Report on the Help-desk activities incl. FAQ list

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1 Development of sustainable heat markets for biogas plants in Europe Project No: IEE/11/025 Report on the Help-desk activities incl. FAQ list D4.5 April 2015

2 Authors: Tomas Vorisek, Bohuslav Málek, Energy Efficiency Center SEVEn, Czech Republic with contributions from all BiogasHeat partners Report No. D4.5 WP4, Task 4.4 The BiogasHeat project (Development of sustainable heat markets for biogas plants in Europe) is supported by the European Commission in the Intelligent Energy for Europe Programme. The sole responsibility for the content of this publication lies with the authors. It does not necessarily reflect the opinion of the European Union. Neither the EACI nor the European Commission is responsible for any use that may be made of the information contained therein. The BiogasHeat project duration is from April 2012 to April 2015 (Contract Number: IEE/11/025). BiogasHeat website: April / 17 SEVEn

3 Table of Contents 1 Introduction 4 2 General considerations on economic viability of BCs 4 1. Heat supply to external customers (by hot water piping or satellite CHP) 4 2. Drying solutions (for digestate or wood) 5 3. Additional power generation using OCR unit 5 4. Lowering own heat demand of biogas plant 5 3 Organization of the help desk 7 4 Specific questions and answers 8 5 Attachment: Templates for economic assessment of followed BCs 13 April / 17 SEVEn

4 1 Introduction This report summarizes the help-desk activities during the field test provided by project consortium to cooperation partners selected for development of most promising business case(s) within WP4 tasks. With cooperation partners, following heat use options were developed into a business case: Heat supply to external customers (5 BCs 2 Czechia, 1 Germany, 1 Latvia, 1 Italy) Wood drying (2 BCs 1 Austria, 1 Latvia) Digestate drying (1 BC Romania) ORC installation (2 BCs 1 Croatia, 1 Italy) Lowering own heat demand of biogas plant (1 BC Denmark) General considerations summarizing the experiences during the filed tests are summarized below in Chapter 2. Chapter 3 of this report shows the questions raised by cooperation partners and answers provided by the consortium. 2 General considerations on economic viability of BCs Generally speaking, for the correct assessment of the economic viability of business cases for effective heat utilization from existing or planned biogas plants, it is needful to carefully define following input parameters: Capital costs Technical parameters Annual energy flows Operation costs Assumptions for economic evaluation Based on the calculations carried out by each project partner for given business case, there were worked out templates featuring examples how properly assess the economic efficiency of model project cases for possible public use in future similar projects. There can be found attached and, below, there is a short description of each model project case, the assumptions used and conclusions which can be drawn from them. 1. Heat supply to external customers (by hot water piping or satellite CHP) Capital costs can differ significantly depending on the type of surface to be covered along the piping route and possible fees to be paid to institutions and to land owners (for their consent with piping installation). The exemplary calculation includes simplified approximation of pumping power and heat losses for pipe diameters around DN 100. Economic feasibility is significantly influenced by the volume of heat sold and the annual profile of supply (actual utilization of the piping capacity). The third critical aspect is the current heat price the prospective customer to whom heat from a biogas plant is to be supplied to. The experience is that heat from the biogas plant shall be priced a certain percentage (10-20 %) below the present variable part of the heating costs the customer has. The variable costs April / 17 SEVEn

