Power Generating Module (PGM)
European Union Electricity Market Glossary

 


 

 

Power Generating Module (PGM) is either a Synchronous Power Generating Module or a Power Park Module (PPM) (Article 2(4) of the Network Code on Requirements for Grid Connection of Generators (NC RfG)). 

 

NC RfG introduces four categories of PGMs:

 

Type A Power Generating Modules,

 

Type B Power Generating Modules,

 

Type C Power Generating Modules,

 

Type D Power Generating Modules.

 

The categories are defined by the voltage level of grid connection and the installed capacity of a PGM.

 

As ENTSO-E guidance document for national implementation for network codes on grid connection, Selecting national MW boundaries, Draft for consultation 1 July - 15 August 2016, 30 June 2016, underlines, categories of PGMs are introduced by following the principle of subsidiarity and proportionality.

 

The capacity thresholds are defined as limits of capacity threshold which define the maximum lower limit of each category leaving its final determination to the national level.

 

Type B, C, D thresholds need to be determined at national level regarding the following points:


- maintaining requirements which already exist from previous national regulations and have proven their need and benefit through operational experience in normal and emergency network situations,


- taking into consideration the national generation portfolio characteristics and its evolution (e.g. level of penetration of renewable energy sources),


- taking into consideration national system characteristics and its evolution (e.g. rural/urban conditions, density of load and generation),


- ensuring that requirements needed for guaranteeing security of supply will be fulfilled considering the peculiarities of each national system (e.g. dependency on power imports from abroad).

 

The aforementioned ENTSO-E guidance document of 30 June 2016 evidences the following key rationales for choosing the pertinent thresholds:

 

- A/B threshold: the need of fault-ride-through (FRT) capability of small generation units if 
otherwise the loss of a large volume of generation in case of a fault on the 
transmission network would jeopardize system security, and the need to increase observability of small generation units.

 

- B/C threshold: as regards frequency control capability of renewable energy sources (RES) generation: in case of high volumes of RES generation a large amount of conventional generation resources will be displaced and hence not be available to manage system security during certain periods (in these cases, the need of additional capacity to control frequency must be evaluated, regarding the amount needed and the expected size of new generation units).

 

- C/D threshold: need of FRT capability of large PGMs and units connected to typically the highest voltages of the grid, to guarantee the stability of the grid.

 

Winter Energy Package (Annex to the Proposal for a Regulation of the European Parliament and of the Council on the internal market for electricity (recast), 30.11.2016, COM(2016) 861 final 2016/0379 (COD)) provides for the regional outage coordination of Power Generating Modules.

 

This task is entrusted to Regional Operational Centres (ROCs).

 

Pursuant to the said draft each ROC would perform outage coordination "in order to monitor the availability status of the relevant assets and coordinate their availability plans to ensure the operational security of the transmission system, while maximizing the capacity of the interconnectors and/or the transmission systems affecting cross-zonal flows."

 

Each Regional Operational Centre would also maintain a single list of relevant grid elements, Power Generating Modules and demand facilities of the system operation region and make it available on the ENTSO for Electricity operational planning data environment.

 

Further, each ROC would carry out the following activities related to outage coordination in the system operation region:


(a) assess outage planning compatibility using all Transmission System Operator's (TSOs') year-ahead availability plans;


(b) provide the transmission system operators of the system operation region with a list of detected planning incompatibilities and the solutions it proposes to solve the incompatibilities.

 

 

Relevant Power Generating Modules

 

 

Network Code on System Operation In Articles 84 - 86 envisions the establishment of the lists of "relevant Power Generating Modules" (along with the list of "relevant Demand Facilities").

 

According to Article 103(1) and (2) of the Network Code on System Operation each Power Generating Facility owner must ensure that all relevant Power Generating Modules it owns:


- are ready to produce electricity pursuant to their declared technical capabilities when necessary to maintain operational security, except in case of forced outages - in case of modules which are declared ‘available’,


- do not produce electricity - in case of modules which are declared ‘unavailable’.

