AUGUST 20 19
Bundesnetzagentur für Elektrizität, Gas, Telekommunikation, Post und Eisenbahnen Tulpenfeld 4
53113 Bonn
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Establishing requirements 2019-2030
Summary at consultation start
Introduction
The electricity network development plan (NDP) is a fundamental element of Germany's energy transi- tion. It is the result of numerous legal, political, eco- nomic and technical framework conditions. It deals with a wide range of issues that are important and the subject of discussion within the context of the energy transition. Now the time has come around again: the transmission system operators (TSOs) have once again identified the grid expansion re- quirements for the period up to 2030. The TSOs have set out in their NDP the transmission system expan- sion measures and offshore transmission links that they consider are needed up to 2030. The basis for the NDP is the current scenario framework that the Bundesnetzagentur approved on 15 June 2018.
The NDP is the official planning element for the ex- pansion of the electricity transmission network. It focuses on showing the possible breadth of Germa- ny's future energy supply. Based on the assumptions made, it works out an appropriate expansion of the existing transmission network. In preparation for a subsequent federal requirements plan, the Bundes- netzagentur carries out an accompanying strategic environmental assessment (SEA) on the basis of the NDP. The SEA begins with a scoping exercise that includes defining the methodology and level of de- tail for the assessment. Following input primarily from those public authorities whose environmental and health remits are affected by the NDP, the scope of the assessment was defined and published in April 2019. On this basis, the draft environmental report was drawn up and is being published togeth- er with the NDP for consultation from 6 August to 16 October 2019 with the participation of specialists and the general public concerned. The Bundesnet- zagentur is holding five information events in Bre- men, Mannheim, Münster, Erfurt and Regensburg alongside the consultation process.
The German federal government has set the target of achieving at least 80% of the country's electricity con- sumption from renewable sources by 2050. The target of 65% by 2030 is reflected in the NDP 2019-2030.
The Commission on Growth, Structural Change and Employment, also known as the "Coal Com- mission", published its final report on 26 January 2019. The Commission's proposals are taken into account in the NDP 2019-2030 in Scenario C 2030, which reflects the phase-out of coal-fired power generation during the period up to 2030. The Bun-
desnetzagentur uses an additional scenario to also take account of the long-term effect of a complete phase-out of coal. This scenario – Scenario C 2038* – goes further than the assumptions of the scenario framework.
It takes account of developments in, for instance, stor- age, coupling between the electricity, heating and transport sectors, and the flexible use and provision of electricity. The fact that electrical energy is being used more and more efficiently also plays a role.
Current assessments, assuming a renewables share of 65% of gross electricity consumption in 2030 and a complete phase-out of coal by 2038, indicate that the projects currently listed in the Federal Requirements Plan Act are as important as before.
The TSOs published their first draft of the NDP 2019-2030 for consultation on 4 February 2019.
They subsequently revised the draft and submitted the second draft to the Bundesnetzagentur for evalua- tion on 15 April 2019.
All parties concerned are invited to put forward their opinions, ideas and comments. The draft environmen- tal report, the second draft of the NDP 2019-2030 and the Bundesnetzagentur's preliminary evaluation re- sults can therefore be viewed at the Bundesnetzagen- tur's offices in Bonn (Tulpenfeld 4, 53113 Bonn) and online at https://www.netzausbau.de/2019-2030-nep-ub between 6 August and 17 September 2019; the dead- line for responses is 16 October 2019.
The start of the consultation in no way means that the Bundesnetzagentur has completed its evaluation and opinion-forming process. The Bundesnetzagentur is open to comments, new arguments and alternative solutions. It will continue its own calculations and accompanying assessments while the consultation is running.
After the consultation closes, the Bundesnetzagentur will analyse the responses received and take them into account when confirming the NDP and revising its environmental report.
Figure 1: Five steps to grid expansion
Formal participation steps
Anyone German legislator Particular groups of people
Source:
Bundesnetzagentur
To drive forward the necessary nationwide expansion of the electricity grid, the country's requirements for the extra-high voltage networks are regularly studied and identified in a transparent process involving five steps that build on each other and with broad-based public participation. The aim is to equip the electricity grid for the transition to renewables as effectively as possible, taking the necessary decisions together with the local communities.
1. Scenario framework
How much electricity will we consume in the coming years? What part will coal-fired and wind power sta- tions play in future? Possible answers are provided by the scenario framework, which is drawn up regu- larly by the TSOs. This describes probable develop- ments in the German energy landscape and is created jointly by the four TSOs Amprion, TransnetBW, 50Hertz and TenneT. The Bundesnetzagentur invites the public to submit views on the TSOs' draft, modi- fies the scenario framework in line with well-founded proposals from the public consultation or as a result of its own insights, and finally approves the scenario framework.
2. Network development plan (NDP)
The TSOs, building on the scenario framework, draw up an NDP to establish the expansion requirements in the transmission network. The NDP contains the measures needed to optimise, reinforce and expand the electricity grid in line with requirements and ap- plies to the whole of the federal territory. The NDP 2019-2030 is the first NDP to include the plan- ning for offshore transmission links, replacing the previous offshore NDP. This planning is based on the provisions of the site development plan, which de- termines the order in which sites are to be auctioned for offshore wind farms as well as the commissioning dates for the transmission links required to connect the sites on time. On the basis of these provisions, the NDP defines the necessary offshore transmission links including the respective commissioning years and onshore grid connection points. The Bundes- netzagentur examines the measures proposed in terms of their necessity for the energy supply. Mem- bers of the public, associations and public authorities can state their positions in multiple participation rounds.
Scenario framework Network development plan Federal requirements plan Federal sectoral planning Planning approval
Establishing requirements Project
How are electricity generation and consumption changing?
Where does the grid have to be optimised, reinforced or expanded?
Which projects are laid
down in the legislation? Where do the
route corridors run? Where exactly does the line run within the corridor?
Consultation on the
scenario framework Consultation
by the TSOs Parliamentary
proceedings Scoping conference Scoping conference
Consultation by the Bundesnetzagentur
Participation of the authorities and the public Public inquiry
Hearing Public inquiry TSOs/Bundesnetzagentur TSOs/Bundesnetzagentur Bundestag TSOs/Bundesnetzagentur TSOs/Bundesnetzagentur
Besides examining the NDP, the Bundesnetzagentur identifies, describes and evaluates the likely signifi- cant environmental effects in an SEA. The SEA serves as a kind of early warning system, identifying poten- tial conflicts with justified concerns for the protection of persons and nature right at the beginning of the process and, consequently, mitigating them as effec- tively as possible or, best of all, preventing them completely. The findings are captured in an environ- mental report. The environmental report is then put up for consultation in parallel with the revised NDP.
