EcoGrid EU. The EcoGrid Price System in a Demand Response Perspective. Dok. 13/

Transcription

1 EcoGrid EU The EcoGrid Price System in a Demand Response Perspective 1

2 2

3 Content 1. Why Demand Response ENTSO-E Demand Response EU and regulatory frame ACER and CEER SEDC the European perspective UK perspective from Ofgem the British Regulator Demand Response lessons learned EPRI Demand Response in the USA Green Button Campaign Consumer engagement California PG&E framing Demand Response UK potentials for Demand Response Entelios Strong German engagement ebutler the Consumer perspective FlexPower Demand Response for balancing power % Peak Shaving The SEAS-NVE experience eflex Day-Ahead and dynamic grid tariffing ,000 MW Demand Response the Swedish way Norway market based Demand Response Address Active Demand that works Smart consumers in Salzburg CYBERGRID and OpenADR ICT platform for DR Ongoing Demand Response projects Grid4EU six demonstrators TotalFlex new market concepts for DR INCAP - Consumer preferences for DR and flexibility FINESCE Consumer friendly App solutions Other ongoing DR projects GreenCOM READY Nordic pilot project for 5 MW RPM DREAM VPP4SGR EcoSense ipower and FLECH EcoGrid EU Demand Response perspective The EcoGrid EU five minutes market Advantages of the EcoGrid EU market Future ideas for Demand Response DR in the existing market places Novel DR what is waiting to be demonstrated? Demand Response references List of reports and web links used for this survey Compilation of data, Mr Kim Behnke, August 2014 Energinet.dk Tonne Kjærsvej 65 DK-7000 Fredericia 3

4 1. Why Demand Response Historically, electricity has been generated from large power plants end transported to end consumers for demand. The power system needs to be in balance 50 times a second. To ensure high service for the electricity customer the primary focus has been on how to regulate the generation to an optimum. For generation capacity like hydro power or gas turbines this regulation to balance the power flow is achievable. Large thermal power plants and especially nuclear plants are preferable operated at full power. The demand side has been used for balancing the power system with different types of incentives where Time-of-Use is the most common. For the power system operators it is more cost efficient to pay the costumer for a changed demand than to regulate the thermal power plants. These kinds of Load Management, Demand side Management or Time-of- Use tariffs are used on a daily basis all over the world. In some power systems there are problems with adequacy. Either because the power system does not have enough power supply capacity to balance the demand or because the grid has limited capacity. To avoid Black Outs (not planned power failure) or Brown Outs (planned load shedding) many utilities have used different kind of demand reduction to help balancing the system. Illustration: Entelios AG The future trends are that power will be generated from a number of 1-10 MW sized units instead of 500-1,000 MW large power plants. Many small decentralized units like private solar (PV) units of 10 kw, small residential wind turbines of 25 kw or micro-chp of few kw capacities will be a growing part of the power systems capacity. These many small generation resources are renewable in the sense that they are able to achieve energy from wind, sun, ocean or geothermal. The predictability of a 1,000 MW nuclear power plant is being substituted with 500 wind turbines in an offshore farm depending on the changing weather in the next hours. The grid of the power system will be instable due to the fact that most of the new types of generation are based on inverter technology (DC/AC) and not classic synchronous generators. The power system will need ancillary services like inertia, short-circuit power, voltage control and frequency control to ensure a stable system with a high power quality. 4

5 Since the power system historically has been designed to transport electricity from large power plants connected at the HV level all the way down to end consumers at LV level, it is a growing challenge if the future power generation comes from many thousand distributed energy resources (DER) located in the LV grid. There will be multiple cases of congestion in the LV grid. Electricity is being traded at a power exchange. Supply and demand must meet at least every hour. Owners of thermal power plants or wind turbines have different market strategies. Thermal power plants need a market price to cover the marginal costs of the operation. Wind turbines have a marginal cost close to zero and owners would like to trade every MWh when the wind is expected to blow the next 24 hours. Outside the marketplace there are different and often highly complex subsidy schemes for different types of power generation that also have a secondary effect on the market. The market becomes more and more volatile. Volatility is not a bad thing. Many marketplaces reflect the ever changing supply and demand situations in the price. However, electricity is a rare commodity with little potential for storing at least without substantial losses. Demand Response must be seen in the change of paradigm for the power system. Demand Response is one of many tools to be integrated in the present and future development of the coherent power system. 1.1 ENTSO-E ENTSO-E (European Network Transmission System Operator for Electricity) is a forum where more than 40 European TSOs (Transmission System Operators) are organized. ENTSO-E has a mandate from the European Commission. ENTSO- E and its member TSOs are responsible for the balancing of the European power system and the massive integration of renewable electricity generation. Doc. ENTSO-E, Demand Side Response, Link Note Final version. ENTSO-E has recently published a report about how Demand Side Response (DSR) or Demand Response (DR) might engage the consumer side (load) of the balancing equation. Most European countries and power systems are looking into a future where Demand Response is going to be a welcome and necessary tool for balancing the system whether it is in the minute or in several hours. ENTSO-E has this definition of Demand Side Response (DSR) or Demand Response (DR). 5

6 Enabled intelligent and active electricity usage, which means that people can now play an active role in how and when they use electricity, resulting in benefits for them and the environment (more efficient electricity usage that facilitates the integration of renewable electricity sources into the system). This process is called demand side response (DSR). ENTSO-E believes. - Demand Side Response (DSR) is a key component in the successful evolution of the power system, from a conventional based generation system to one that has significant contributions from intermittent sources of generation and power intensive loads; - DSR creates value for consumers and society at large. DSR can be a cost-effective option to contribute affordable energy for consumers and the opportunity for rewarding customers for changing their consumption behavior; - DSR adoption needs to be broad and deep if EU 2030 and 2050 energy policy and decarburization targets are to be achieved; - DSR provides TSOs with flexibility to maintain security of supply, optimize the utilization of the infrastructure and investment of the grids, system adequacy and, in many cases it can be a competitive alternative to other tools such as generation; - DSR enhances competition and improves the target market model by providing a credible alternative to sources of power. To fully deploy and utilize DSR potential a paradigm shift in consumer attitude to using power is required; by placing consumer needs at the heart of the DSR evolution benefit from the value can be created. Recommendations - ENTSO-E should take the initiative in informing decision makers and stakeholders, not only on DSR technicalities and economics, but also for the broader debate on how to organize the roles concerning DSR within future electricity markets in Europe. This policy should keep in mind that TSOs are independent parties which have played a crucial role in executing the 3rd Package and maintaining total system balancing. - For the DSR-policy paper, all TSOs should undertake reasonable endeavors in facilitating deployment of DSR in their system and market operations. In order to do this, all TSOs will need to actively take the lead on engaging the market and aligning with policy makers at both the European and national level. - Finally, TSOs and DSOs shall collaborate and use reasonable endeavors to facilitate and enable the delivery of the DSR, with customer engagement into their networks and the markets in a transparent way and in accordance with applicable legislation, thereby avoiding negative adverse effects. ENTSO-E has been asked by the European Commission to host the huge task of ensuring Network Codes as a mean of European harmonization in the area of Demand Response the Network Code is called Demand Connection Code. The Network Code sets up a common framework for Network Connection Agreements between Network Operators and the Demand Facility Owner or Distribution Network Operator. 6

7 Doc. Link Note ENTSO-E Network Code on Demand Connection, Draft version. The Network Code defines a common set of requirements for Demand Facilities, Distribution Networks and Distribution Network Connections, both existing and new, which are significant according to the provisions of this Network Code. The Network Code sets up a common framework for Network Connection Agreements between Network Operators and the Demand Facility Owner or Distribution Network Operator. For the avoidance of doubt the requirements and conditions, contained within the articles for demand (excluding DSO networks) set out in the report is specified on the basis of a pure demand. In situations where generation and demand co exist in a Demand Facility or Closed Distribution Network, all demand requirements within this code will be evaluated on the basis that the generation is not present. The Power Generating Modules will have to comply with the requirements of the Network Code on Requirements for Grid Connection applicable to all Generators. In accordance with the Article 8(7) of Regulation (EC) N 714/2009, the Network Code shall not apply to the small isolated systems and in the micro isolated systems. 7

8 2. Demand Response EU and regulatory frame Demand Response is about consumer engagement in the balancing of the power system. Since both TSO and DSO are regulated businesses then it is highly relevant that the European regulatory institutions write guidelines for Demand Response. The aim is to ensure harmonized European guidelines for enhanced market participation and cross-border engagement. 2.1 ACER and CEER ACER (Agency for the Cooperation of Energy Regulators) operates within a mandate from the European Commission. Doc. Framework Guidelines on Electricity Balancing, Link Note ACER has a number of other reports about Smart Grid and Demand Response issues please look at the website. ACER has this definition of Demand Response. DR changes in electricity usage by end-use consumers from their normal load patterns in response to changes in electricity prices and/or incentive payments designed to adjust electricity usage, or in response to the acceptance of the consumer s bid, and through aggregation. The Network Code on Electricity Balancing shall require the harmonization of the pricing method for balancing energy products, which shall ensure an economically efficient use of demand response and other balancing resources subject to operational security limits and shall give correct price signals and incentives to market participants. However, if it can be demonstrated that social welfare is improved and that it does not hinder the participation of demand response, renewable and intermittent energy sources, then a TSO may be allowed to combine procurement and to accept additional bids linking upward and downward bids, subject to approval by its NRA (National Regulatory Agency). CEER (Council of European Energy Regulators) is the voice of Europe's national regulators of electricity and gas at EU and international level. Through CEER, a non-for-profit association, the national regulators cooperate and exchange best practice. A key objective of the CEER is to facilitate the creation of a single, competitive, efficient and sustainable EU internal energy market that works in the public interest. The object for CEER in deployment of DR is to incentivise the deployment by knowledge-sharing of best practice. 8