5 compose primarily payments for fuel used, and, in some case, even its part (typically case for natural gas or electricity which is billed partly in fixed payments according to the connected capacity). Due to capital intensity, the maximum permissible lengths for heat pipelines may vary between 2 to 4 kilometres. For bigger lengths, then, establishing biogas pipeline and moving a biogas-based CHP unit closer to the heat demand is then a more economic option. 2. Drying solutions (for digestate or wood) Utilization of heat for digestate drying may be motivated by the intention to lower transport costs for its ultimate use as a fertilizer, as a way how to remove nitrogen, or to produce a combustible product biomass fuel. The permissibility of either of these solutions and their economic efficiency depend on national/local conditions. Generally speaking, however, the last option is seen as the environmentally recommendable option by the BiogasHeat Project only if the digestate is polluted excessively with heavy metals when, for example, comes from hazardous biowaste-type inputs. In some countries, to better economics may help the eligibility for CHP bonus (which should be accounted for into revenues). The resulting costs of digestate drying may be expressed per ton of dried product, per tonne of the removed product (liquid-phase) or per unit of lower heating value (MJ or MWh). In the last case, it should be also known, that for possible use as a fuel, further processing is usually needed granulation into pellets or briquettes which increase the total production costs further (and making it typically quite expensive opposed to other biomass-based fuels). Another reasonable option is to make use of disposable heat production from a biogas plant for drying of wooden biomass usable then as the input for e.g. pellet production or as better quality fuel (in the form of wood chips). 3. Additional power generation using OCR unit Eligibility as useful heat utilization again differs from country to country. Economic feasibility depends on actual pricing of electricity produced and on unit size of the biogas plant and disposable heat utilized in particular ORC modules. Typically, the ORC can use only about half of the heat energy available (high temperature portion coming from exhaust gases), but there also exist ORC technologies which use heat energy available from motor cooling water cycle. There are several types of ORC units offered by different manufacturers, but from each type there is mostly only one unit size available. Optimum implementation is only when the nominal capacity of the OCR module is fully utilized; at lower loading the payback period is much longer (it may vary from 5 to well over 10 years). In Croatia, two possibilities for ORC implementation were considered. The first one included upgrading ORC system to existing cogeneration unit, what would resulted in increased overall installed power and hence change in feed-in tariff. This option was evaluated as economically unfavourable, since it would result in the decrease revenues from electricity sales due to lower feed in tariff. The second option considered embedding of ORC into existing cogeneration unit contract (i.e. the overall electrical power would remain the same). In that case the feed-in tariff would remain the same, while the demand for maize silage as feedstock would be reduced resulting in significant economic advantage. Calculations showed that this option is economically viable with payback period of 8.5 years. Generally, the payback period depends on the cost of ORC technology and the cost of substrates for biogas production. 4. Lowering own heat demand of biogas plant The Danish company Bigadan A/S has developed, produced, installed and operated biogas digesters (and biogas plants) since more than 30 years. For most of this period, the main focus has been to optimize biogas production as well as electricity production through cogeneration, whereas in recent years there has been a shift towards the possibilities of April / 17 SEVEn

6 upgrading the biogas and injection into the natural gas grid. Little attention has been given to internal technical and design optimization. Discussions with Bigadan A/S have now led to the assumption that a considerable potential for optimization of internal heat consumption at Bigadan biogas plants might exist. Bigadan digester design involves uninsulated top and bottom, and it is thus considered relevant to model the consequences for the heat loss and thus the total energy balance - of the digesters, if insulation is applied; is it feasible to insulate existing/new digesters, and what would be the optimum thickness of the insulation and digester wall/top/bottom? Also, the set points and the operation of the heating system are to be checked, including heat exchangers and pasteurization tanks. Preliminary calculations suggest that internal heat consumption could be reduced by 10-20%; for Limfjordens Bioenergi Biogas Plant, reduction of internal heat consumption by 15% would correspond to app. 660MWh annually. Assuming that this heat instead could be sold to the local district heating grid, the payback time for the investment (calculated at Euro) would be less than two years. April / 17 SEVEn

7 3 Organization of the help desk Communication activities of the Help desk took place on 3 levels: Level 3 Advisory committee + external experts Level 2 Consortium (project) Level 1 Participating countries Questions Practically all questions came in on the national level in the participating countries. Most of these questions were also directly answered by project partners who are familiar with specific conditions in the national legislation and have experiences with the business environment in the country. Some questions were also discussed on the project level between the partners, such a exchanging information about the different national regulations, promising technical solutions and good practice examples successfully implemented in respective countries. Several specific, mainly technical questions were also consulted with the advisory committee and/or with external experts. Another opportunity to address BioasHeat helpdesk has been made available for external people by placing the help-desk in the Facebook. There are about 160 members of the BiogasHeat facebook page. Moreover the consultations were also given through LinkedIn. The role of the help desk and its performance in the project might be summarised as follows: The problem of efficient heat use from biogas plants at the first look might seem to be easy to handle because several general solutions (also provided and summarized in BiogasHeat handbook) exists. On the other hand, the questions arise only when real project implementation is started. So, BiogasHeat helpdesk was somewhere in-between these two steps. Answers to general questions were provided in WP3 (during feasibility checks) and summarized in the brochure (WP5), while answers to specific questions during heat use project implementation in field tests (WP4) are summarized in this report. April / 17 SEVEn