3. Federal requirements plan
The confirmed NDP and the environmental report together provide the basis for the federal require- ments plan. This contains a list of projects for the power lines needed. The Bundesnetzagentur submits the draft federal requirements plan to the federal government at regular intervals. The government can then start the legislative process, at the end of which the necessity of the projects in terms of energy supply is established in the Federal Requirements Plan Act.
4. Federal sectoral planning
In the next step the TSOs propose the so-called route corridor, with alternatives, through which a new ex- tra-high voltage line is to run.
For projects that do not cross any federal state bor- ders a spatial planning procedure is undertaken by the federal state concerned. For lines marked as cross- ing federal state and/or national borders in the Fed- eral Requirements Plan Act, the Bundesnetzagentur carries out what is known as a federal sectoral plan- ning procedure.
5. Planning approval
Planning approval is based on the route corridors put forward in the fourth step of the process. It is in this step that the exact route of the transmission line is determined. Yet alternative routes must also be con- sidered. The TSOs' proposals are studied with respect to their effects on humans and the environment, among other things. Ultimately, a decision is taken approving a route that promises the minimum nega- tive impact.
1. Methodology
The NDP establishes the expansion requirements for the coming years. Determining what these expansion requirements for the transmission network are is based on the expected network load. Network areas with constant or diminishing loads will not need ex- pansion. They do not need more transport capacity.
Network areas with high transport requirements ex- ceeding current transport capacity, on the other hand, must be optimised, reinforced or newly constructed in an adequate manner, taking account of the NOVA principle (network optimisation before reinforcement before new construction). The determinant of network load and hence of expansion requirements is feed-in and offtake from the transmission network in the ref- erence year 2030. The requirements are identified in a multistage development process that is repeated at regular intervals and which is outlined below.
1.1 Scenario framework
Identifying the grid expansion requirements begins with drawing up the scenario framework. This framework describes various development pathways (scenarios) for future electricity generating capacity and consumption.
The scenario framework 2019-2030 underlying the NDP 2019-2030 was approved by the Bundes- netzagentur on 15 June 2018. It features a total of five scenarios. Three of these describe development path- ways up to 2030, one describes a pathway up to 2035 and one a pathway up to 2025. In contrast to the sce- nario framework 2017-2030, the Bundesnetzagentur has approved not only the minimum number of four scenarios as required by law, but an additional inter- im scenario, Scenario B 2025. The purpose of this in- terim scenario is to examine the ad hoc measures submitted by the TSOs.
Scenario A 2030 (low degree of sector coupling with more centralised structures) is characterised by a high rate of change in implementing the energy tran- sition (65% of gross electricity consumption from re- newables), with primarily central electricity generat- ing capacity (lignite, hard coal and offshore wind) and a primarily low degree of innovation (sector coupling as a driver, flexibility options and storage facilities).
1.2 Regionalisation
The scenario framework provides data on generat- ing capacity, energy consumption and annual peak load, aggregated for the country as a whole and broken down by energy source. A regional break- down is needed for modelling the transport of electricity in future years in order to establish where what congestion will arise in the transmis- sion network facilities in 2030. Here, specific loca- tion data are used, where available, especially for the smaller and easily set up renewables generat- ing plants. But forecasting methods are also used to enable assignment to the individual nodes.
1.3 Market modelling
Following regional assignment to the individual transmission network nodes, the feed-in from the generators that is needed to cover future demand is established in a third step. This step is necessary so that the level of transport requirements and the de- mands this will make on the grid ten years on can be estimated.
Another important factor in market modelling is the weather. The weather affects the production of renewable wind and solar energy as well as antici- pated demand in certain situations (eg lengthy pe- riods of frost). To allow for this, a "historical"
weather year (2012) is used as a basis for the mod- elling, in other words past experience.
Market simulation creates a model that details, down to the hour and network node, when and where in 2030 how much electricity will be generated and con- sumed or imported or exported. In other words it de- scribes the transport operations the grid will need to handle.
Table 1: Scenario framework 2019-2030 Installed capacity [GW]
Energy source Reference
2017
Scenario A 2030
Scenario B 2030
Scenario C 2030
Scenario B 2025
Scenario B 2035
Nuclear 9.5 0.0 0.0 0.0 0.0 0.0
Lignite 21.2 9.4 9.3 9.0 9.4 9.0
Hard coal 25.0 13.5 9.8 8.1 13.5 8.1
Natural gas 29.6 32.8 35.2 33.4 32.5 36.9
Oil 4.4 1.3 1.2 0.9 1.3 0.9
Pumped storage 9.5 11.6 11.6 11.6 11.6 11.8
Other conv. gen. 4.3 4.1 4.1 4.1 4.1 4.1
Capacity reserve 0.0 2.0 2.0 2.0 2.0 2.0
Total conv. generation 103.5 74.7 73.2 69.1 74.4 72.8
Onshore wind 50.5 74.3 81.5 85.5 70.5 90.8
Offshore wind 5.4 20.0 17.0 17.0 10.8 23.2
Photovoltaics 42.4 72.9 91.3 104.5 73.3 97.4
Biomass 7.6 6.0 6.0 6.0 7.3 4.6
Hydropower 5.6 5.6 5.6 5.6 5.6 5.6
Other renew. gen. 1.3 1.3 1.3 1.3 1.3 1.3
Tot. renew. generation 112.8 180.1 202.7 219.9 168.8 222.9
Total generation 216.3 254.8 275.9 289.0 243.2 295.7
Net electricity consumption [TWh]
Net electricity con- sumption1)
530.1 512.3 543.9 576.5 528.4 549.4
Driver sector coupling [millions]
Domestic heat pumps 530.1 512.3 543.9 576.5 528.4 549.4
Electric cars 0.1 1.0 6.0 10.0 2.0 8.0
Flexibility options and storage facilities [GW]
Power-to-gas --- 1.0 2.0 3.0 0.5 3.0
Photovoltaic battery storage
0.3 6.5 8.0 10.1 3.2 12.3
Large battery storage 0.1 1.5 2.0 2.4 1.2 3.4
DSM (industry & GHD) 1.5 2.0 4.0 6.0 3.0 5.0
Market modelling CO2 market model- ling requirement [million tonnes of CO2]
--- maximum
184
maximum 184
maximum 184
maximum 240
maximum 127
1) Including total transmission network losses in terawatt hour
1.4 Network planning
To plan the grid of the future, load flows are cal- culated for all the 8,760 hours of the year using the feed-in and load situations that market mod- elling has established. These calculations show the load on the grid and, with the aid of failure simulation, grid overload as well. The departure point for this is initially the start network. The start network comprises today's transmission network. It is augmented by measures that are al- ready at a far advanced stage of planning or that are under construction and for which energy supply requirements have been identified, most notably by the Power Grid Expansion Act (En- LAG) or through planning approval. It is on the basis of these analyses that the TSOs identify the grid expansion measures needed to maintain network security in the reference year 2030. These measures are identified as a general rule under the NOVA principle. This means that the TSOs, in the first instance, seek to optimise the grid, for in- stance by switching actions. Only when the po- tential for optimisation has been exhausted are re- inforcement measures taken, for instance ex- changing 220 kV for 380 kV wiring. When this po- tential, too, has been exhausted, grid expansion measures are then permitted, for instance the construction of new extra-high voltage lines.