9 Doc. Link Note CEER Status Review on European Regulatory Approaches Enabling Smart Grid Solutions, ME CEER has a number of other reports about Smart Grid and Demand Response issues please look at the website. In the majority of countries, static Time-of-Use tariffs (71%) and load control through remote means (58%) are used to incentivise demand side response. Load control at premises is used to a lesser extent in 33% of the countries that responded to the survey. In France, DR operators will receive an additional payment that takes into account the benefits DR has provided. In Italy, load control is currently limited to very large industrial customers through remote means, while in the Netherlands, 95% of energy for balancing is provided through short-term activation (less than 15 minutes) with near real-time pricing. 2.2 SEDC the European perspective SEDC (Smart Energy Demand Coalition) is cooperation between wide ranges of energy industries and organizations aiming at deploying Demand Response all over Europe. SEDC has a mandate from the European Commission. Tracking Compliance with Article 15.8 of the Energy Efficiency Directive. Doc. Link Note A Demand Response Action Plan for Europe, major industries as executive members and 31 large organizations as associated members of SEDC. SEDC has an agenda of making it possible for electricity consumers (commercial and private) to participate with Demand Response. There is a need for changes and development of the European electricity market places especially to manage DR as an equal product to generation capacity. 9

10 The moderate scenario for the European (EU28) potentials for DR is to achieve 59 TWh energy savings, 30 megaton CO 2 reductions, 28 GW reductions in the need for new peak generation and 20 billion saved investments in grid reinforcements. The maturity of commercial DR in Europe by 2014 is as shown in the map below. In the six countries where DR is commercially deployed there is a 70-80% rate of success when resources are activated for DR. Lessons learned are that there are at least three barriers to be removed for successful DR deployment. - Permission for independent aggregators to make commercial agreements with all types of customers without approval from the BRP. - Aggregators must keep the BRP informed to avoid imbalances. - There must be a fair payment for DR to aggregators and customers from electricity vendors and BRP. Doc. Mapping Demand Response in Europe Today, April 2014 Link Note Mapping of DR activities in the following 15 European countries: Austria, Belgium, Denmark, Finland, France, Germany, Great Britain, Ireland, Italy, Netherlands, Norway, Poland, Spain, Sweden and Switzerland. The following charts provide an at-a-glance overview of the Member States analysis in 2014 and comparison with There is still a lot of work to do before DR is fully and commercially deployed in Europe! 10

11 The key below describes the criteria for this grading system. 11

12 2.3 UK perspective from Ofgem the British Regulator Ofgem, the British regulator for UK, has a strong focus on DR or DSR. Demand Side Response (DSR) is one of the priority reform areas of the program. DSR is likely to make an increasingly important contribution across the first three themes above. We recognize that the regulatory framework plays a key role in determining the use of DSR and this issue will be explored in a number of the projects within in Ofgem programs. Doc. Creating the right environment for demand side response, Link Note There are several reports about DR and DSR in the UK available from the Ofgem website. Ofgem's initial conclusion is that current arrangements do not meet three essential pre-conditions for the longer-term development of DSR: - Industry parties need to be confident that there is value for them in DSR which justifies the investment. - The value of offering different DSR services needs to be communicated effectively to customers. - Customers need to be aware of the opportunities to provide DSR, and be able to readily access information on options and able to act. DSR is a term encompassing many types of change in energy consumption. These changes can lower electricity costs in many ways, so the value they can provide is divided between various uses for different parties in the disaggregated supply chain. Ofgem has identified three challenges that will need to be addressed as a matter of priority. These challenges could dictate the pace of market development, whereas the other challenges we identify will generally materialize, once further market development takes place. They focus on improving incentives for industry parties to use DSR and on ensuring that regulatory and commercial arrangements complement these incentives to deliver the required investment. 12

13 - Revealing the value of DSR across the system. The right incentives for parties across the supply chain to use DSR can encourage them to use it when it is cost-effective to do so, even today. Ofgem is already taking steps to improve incentives for DSR, including with our EBSCR and Smarter Markets work on settlement reform. - Making DSR more secure, so that industry parties can be confident they can recoup investment needed to deliver DSR. We have identified constraints in current arrangements, suggesting that further work needs to done to examine how these investments can be supported. For example, further work could explore whether monitoring and verification arrangements can make revenue streams from demand side response more secure improving its investment potential. - Improving signals to customers. Customers will not provide DSR unless signals communicate its value to them. Current arrangements to not appear to transmit these signals effectively. Further work is therefore needed, to explore what new routes to market might look like. At a high level, there are various possible future models for transacting around DSR. There is a spectrum of options, including customers contracting directly for DSR with industry parties across the supply chain, or through more centralized arrangements. Each could involve intermediation through third parties. There are of course a range of other models and variations to be considered, including different customer segments. We have included these illustrations to stimulate debate and better inform how work on future arrangements should be taken forward, not to determine whether the high-level arrangements outlined here should be developed. 13

14 3. Demand Response lessons learned Demand Response (DR) has a totally different meaning in the USA. A relatively old power system and lack of enough generation capacity is the reason for too many Brown Outs and even Black Outs. For a modern country like the USA this means socioeconomic losses and reduced comfort for the many. DR is being used all over the USA in several projects and fully deployed solutions. 3.1 EPRI Demand Response in the USA EPRI (Electric Power Research Institute) is the origin of many DR projects and also a monitoring body for the many results achieved. Doc. Assessment of Achievable Potential from Energy Efficiency and Demand Response Programs in the U.S. ( ), January 2009 Link Note EPRI has a large amount of valuable reports about Smart Grid, Demand Response and verification of Demonstration activities. Look at this special library on the website but note, that some reports require EPRI membership. EPRI has analyzed DR for the period and made a forecast for In the USA there is a challenge every summer with Peak Load from air condition. By 2008 the Summer Peak was 801 GW and is expected to raise to 1,117 GW in 2030 a problematic growth of 39%. Peak Load grows more than the electricity consumption, primarily because air condition has become more and more common. DR might reduce the Summer Peak with GW. Towards 2030 the Summer Peak might be 14-20% lower with DR implementation. DR potentials are technical forecasts. The prognosis is based on already acquired response. From the annual growth in DR has been 2.1%. The expected growth will continue until 2030 with annual 1.5%. DR will reduce the growth in Summer Peak with some 0.83% as forecasted. If DR is deployed more aggressively the annual growth rate for the Summer Peak might be reduced to only 0.53%. After many hundred demonstration projects for DR in the USA, the potentials have been adjusted to a realistic level. DR of 16.6 GW in 2010 will grow to 44.4 GW in 2020 and 78.4 GW by 2030, which is equivalent to 2.2%, 4.6% and 7% of the expected Peak Load. The accumulated investment in DR related technical equipment, meters, ICT and SCADA-systems have been $1-2 billion in 2010, is expected to be $8-20 billion in 2020 and some $19-47 billion by How about the customers, how about the payback for DR? In 2013 there was a cashback to the customers of $2.2 billion for a 29.5 GW DR in hours of Peak in USA. Is expected to grow towards 2030 when even more DR is activated. 14

15 EPRI has forecasted the DR potentials in the USA for the decades 2010, 2020 and 2030 based on already achieved DR in the many demonstration projects. DLC means Direct Load Control based on an on/off signal from the electricity vendor, the aggregator or most often the local utility. For residential customers (private houses) the potentials are DLC of the aircondition system. Example: In Florida town of Kissimmee the local utility KUA (Kissimmee Utility Authority) has managed to secure their 15% summer peak reserves and avoid Brown Outs by using DR incentives for Peak Shaving. In Kissimmee the average residential family spends $1,300 per year on electricity. Back in 2005 all residential customers were offered a discount of $150 if installing a control unit in the central air-conditions system. By random selection air-condition was turned off from remote control 30 minutes some nights. This was enough to avoid Brown Outs. Today, Kissimmee Utility Authority offers curtailable service rates and interruptible service rates to customers with monthly demand of 500 kw or more. Non-residential customers with demand above 500 kwh per month are offered time-of-use rates, while non-residential customers with monthly demand over 5,000 kwh per month are offered time-of-day rates. The Commercial potentials for DR are primarily focused on ventilation, aircondition, cooling and/or heating as interruptible demand. EPRI has annual reports about lessons learned from DR demonstrations in the USA. EPRI 2012 EPRI 2011 EPRI

16 3.2 Green Button Campaign Consumer engagement The Green Button Campaign has been initiated by the Department of Energy (DOE) in the USA as an Industrial Initiative. The aim is to give private and business access to their AMR data for electricity consumption with a resolution of 1 hour. Today, around 45 utilities are sharing their AMR data with their customers with the Download My Data facility and more than 43 million customers have submitted. The AMR data are available in a standardized XML format. 38 ICT-companies are offering the customers different forms of software for displaying the customer s electricity consumption. The customer downloads their data to their own computer for further usage. A number of Apps for Smart Phones are also available. Almost 30% (28%) of the customers who submitted the Green Button facilities are active. Most of the customers have a saving around 15% once their electricity consumption is displayed. Several Utilities are offering a service where the customer can compare their consumption with similar homes. To the benefit of reduced grid congestions and need for Peak Shaving the Green Button Campaign has enabled customers to offer DR and avoiding Peak Load to such a degree that the number of Black Outs and Brown Outs have been reduced with more than 20% and the Utilities has reduced their purchase of Peak Generation Capacity with 30-37%. The Green Button Campaign is now moving to the north where several Utilities in Canada are now offering the service. 16