8 4 Specific questions and answers Czech Republic (SEVEn) Q1. Potential heat consumer is a public institution and a heat supply contract has to be awarded based on a public tender. How should they proceed and what criteria should be selected? The crucial criterion should be the heat price at the delivery point, which would typically be at the existing heat source of the client, i.e. at the end of hot water supply line. Participating in the tender might be, besides the biogas plant operator, also other potential heat providers such as new external firms offering operation of the current heat source (typically a natural gas fired boiler plant) as an outsourced service or investors of natural gas fired cogeneration unit. Competition of the latter can be eliminated by requiring in the tender requirements that the current level of local emissions (especially NO x ) must not be exceeded. Q2. Supply of heat from biogas plant to a district heating system requires a long term contract but the municipality cannot guarantee preserving the integrity of the system in the long term perspective. How can this problem be treated? The municipality should understand and explain to end-consumers of heat that the supply from a biogas plant will be a strong stabilization factors, because the heat price can be guaranteed in the long term perspective, as it depends mainly on initial investment costs (which are known in the start of contract) and not on unpredictable prices of fossil fuels. Q3. Heat supply to district heating would require some additional investments in the system to extend its lifetime and reliability. How could these costs be covered? Thanks to very low variable cost of heat from the biogas plant, the heat supplier can assume some additional responsibilities besides the installation of the connecting hot water line. These costs can be included in the offered heat price which can possibly be kept under the current level even with partial modernization of the system. Q4. What investment subsidies can be obtained for heat supply? The new operational program currently prepared in the Czech Republic includes a specific supported activity for heat supply from existing biogas plants. This subsidy can be up to 50% of eligible costs, depending on the type of applicant. Small companies like firms owning and operating biogas plants will be entitled to the highest relative subsidies. The heat supply contract should reflect the reduction of capital expenditure by the heat supplier and share the benefits also with the heat consumers (reduced heat price). Germany (WIP) Q5. What are the most important issues to be considered on the revenues from the sale of heat? Income may be earned through the sale of heat. Long-term heat supply (preferably more than 10 years) with the heat consumers should be planned. The supply type (base load or peak load supply) should be indicated in the contract. Proposals for the design of a heat supply agreement are provided in a report by Wagner R. (2010) Vorschläge für die Gestaltung eines Wärmeliefervertrages. Nr. V 8/2010. In addition to the heat supply contract, agreements with the land owners should be signed in order to being able to install new heat pipes. The heat should not be sold at zero cost to the heat consumers. There are different calculation models for the sale of heat. Costs for the heat consumers can be based on the fixed annual charge per household or on the energy consumption rate per kwh. April / 17 SEVEn