In technical terms, expansion planning follows the planning principles of the TSOs. One such principle is unrestricted operation of the grid even in the event of the failure of individual facil- ities, also called n-1 security. Instruments provid- ing flexible operation such as redispatch that have been available in the past as security back-up, are not now considered. Later operation of the grid would face restrictions if network planning were to use such instruments. This would have unpre- dictable consequences for the historically high level of reliability of the German energy supply infrastructure.
The result of these network calculations consti- tutes the grid expansion requirements required up to 2030 and 2035, which are then taken up by the TSOs in their NDP.
2. Examination
Publication of the second draft of the NDP marks the start of the Bundesnetzagentur's examination of the grid expansion measures proposed by the TSOs. The Bundesnetzagentur is considering all the scenarios for 2030; however, due to the proposals made by the Commission on Growth, Structural Change and Em- ployment, special focus is given to how a measure in Scenario C 2030 performs, since the installed capacity of coal-fired power stations in this scenario corre- sponds to the phase-out of coal-fired power genera- tion. Eligible for confirmation are those projects that meet the criteria of effectiveness and necessity or other considerations (cf sections 2.1ff). Of these projects, moreover, only those are confirmed that show them- selves to be robust in relation to changed framework conditions – after all, there is always some uncertainty involved in forecasting future developments. That said, measures not eligible for confirmation at present may well be regarded in the coming years as effective and necessary on account of changed framework con- ditions.
As a first step, the Bundesnetzagentur revisits all the measures in the Federal Requirements Plan Act to see whether they are still eligible for confirmation. Only then are remaining sources of congestion that oc- curred frequently in all the scenarios identified in the next step and the measures for their removal pro- posed by the TSOs studied.
The start of the consultation does not mean that the Bundesnetzagentur has completed its examination. It will continue its calculations and accompanying as- sessments while carefully examining and taking ac- count of all relevant contributions from the consulta- tion. The same applies to the insights from the exter- nal expert opinion on the NDP 2019-2030 commis- sioned from the IAEW institute of RWTH Aachen University.
Examination of the measures a. Effectiveness
b. Necessity
2.1 Effectiveness
The criterion of effectiveness establishes whether a measure is needed in order to maintain security of operation in the modelled situation for the network of 2030. Studied therefore is the extent to which se- cure network operation is possible with, and with- out, this measure. To this end, in a model of the grid, the measure is first taken out or deactivated and the grid analysed. Subsequently the same analysis is carried out, this time with the measure considered.
Both outcomes are then examined for prohibited operating states and overload. If it is established that the measure under scrutiny can reduce, or even completely remove, the number of cases of overload and prohibited operating states, it is judged effec- tive. In line with the planning principles it suffices if the avoidance of overload occurs only in one partic- ular instance of use, in other words solely in one hour in the year.
Additionally, there are measures whose effectiveness may result solely from other considerations. In these cases other indicators are consulted for an assessment.
Thus some projects are justified only through the re- moval of overload at the underlying network levels.
To test the effectiveness of these measures the data for the underlying 110 kV networks are examined.
Expansion of the transmission network can possibly avoid large-scale expansion in the underlying net- work so that expansion only of the underlying net- work is not a feasible option.
In the case of transboundary measures, the so-called interconnectors, their transboundary benefit is ana- lysed. For this, analyses by the TSOs of the Europe- wide Ten Year Network Development Plan (TYNDP) are consulted in addition to external expert opinions.
These analyses show the specific benefits and place the measures and their advantages in the European context.
2.1 Necessity
The Bundesnetzagentur, in examining how necessary a measure is, goes beyond the TSOs' planning criteria.
In light of the existing imponderables a study of effec- tiveness is not enough to uphold proportionality and to comply with the Bundesnetzagentur's mandate of creating a sufficient basis for parliamentary confirma- tion of the need for expansion in the form of a law.
The measures for which confirmation is required must therefore be sufficiently robust as well, that is
to say they must generate sufficient benefit even under the most diverse conditions.
Yet the capacity limits should not be set too high so as to be able to respond in the event of failure in later operation to operational shutdowns or other events. Ultimately, an indicator of robustness for the utilisation of a line in the range of 20% seems suitable. But this degree of utilisation indicates a borderline because below 20% utilisation, tech- nically speaking, a 110 kV line could also come under con- sideration for handling the transport requirements.
3. Preliminary assessment results
The TSOs have proposed 179 measures for expansion of the transmission network. Of these, the Bundes- netzagentur considers 96 to be eligible for confirma- tion. Current assessments indicate that the projects already listed in the Federal Requirements Plan Act of 2013 are as important as before, even assuming a renewables proportion of 65% in 2030 and a complete phase-out of coal by 2038.
In the NDP 2019-2030, the TSOs have proposed that additional high-voltage direct current (HVDC) corri- dors be constructed in the period up to 2030.
The Bundesnetzagentur approved the direct current projects DC1 to DC5 as effective and necessary in the previous procedures. HVDC measures are subject to more stringent requirements in the approval proce- dure than alternating current (AC) projects primarily because of their length and cost. The construction of an HVDC line should be considered if considerable transregional congestion occurs that can no longer be remedied efficiently by individual AC projects. Since an HVDC line can transmit a large amount of power over long distances, construction of a line makes it possible to reduce the transmission requirements in the AC network. The Bundesnetzagentur has there- fore decided in the current procedure to first consider whether further HVDC projects are necessary before carrying out the iterative examination. Building on this, it is then possible to identify the locations at which additional local AC measures are needed.
The technical examination of the ad hoc measures proposed in the NDP 2019-2030, the examination of the point measures and the examination of the pro- posed load flow management facilities (eg phase shifting transformers) are still ongoing.
