimes, it may be necessary to update the inverter’s firmware, or install an additional internal card or external data logger.
In the case of the active power limitation function, if the inverters cannot be regulated at all, the CCI can implement the command by disconnecting the individual inverters, i.e. by partially reducing production, while still keeping the system connected to the grid, i.e. by keeping the DI and DG closed.
Similar to photovoltaic inverters, traditional generators can also be regulated by sending active and reactive power commands, directly or through an external controller (e.g., PLC).
Even for traditional generators, in the case of the active power limitation function, if the generators cannot be regulated at all, the CCI can implement the command by disconnecting the individual generators, i.e., partially reducing production, while still keeping the system connected to the grid, i.e., by keeping the DI and DG closed.
Yes. Annex O of the CEI 0-16 standard does not impose requirements on how the CCI is connected to generators/inverters.
In any case, the connection must ensure compliance with the standard’s requirements, in particular:
- Reliability: The CCI, and some of its features, must be available 99% of the time annually.
- Performance: the CCI must be able to collect data from individual generators, if requested, with a maximum sampling time of 4 seconds, and the response time of the control functions must be less than 1 minute for active power regulation, including Active Power Limitation upon external command from the DSO (required by Resolution 385/25), and 10 seconds for reactive power regulation.
Once all tests, including functional tests, have been performed and the certifications described in Chapter O.15 of CEI 0-16 2022-03 have been obtained, CCI manufacturers may issue a self-declaration of conformity to the standard, Annexes O and T. The resulting technical file must be retained for at least 10 years from the product’s last manufacturing date and must be made available to the regulatory authorities. A third-party body accredited for these annexes of the standard can certify the product’s conformity, further supporting the self-declaration.
Chapter O.15 of CEI 0-16 2022-03 specifies stringent requirements for both hardware and software cyber security. In particular, the use of a cryptographic component capable of detecting and responding to physical tampering is required, certified according to FIPS-140-2 with level 3. Furthermore, certification to IEC 62443-4-1 is required, according to the IsaSecure Secure Development Lifecycle Assessment (SDLA) scheme, of the CCI production process, and to IEC 62443-4-2, according to the IsaSecure Component Security Assurance (CSA) scheme, of the CCI product.
Chapter O.15 of CEI 0-16 2022-03 requires that the CCI be IEC 62443-4-2 certified according to the IsaSecure CSA scheme (which includes and exceeds the EDSA cited in the standard). This certification requires numerous IT security features, which must be implemented, and tested, by the CCI. Annex O of CEI 0-16 2022-03 establishes that all the required CCI features “…they can also be integrated into one of the other devices constituting the system provided that it is possible to test the features of the aforementioned devices according to the indications of this Annex”. In summary, the features must be present, in integrated form or not, in the CCI, and these must be tested and certified.
No, the CEI 0-16 Annex O standard requires several tests, which cannot be carried out in just any laboratory. To comply with the standard, the product must pass the insulation, EMC, noise immunity and climate tests in an ISO 17025 accredited laboratory, and the functional tests in the presence of an ISO 17065 accredited inspection body.
Once all the tests have been passed, the relevant test and inspection reports have been obtained, and the required certifications have been obtained, at that point the manufacturer self-declares that the CCI complies with CEI 0-16 Annex O and T. The technical file with all the test reports and certifications must be kept and made available for 10 years.
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