17 3.3 California PG&E framing Demand Response California has been struggling with a deficit of power generation capacity for many years. Especially in the summer there is a need for Peak Shaving. PG&E (Pacific Gas and Electricity) has been active with a large energy savings program since The objective is to use many DR incentives for reducing Summer Peak. The total Supper Peak in California is 46.8 GW. About 5% of the Peak Generation capacity is only used for 50 hours per year and 25% of the capacity is only used in less than 10% of the year. This is really a case for DR. Doc. Link Note Pacific Gas & Electric Company (PG&E) Smart Rate, September srebates/demandresponse/cs/ Evaluation report made by ADS, Association for Demand Response + Smart Grid. Small residential customers are offered a Smart Rate, with individual prices each hour. More than 100,000 customers are using the Smart Rate arrangement. For those customers who are willing to accept remote control of the central aircondition, there is a special SmartAC rate. PG&E is installing the necessary HAN ICT communication for free. 17

18 To encourage the customers for more savings they are being sent automated calculations of how much they are able to save if they go for the Smart Rate billing instead of flat rate. It seems that 48% of the residential customers participating with Smart Rate are low income families. For such a family any savings on the electricity bill is probably most welcome. PG&E also has a wide range of special offers for businesses, public buildings and industries. Peak Day Pricing; Base Interruptible; Demand Bidding; Scheduled Load Reduction; Optional Binding Mandatory Curtailment Plan just to mention some of the opportunities to tailor the electricity consumption and reduce the bill by DR schemes. The total load being ready for DR is more than 870 MW from the first whole year in There is a special aggregator program for management Portfolio and Capacity Bidding. Businesses are offered compensation up to $125/kW Peak Reduction when there is a manual response on the DR signal. PG&E refunds 50% of the costs to make different electricity appliances DR-ready and 100% for new buildings DR-ready by design. If the business is ready for automated DR response the compensation is up to $250/kW measured kw reduction. All necessary control and ICT-equipment is sponsored 100% from PG&E. The business must sign up for at least three year in the program. There is always a 24 hours warning before DR. Businesses are dived into 19 clusters. The range is from mining and offices to schools and hospitals. Example: - School district has achieved savings of $14,000-17,000 from DR of AC and light in Peak Hours. - Food industry has achieved savings of $4,000 in one summer month from DR of cooling, light and non-critical processes. Peak Hours announced 24 hours in advance. - Fresh water and gray water utility has opportunities from the many pumps. During three days 3 MW of pumps were disconnected in critical Peak Hours. The hourly electricity consumption was reduced from 8,000 to 6,000 kw. The special DR for Peak Shaving with 3 MW gave an extra $12,000 bill reduction and the annual savings were $23, Warehouses for shops are able to turn off AC and light in a Peak Hour. Buildings that normally use 2 MW/h got an annual saving of $4,000 from active DR. The total effort from PG&E means that the number of Brown Outs and need for investment in Peak Generation capacity have been reduced to the benefit of the Californian residents. 18

19 3.4 UK potentials for Demand Response In the UK there is a Peak Load of 63 GW. 10% of the electricity generation capacity is only being utilized for Peak Generation and that is in less than 1% of the time. Often these Peak Load generation facilities are old power plants with poor environmental performance. National Grid, being the TSO in the UK, has a strong focus on frequency balancing in the British grid. Demand Response is one of the obvious resources to use in the effort of ensuring the right frequency. Frequency Control Demand Management (FCDM) provides frequency response through interruption of demand customers. The electricity demand is automatically interrupted when the system frequency transgresses the low frequency relay setting on site. An FCDM provider must provide the service within 2 seconds of instruction, deliver for minimum 30 minutes, and deliver minimum 3 MW, which may be achieved by aggregating a number of small loads at same site, at the discretion of National Grid. National Grid is also very active in ensuring new business in the area of aggregators. There is a Commercial Aggregation Service Providers initiative for new businesses. National Grid aims at ensuring more DR capacity by aggregation from new vendors who have customer designed commercial products. Back in 2010, National Grid made a survey of potentials for DR in UK. The result is shown below. Since the largest potential is from air-condition and industrial refrigerators there are a substantial need for aggregation. Reed more about the UK expectations and programs from the National Grid website Aggregators have established contracts with the TSO (National Grid) and a number of DSOs organized in the UK Power Network. The contract is about Demand Side Management (DSM) for the 100 hours of Critical Peak situations a year. 19

20 National Grid purchases 2.6 GW of Peak balancing for 91.4 million a year. Doc. Demand Response in the UK Forward Thinking Markets Link ml Note In UK there are four active aggregators: ENERNOC, MATRIX, Flexitricity and KiWi Power. KiWi Power has been in business since 2009 as aggregator, having more than 100 MW available Demand Side Management (DSM) resources using assets at the consumers. The consumer is offered the necessary appliances and ICT for control of light, ventilation, air-condition and cooling. There is a DSM scheme for direct control by radio signals from a central SCADA system. Example: - Airports are rewarded 5,000-10,000/year for Peak Shaving from cooling, light, aircondition and emergency power units. - Food manufactures are paid 5,000-15,000/year for turning off cooling and compressors in Peak Situations. - Telecom sector are rewarded 25, ,000/year for Peak Generation using cooling systems and emergency power units. - Supermarkets are paid 5,000-10,000/year for access to Peak Reduction from air-condition, lights, refrigerators and cooling. - Hospitals are paid 25, ,000/year for using emergency power units in peak situations. The largest KiWi Power activation using DSM was in August and September 2013, where 47 MWh/h was delivered to UK Power Network (DSO) in a total of 45 separate hours. Total payback to the participated consumers was 150, Entelios Strong German engagement German legislation from 2012 (Verordnung zu abschaltbaren Lasten, AbLaV) allows larger industries to get access to a bonus for Load Reduction if offered for the stabilization of the power system in critical situations. Businesses and industry must have more than 50 MW power loads, be connected to 110 kv or above. The AbLaV or Power Load Shedding is about remote control for load reduction in critical hours by DR. The system has been environmental certified to ensure sustainable balancing of the power system. Doc. Demand Response Solutions & Virtual Power Systems, 2013 Link Note Most of Entelios information materials are only available from their website. 20

21 Entelios is a DR aggregator and operator. Their job is to find simple and costefficient DR solutions primarily at businesses and industry. There are three primary contributions; demand, industrial power units and storage facilities. Until now there are contracts with a number of customers; metal plants, chemistry, paper, aluminum, food and breweries. But also large public buildings, fresh water and grey water plants are engaged. Entelios Network Operations Center (NOC) has online communication with TSOs, DSOs and balance responsible. There are direct controls of all assets at the end user with a local E-Box. Entelios has delivered the E-Box and all ICT needed for standardized solutions in compliance with ENTSO-E guidelines. AbLaV must ensure access to a minimum of 3,000 MW DR capacity per month for the TSOs to be able to balance the power system in critical situations. There is a capacity payment of 2,500/MW per month or 30,000/MW per year if accessible for an entire year. The payment when activation is the market price for regulation power up to 400/MWh. 3.6 ebutler the Consumer perspective The ebutler project is about consumer engagement. It is a Danish project about engaging consumers with Smart Meters in how to display electricity and heat (district heat) consumption. 1,400 houses are monitored, 15 test families are involved in further anthropological studies. 15 houses are mapped for a detailed insight in electricity and heat consumption and consumer behavior. The first results show that the typical costumer sees himself as just a consumer with a single annual contact to the utility when paying the bill. Electricity is seen as a passive supply and if the bill goes up it must be because of external causes like the weather or new taxes. There is little awareness of the consumption pattern as potentials for flexibility. They regard themselves as average and normal, meaning that they don t need to change their behavior. Next phase is about consumer engagement, how to show the consumption in a way that engages the consumer especially teenagers in the families. See link: FlexPower Demand Response for balancing power The Nordic market for regulation power NOIS (Nordic Operational Information System) is open for DR bid in the market. There is a threshold of 10 MW and 15 minutes access time. For decades the traditional thermal power plants and hydro power have been the primary assets on the list of NOIS. In Norway and Sweden large consumers with up to 1,000 MW has been available for DR in case of extreme prices. In normal operation it would be beneficial to have aggregated smaller resources in the size of MW for balancing the Nordic power system. And it would be of value with a faster response than 15 minutes. This is why the FlexPower project looked into potentials from small aggregated resources responding on 5 minutes prices. In the project there was participation from 45 bottle coolers, 15 domestic electric heated houses, ventilation and a grey water facility. The 10 MW was simulated. The test showed that 5 minutes prices designed from historic NOIS market 15 minutes prices have a large potential for the assets being demonstrated. The 5 minutes response worked excellent. 21