Table 2: NDP 2019-2030 statistics Kilometre overview
NDP 2019-2030 (reference year 2030)
Currently eli- gible for con- firmation
Currently not eligible for con- firmation
For comparison:
federal require- ments plan
AC new build 500 km 350 km 150 km 250 km
DC new build 3,300 km 2,850 km 450 km 2,150 km
DC interconnectors 300 km 250 km 50 km -
AC reinforcement 5,800 km 3,700 km 2,100 km 1,600 km
AC/DC conversion 300 km 300 km - 300 km
By now in the start network:
1,600 km
Total 10,200 km 7,450 km 2,750 km 5,900 km
Number of measures
(incl. network point and ad hoc measures)
Total Currently eli-
gible for con- firmation
Currently not eligible for confirmation NDP 2019-2030
(reference year 2030) 164 96 68
Total 40 40 -
Table 3: List of measures eligible for confirmation
Project Measure Grid connection points Type
DC1 DC1 Emden/east – Osterath Line
DC2 DC2 Osterath – Philippsburg Line
DC3 DC3 Brunsbüttel – Großgartach Line
DC4 DC4 Wilster – Bergrheinfeld Line
DC5 DC5 Wolmirstedt – Isar Line
DC21 DC21a Heide/west – Wilhelmshaven 2 Line
DC21 DC21b Wilhelmshaven 2 – Uentrop Line
DC25 DC25 Wilhelmshaven 2 – Polsum Line
P20 M69 Emden/east – Halbemond Line
P21 M51a Conneforde – Cloppenburg 1 rural district – Cloppenburg 2 rural district
Line
P21 M51b Cloppenburg 2 rural district – Merzen/Neuenkirchen Line
P22 M80 Elsfleth/west – Ganderkesee Line
P22 M82 Conneforde – Unterweser/west Line
P22 M87 Unterweser/west – Elsfleth/west Line
P23 M20 Dollern – Elsfleth/west Line
P24 M71b Dollern – Sottrum Line
P24 M72 Sottrum – Mehringen Line
P24 M73 Mehringen – Landesbergen Line
P25 M45 Klixbüll/south – German border (DK) Line
P26 M432 Brunsbüttel – Büttel Line
P26 M76 Büttel – Wilster/west Line
P26 M89 Wilster/west – Dollern Line
P33 M24a Wolmirstedt – Helmstedt – Hattorf – Wahle Line
P33 M24b Wolmirstedt – Helmstedt – Gleidingen/Hallendorf – Mehrum/north
Line
P37 M25a Vieselbach – Thuringia/Hesse federal state border Line P37 M25b Thuringia/Hesse federal state border – Mecklar Line
P39 M29 Röhrsdorf – Weida – Remptendorf Line
P43 M74a Mecklar – Dipperz Line
P43 M74b Dipperz – Bergrheinfeld Line
P44 M28a Schalkau – Thuringia/Bavaria federal state border Line P44 M28b Thuringia/Bavaria federal state border – Grafenrheinfeld Line
P47 M31 Weinheim – Daxlanden Line
P47 M32 Weinheim – G380 Line
P47 M33 G380 – Altlußheim Line
P47 M34 Altlußheim – Daxlanden Line
P47 M60 Urberach – Pfungstadt – Weinheim Line
Table 3: List of measures eligible for confirmation
P48 M38a Grafenrheinfeld – Kupferzell Line
P48 M39 Kupferzell – Großgartach Line
P53 M54 Raitersaich – Ludersheim Line
P53 M350 Ludersheim – Sittling – Altheim Line
P72 M351 Lübeck – Göhl Line
P72 M49 Lübeck – Siems Line
P72 M50 Segeberg district – Lübeck Line
P84 M367 Hamburg/north – Hamburg/east Line
P84 M368 Hamburg/east – Krümmel Line
P112 M201 Pleinting – German border (AT) Line
P112 M212 Branch Pirach Line
P113 M202a Krümmel – Lüneburg – Stadorf Line
P113 M203 Stadorf – Wahle Line
P113 M519 Stadorf/Wahle Plant
P116 M206 Dollern – point Landesbergen Line
P116 M494 Point Landesbergen – Ovenstädt Line
P118 M207 Borken – Mecklar Line
P124 M209b Klostermansfeld – Schraplau/Obhausen – Lauchstädt Line
P133 M253 Borken – Gießen/north Line
P135 M255 Bechterdissen – Ovenstädt Line
P150 M352a Schraplau/Obhausen – Wolkramshausen Line
P150 M463 Wolkramshausen – Vieselbach Line
P151 M353 Borken – Twistetal Line
P161 M91 Großkrotzenburg – Urberach Line
P170 M380 Uchtelfangen — Ensdorf — German border (FR) Line
P175 M385 Wilhelmshaven 2 – Fedderwarden Line
P175 M466 Wilhelmshaven 2 – Conneforde Line
P176 M387 Eichstetten – German border (FR) Line
P180 M406 Marzahn – Friedrichshain – Mitte – Charlottenburg – Reuter – Teufelsbruch
Line
P185 M420 Redwitz – Bavaria/Thuringia fed state border (point Tschirn) Line
P211 M434 Gießen/north – Karben Line
P221 M460 Güstrow – southern Sweden (Hansa PowerBridge) Line
P222 M461 Oberbachern – Ottenhofen Line
P228 M469a Landesbergen – Mehrum/north Line
P310 M485 Bürstadt – Kühmoos Line
P315 M491 Hanekenfähr – Gronau Line
P327 M522 Load flow management measure in the Ruhrgebiet Plant
Table 3: List of measures eligible for confirmation
P328 M534 Fedderwarden – UK Line
P345 M556 Load flow management measure in Hamburg/east Plant P346 M557 Load flow management measure in Hanekenfähr Plant P347 M558 Load flow management measure in Oberzier Plant
P348 M559 Load flow management measure in Wilster Plant
P349 M560 Load flow management measure in Würgau Plant
P350 M561 Load flow management measure in Pulverdingen Plant P353 M532 Load flow management measure in Twistetal Plant
P357 M566 Load flow management measure in Güstrow Plant
P359 M571 Osterburg – Stendal/west – Wolmirstedt Line
P403 M603 Hattingen – Linde Line
P406 M606 Aach – Bofferdange Line
P410 M624 Load flow management measure in Enniger Plant
P426 M645 Load flow management measure in Philippsburg Plant
P450 M675 Hamburg/north – Hamburg/east Line
P450 M676 Hamburg/south – Dollern Line
P450 M677 Hamburg/east – Hamburg/south Line
P450 M678 Siedenbrünzow – Stendal/west – Güstrow – Putlitz – Per- leberg
Line
P450 M679 Wolmirstedt – Lauchstädt – Klostermansfeld Line
P450 M680 Streumen – Röhrsdorf Line
P450 M681 Graustein – Bärwalde Line
P450 M682 Stendal/west – Wolmirstedt Line
P450 M683 Ragow – Streumen Line
Table 4: List of measures not eligible for confirmation
Project Measure Grid connection points Type
DC23 DC23 Uentrop – Altbach Line
P47a M64 Kriftel – Farbwerke Höchst-Süd Line
P48 M38b Point Rittershausen – Stalldorf – Kupferzell Line
P50 M41 Oberjettingen – Engstlatt Line
P50 M366 Pulverdingen – Oberjettingen Line
P52 M59 Herbertingen – Tiengen Line
P74 M96 Vöhringen – point German border (AT) Line
P124 M209a Wolmirstedt – Klostermansfeld Line
P150 M352b 380 kV series compensation Wolkramshausen Plant P150 M352TR2 Grid couplers Querfurt and Wolkramshausen Plant