9 Q6. Is it economically feasible to install an ORC system for a 180 kw biogas plant? In general, the investment costs in an ORC system are quite high. According to the Biogas Forum Bavaria (2010), ORC plants are economically feasible if a biogas plant reaches at least 1 MW electrical output. According to another study by the Bavarian State Office for the Environment (2007), the ORC systems are economical only for biogas plants from 500 kwel. Investment costs for an ORC system are approximately 350,000. At the moment it seems that ORC system for small biogas plants is not economical, because the investment costs are too high. Q7. Is the heat transport in containers a promising technology? Currently there is still a lack of experience on the mobile heat containers, especially when combined with biogas plants. There is a BMU funded (Federal Ministry for the Environment) project on latent heat storage. LaTherm is storing heat in container systems and transports them by truck to heat consumers. However, various concepts and equipment suppliers recently faced economic problems. Croatia (EIHP) Q8. What are the impacts of ORC installation on feed-in tariff? Installation of an ORC unit to existing CHP unit operated at full load would increase the power supplied to grid. In Croatia it would require the necessary change in feed-in agreement with Croatian energy market operator (HROTE). The new feed-in tariff for subsidized electricity production would be reduced according to current feed-in tariff system. Q9. How can the design conditions of the ORC be optimized? ORC should be nested under the same feed-in range as the CHP is. Otherwise, feed-in tariff would be changed (i.e. reduced). In that case, ORC system should be designed in regards to the new optimal working point of CHP unit and the biogas plant. Q10. What would be the possible benefits of nested ORC implementation (i.e. under the same feed-in contract)? Decrease of feedstock needed for biogas plant (as well as everything related to this), prolonged working life of CHP unit, avoidance of possible cooling problems of CHP unit. Romania (MNG) Q11. What are the benefits of sludge drying for the WWTP The digestate from the WWTP biogas facilities has to be disposed at the landfills, as it is not allowed to be used for agriculture. The content of the water into the digestate varies a lot, but could reach even 80% in some cases. The routine is to use transport with containers from the WWTP to the nearest landfill station. This is incurring two main costs: transport and pay per ton. Both costs component are highly dependent on the content of the water in the digestate. Hence, the costs for digestate disposal could be reduced with an important percent. Secondly, the solid state digestate is easier to handle and dispose. Q12. What investment subsidies can be expected? One direction is the opening of the calls for structural funds that will probably occur in the fourth trimester of The opening of the calls for grants is conditioned by the finalisation of the national strategy and by the counter-signing of this by the EC. A second solution is a loan from the banks of investment funds. In the last year we observed an intense activity of different investment funds from Europe, interested to finance renewable energy projects, including biogas. April / 17 SEVEn

10 Q13. The law is not clearly stipulating if the third green certificate obtained for a MWh into a facility based on energy crops is allowing obtaining a forth certificate for high efficiency cogeneration. ANRE is aware of this lack in the legislation and is also in the measure to propose amendments to the law. We have stressed this problem and ANRE representative assured that they will undergo the necessary measures to the decision factors to remediate the problem. The problem lays not in the RES law, but in the technical norms under development at the main regulatory agency. Practical examples show that the process could be urged by the direct request/negotiations of the plant owner to/with the regulatory entity. Latvia (Ekodoma) Q14. What are the possible cooperation and financing models for delivery of heat from a biogas plant to municipality owned district heating system? There are several investment positions to be considered when a project of heat supply to a distant district heating system has to be implemented. If part of the heat or most of the heat is supplied to the district heating system, the investment in heat pipes and connection to the existing network, including measuring devices shall be made. One option is that connection costs are covered by the biogas plant. Usually biogas plant operators do not prefer this option because their main business is biogas production and not the operation of the district heating network (including the maintenance of the pipelines). Another option is that municipality invests in the district heating pipeline and takes over the maintenance of the new part of the heating grid. This option requires investments and brings in the risk of payback of the investments in case if heat supply from the biogas plant does not run properly. To minimize the burden of additional investment costs, the payback of this investment might be included in the form of reduction of the price of the supplied heat. The third option is to share investment costs between biogas plant and municipal district heating system. In that case the cost of the heat is first increased to cover the part of investment costs made by the biogas plant and once the investment has paid back, the price of the heat is decreased. Q15. If biogas plant is able to provide only the base-load of the heat demand of the district heating system, what are the options for securing peak load deliveries and minimizing costs and risks for the district heating system operator? Baseload and peak load management and supply shall be foreseen in the heat delivery contract between biogas plant and the district heating system operator (municipality). Peak loads can be covered by installation of additional heat sources either on site of the biogas plant or in the heating plant of the district heating system. In most of the cases it is not economically feasible to operate district heating plant for covering peak loads only (since the peak loads occur only few days in the year, but the running costs of the heating plant are present the whole time). Therefore the solution would be the installation of a peak boiler (e.g., wood chips boiler) at the biogas plant or sharing of the running costs between district heating system operator and the biogas plant in case if peak load management is done in the heating plant of the district heating system. Q16. How can the biogas plant gain trust of the district heating company for cooperation on heat supply The field test implemented in Nica (Latvia) has shown that trust is more important than economic considerations when it concerns public heat supply. A promising business model providing win-win solution for all parties has not been accepted by the municipal district heating company due to lack of the trust for the biogas plant operator. Building the trust between parties is a long term process. In the future, the biogas plant should prove that they are reliable partners and bring additional value for the local and regional development. The trust can be further strengthened by improving personal relations and by detailed description of risks and risk management strategy in a mutual memorandum of agreement. April / 17 SEVEn

