Renewables in action: a German case study

A Dec 2018 case study of a two market events in Germany illustrate the rising importance of wind output uncertainty on power price dynamics.

January 14, 2019

The roll out of wind and solar capacity is transforming power markets across Europe.  If you want to understand the practical impacts of high renewable penetration, Germany is a great place to start.

Renewable generation output contributed about 38% of gross German electricity consumption in 2018.  The German market is particularly interesting because renewable production is dominated by intermittent sources:

  • Wind: 59GW of installed capacity (53GW onshore, 6GW offshore)
  • Solar: 45GW of installed capacity.

Wind and solar combined make up more than half of Germany’s 205GW of installed capacity, as well as dominating new capacity growth.

In today’s article we look at a Dec 2018 case study of swings in renewable output and their impact on German power prices.  This is an interesting ‘lab experiment’ for much bigger things to come next decade.

The behaviour of renewable intermittency

Perhaps the most important impact of rising intermittency is its effect in increasing market uncertainty.  Despite leaps forward in the ability to analyse weather data, it is difficult to predict wind & solar output tomorrow, let alone next month. The inherent uncertainty of renewable output is reshaping the risk/return profile of power assets.

Despite uncertainty, wind and solar output follow seasonal patterns that help define the range of output uncertainty.  For example, current German generation output distributions show that:

  • On sunny summer days solar output can reach nearly 30GW, but output rarely rises above 10GW in mid-winter.
  • Wind output can reach 45GW in winter but rarely breeches 30GW across the summer.

These numbers can be compared to annual peak demand around 84GW (gross).

Wind output is a much greater source of uncertainty than solar.  This is because wind speeds can ebb and flow substantially over the space of just several hours.  For more details see our article on analysis of quantifying wind and solar output distributions.

But fluctuations in wind and solar output are only half the story.  What is more important from a commercial perspective is the impact of these swings on market prices and plant load factors.  That is well illustrated via a recent German market case study.

A December 2018 case study

Chart 1 provides a summary of generation output (top panel), prices (middle panel) & cross border flows (bottom panel) in the German power market across the first half of Dec 2018.

Source: Fraunhofer ISE

Two events across this horizon illustrate some of the practical impacts of swings in renewable output.

Event 1: High wind output, low prices

The 8-9th of Dec was a relatively mild weekend. As a result, system demand was lower than average.  This set up an interesting combination of events:

  1. Wind output levels were very high across the weekend, above 44GW on 8th Dec (top panel)
  2. This drove both day-ahead and within-day prices below 10 €/MWh, with negative levels in some periods (middle panel)
  3. All flexible thermal generation units (gas, coal & lignite) were forced down to minimum output, with nuclear units providing marginal flexibility (top panel)
  4. Germany exported large volumes of low priced surplus power into neighbouring markets such as Austria, Switzerland, Denmark, Czech Republic & the Netherlands (bottom panel).

Event 2: Low wind output, higher prices

Several days later, on Fri 14th Dec the situation had flipped. Being a weekday, German demand was higher, but there was also a cold snap in Scandinavia that saw Sweden & Denmark pulling on German exports:

  1. Wind output levels were low (5-6GW)
  2. Imports from Scandinavia rose towards 2GW (vs 2GW exports on 8-9th Dec)
  3. Day-ahead prices topped 90 €/MWh, with intraday prices above 175 €/MWh
  4. German coal, lignite and CCGTs were running at high load factors with more expensive peaking flex (e.g. gas peakers & pump storage) setting prices.

A lens into the future

Germany has set a 65% renewable target by 2030 (vs current 38%).  Whether or not it achieves this target, there are concrete steps being taken to roll out substantial volumes of wind & solar capacity in the 2020s.  Many other markets in Europe are following suit.  Events like the two described in the case study above are set to become more frequent and larger as renewable penetration increases next decade.

Understanding the impact of renewable output uncertainty on power price dynamics is one of the key commercial challenges that the energy industry faces over the next 5 years. We will return in an article shortly that looks at how renewable uncertainty can be captured in power market modelling.

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