P153 M355 Alfstedt Plant
P159 M62 Bürstadt – BASF Line
P200 M425 Hambach Line
P203 M429 380 kV conversion Amelsbüren and restructuring Walstedde Line
P204 M430 Tiengen – Beznau Line
P215 M454 Güstrow – Bentwisch –search area Sanitz/Dettmannsdorf municipali-
ties Line
P215 M521TR1 Transformers in search area Sanitz/Dettmannsdorf municipalities Plant P216 M455 Güstrow – Siedenbrünzow – Alt Tellin – Iven Line
P216 M523 Iven – Pasewalk/north – Pasewalk Line
P216 M584 Transformer Iven Plant
P223 M462a Güstrow – Wessin – Görries – Görries – Klein Rogahn – Krüm- mel
Line
P223 M462b Double circuit connection Görries Line
P252 M504 Thyrow – Berlin/south-east Line
P252 M585 Berlin/south-east Plant
P304 M514 Kupferzell – Goldshöfe Line
P305 M515 Niederstotzingen – Dellmensingen Line
P306 M518 Großgartach – Pulverdingen Line
P311 M486 Weißenthurm – Bürstadt Line
P312 M487 Westerkappeln – Wettringen Line
P313 M488 Second interconnector Germany – Belgium Line
P314 M489 Load flow management measure in the Saarland Plant
P320 M497 Oberzier – Dahlem Line
P324 M512 Witten – Hattingen Line
P325 M520 Dahlem – Niederstedem Line
P333 M553 Eichstetten – Kühmoos Line
P333 M554 Eichstetten – Schwörstadt Line
Table 4: List of measures not eligible for confirmation
P333 M555 Schwörstadt – Kühmoos Line
P352 M531 Load flow management measure in Grohnde Plant
P354 M533 Load flow management measure in Wahle Line
P355 M599 Neuenhagen – Eisenhüttenstadt – Preilack Line
P358 M567 380/220 kV transformers in Lauchstädt, Eula and Weida Plant
P358 M570 Weida – Herlasgrün Line
P359 M582a Osterburg Plant
P359 M582b Connection Osterburg Line
P361 M470a Connection Großschwabhausen Line
P361 M470c Plant Großschwabhausen Plant
P362 M452b Delitzsch Plant
P362 M452c Connection Delitzsch Line
P363 M449 New substation Grabowhöfe Plant
P363 M581 New substation search area Landsberg town Plant P365 M583 Grid boosters at Audorf/south and Ottenhofen Plant
P401 M601 Arpe – Dauersberg Line
P402 M602 Westerkappeln – Gersteinwerk Line
P404 M604 Gersteinwerk – Unna – Wambel Line
P405 M605 Büscherhof – Walsum – Uerdingen Line
P408 M620 Point Günnigfeld – point Wanne Line
P408 M621 Eiberg – Bochum Line
P408 M622 Bochum – Hattingen Line
P409 M623 Limburg – Kriftel Line
P411 M625 Grid boosters at Wehrendorf and Hoheneck Plant P413 M596 Double circuit connection Klostermansfeld Line
P414 M414 hybridge electrolysis Plant
P420 M630 Point Reicheneck – point Rommelsbach Line
P423 M641 Gurtweil – Beuren Line
P423 M642 Connection Engstlatt – Kühmoos – Villingen in Gurtweil Line
P424 M644 Grünkraut – Herbertingen Line
P425 M640 Point Hüfingen Trossingen – Beuren Line
P427 M646 Grid booster at Kupferzell Plant
Figure 2
B Evaluation of offshore transmission links
1. Methodology
The NDP 2019-2030 is the first NDP to include the planning for offshore transmission links, replacing the previous offshore NDP. This planning is based on the provisions of the site development plan, which determines the order in which sites are to be auc- tioned for offshore wind farms as well as the years in which the transmission links need to go into opera- tion for the sites to be connected on time. On the basis of these provisions, the NDP defines the necessary offshore transmission links including the commis- sioning years and onshore grid connection points.
The assessment of the offshore measures is different from that of the onshore measures. It specifies a con- nection plan for generating units whose electrical en- ergy needs to be transported to land. This gives rise to a plan for the schedule for when offshore wind energy generated in Germany's coastal regions should start being fed in to which locations. Since the energy generated offshore is not consumed there – in the sense of the uptake of electricity – almost 100% of it has to be transported to land.
The NDP must include all measures necessary for the expansion of offshore transmission links in line with demand, including the timing for the planned com- pletion and the onshore grid connection points.
2. Assessment
The offshore transmission links are assessed with ref- erence to the steps listed below:
The input parameters and each stage of the assess- ment are presented below.
2.1 Consideration of the scenario framework
The transmission system operators (TSOs) have taken the generating capacity from offshore wind energy from the approved scenario framework 2019-2030.
They have divided the total generating capacity from offshore wind energy for the scenarios underlying the assessment as follows: for Scenario A 2030, 17.8 GW in the North Sea and 2.2 GW in the Baltic Sea, for Sce- narios B and C 2030, 14.8 GW in the North Sea and 2.2 GW in the Baltic Sea.
2.2 Consideration of the offshore fed- eral sectoral plans
When determining the expansion requirements for offshore transmission links in the draft NDP, the TSOs must take as a basis the site development plan.
The following data from the site development plan are particularly relevant for the assessment of the NDP:
•areas (formerly called clusters) and sites within the areas for the auction of offshore wind energy, the time sequence in which these sites are to be auc- tioned and the probable generating capacity to be installed at the sites,
•the calendar years in which the accepted offshore wind farms and the respective offshore transmis- sion links at the specified sites are to be taken into operation,
•border corridors where the offshore transmission links cross the border between the Exclusive Eco- nomic Zone and coastal waters,
•standardised technical and planning principles,
•test fields for pilot wind installations, the calendar years in which the pilot wind installations and test field transmission link are to be taken into opera- tion on the test fields for the first time and the ca- pacity of the test field transmission link.