22 And for the owners of the assets there was also a fiscal bonus. Bottle coolers reduced their electricity bill (excl. taxes) with 6.7% and electric heated houses with 7.4%. And the aggregation was possible with relative simple electronic control equipment. Read more about the project: / % Peak Shaving The SEAS-NVE experience The project Wind with new electricity habits (Vind med nye elvaner) is about Peak Shaving in the daily Peak Hour during the families cooking of dinner (17-20h). Time-of-Use pricing with artificial prices are being used in the demonstration which involves 300 normal private homes without electric heating. The average end consumer price for electricity in Denmark is 2.22 DKK/kWh including all tariffs and taxes. There are three different prices: 06:00-17:00h the price is 1.50 DKK/kWh. From 17:00-20:00h the price is 8.00 DKK/kWh. From 20:00-06:00h the price is 0.00 DKK/kWh. The project is about potentials for postponing electricity demand from the Peak Hours until evening and night. The distribution of the electricity consumption in a classic Danish home with annual 3,700 to 4,500 kwh average loads has changed the distribution in the past decades. Entertainment is now the largest part with 32% of the load. From international demonstration projects with Peak Shaving or DR as objective it is typically possible to postpone 2-10% of the load until after Peak Hours. In this project it has been possible to postpone a record high of 25% lead. The consumer pattern has not changed just been suspended in a few hours. Looking at the pie chart of the load distribution for the families it is admirable that such a large share is flexible and DR ready. The three Time-of-Use prices are artificial in the project. And all families are kept on their traditional electricity bill. Savings are being refunded extra costs are covered by the SEAS-NVE utility. Read more about the project: eflex Day-Ahead and dynamic grid tariffing This project governed by DONG Energy (utility department) is about potentials for using dynamic grid tariffs for DR activities together with full use of Day- Ahead pricing for 119 private homes many of them having heat pumps as the domestic heat source. DONG Energy has been working closely with anthropologists about how to monitor and change the consumer engagement. The benefit is both for balancing the power market and for avoiding grid congestion in the LV-grid. 22

23 Doc. Link The eflex Project, November 2012 and eflex :: Fleksibelt elforbrug, eFlex%20Project-low.pdf veloping/pages/eflex.aspxx, Note apport.pdf The eflex Report :: Fleksibelt elforbrug (Flexible demand) is the anthropology results from the project and describes consumer behavior. The demonstration was carried out in the year of 2011 and All houses got Green Wave Reality appliances for control of the domestic electric assets being involved in the project. To help monitoring each house and their electric consumption a PODO online platform was established as a community for all participants. It was possible to compare your consumption with similar houses. The DR was combined to the Nord Pool spot price with a 3-step grid tariff. The savings for a traditional family was from 250 to 600 DKK/year. Additionally, the annual electricity consumption was reduced by 10%. For houses with heat pumps the annual savings was from 1,025 to 1,375 DKK/year when responding to the eflex prices by Peak Shaving. In the project it was possible to suspend 50% (47-61%) of the Peak Load one hour within the Peak Hours (17:00-20:00h). Two hours of suspension gave almost the same result. This indicates that a more aggressive DR might be possible. The Peak Load of the LV-grid was reduced by 18%. The Grid reserves in the 10 kv grids were improved by 4-9%. With a higher distribution of heat pumps and active DR the potential for better grid reserves are 10-15% ,000 MW Demand Response the Swedish way In Sweden there is a Peak Demand of 26,000 MW. The TSO is required to ensure strategic reserves of 1,750 MW in reduced to 750 MW in There is a strong desire in Sweden to ensure that DR will be an active part of the Nordic market. There is a focus on industries being able to reduce load in short periods of 30 minutes to 3 hours. In the Nordic area the winter peak is the challenge since electricity is being used as primary energy source for heating in Norway, Finland and Sweden. Denmark is using district heat in 60% of the buildings. In Sweden there has been an auction of 2,000 MW as strategic capacity reserve. It was a success with a split between power plants and DR. Two power plants are responsible for 720 MW and 10 industrial plants are responsible for 626 MW DR. 23

24 The strategic reserves are paid when activated with 1,000-1,400 /MWh. The largest activation was 230 MW in hour 9 on February 22 nd, Doc. Link Note Demand response in the strategic reserve, 14:29, July 2014 Prosumer with demand response, 13:59, May Swedish ELFORSK has made several DR studies. Please look at the website. The local grid in Sweden is challenged by a growing share of local generation from solar-units (PV) and micro-chp, and new local demand from heat pumps and electric vehicle (EV). If the domestic customers have both, they are Prosumers but they use the grid for balancing their own private system. The local grids need capacity since the flow in the LV transformers is growing with 30% a year. But there are only critical situations in 2% of the time which calls for DR solutions. A demonstration project with 250 private houses having PV-units, heat pumps, micro-chp and EVs showed that if there is a hard control of the systems with remote technical activation then 20% of the energy generated will be lost. If on the other hand there is a soft control using DR with price incentives then a much larger share of this new local generation might be utilized for local demand and only 1.5% of the electricity is lost Norway market based Demand Response The annual electricity consumption in Norway is 127 TWh with a winter Peak Demand of 24 GW. 64% of the electricity is used for room heating and 15% for heating of water. The DR potential is predicted at 3 GW from industries and 1.7 GW from private homes and commercial. All customers will have a Smart Meter with remote control by the latest in Doc. Market Based demand Response, April 2012 Link Note Presentation at IAE/DSM workshop, Trondheim, Norway by Ove Grande. Look at SINTEF website for other analyses and research in the area of Demand Response and market development. SINTEF is by far the most engaged research institute in Norway looking at the development of the Nordic market with active inclusion of DR resources. It is important that DR is market-based in Norway. 25% of all consumers in Norway buy their electricity from the Nord Pool Spot market. There is a Peak Payment of 0.08/kWh for all critical situations and hours during the winter season. 24

25 A new market product Fixed Price with return option has been deployed. The consumer purchases an annual kwh energy service from the electricity vendor with an opportunity to sell back electricity not used in Peak Hours and to the hourly spot price in the critical situation. Electricity might be bought for the whole year at a relatively low average market price. When sold back in hours of Peak then it is probably at a higher price with an economic benefit for the customer. In the summer 2012 there were 2,500 customers on this new type of contract, many of them businesses and industries. The DR in this type of arrangement is willingness to reduce/avoid electricity consumption and load in the critical hours and a financial reward. The paradox in Norway is that DR has been introduced because of lack of Peak Generation capacity. The more success there is with new DR products, the incentives are being reduced in the market for investments in new Peak Generation capacity. SINTEF has been leading several DR demonstration projects. Example: - 41 houses with Time-of-Use. Two daily Peak Hours with 0.1/kWh instead of the market price. The customers shut off electric heaters (2-14 kw). For the entire Norway this means a potential of 600-1,000 MWh/h for DR houses with DR from Nord Pool Spot prices and automated control to shut off dedicated appliances at high prices beyond 0.07/kWh. In the test phase it was winter and there were up to 9 hours of high prices in a row. This was too much and resulted in manual overwrite of the automated control signal. Lessons learned in Norway are that there is a significant potential from industries and private water heaters for DR and success with add-on prices in critical hours Address Active Demand that works The Address project is one of the largest European projects investigating possibilities for DR through Active Demand. The project is about DR from 5 minutes price signals to residential EBox (Energy Box) for direct control based on a combination of Time-of-Use prices and direct measurements from LV-stations in the 10 kv grids and substations to balance the voltage, the power flow and avoid Peak Load. Results from the project have been implemented for 6,500 customers in Ireland with Time-of-Use mechanism and common aggregator. Doc. Active Demand, The Future of Electricity, Link Note There are several reports from the finalized project available from the website. 25

26 The aggregator broadcasts a signal to the local EBox every 5 minutes. The residential Smart Meter had a 15 minutes reading. There were four price steps based on actual load. Under 0.6 kw; kw; kw; more than 1.2 kw are the four steps. Price and tariff are calculated every 5 minutes. The aim is to reduce Peak Load, and local grid services. In Spain there was a demonstration project involving 263 homes with EBox and Smart Meters. Each house was equipped with five Smart Plugs for on/off of electric appliances. 25 Smart laundry machines and 14 air-condition units were involved. The test ran for over four month in 2013 and included Time-of-Use pricing with the four steps. Measurements from the test houses were compared with normal consumption in the hour. Discount if reduction of load. Reduction to kw = 0.00; to kw = 0.01; to 1-0 kw = In a test case there was a need for 10 kw reductions from 22:00-23:00h. Every house that reduced load with 0.5 kw got a reward of 0.015/kWh reduction. The response rate was between 55% and 70%. In France the demonstration project included 373 private homes with EBox. There was an average reduction of 700 W per house during the test. In the project there was also a simulated market response in case of scaling up to 250 MW aggregated load. The market price would be reduced from 232/MWh to 212/MWh if 250 MW DR was market active. In France 52% of the DR potential comes from room heating, 12% from water heating and 7% from home appliances. In an average household 29% of the load is not flexible Smart consumers in Salzburg In Salzburg Austria they have conducted a relatively large Smart Consumer project including DR. The project had 474 private homes, one major industry, 30 small businesses and 58 buildings engaged. Doc. Link Note Results & Findings, From the Smart Grid Model Region Salzburg, May _upload/downloads/sgms_results_findings_ pdf The Salzburg Smart Grid project is not only about DR. There are a number of activities also including emobility. The projects are not completed yet. Please look for further reporting on the website. 26

27 One of the activities in Salzburg is Customer-to-Grid (C2G) where 288 houses managed to reduce their electricity bill with an average of 7% ( ). The customers got interactive information from a Wattson platform about their own electricity pattern and consumption. They were also compared with 68 customers who only got the traditional annual electricity bill. Another activity is the FORE-Watch. Customers get a 24 hours price forecast shown as red-yellow-green. Customers with electric heating and the FOR-Watch system achieved a 15% reduction of the bill. The Salzburg project managed to get 5 MW flexible DR and a reduction of Grid Peak of 20%. There were no special price signals just the market price being communicated to the customers. And the only rewards for the customers were a reduction of the electricity bill CYBERGRID and OpenADR ICT platform for DR An important part of DR implementation is ICT-solutions for communication between the local asset, the aggregator, the electricity vendor and the utility. Many projects have developed their own ICT-solutions which is not recommendable. The customers are seeking Plug n Play ready solutions based on open international standards. 27