 

 

 

Network Code on System Operation

Articles 84 - 86

 

Article 84
Methodology for assessing the relevance of assets for outage coordination


1.   By 12 months after entry into force of this Regulation, all TSOs shall jointly develop a methodology at least per synchronous area, for assessing the relevance for the outage coordination of power generating modules, demand facilities, and grid elements located in a transmission system or in a distribution system, including closed distribution systems.


2.   The methodology referred to in paragraph 1 shall be based on qualitative and quantitative aspects that identify the impact on a TSO's control area of the availability status of either power generating modules, demand facilities, or grid elements which are located in a transmission system or in a distribution system including a closed distribution system, and which are connected directly or indirectly to another TSO's control area and in particular on:


(a) quantitative aspects based on the evaluation of changes of electrical values such as voltages, power flows, rotor angle on at least one grid element of a TSO's control area, due to the change of availability status of a potential relevant asset located in another control area. That evaluation shall take place on the basis of year-ahead common grid models;


(b) thresholds on the sensitivity of the electrical values referred to in point (a), against which to assess the relevance of an asset. Those thresholds shall be harmonised at least per synchronous area;


(c) capacity of potential relevant power generating modules or demand facilities to qualify as SGUs;


(d) qualitative aspects such as, but not limited to, the size and proximity to the borders of a control area of potential relevant power generating modules, demand facilities or grid elements;


(e) systematic relevance of all grid elements located in a transmission system or in a distribution system which connect different control areas; and


(f) systematic relevance of all critical network elements.


3.   The methodology developed pursuant to paragraph 1 shall be consistent with the methods for assessing the influence of transmission system elements and SGUs located outside of a TSO's control area established in accordance with Article 75(1)(a).


Article 85
Lists of relevant power generating modules and relevant demand facilities


1.   By 3 months after the approval of the methodology for assessing the relevance of assets for outage coordination in Article 84(1), all TSOs of each outage coordination region shall jointly assess the relevance of power generating modules and demand facilities for outage coordination on the basis of this methodology, and establish a single list, for each outage coordination region, of relevant power generating modules and relevant demand facilities.


2.   All TSOs of an outage coordination region shall jointly make the list of relevant power generating modules and relevant demand facilities of that outage coordination region available on the ENTSO for Electricity operational planning data environment.


3.   Each TSO shall notify to its regulatory authority the list of relevant power generating modules and relevant demand facilities for each outage coordination region in which it participates.


4.   For each internal relevant asset which is a power generating module or demand facility, the TSO shall:


(a) inform the owner of the relevant power generating module or relevant demand facility about its inclusion in the list;


(b) inform DSOs about the relevant power generating modules and the relevant demand facilities which are connected to their distribution system; and


(c) inform CDSOs about the relevant power generating modules and the relevant demand facilities which are connected to their closed distribution system.


Article 86
Update of the lists of relevant power generating modules and relevant demand facilities


1.   Before 1 July of each calendar year, all TSOs of each outage coordination region shall jointly re-assess the relevance of power generating modules and demand facilities for outage coordination on the basis of the methodology developed in accordance with Article 84(1).


2.   Where necessary, all TSOs of each outage coordination region shall jointly decide to update the list of relevant power generating modules and relevant demand facilities of that outage coordination region before 1 August of each calendar year.
3.   All TSOs of an outage coordination region shall make the updated list of that outage coordination region available on the ENTSO for Electricity operational planning data environment.


4.   Each TSO of an outage coordination region shall inform the parties referred to in Article 85(4) about the content of the updated list.

 

Article 103(1) and (2)

 

1.   Each power generating facility owner shall ensure that all relevant power generating modules it owns and which are declared ‘available’ are ready to produce electricity pursuant to their declared technical capabilities when necessary to maintain operational security, except in case of forced outages.

 

2.   Each power generating facility owner shall ensure that all relevant power generating modules it owns and which are declared ‘unavailable’ do not produce electricity.

 

 

 

 

 



Last Updated on Sunday, 24 September 2017 20:59
 

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