Regarding the development pathway for offshore wind energy, the site development plan takes the existing provisions of the Offshore Wind Energy Act (WindSeeG) as its legal basis. By contrast, the Assessment of the transmission links
1. Expansion requirements 2. Order of implementation and
planned completion date of transmission links
3. Test field link
4. Grid connection points
5. Consistency of onshore expansion
man government's target of raising the proportion of renewable energy to 65% of gross electricity con- sumption by 2030, which is not yet laid down in law.
Nevertheless, for information purposes the annex of the site development plan presents a development corresponding to Scenarios A 2030, B 2030 and C 2030 as well as sites that will be available for auction af- ter 2030.
2.3 Need for expansion
The need for expansion is basically identified using the requirements of the site development plan with respect to the areas and sites that are to be auctioned, the probable generating capacity to be installed at the specified sites and the transmission capacity of the transmission links. In other words, if the site de- velopment plan contains sites that are not already connected with a transmission link, there will be an expansion requirement in the NDP. How many transmission links are necessary is calculated by comparing the size of the area to be connected and the transmission capacity of the transmission link.
For example, according to the site development plan, in area N-6 in the North Sea there are two sites to be auctioned, N-6.6 and N-6.7, with a probable generat- ing capacity to be installed of 900 MW in total. There are no other unconnected sites in the area. Therefore the sites must be connected using a transmission link with a transmission capacity of 900 MW. This would be the transmission link NOR-6-3 (the two existing transmission links, NOR-6-1 and NOR-6-2, are al- ready in use by existing wind farms).
The site development plan is based on the annual development pathway for the years 2026 to 2030, which is binding pursuant to the WindSeeG, leading to an expected expansion of offshore wind energy of 15 GW by 2030. Meanwhile, the scenario frame- work 2019-2030 is based on a greater expansion of offshore wind energy to implement the 65% target by 2030. Moreover, Scenario C 2038* is taken into consideration in the assessment of onshore measures for 2030 to take account of the upcoming phase-out of electricity produced from coal. This assumes an expansion of 26.9 GW of offshore wind energy.
by 2030 to implement the offshore development pathways of the scenario framework, including the commissioning years of the transmission links re- quired, are provided in the annex of the site devel- opment plan for information purposes. The sites that would potentially be available for further ex- pansion of offshore wind energy after 2030 are also provided for information. It is further possible to use this base to identify the additional transmission links that would be necessary to achieve the off- shore development pathways given in the scenario framework. According to the Bundesnetzagentur's current assessment, these transmission links can be confirmed subject to the proviso that a future up- date of the site development plan makes binding the sites currently only given for information purposes in the annex of the current site development plan. A legal basis has to be created, both for the implemen- tation of the offshore development pathways of the scenario framework and for the sites to be connect- ed after 2030. If this does not happen in the near fu- ture, completing the additional transmission links and conducting the preliminary study and auction for the additional sites on time seems unrealistic.
2.4 Order of implementation and planned completion date of transmis- sion links
The planned completion schedule for the transmis- sion links is drawn up using the requirements of the site development plan regarding the order of the de- fined sites and the commissioning years of the trans- mission links necessary to connect the sites. This au- tomatically results in the order of implementation of all necessary transmission links.
For example, the site development plan specifies that the transmission links to connect sites N-6.6 and N- 6.7 in area N-6 have to be taken into operation in 2029. Therefore, the planned completion date of 2029 would have to be given as the commissioning year for the necessary transmission link NOR-6-3 in the site development plan.
2.5 Test field link
According to the site development plan, an area in the coastal waters off Mecklenburg-Western Pomerania is to be designated as a test field for pilot wind energy installations. The calendar year given for the expected commissioning of the transmission link to connect the test field (test field link) is 2024. The transmission ca- pacity of the link is given as 300 MW.
The OST-7-1 transmission link proposed in the sec- ond draft of the NDP 2019-2030, which has a trans- mission capacity of 300 MW, was originally intended to connect a site for commercial wind farms in the same area but can now be used to connect a test field.
2.6 Grid connection points
The NDP further specifies the grid connection points necessary to integrate the offshore transmission links into the onshore grid. The TSOs give these points in the draft NDP. However, some transmission links might require alternative grid connection points, primarily because some of the points proposed by the TSOs are very far south, which would require an onshore line for the transmission link covering a great distance.
Consequently, the TSOs themselves do not expect that the relevant transmission links can be finished in time by 2030 or even earlier. It is therefore necessary to look at alternative grid connection points that are nearer to the coast in the rest of the procedure up to the confirmation of the NDP.
2.6.1 Consistency of onshore expansion
The expansion of the necessary transmission links must be compatible with the expansion of onshore measures, with particular interfaces being the grid connection points onshore. There is consistency be- tween onshore and offshore network expansion if the offshore generating capacity to be integrated can be transported onshore.
It is therefore necessary to synchronise the imple- mentation of the measures, i.e. if one or more on- shore measures are needed for a transmission link to be connected, the planned commissioning of the measures must match the planned completion of the transmission link.
At the moment, there is essentially consistency be- tween onshore and offshore expansion, but, depend- ing on the scenario, a few transmission links could be finished one or two years before the corresponding onshore measures. That does not mean that it would be completely impossible to feed in the electricity generated offshore, merely that there could be con- gestion management, and in particular a temporary restriction of the offshore wind energy, until the on- shore measures are finished.
3. Preliminary assessment results
The transmission links regarded as eligible for con- firmation (pending further findings) are shown in Figure 1 for the North Sea and Figure 2 for the Baltic Sea.
Figure 1: North Sea transmission links currently regarded as eligible for confirmation
Figure 2: Baltic Sea transmission links currently regarded as eligible for confirmation
Table 1: Offshore transmission links currently eligible for confirmation
Transmission link Planned completion date
Grid connection point Scenario A
2030
Scenario B/C 2030
Scenario C 2038*
OST-7-11 2024 2024 2024 Municipality of Papendorf
OST-1-4 2026 2026 2026 Municipalities of Lubmin/
Wusterhusen/Kemnitz
NOR-7-2 (BorWin6) 2027 2027 2027 Büttel
NOR-3-2 (DolWin4) 2028 2028 2028 Hanekenfähr
NOR-6-3 (BorWin4) 2029 2029 2029 Hanekenfähr
NOR-9-1 (BalWin 1) 2028 2029 2029 Wilhelmshaven 2 (or
Unterweser)
NOR-9-2² (BalWin 2) 2029 2030 2030 Heide/West (or
Unterweser)
NOR-10-1² (BalWin 4) 2030 2030 2030 Wilhelmshaven 2 (or
Unterweser)
NOR-12-1² (LanWin 1) 2030 - after 2030 Unterweser (or Wilhelmshaven 2)
NOR-11-1² (LanWin 3) - - after 2030 Westerkappeln
NOR-11-2² (LanWin 4) - - after 2030 Wehrendorf
NOR-13-1² - - after 2030 Halbemond
1 Test field link
2 Eligible for confirmation subject to the proviso that a future update of the site development plan includes the sites to be connected
port: strategic environmental assessment based on the second draft of the electricity NDP
Background
A key part of establishing requirements is to identify, describe and evaluate the likely significant environ- mental impact caused by the grid expansion. This is the purpose of the strategic environmental assess- ment (SEA). This year's procedure focuses on estab- lishing requirements for the target years 2019 to 2030.