28 To help competition, these standards should be international and organized by IEC. The CEN/CENELEC organization is working on several mandates from the European Commission to speed up the standardization work. Cybergrid Toshiba has developed an ICT-platform and invited DSOs and utilities to be a part of a Cybergrid platform for demonstration of Virtual Power Plant (VPP), aggregation and DR. The system is ready for DR solutions involving local electricity storage, EVs, households, RES and a number of businesses. Businesses already involved are steal, paper, glass and ceramics and chemistry but also shopping centers and hospitals. DR is supporting the power system's need for tertiary reserves manual 15 minutes response both up and down regulation. Example: - Vattenfall Demo in Germany. Participation for 80 electricity driven units where 54 were with automated control. They participated in the German Minuten Reserve market. Local electricity storage showed impressive value for DR as technical assistance for operating the grid. The relatively low prices in the market for reserves were the largest barrier for funding the investments in DR equipment. - Elektro Ljubljana Demo in Slovenia. VPP aggregation of 12 MW for DR. 24:7 access to the industrial load at steal-, paper- and chemistry plants. Used for Peak Shaving (Load curtailment). Contract with TSO included two activations a day with a limit of two hours each and 10 hours of pause between the activations. Only good experiences in practice the TSO only needed three activations a month. From Cybergrid there is a general request for improving the DR market by: Removing complex contracts; Allow for down to 1 MW bid in the market; Two hours as maximum activation; 15 minutes response time; Allow asymmetric bids; Allow to change between DR resources during the activation. Read more about the platform on this link. OpenADR OpenADR is an alliance between many organizations around the world working for a standardized ICT-platform for Smart Grid and DR. 28

29 The developed ICT-systems are already installed and in operation at aggregators in 10 countries. In USA 11 systems are in operation. The installed systems have aggregated 260 MW of DR mostly for Peak Shaving. Doc. Link Note OpenADR, Enabeling The Standard for Automated Demand Response, This is a presentation made at the PMLA Spring 2013 Demand Response seminar in Austin Texas. Please look at the link for more about the alliance. The OpenADR ICT-systems are relevant for Direct Load Control, Interruptible Load, Critical Peak Pricing, Load as Capacity Reserve, Time-of-Use, Real Time Pricing or Peak Time Rebate. The experience is that the system is most favorable with situations of high compensation for Peak Shaving. The system is operational with different types of price signals. Example: - Simple ladder. 1 = moderate price, 2 = special price and 3 = high price. - Time of activation: 15, 20 or 30 minutes of duration. - Simple price steps: 1 = $1.05, 2 = $1.15 and 3 = $ Discount per kwh response from a published time/price table see above. - Price multiplication: The end consumer price/kwh is being multiplied with a load factor. o Normal operation: Price = 1 x market price/kwh o Normal Peak Shaving: Price = 2 x market price/kwh o Critical Peak Hours: Price = 4 x market price/kwh The OpenADR alliance is also supporting the international work for ICT standardizations of the communication protocol used for DR and Smart Grid. 29

30 4. Ongoing Demand Response projects There are too many DR projects all over the world to be mentioned here. For those outstanding projects not being mentioned please take our apologies. Below is a short list of some ongoing DR projects which are expected to yield valuable knowledge. At the European Commission an annual Smart Grid report is being published from the Joint Research Center along with an excellent website where many data can be downloaded. Doc. JRC Smart Grid Projects Outlook 2014, April 2014 Link Note It is a 159 pages complete list over European Smart Grid projects and analyses on the achieved results as well as identification of gaps needed to be filled out in upcoming projects. If you look at the number of European Smart Grid R&D projects DR has a growing share (olive green) around 2012 and If you look at R&D DR projects distributed by an EU country it is clear that countries like Germany, Denmark, France, UK, Netherlands and Italy in the lead. 30

31 4.1 Grid4EU six demonstrators GRID4EU brings together a consortium of six European energy distributors. It will test the potential of Smart Grids in areas such as renewable energy integration, electric vehicle development, grid automation, energy storage, energy efficiency and DR load reduction. The project consists of six demonstrators, which will be tested over a period of four years in each of the European countries represented in the consortium. Doc. Grid4EU, General Functional Requirements and specifications of joint activities in the Demonstrators, October 2012 Link Note On the website you find a long list of reports from the dissemination activities. The Demand Response Use Case supposes that the customer has a DR contract established with the retailer or energy vendor. The Use Case has been placed in the operation domain because at that level this information is available: - from the TSO in case of HV shortages happen; - from the MV control system in case of MV shortages or outages happen; - from the voltage control system in case it publishes the MV Load set points. In addition to the DR test for energy and power balancing of the system activation of DR, resources are also used for technical control of the power system. The Anti-Islanding Use Case will be put in place at station level. The Voltage Regulation Use Case is performed by the equipment located at station level according to a decentralized approach. The Measurement Acquisition Use Case is strictly related with the Anti-Islanding and Voltage Regulation use cases as a fundamental base for the algorithms calculation so it is located at station level as well. 4.2 TotalFlex new market concepts for DR This Danish project is about development and testing of novel price and tariff systems for the benefit of the end consumer and makes them ready for a future with possible higher and more volatile prices. A new ICT platform is being developed to manage the different prices and products as well as VPP-solutions for aggregated DR resources. Scenarios: The EV is able to communicate with the residential gateway and inform about the need for charging and availability. Together with the need for electricity for the entire house and consumer profile it is possible to forecast the 31

32 need for electricity 24 hours ahead. This allows the retailer to buy electricity at an optimal time and price. This also shows potentials for DR. The TotalFlex project is also engaged in the large EU project ARROWHEAD where software technologies can be tested for scalability and possible replication around Europe. All tests are in the existing markets for electricity. Read more about the TotalFlex projects: INCAP - Consumer preferences for DR and flexibility This is a Danish project to enhance the participation and interest from the consumers in automated load control at residential appliances based on dynamic prices. The object of the project is to examine the consumer reaction on price offers and automated remote control from randomized field tests. This will yield valuable knowledge about barriers, motivation and behavior for a better design of future consumer driven products for DR. The tests are being developed and performed in the grid of SE where more than 250,000 customers have Smart Meter for remote reading of the actual change in behavior. Read more about the project: FINESCE Consumer friendly App solutions This is a European project involving seven Smart Energy use case test sites in Europe. ICT solutions based on open international standards are being developed. The focus is on consumer ready App solutions for automated energy control involving DR. Doc. Taking Energy. From reactive to pro-active energy management, 2012 Link Note There is a European FP7 project FINESCE with a Danish partner, INSERO and a Danish test site Live Lab. In the project there is focus on the entire energy consumption for the buildings, and not only electricity. DR activation of the electricity might influence the other energy supply of the building district heat, gas, cooling and other. From Denmark the partner is INSERO and the Danish test site is Live Lab with 25 houses in the town of Stenderup outside Horsens. All the houses are equipped with new ICT solutions for energy optimizing. Some have solar panels 32

33 for heat generation and a sun-well for storing the heat. The houses have heat pumps for room heating and hot water. 4.5 Other ongoing DR projects There are multiple Smart Grid projects around Europe many of them have a focus on development and demonstration of new ways of using DR as an active part of the Smart Grid operation. The projects below are just a flavor of some ongoing projects being active in Denmark GreenCOM A project about real-time measurements in the local grid and consumer load to provide a better picture of the actual need for DR services in the local grid. The GreenCom project is an EU-funded pan-european project (European Commission FP7 ICT Smart Energy Grids) and a demonstration site in Denmark on the island of Fur. The aim of the GreenCom project is to utilize the flexibility and intelligence in the low-voltage demand and local supply side infrastructure to create increased regulation capacity and reserve power in the centralized power grid by extending the means to effectively and securely manage and control the demand and supply within defined boundaries. The project thus aims at balancing the local exchange of energy at the community micro grid or sub grid level, to avoid affecting the centralized grid with instability. To provide such means, the GreenCom project will develop a Smart Energy Management System (SEMS), i.e. an energy management and control platform that allows energy providers (DSO or Retailers) for the first time ever to measure and balance load in the low-voltage grid and thereby prevent or reduce critical peak situations. It will thus allow the energy distributors to move beyond focusing on Power Grid efficiency and start focusing on Energy System effectiveness; a giant step forward in European energy distribution. The GreenCom Smart Energy System will collect, aggregate and analyze realtime or near real-time data from appliance level consumption devices such as appliances, smart home devices, sensors and actuators and smart meters, via an independent data communication network. The data analysis will provide real-time consumption data on type of devices and location together with short term forecasts (up to 4 hours). Data can be aggregated over several sectors of the grid. Having a real-time picture of the grid stability and the consumer behaviour will provide the needed information for the aggregator or retailer to use DR for optimization of the local system. Read more about the project: 33

34 4.5.2 READY Project about design of ICT tools and algorithms to enable an aggregator service for a better DR covering thousands of appliances and customers. The READY project is about development of a VPP Controller, primarily for aggregation of heat pumps. The main purpose of the READY project is the development of a Smart Grid ready Virtual Power Plant (VPP) server that can control a large number of heat pumps. In this context, a VPP server is a unit that can control thousands of consumption appliances, but seen from the operator they act as one controllable unit. The main aspects of the project are: Large scale aggregation of heat pumps; Management of grid constraints; Recommendation for future installations of heat pumps and controllers; User involvement and business cases. A possible road map for development of markets for local grids. Years are only indicative. Read more about the project: 34