11 Q17. What are the factors affecting the choice of the drying solution for a biogas plant? Biogas plant operators may opt for an installation of the dryer if there is no other feasible way for the utilization of heat in the vicinity of the biogas plant. In Latvia there are several types of dryers used in biogas plants drying in containers and drying cameras. The choice of the dryer depends on the product that will be dried. If biogas plant operator prefers drying wood construction material (e.g., wood boards), then it is better to choose a camera dryer where drying process parameters can be controlled more efficiently. If a biogas plant operator wants to be more flexible and go for several types of loose product drying (e.g., woodchips, grain, digestate), then it is better to choose drying in containers. Another factor that affects the choice of the drying solution is the investment cost and the size of the business that biogas plant wants to build around the drying facility. If drying is done only for own consumption (e.g., woodchips for own stoves, drying of digestate to decrease the transportation costs or use it as a bedding material in farm), then biogas plant operator will look for a cheap drying solution like drying in containers. If drying is sold as a service for external customers or the dried product is sold in the market, then biogas plant operator may look for more advanced drying technological solution and make additional investment in infrastructure (e.g., storage facilities). Austria (e7) Q18. What conditions have to be met for obtaining the CHP bonus in Austria The CHP-bonus in the amount of 0.02 EUR per kwh for electric energy will be granted only if the CPH plant is running with biogas only and the efficiency criterion of 0.6 is met (according to the CPH act / KWK-Gesetz, 8 Abs. 2). If other substrates than agricultural substrates are used, then the tariff will be decreased by 20%. In order to obtain a CHP bonus a significant fraction of the heat needs to be utilized. For instance, a 250 kw el biogas plant should provide a thermal degree of utilization of about 37%, beside the green power production. The efficiency criterion of 0.6. is calculated as follows. whereas: 2/3*W/B + E/B 0.6 W = quantity of heat (kwh), which is fed into the public heating grid, or used economically as process heat. B = total fuel input in kwh. E = quantity of electric energy (kwh), which is fed into the public power grid or metered at the generator terminal. Other than in Germany there is no positive list in Austria available, which shows efficient and, hence, eligible heat use options. However, aspired heat use and heat revenue streams have to be explained. Further information can be found here: ag.at/fileadmin/user_upload/dokumente/investitionsfoerderung/informationsblatt_kwk- Anlagen.pdf. Q19. Which wood drying solutions are preferable From BiogasHeat experiences within the frame of feasibility checks and the business case, it can be concluded that drying of wood chips in a container is the most preferable drying solution. This is due to several facts: Investment and running costs of containers are relatively cheap, in comparison with other drying solutions (e.g. feed-and-turn-dryer); Containers are relatively simple to install and operate; Containers can be moved and exchanged easily; April / 17 SEVEn