The results of the SEA are documented in the current environmental report, for which there is also a con- sultation involving both authorities and the general public.
What does the SEA include?
What is the function of the SEA?
Environmental assessments are intended to ensure that, prior to or during the implementation of spe- cific projects, plans and programs – such as those pertaining to network expansion in the context of the energy transition – possible effects on the envi- ronment, including people, are taken into account.
An SEA starts at the planning level and not when the implementation of individual projects has al- ready begun. Potential effects resulting from the expansion of the extra-high voltage transmission network should be identified while preparing the federal requirements plan. The SEA therefore acts as an early warning system.
Are alternatives examined?
Alternatives must be considered in an SEA in order to effectively protect the environment. However, on- ly "reasonable" alternatives will be reviewed – mean- ing they are feasible at a reasonable cost and largely support the achievement of the plan's objectives.
Which alternative is ultimately included in the fed- eral requirements plan also depends on other as- pects, such as the technical feasibility and economic efficiency.
assessment. As part of the approval of the federal re- quirements plan, legislators are required to consider all relevant aspects in combination and comparison with each other.
What is the environmental report?
The environmental report uses text and graphics to show the potential environmental impact of the net- work expansion identified and evaluated in the SEA.
Only potentially significant, that is, severe, environ- mental impacts on "protected assets" were assessed.
These protected assets are specified in the law pertain- ing to the Environmental Impact Assessment Act (UVPG) as:
•people, including human health,
•fauna, flora and biodiversity,
•land, soil, water, air, climatic factors and landscape,
•cultural heritage and other material assets,
•interactions between the above protected as- sets.
What has changed in comparison to the last environmental report?
A far-reaching overhaul of the SEA methodology for this round of establishing requirements was started at the beginning of 2018 with expert support provided by a consortium led by Bosch & Partner GmbH.
•Changes have been made to the construction of the assessment areas, the method for evaluating environmental impact, the comparison of alterna- tives and the survey of the overall plan, among other things.
•The expansion form notified by the TSOs is taken into account in the identification, description and evaluation of environmental effects to form a more realistic forecast of the likely significant environ- mental impact. Moreover, environmental problems and other impacts previously identified are includ- ed in the assessment.
•Some more categories of site were included than in the previous environmental report to reflect the en- vironmental objectives.
•Moreover, the protected asset "land" has been inte- grated into the analysis. The revised methodology also allows interactions between protected assets to be identified and evaluated.
The particular framework conditions of an SEA at an abstract planning level had to be taken into account for all changes.
The methodological changes were triggered by the rising expectations of members of the public and ex- perts as regards weighing up the advantages and disadvantages of alternatives and taking better ac- count of the form of expansion. The intention of the revised methodology is to be able to compare the likely significant environmental effects of alterna- tives in a systematic and reproducible way.
The methodology envisions a greater level of automa- tion in order to cope with the rising number of NDP measures that need to be examined and produce the environmental report within the statutory deadlines, including in future rounds. The time-consuming evalu- ation used previously has been replaced by a GIS- supported evaluation.
What has the Bundesnetzagentur exam- ined for the environmental report?
The likely development of the energy industry as a basis of the network development planning in the electricity NDP is laid down in the scenario frame- work using certain assumptions (including propor- tions of fossil and renewable energies, increase of photovoltaic installations and onshore and offshore wind turbines, and annual consumption). The scenar- io framework approved by the Bundesnetzagentur for the NDP 2019-2030 sets out a conservative scenario (A 2030), a transformation scenario (B 2030) and an innovation scenario (C 2030).
The subject-matter of this year's SEA is as follows:
assessment of a total of 117 measures (106 on- shore and 11 offshore measures).
Additionally, the following alternatives were exam- ined:
Scenarios A 2030, B 2030 and C 2030 as alternative overallplans,
22 project-specific alternatives.
"Start network measures" are not examined, since these have either been implemented already, are in an ongoing planning approval procedure or their necessity has already been determined by law.
"Point measures" such as substations are not looked at either. Point measures are not part of the federal requirements plan and are therefore not the subject matter of the SEA and the environmental report.
Offshore projects located in the Exclusive Econom- ic Zone of the North and Baltic Seas and originally part of the offshore NDP now undergo an SEA as part of the drawing up of the site development plan.
Methodology: how does the Bundes- netzagentur go about the environmental report?
The focus of the SEA is to examine where, and to what extent, potential environmental effects are likely and how far they are to be viewed as significant.
In previous years, the methodology for the SEA for the federal requirements plan was largely kept the same, with only some minor adjustments. However, in the current round of establishing requirements it has been thoroughly overhauled. The background to this is factors including the improvement of the in- clusion of previous impacts, the appropriate consid- eration of the expansion form (and thus also the NOVA principle) and the further development of the comparison of alternatives.
Changes have been made to:
•the construction of the assessment areas,
•the identification, description and evaluation of the likely significant environmental impact,
•the reflection of environmental objectives in (ad- ditional) site categories,
•the more appropriate consideration of the planned expansion forms (NOVA),
•the consideration of the existing im- pacts/environmental problems in the assess- ment area,
•the survey of the overall plan and the comparison of alternatives.
The Bundesnetzagentur's methodology for identify- ing, describing and evaluating the likely significant environmental impact comprises the establishing of a
Figure 2: Methodology step 2
Figure 3: Methodology step 3
Figure 4: Methodology step 4
Figure 5: Methodology step 5
basis (steps 1-5) and the subsequent derivation of results (steps 6-8). A more detailed explanation of the improved methodology may be found in sec- tion 3. The individual methodological steps are outlined in brief below.
Step 1: identification of impact fac- tors and environmental objectives (see section 3.4.1)
The appraisal of possible effects on the UVPG protect- ed assets is based on knowledge about the type and intensity of effects of the different types of implemen- tation of the grid expansion (overhead lines, under- ground cables, submarine cables). These "impact fac- tors" are first described in an abstract manner, without reference to location but with reference to individual protected assets. For example, the general effects of an overhead line on the protected asset "landscape" is considered, such as the spoiling of views (more details on impact factors may be found in section 4).