35 4.5.3 Nordic pilot project for 5 MW RPM The Nordic Balance Regulation Group has made a report about developmemnt of the Demand side bidding in Regulation Power Market (RPM) from October 4 th The groups of Nordic TSOs are Fingrid (Finland), Statnett (Norway), Svenska Kraftnät (Sweden) and Energinet.dk (Denmark). They are all co-owners of the Nordic Power Exchange, Nord Pool and the NOIS (Nordic Operational Information System) platform for the regulation power market. In the existing RPM there is a threshold of 10 MW, 15 minutes activation response and compulsory on-line measurement from active assets. This has been challenged for some time from the market actors and other stakeholders. The report recommends that the four Nordic TSOs enable national pilot projects where the RPM threshold is lowered to 5 MW, still 15 minutes activation time but no mandatory on-line measurement. Aggregation of DR resources for a total of 5 MW is also an opportunity. The purpose of these pilot activities is to enable fore active DR participation from industrial assets and aggregated consumption. Doc. Link Note Balance Regulation Group Demand side bidding in Regulation Power Market (RPM), nske%20dokumenter/el/demand%20side%20bi dding%20in%20rpm% pdf The report is about pilot projects and development of the Nordic RPM in Finland, Norway, Sweden and Denmark. 5BALL RPM project in Denmark The Danish part of the Nordic RPM pilot project has been subject for a public announcement for possible partners to join in one or two 5 MW projects. DI the Confederation of Danish Industry holds the role of project manager. The project is called 5BALL (5 MW Balancing Load). Please see illustration of an example of 5 MW aggregations below: 35

36 Read more about the 5BALL project and expected disseminations from DI the Confederation of Danish Industry on this link: DREAM DREAM (Danish Renewable Energy Aligned Market) is a project about how to enable private consumers to find a private business case in DR participation. The step from pilot or demonstration projects with subsidies to full scale deployment of DR systems requires a financial model for the whole value chain. DR is only going to be a success if all stakeholders "get a slice of the cake". Private homes or small businesses might have incentives to do investments in appliances for energy savings since every saved kwh contributes to the funding. Changing from an oil boiler to a heat pump might be a good idea since there is a short return of investments with increasing oil prices and a better insulation of the building. Investments in control units, Smart Grid Ready appliances, ICT infrastructure and other mandatory equipment for DR activation is another story. Such investments need to be a part of a larger package. In the DREAM project a number of models have been developed for improving the private business case for electrification of heat and transportation (EVs) as well as optimization of the electricity market participation with DR options. Doc. Link Note DREAM, Danish Renewable Energy Aligned Market, ekt-dream-rammerne-for-tidligkommerciel-udrulning-af-smart-gridloesninger/32966 The Dream project has finalized its phase 1 and is now about to start a phase 2. Lessons learned in phase 1 are that it is only a feasible economy for private house owners and small businesses if they are offered a Turn Key solution. The package must include elements like: Improved insulation of the building, 36

37 energy savings from changed behavior, coherent energy solutions with combinations of heat pumps, solar energy (heat and PV) and automated appliances with novel ICT. It is also a benefit if the consumers in a street or area form a community for optimal procurement of the contractors and appliance retailers VPP4SGR EcoSense The VPP4SGR project (Virtual Power Plant for Smart Grid Ready buildings and consumers) is about how to engage a 192 student living in a 159 flat dormitory near Aarhus University The Grundfos Dormitory (Grundfos Kollegiet) in Smart Grid, green living and energy savings. The project is a demonstration site in the much larger EcoSense project. In tomorrow s electric system the Smart Grid much more flexibility is needed from the electricity customers. Furthermore, the interaction between the different energy systems must be utilized to a much greater extent than today. In addition, customers need to be involved to become a useful asset in the demand response of the Smart Grid. To be successful, the involvement of the users should be based on other incentives than just the economic one. This involvement of users and sensing of their activities provide synergy with the EcoSense analysis methods. Demand Response is also about consumer engagement. This project has a special profile of the participants since it is a dormitory with almost 200 students. Read more: ipower and FLECH The ipower project is a Danish national research project focused on the development of intelligent DR controls for handling of decentralized power consumption, and integration of decentralized energy resources (DER) and renewable energy (RE). Through the ipower project, universities and industry partners meet with the aim to research, develop and mature Smart Grid products for the Danish and European energy markets. The ipower project reduces business un- 37

38 certainty through demonstration and validation of new technologies, concepts and systems for easy smart grid implementation in Denmark. These work span from the technical aspects of bringing the domestic DR flexibility to a market for DSO flexibility services (called FLECH), to understanding the private consumers and prosumers behavior, preferences and attitude to the challenges in a domestic DR future. FLECH (FLExibility Clearing House) is an aggregation platform and clearing house for multiple DR assets to be combined for market integration. The software platform of the clearing house has been tested and is ready for implementation in a full size distribution grid. The focus is on DR and optimal activation of flexible load both for better market integration through balancing services and for congestion management of the local grid together with ancillary services. Read more about ipower and the FLECH platform: Video: e3/content 38

39 5. EcoGrid EU Demand Response perspective The original idea of the EcoGrid EU project was and is: To develop and demonstrate in large-scale a generally applicable real-time market concept for smart electricity distribution networks with high penetration of renewable energy sources and active user participation. The concept is based on small and medium-size distributed energy resources (DER) and flexible demand response to real-time price signals. Market-based, cost efficient and standardized solutions will be aimed for. The project is aiming at optimizing DR in the form of a real-time market where price signals are broadcasted every five minutes for consumers to response either manually or with automated appliances. Read more at The EcoGrid EU five minutes market The EcoGrid EU project has decided that a real-time market should be tested in the form of a five minutes market. Arguments for a five minutes resolution? First of all there is a European trend going in the direction of reforming the existing market for balancing power from a market with 15 minutes response to 5 minutes response. Second argument is that a five minutes market will enable the balancing market to expand and at the same time reduce the need for automated controlled spinning reserves in the power system. Third argument is that by inviting the consumers to be part of a DR system and deliver aggregated balancing services with a five minutes resolution then the cash back might be higher since the service has a higher value for both the TSO and the DSO. The EcoGrid EU will show DR potentials in the frame of a real-time market contribution with a five minutes resolution. This is a novelty compared to the many DR projects and semi commercial products with a focus on the Day-Ahead market and a 1 hour resolution. 39

40 The EcoGrid EU system involves several stakeholders and a complete solution. The primary focuses on the five minutes real-time price to be broadcasted and the active DR from the consumers. However, there is a need for access to information from the TSO NOIS balancing market prices 45 minutes in advance of the hour of operation. Spot market Day-Ahead prices for 24-hours ahead to make a forecast of the price level. Weather forecast Part of the forecast. Historical metering data for the active feedback and the settlement process based on Smart Meters data with five minutes resolution. In order to operate such a real-time system with a closed automated loop there is a comprehensive data infrastructure with clear roles for every stakeholder. The DSO is the host of the entire system. The DSO has the role of being owner and responsible for the metering. The DSO has the direct contact to the consumers and the DSO can use the system for local balancing to avoid congestion in the LV grid. 40

41 The traditional set-up for a demonstration project is to send out a price signal to the consumer or to the aggregator party. The DR on the price is then being measured to document the response and for billing and settlement. In the EcoGrid EU project there is a feedback mechanism where the change of the system balance is being used for calculation of the next five minutes price. This allows for close to real-time balancing of the system with little delay. This also opens for congestion reduction in the local LV grid. The principle of closed loop operation is shown below. The meter reading is in off-line operation and is being used for the billing. The EcoGrid EU participants are receiving their normal electricity bill of the used kwh energy. Many of the EcoGrid EU customers have a reduced consumption due to more awareness and to their benefit. The bonus for DR is being calculated in the project and a final bonus is being distributed at the end of the project. Participation of 2,000 customers on the island of Bornholm is almost 10% of the consumers. But since participants have been prioritized selected if having heat pump, electric heat or other special flexible demand the percentage of possible participants is as high as 75-80%. 5.2 Advantages of the EcoGrid EU market Since the EcoGrid EU project and concept was born back in 2010 there have been major changes in the energy landscape. The continuing increase of fluctuating forms of renewable energy and simultaneous phase out of thermal power plants has increased the need for new ways of balancing the power system especially in the critical peak hours. DR is no longer just a nice ad-on for the power system DR is going to be a mandatory part of the daily operation. A great value of the EcoGrid EU concept is the relatively easy implementation on a larger scale. The concept is easy to replicate and integrate in many types of power systems with different DER available for DR activities. 41

42 A system responsible and neutral party the TSO issues a price that is related to the actual imbalance of the system and the need for DR activation of the balancing resources without any market arbitrage or discrimination. Having a system with broadcasted prices single way communication without requirements for individual bids to be send from the consumer or aggregator, makes it much faster to obtain the needed response. A broadcasted price without any obligation or reservation from the DR applied resources avoids several issues related to complicated settlement and correction of the Balance Responsible or aggregator. This is important to underline since it avoids conflicts and confidentiality aspects among the market actors. New independent aggregators are invited to bring in new DR resources to be integrated. Price based on present and expected system balance as well as forecasts of price elasticity (no bids). This report has collected information and results from a wide range of European and US projects and semi commercial DR products. Most of them with a relatively high DR score and the success rate is based on Time-of-Use. Time-of-Use is a relevant DR regime when there is a need for balancing thermal generation or other planned resources like hydro power. Timeof-Use is also a relevant approach when the need is avoiding grid congestion. If and when the DR resources are to be utilized for balancing a power system with a high penetration of non-scheduled fluctuating renewable resources for power generation like wind, sun or wave, then DR should be in a form of realtime response opportunities based on a clear monitoring and system awareness. The EcoGrid EU concept is needed even more than at the birth of the idea. 42