12 Containers can be seen as modules. If heat capacity increases (decreases) another module can be bought (sold); As most of the biogas plants are in remote areas, heat has to be used on-site. Therefore, wood chips have to be carried to the heat source. It is simple to receive wet wood chips in a foreseen container, connect the container to the heat tube for drying and carry the container with dried chips to the consumer. So a container with dried material can be exchanged with a container with wet material. Q20. How high is the heat price in Austria typically? Heat prices vary to a large extent. However, the heat price depends on the market fundamentals of demand and supply. As most of the biogas plants are placed in remote areas, both market demand and supply of waste heat from biogas plants might be limited. For the case that heat is utilized in a district heating network, a crucial factor is the differentiation in peak load (higher price) and base load (lower price). Price will also be low if the heat provider cannot give a guarantee that heat will be delivered all the time. The heat price also refers to the price of the competitive energy carrier and technology, in this case mostly natural gas. In order to provide a competitive price, the price for the use of a kwh waste heat must be below the price for a kwh heat made from gas. Experiences from BiogasHeat feasibility checks and business case show that there is a big range of heat prices on various local heat markets, which especially depends on the negotiation skills of the customer and the vendor. Denmark (DTI) Q21. How much heat is used at a biogas plant for process heating? It depends on a number of factors especially if the digester temperature is mesophilic (37-40 o C) or Thermophilic (50-55 o C), but also on the design of the components (digesters, heat exchangers, pasteurization facilities etc). In general, for plants larger than 50kWe, process heat consumption of up to 30-35% of the total heat production can be considered acceptable. Q22. Is it worthwhile considering optimizing the process heating? For existing plants, it may not be feasible to make large investments with the aim of reducing process heat consumption. However, if all biogas/heat/electricity from the plant can be sold, optimization should be at least considered. For new biogas plants, process heat optimization could be feasible in most situations, where heat production is utilized. Q23. Is there simple a way of calculating heat loss from digesters and possibly optimizing the process heat consumption? Yes. Within the BiogasHeat project, an easy-to-handle tool has been developed, which can determine heat loss form digesters. And it can simulate savings by for example increasing insulation thickness. Q24. Can additional insulation of existing digesters be economically viable and under which conditions? Putting insulation to existing digesters is especially relevant if the current envelope structures are not insulated and the energy savings can increase the actual heat supply from the biogas plant (the demand is larger than the current available capacity). Optimum solutions have to be found in each case. For the Limfjordens Bioenergi Biogas Plant the preliminary calculations suggest that internal heat consumption could be reduced by 10-20%; reduction of internal heat consumption by 15% would correspond to app. 660 MWh annually. Assuming that this heat instead could be sold to the local district heating grid, the payback time for the investment (calculated at Euro) would be less than two years. April / 17 SEVEn

13 5 Attachment: Templates for economic assessment of followed BCs 1.1.a Heat supply by hot water piping Exemplary economic assessment models Heat supply by hot water piping Capital costs k 1076 specific cost of HW piping installed /m route 240 route length km 4 piping costs k 960 additional fees (institutional, ownership rights etc.) k 96 additional technical equipment (pumps, HE) k 20 Nominal technical parameters nominal piping diameter (2 x DN) mm 100 nominal temperature diference K 25 nominal water velocity m/s 1,0 nominal water flow kg/s 7,85 nominal capacity of heat transport kwt 820 nominal pumping power kwe 9,24 nominal heat losses kwt 143 Annual energy volumes actual volume of heat sold MWh/a GJ/a corresponding to full load hours of pipe's capacity h/a electricity consumption of pumping MWh/a 68 heat losses MWh/a Operation costs k /a 123,20 Fixed costs k /a 117,79 Annuity of capital costs k /a 110,79 Maintenance&repair k /a 2,00 Staff k /a 5,00 Variable costs 5,41 electricity price (for self-consumption) /MWh 80 heat price at source (for heat losses) /MWh 0 Electricity costs k /a 5,41 Heat losses costs k /a 0 Specific costs per heat sold /MWh 30,80 fixed portion 29,45 variable portion 1,35 Competitive price of heat at supply side /MWh 33,33 April / 17 SEVEn

14 1.1.b Heat supply from a satellite CHP connected to biogas plant via gas piping Exemplary economic assessment models Raw biogas supply to distant CHP unit Capital costs k 1168 specific cost of gas piping installed /m route 80 route length km 8 piping costs k 640 additional fees (institutional, ownership rights etc.) k 128 additional technical equipment (blowers, gas cooling) k 100 additional installation costs for the distant CHP k 300 Nominal technical parameters nominal piping diameter (DN) mm 160 nominal gas velocity m/s 7,0 nominal gas flow m3/h 506 nominal heating capacity of transported gas kwt nominal power for blower and cooling kwe 4,00 Annual energy volumes actual volume of heat sold MWh/a GJ/a operation hours h/a electricity consumption (blowers, gas cooling) MWh/a 45 Operation costs k /a 135,86 Fixed costs k /a 132,26 Annuity of capital costs k /a 120,26 Maintenance&repair k /a 2,00 Staff k /a 10,00 Variable costs 3,60 electricity price (for self-consumption) /MWh 80 Electricity costs k /a 3,60 Specific costs per heat sold /MWh 33,97 fixed portion 33,07 variable portion 0,90 Competitive price of heat at supply side /MWh 33,33 April / 17 SEVEn