A further basis for the assessment of potential envi- ronmental impact is applicable environmental objec- tives, from which the significance of the affected envi- ronment may be derived (more details on environ- mental objectives may be found in section 5).
Step 2: selection of site categories and identification of potential conflicts (see section 3.4.2)
Knowledge of the environmental characteristics of the area is needed to assess the likely significant en- vironmental impact. Site categories, such as nature conservation areas, are used to indicate spatial char- acteristics at the abstract planning level of the federal requirements plan, which evaluates the whole coun- try. The site categories are based on national stand- ardised and site-related data and are derived from the impact factors of the grid expansion and envi- ronmental objectives. Potential conflicts that could arise between the environmental objectives and the impact factors relevant to the respective site catego- ries are identified for the environmental assessment.
One site category can stand in for several potential conflicts, because it usually reflects several relevant spatial and environmental characteristics. For exam- ple, for overhead line measures, the site category
"FFH areas" might include bird collisions with power lines or changes to groundwater resources as poten- tial conflicts. "Sites with limited availability" are also taken into account across site categories. For these areas, it can already be seen at the federal require- ments planning level that there is likely to be no or
limited usage for power line construction.
Step 3: assessment of potential con- flicts (see section 3.4.3)
A conflict risk is determined for each potential con- flict in a site category. To do this, each potential conflict is given one of three possible ratings using the following parameters:
•Sensitivity: estimate of the extent of reaction of en- vironmental characteristics to the effects of types of implementation (overhead lines, underground ca- bles, submarine cables).
Ratings: the characteristics reflected in the site category are of low, medium or high sensitivity to the impact factors of the type of implementa- tion.
•Significance: reflection of the legal and social value of the site category.
Ratings: The values associated with the site category can be overcome taking into account low, medium or high requirements.
•Accuracy: representation of the suitability of a site category for the assessment of a potential conflict.
Ratings: the site category reflects the spatial and en- vironmental characteristics and the related conflicts in a way that is: very inaccurate (+), not very clear and accurate (++) or very clear and accurate (+++).
The parameters are assessed independently. The indi- vidual ratings of the parameters "sensitivity" and
"significance" are then merged into a conflict risk for each potential conflict using a matrix. The conflict risk can be lowered (++) or raised (+++) by one level ac- cording to the accuracy. If the accuracy is low (+), the conflict in question is not further included. The con- flict risk is categorised into one of four conflict risk classes: "low", "medium", "high" and "very high".
The assessment of the conflict risk of the site catego- ries is carried out separately for each type of imple- mentation and may be found in the assessment tables of the site categories in the annex to the environmen- tal report.
Step 4: derivation of the conflict risk for the site categories (see section 3.4.4)
The individual ratings of the conflict risks of all po- tential conflicts in a site category are merged into a conflict risk encompassing all protected assets per site category. The deciding factor for the conflict risk class of the site category is always the highest conflict risk for any potential conflict. For example, if there is a po- tential conflict (1) with a medium rating and a poten- tial conflict (2) with a high rating, the conflict risk class for the site category will be "high". As well as the conflict risk that covers all protected assets, a conflict risk per protected asset can also be identified.
To do this, all potential conflicts in the site category that can be assigned to the same protected asset are also merged according to the principle of the highest rating. The conflict risks are converted into conflict risk points (1 = low to 4 = very high).
Because site categories often reflect individual protected assets particularly well, the related conflict risk is particularly relevant for assessing the interaction between the protected assets.
Each site category is therefore assigned a main protected asset, which can be seen in annexes 1- 3.
Step 5: forming assessment areas for the measures (see section 3.4.5)
Exactly where lines and routes will run is not deter- mined at the level of the federal requirements plan.
Only the grid connection points that have to be joined up are decided on. The straight line between the grid connection points is surrounded by a buffer to help delineate the assessment areas for new con- struction measures. This is designed in the ratio of length to width 2.5:1. For reinforcement measures, a corresponding buffer is put around the line to be re- inforced that is mentioned in the NDP. The standard- ised construction of the assessment areas is intended to prevent the assessment area having an influence when comparing different types of implementation and forms of expansion. The areas behind each grid connection point, which are also taken into account, are calculated by forming a circle around the mid- point of the straight line or, in the case of deviating lines to be reinforced, around an auxiliary point.
They are capped at a maximum 5 km.
Particular designs of the grid connection points re- quire the assessment area to be adjusted. This applies to:
•measures with supports and/or search areas,
•measures whose assessment area touches a na- tional border and
• offshore transmission links.
The basic principle is, however, always followed as far as possible.
The transboundary environmental effects are not taken into consideration at this level, but the Bundesnetzagentur will notify the potentially affect- ed neighbouring countries of the processes in which requirements are established, that is to say the ener- gy-related examination of the NDP, and of the SEA.
Step 6: survey of measures (see section 3.5)
The survey of measures encompasses the analysis of the actual state of the environment using the site categories and the identification and evalua- tion of the likely significant environmental impact.
The evaluations of the measures are presented in factsheets that contain general information such as location, size of the assessment area etc and doc- ument the evaluation result of the measures in- cluding any partial evaluations undertaken.
The survey of measures is carried out both for each protected asset and across protected assets. For the evaluation of the likely environmental impact across assets, the site categories in the assessment area are first laid over each other on a map. In 50m x 50m ras- ter cells, the highest individual value of the overlap- ping conflict risk points determines the conflict risk of the raster cell (highest rating principle). Interactions, existing impacts and expansion forms are then taken into account by adding and deducting conflict risk points. The consideration of interactions is explained in more detail in the subsection, "Consideration of the protected assets "land" and "interaction"” below.
Figure 6: Methodology step 6
Figure 7: Methodology step 7
Figure 8: Methodology step 8
The total conflict risk points per assessment area in combination with its size results in the first evalua- tion parameter: conflict risk density. The conflict risk density is classed as "below average", "average" or
"above average".
The second evaluation parameter is the expected length of the measure: for the lengths of new con- struction measures, which are "as the crow flies", a detour factor of 1.3 is applied to allow comparison with reinforcement measures. The lengths are divid- ed into three classes (short, medium, long).
Using the ordering of areas with the highest conflict risk, where applicable in conjunction with sites of limited availability, the assessment area is also ex- amined for possible obstacles that have to be crossed (known as "bars"), which form the third evaluation parameter. The rating reflects whether there is a bar (bar class 1 or 2) or not (bar class 0).
Matrices are applied to combine the three evaluation parameters and ultimately categorise the likely sig- nificant environmental impact of the measure in question: it can be seen whether the scale of likely significant environmental impact on the protected assets is expected to be very small, small, moderate, large or very large (label).