43 6. Future ideas for Demand Response Demand is obviously not fully deployed in any country or power system. A wide range of projects have been initiated and there are DR schemes in operation in many countries. The European survey by SEDC (Chapter 2.2) shows that only few European countries are running commercial DR systems. In the US there are several DR systems in operation for curtailment of the Peak Demand to help Peak Shaving. Most projects show that DR in the form of Time-of-Use has a relatively high success rate being able to control some 70-80% of the admitted load by remote control. The real challenge is to enable DR in systems with no daily risk of Brown Outs or other lack of security of supply. DR and power generation should be equal tools and market objectives in obtaining balance in the system. This is not the case. The green revolution where a large power plant in MW size is taken out of operation and substituted with ten thousands of 6 kw PV-units and 6 MW wind turbines is a paradigm shifting challenge where the consumption side of the equation needs to be fully integrated. The question is: How much is DR worth? And: Is DR as competitive as Peak Generation capacity? To answer these questions we need to find out what the cost is when turning off the power supply for a specific consumer. In Germany the Forschungsgesellschaft für Energiewirtschaft has made a study of the costs with load shedding or load shifting in dedicated industries. The figure shows that DR has many costs and potential prices. 43

44 Load shedding is where the power supply is turned off in a short period where the power system needs to reduce the consumption Peak Shaving. And for many industries this comes with a relatively high cost, since production is being interrupted even if there is a 24 hour response time. Load shifting means that the consumption is being postponed for a short period. If it is an air condition system or a heat pump then the power load might be shot off for an hour, but the energy demand is still there and the appliances will start an hour later delivering the comfort for the consumer. This might not be as cost-intensive since smart DR allows for shorter periods of curtailment without any loss of comfort. The figure from FfE shows that it is more feasible to find DR resources ready for load shifting since the cost of Peak Shaving might be much lower. But most important, the socioeconomic costs of load shifting if often much lower than cost of load shedding where valuable production might be delayed or even reduced. DR should be implemented with minimum losses both with respect to comfort and costs. What is the value of DR for the power system? DR has two perspectives. For the TSO and the wholesale market DR is an enabler for balancing the power system (MW and MWh) by using demand reduction or extra demand as a way of obtaining balance within the hour of operation. DR should be used as a competitive alternative to Peak Generation. DR is even able to have a faster response than the typical 15 minutes for Peak Generation. For the local grid and the DSO domain DR is able to reduce congestion (MW) and ensure a stable grid with sufficient ancillary services for optimal grid operation (Voltage, Frequency as examples). The DSOs are challenged from two opposite developments in their grid. First of all, the entire society are to be electrified. This means that many other energy sources based on fossil fuels are to be exchanged with electric appliances ex oil boiler are changed to an electric boiler or heat pump. Combustion cars are changing to electric vehicle. This means that the grid must carry much more electricity. Traditional solutions are grid reinforcements. The smart solution is to enhance the usage of the existing grid. Second the local grid is where there is a dramatic growth in the integration of new generation capacity. PV-units, wind turbines, micro CHP units, biogas units and other renewable generation capacity is being grid connected in the LV grid. The original architecture of the power system was built after the principle of a pyramid. Large power generation capacity at the top of the system and then distribution of power downwards in the system to the end consumer in the LV grid. Power generation in the LV-grid will challenge the system and fully change the power flow. The traditional solution is to invest in grid reinforcements. The smart solution is to utilize the power as close to generation as possible. The Power System 2.0 is not only about technical solutions. The market must also adopt the new paradigm and find new products that allows for an optimal operation of the power system. DR is not just a buzz word but an umbrella of possibilities which need to be demonstrated and deployed. 44

45 6.1 DR in the existing market places Many DR projects have already been completed and a vast range of lessons has been learned. The power market has a wide range of existing market places. Below is a list of the services the TSO requires. - The best known is the Day-Ahead market where the wholesale actors buy and sell energy (MWh) for the next 24 hours. - The balancing market or regulation power market or RPM is also with Day-Ahead bid. In the Nordic Market a minimum of 10 MW both up and down, and with 15 minutes response time must be acquiesced by the Balance Responsible. There is a mechanism where amount (MW) and price (Euro) might be changed until 45 minutes before the hour of operation. - There is an Intra-Day market called ELBAS in the Nordic region. - This is a market for the Balance responsible where they might trade imbalances between them. - There are different types of reserve markets where the TSO are reserving capacity for security of supply in case of N-1 incidents also known as tertiary reserves. - Additional to the Tertiary reserves there are Secondary reserves or LFC (Load Frequency Control) and Primary reserves (Spinning capacity). Dedicated units are for black-start of the power system. - The power system is as an AC system and only operational if supported with ancillary services like Short-circuit power, Reactive reserves and Voltage control. The DSO approach is often to plan and build grid reinforcements once local congestion or voltage problems are identified. There are only few examples of genuine marketplaces for using DR or other DER as service for the DSO to purchase as an alternative to grid reinforcement. DR is often used to avoid Brown Outs in the local grid. DR also has potential for optimal grid operation in the daily operation and not only in cases of trouble. In Denmark there has been an agreement between the TSO and (all 65) DSO in cooperation with their branch organization Danish Energy Association about how such a market should be designed and operated. The idea is that the DSO identifies local resources feasible for DR services. Once the business arrangement is signed then the Balance Responsible is notified to avoid imbalances. 45

46 The DanGrid report has the full description. There are three chapters. - The Smart Grid concept where the TSO and the many DSOs have agreed on how Smart Grid should be integrated from the end consumer connected in the LV grid and all the way up to the overarching HV transmission system. This concept includes a clear definition for all shareholders and actors. - The information model for ICT and data communication is a commitment to use the open international standards of IEC (Logical Nodes) in the component oriented appliances and IEC (CIM) in the system oriented platforms and SCADA infrastructure. - A mutual Danish road map focusing on the role of the grid companies and their individual strategies for deployment. Doc. Smart Grid in Denmark 2.0, 2012 Link nts/engelske%20dokumenter/forskning/s mart%20grid%20in%20denmark% pdf Note The report and the new model is often called DanGrid. An important key message from the report is that grid optimizing and achieving the benefit of Smart Grid investments instead of traditional Dum Grid investments often requires up front investments in improving the monitoring of the grid to obtain much better system awareness. Such investments must be approved by the national regulator. DR optimizing in the existing Day-Ahead market The existing Day-Ahead market has several opportunities to yield a benefit if using DR as a way of improving the balancing of the power system and reduces the end consumer electricity bill. Experience from several Danish projects shows that if you are a classic Danish end consumer with an annual electricity consumption of 4,000 kwh to 4,500 kwh (cost of 8,000 to 9,000 DKK including tariffs and taxes) you might optimize your usage by load shifting postpone the dish washer service or wait a little longer before turning on the lights. Such manual activities might result in annual savings of 300 to 600 DKK which does not allow for Smart Grid investment in automated appliances. If the end consumer has installed a heat pump the annual saving might amount to 1,000 to 1,400 DKK. An important message is that savings from traditional classic electricity consumption is relevant for energy savings and not as much for Smart Grid or DR services. But energy supply is going to be electrified on a larger scale! New consumption of electricity for heat pumps, electric boilers, air condition, electric vehicles and larger appliances in businesses and public buildings are much more 46

47 relevant. Smart Grid solutions with DR are also relevant in the Day-Ahead market. The relatively high penetration of wind power (35% of annual electricity consumption in 2014) with hours of 130% coverage and hours with 0% coverage of the demand is a new challenge for the power system. Most of the imbalances from wind power are being balanced in the market for regulation power (NOIS) but also the Day-Ahead market based on wind forecasts is influencing the prices Day-Ahead. The Danish Day-Ahead market is showing a high volatility already today. Day Ahead prices in the wholesale market might jump from DKK/MWh within few hours as shown below (green curve) from February 26 th The seven days from February 26 th to March 4 th 2014 is a typical picture of how much volatility there is in the pricing of electricity. DR engaging consumers with flexible demand is an obvious opportunity for savings. Graph supplied by EMD international - Looking at another period January 1 st to January 27 th 2014 where the price spread went from 525 to 0 DKK/MWh had a pattern where prices were lowest in the night and highest in the peak during the day. The prices followed the demand almost perfectly. But this is not always the situation. To balance the consumption according to the Day-Ahead market you need a direct price signal to respond. Time-of-Use pricing where ex prices are always low during the night might even worsen the situation. 47

48 Graph supplied by EMD international - Below is another volatile period January 8 th to 17 th Several important messages from the real life data in the graph are for learning. A) The prices were at a relatively normal level of 200 DKK/MWh in the night between Wednesday and Thursday. If there had been a Time-of-Use pricing then load would have gone up, but generation was at a low. Extra load would have implicated import or start of Peak Generation capacity. B) The electricity production was too high during that night between Saturday and Sunday. The prices went to 0 DKK/MWh (F) calling for a beneficial DR using more electricity. C) Another night between Monday and Tuesday with minor wind generation and average price of 200 DKK/MWh and no need for extra load. D) The same as C two days in a row shows that DR in the shape of Timeof-Use solutions might be of negative influence for the load balance in the power system. E) Between the two nights (C and D) was a normal day with normal load but relatively high prices of 525 DKK/MWh in the peaks. DR would have been helpful now the Peak Load was covered from import. Time-of-Use would have been a help that specific day but look at two days before and after! Time-of-Use is not the answer. F) Having several hours of 0-pices and other situations with relatively low prices is an opportunity for DR. G) Wind power as a part of the total generation requires that the wind is blowing. Sometimes there is no wind for many hours. 48