15 1.2.a Digestate drying (for possible use of dried digestate as solid fuel) Exemplary economic assessment models Digestate drying Capital costs k 200 belt dryer k 200 additional equipment k Nominal technical parameters input material rate kg/h 400 input dry matter % 25% output dry matter % 85% output material rate kg/h 118 electricity input kwe 27 heat consumption kwt 395 Annual material and energy balance operation hours hrs/a input material (separate) t/a output material t/a 353 electricity consumption MWh/a 81 heat consumption MWh/a Annual operation costs k /a 41,07 Fixed costs k /a 34,59 Annuity of capital costs k /a 20,59 Maintenance&repair k /a 4,00 Staff k /a 10,00 Variable costs 6,48 electricity price (for self-consumption) /MWh 80 heat price /MWh 0 electricity k /a 6,48 heat k /a Specific costs when used as a fertilizer (by farmer himself): Specific costs per unit of dried product /t 116,4 Specific savings due to lower transport costs 9,6 Net specific costs per unit of dried product /t 106,8 Specific costs with a goal to remove nitrogen from digestate: Specific costs per unit of removed nitrogen /t when considered, how many nitrogen is removed in drying process t 2,49 costs with condensation of ammonia in flue gases from digestate k /a drying 20 Net specific costs per unit of dried product /t ,7 Specific costs with a goal to use it as a fuel: Specific costs per heat in fuel /MWh 29,92 for: total heating value of produced fuel MWh/a when considered: unit lower heating value (LHV) kwh/kg 3,89 MJ/kg 14,00 Competitive price of solid biofuel /MWh 25,00 April / 17 SEVEn

16 1.3 Additional power generation using ORC unit Exemplary economic assessment models Additional power generation using OCR unit Capital costs k 260 ORC unit k 260 additional equipment k Nominal technical parameters net electric output (average, incl. savins at CHP) kwe 35 net electric efficiency 7% input heat rate (average) kwt 500 Annual energy volumes operation hours hrs/a net electricity supply MWh 263 waste heat consumption MWh/a Operation costs k /a 28,77 Fixed costs k /a 28,77 Annuity of capital costs k /a 26,77 Maintenance&repair k /a 2,00 Staff k /a 0,00 Variable costs 0,00 electricity price (for self-consumption) /MWh 80 heat price /MWh 0 electricity k /a 0,00 heat k /a Specific power generationcosts /MWh 109,60 fixed portion 109,60 variable portion 0,00 Revenues /MWh 36,75 basic feed-in tariff /MWh 140 additional bonus (as applicable) /MWh 0 total revenue for electricity k /a 36,75 Revenues minus operation costs (except annuity) 34,75 simple payback 7,48 April / 17 SEVEn

17 1.4 Optimization of internal heat consumption Exemplary economic assessment models Optimization of internal heat consumption Current heat production at biogas plant [MWh/y] Current heat utilization (incl. own technolgical consumption) [MWh/y] Amount of heat to be utilized by BC [MWh/y] Investment costs for BC realization (estimated or really incurred) [thous. EUR] 113 Structure of financing (planned or really made use of): [%] 100 own capital (of BP owner) [%] 100 invstment subsidy [%] 0 bank loan [%] 0 Additional operational costs for BP owner due to BC (estimated or real) [thous. EUR/a] 0 of which: repair and maintenance 0 personnel costs 0 inputs (e.g. electric energy for pumping, additional water etc.) 0 Debt service (if there is bank loan to be utilized for co-financing) [thous. EUR/a] 0 New revenues due to higher heat utilization (estimated) [thous. EUR/a] 68,2 Net income from BC for BP owner (estimated or incurred) [thous. EUR/a] 68,2 Simple pay-back period of BC [years] 1,7 April / 17 SEVEn

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