49 Graph supplied by EMD international - The volatile prices and no systematic pattern is the key argument for finding DR products where the price is used hour by hour and not from a Time-of-Use scheme or price table. If investigating the prices in the balancing power market the benefit from DR capability is even higher. Especially the fact that DR is able to have a very fast response makes it valuable for all market actors to engage with the end consumers having assets with possibilities for flexible load. The market is not always logic. Below is a graph from August 8 th 2014 a full 24 hours with almost no wind power generation and with benefit from photovoltaic generation during the hours of daylight. A lot of the Danish demand came from import since the CHP units and power plant did not have enough incentives to generate electricity since they mostly cogenerate with heat and there were no need for heat in the late summer day. Some of the owners of generation capacity could have made a generous profit if being in operation from 08:00 until 12:00h where the prices went sky high at a maximum of 12,000 DKK/MWh. From a DR perspective this is also of interest. Flexible demand in operation should be turned off and other demand postponed before usage! 49

50 Graph supplied by EMD international - The volatile pattern of a power system based on wind power or other fluctuating types of power generation initiates many DR opportunities. Shut down demand in hours of relatively high prices and use of more electricity in other hours of relatively low or even 0-prices. Sometimes prices are even negative. In mid- March 2014 the prices in the Day-Ahead market went as low as minus 450 DKK/MWh. Having flexible demand; this was profitable hours to achieve. Graph supplied by EMD international Novel DR what is waiting to be demonstrated? DR is an opportunity for most power system and market places. And DR should be used as equal as Generation capacity. From a socioeconomic point of view and from an environmental perspective it might even be better to turn off demand in an critical hour than to ramp up a power plant using fossil fuels. DR even has the advantage of being able to make very fast responses. 50

51 There is room for a number of new demonstration projects in the frame of DR. These projects must have focus on consumer engagement and involvement. Consumers, private homes or businesses, need to be involved in the development of new products and optimized Plug-n -Play solutions and there is a need for dialogue about level of comfort. New projects should demonstrate and show potentials for large scale deployment, replication and scalability. Below is an incomplete list of possible new novel DR demonstration areas for upcoming projects to carry out. Interoperability It is important for consumers that Smart Grid appliances for DR interaction and other types of power system engagement are ready for Plug-and-Play. Technologies provide for DR should be non-proprietary solutions based on open international standards. The backend systems must be prepared for interoperability where costumers have the right to change electricity vendor or aggregator without need for changing their entire technical set-up and gateway. There are lessons to learn from the telecommunication industry and their evolution. Simple solutions For businesses, public buildings and other larger electricity customers there might be need for more advanced equipment for DR interaction. When the DR includes flexible demand in MW-size there are relevant needs for more advanced control, metering and surveillance systems. Even the settlement of the savings or bonus need detailed information for those large customers. Private customers are seeking simple solutions. The information should be provided to existing platforms corresponding to the Smart Phone in a visual simple method like Red-Yellow-Green showing the relative price level the next hours ahead for either automated or manual response. Looking at the graph below from March 26 th 2014 in Denmark there are price variations from 150 to 800 DKK/MWh in the wholesale market. Graph supplied by EMD international

52 It is possible to send or broadcast the 24-hours wholesale market prices, after the gate closure on the power exchange, just as it is possible to broadcast the end consumer price including all tariffs and taxes. But is it the right thing to do? If your appliances are preprogramed to start or stop at a specific price there is a risk that there will be no change in the response if the price is within the same level for many hours. Consumers might then overwrite the system and turn heat on no matter what, if it is cold winter. The loss of comfort will reduce the DR. If the 24-hour prices are distributed into three groups of eight hours each, then there will be a (green) group of the eight hours with cheapest price, a (yellow) group of the eight hours having average price and a (red) group of the eight hours with the most expensive prices. All from a relative perspective and to enable DR even between hours in the same price level as long as there is just a slight difference. Dynamic tariffs and tax incentives To enhance a high DR response it has often been argued that the tariffs and the taxes should be designed in a way to amplify the level of price for the end consumer. If the wholesale market price is only a relatively small part of the end consumer price then the daily price variations are being damped by the high taxes and many tariffs. Tariffs. A tariff from the DSO or TSO should be covering the actual costs of operating the power system. Changes in the consumption or critical peak load situations might be avoided if the grid tariff is dynamic. Instead of having a flat rate tariff for all, it might be beneficial to design a grid tariff which is a mirror of the actual load in the grid. In hours of peak load the tariff might be multiplied by a factor 2, 3 or 4, and in hours of minor load the tariff could be multiplied by a factor 0, -1 or even -2. This will help a better distribution of the load in the grid. Such a system requires high quality measurements from the LV substations. The ADDRESS project has been testing such a system. See more in chapter Taxes. The taxation on electricity is just a way for the Government to ensure a fiscal contribution to the state budget. If the tax is converted from a fixed amount per kwh to a dynamic tax amplifying the consumer price then there is a risk of disrupting the power system. The power flow will be a result of the tax scheme and not a real picture of the situation of the system and power availability. Sometimes the wholesale price goes high se example above with 12,000 DKK/MWh. If tax is a percentage then it would amplify extreme prices to the disadvantage of those consumers with no flexible demand. And what happens in hours of 0-prices or even negative prices like below if the tax is a percentage? See a situation below. A modernization of the tax regimes for electricity is needed thus the challenges mentioned. The taxation of electricity should help the electrification of energy usage and promote DR solutions and at the same time there must be respect for the fact that tax also has a fiscal obligation to help the state budget. DR is going to be many products. For some of the new DR opportunities the tax issues might be a barrier for active participation. 52

53 Graph supplied by EMD international - Example 1: If DR is delivered from a storage facility for electricity (battery) then tax might be collected twofold. If electricity used for charging the battery is with full tax as normal consumption than another consumer is paying tax again for the same electricity once the battery is discharged! Demand response with multiple charging cycles will generate large tax revenue for the Government but no incentives for the owner of the DR properties to participate. Example 2: When commercial businesses are participating with DR then the bonus or compensated activation is an income for the company. If DR is coming from thousands of private homes and aggregated in the market then the question raised is: What kind of tax must the private family pay or should be collected by the aggregator? This could easily be a show stopper. Less is more The present market for balancing power has been designed for the primary purpose of enabling the TSO as single buyer to purchase services from traditional power plants and for them to compete about price and accessibility. The TSO has a legitimate request for online measurement and other technical handshake systems when the DR resource is a 600 MW power plant as spinning reserve. DR in the form of many aggregated small appliances is not relevant if they have to submit the same market codes as large power plants. The future calls for a power system based on stochastic and probabilistic operation rather than the historic deterministic approach. The development of DR and large scale deployment will meet fewer obstacles and barriers if new demonstration activities challenge the existing rules and guidelines for classic DR. The SEDC has even documented (see chapter 2.2) that DR is either impossible due to national regulation or prohibited. A European initiative and large scale demonstration should be initiated to revolve or remove these barriers. 53

54 7. Demand Response references Below, please find a list over reports used for this survey. For each report there is a web link to where the report is available for further studies. 7.1 List of reports and web links used for this survey The report is based on published reports and papers from different organizations and projects. Please note that some of the web links might change over time. # Report Web link 5 ENTSO-E, Demand Side Response, , final version 6 ENTSO-E Network Code on Demand Connection, , draft version 8 Framework Guidelines on Electricity Balancing, CEER Status Review on European Regulatory Approaches Enabling Smart Grids Solutions, A Demand Response Action Plan for Europe, Mapping Demand Response in Europe Today, April Creating the right environment for demand side response, Assessment of Achievable Potential from Energy Efficiency and Demand Response Programs in the U.S. ( ), January Green Button 17 Pacific Gas & Electric Company (PG&E) Smart Rate, September bates/demandresponse/cs/ National Grid 20 Demand Response in the UK Forward Thinking Markets 20 Demand Response Solutions & Virtual Power Systems, ebutler 22 FlexPower / 22 SEAS-NVE 23 The eflex Project, November 2012 and eflex :: Flexible elforbrug, Demand response in the strategic reserve, 14:29, July Prosumer with demand response, 13:59, May Market Based demand Response, April ex%20project-low.pdf ping/pages/eflex.aspxx ort.pdf Active Demand, The Future of Electricity, Results & Findings, From the Smart 54

55 Grids Model Region Salzburg, May upload/downloads/sgms_results_findings_ pdf 28 Cyber Grid 29 OpenADR, Enabeling The Standard for Automated Demand Response, JRC Smart Grid Projects Outlook , April Grid4EU, General Functional Requirements and specifications of joint activities in the Demonstrators, October Total Flex Taking Energy. From reactive to pro-active energy management, GreenCom 34 READY READY-varmepumper.html 35 Balance Regulation Group Demand side bidding in Regulation Power Market (RPM), DREAM, Danish Renewable Energy Aligned Market, ke%20dokumenter/el/demand%20side%20bidding %20in%20RPM% pdf 37 VPP4SGR - EcoSense ipower - FLECH Video: tastreams/file_e07c5ca0-d58b-48ee e3/content 39 EcoGrid EU 44 Smart Grid in Denmark 2.0, ske%20dokumenter/forskning/smart%20grid%20i n%20denmark%202.0.pdf 46 EMD graphs 55