Hydrogen Fuel Station Power to Gas
Standard kits / different sheets in that excel 8 products are ready now
Main government Pipe line grid and tank offer 5 x fcl 40 foot 100 Hm3/h fuel maker + 1 mw generator
Smaller farms Pipe line grid and tank 3 x 40 fcl 100 Hm3/h Fuel maker + 500 kw generator
Basic Just generator 2 x 40 Fcl 100 Hm3/h Fuel maker + 500 kw generator
Small Business Pipeline grid tank 1 x 40 fcl 100 Hm3/h Fuel maker 300 kw Generator
Note we have sizes in between 10 Hm3/h to 100Hm3/h but we should just have 2 clear categories first
Small Business 3 x 20 fcl 10 Hm3/h Fuel maker 230 kw Generator
Basic Pipe line grid 2 x 20 FCL 10 Hm3/h Fuel maker 50 kw Generator Roof top, gas to floors of building fuel cells
Baby 1 x 20 Fcl 10 Hm3/h Fuel maker 25 kw Generator Prepper Kit/ alternate generator fuel cell or tank filling.
Less size not worth while yet I have some things on it but they are basically CHP units and better to sell in 1000 pc with gas grid.
Bigger possible but it is green field factory kit minimum 1000 Hm2/h in size sent in pcs to assemble with our engineers.
Makes Buying Power to Gas unit Affordable and easy to unsderstand.
If however you want to go through all the data it is here for you.
We can Supply Engineers to install or design as required to any scale or number.
Units are Already in Fast Deploy kit form ready to connect and cival survey can be done.
H2 Fuel Station Production Case Study Documentation
Download supporting documentation for H2A Production case studies to learn more about model development, analysis parameters, and results. Documents will be added as new production case studies are posted.
Central and Forecourt Polymer Electrolyte Membrane (PEM) Electrolysis
Fuel Station units are
40 foot containers using 520 kw/hr dc productin 99.9% pure h2 at 16 bar 100cm3/hr direct to grid pipe or engines
no compressor or psa required.
Fuel Station Maker H2 Production Analysis
New Releases 2015
H2 Central Hydrogen Production Model, Version 3.1
H2 Distributed Hydrogen Production Model, Version 3.1
The Hydrogen Analysis production models provide transparent reporting of process design assumptions and a consistent cost analysis methodology for the production of hydrogen at central and distributed (forecourt/filling-station) facilities. Required input to the models includes capital and operating costs for the hydrogen production process, fuel type and use, and financial parameters such as the type of financing, plant life, and desired internal rate of return. The models include default values, developed by the team, for many of the input parameters, but users may also enter their own values. The models use a standard discounted cash flow rate of return analysis methodology to determine the hydrogen selling cost for the desired internal rate of return.
Version 3.1 of the models was released in 2015 and includes the following updates and corrections:
Added 2013 reference and high price cases; added 2014 reference case for feedstock and utility prices; and updated forecasts beyond 2040
Updated price indexes for GDP deflator, plant cost, labor cost, and chemical price until 2013
Corrected hydrogen compression loss ratio for distributed cases
Corrected depreciation calculation
Implemented automatic cash flow calculation replacing buttons
Implemented new tornado charts and added waterfall plots
Updated CSD cash flow analysis to be consistent with production cash flow analysis for distributed cases
Added equivalent prices of feedstock and utility.
Version 2.1 of the central and distributed H2 models was released in September 2008. Version 3.0 of the models was released in 2012, and included the following enhancements compared with the previous version:
Enhanced usability and functionality, including more intuitive and accessible plant scaling
Updated default reference year (2007) for cost calculations, which users can change easily
Updated energy price projections
Improved technical and financial assumptions and calculations.
The two H2 production models (central and distributed) and copies of all technology case studies are available free through this site. Registration is required. Choose from the links below to download the new versions, technology case studies, and documentation.
H2 production models
Central and forecourt production technology case studies
Forecourt (Distributed) Electrolysis
H2 Delivery Analysis
Hydrogen delivery is an essential component of any future hydrogen energy infrastructure. Hydrogen must be transported from the point of production to the point of use and handled within refueling stations or stationary power facilities. The scope of hydrogen delivery includes everything between the production unit (central or distributed) and the dispenser at a fueling station or stationary power facility.
In order to begin the task of hydrogen analysis, the H2 Analysis Group has developed three H2 delivery models: Delivery Carriers Components, Delivery Scenarios Analysis, and Refueling Station Analysis. All models follow the H2A approach to economic parameters, transparency, color coding, and model layouts.
The following H2 delivery analysis tools are available through this site.
H2 Delivery Components Model User's Guide (PDF 2.2 MB)
H2 Delivery Carrier Components Overview Version 1.0 (PDF 405 KB)
H2 Current (2010) Delivery Scenario Analysis Model (HDSAM) Version 2.3 (Excel 8.2 MB)
H2 Future (2020) Delivery Scenario Analysis Model (HDSAM) Version 2.3.1 (Excel 8.2 MB)
H2 Delivery Scenario Analysis Model (HDSAM) Version 2.0 User's Manual (PDF 597 KB)
H2 Refueling Station Analysis Model (HRSAM) Version 1.1 (Excel 2.4 MB)
All H2 delivery models contain macros that are necessary for proper operation. Because Microsoft Excel has a macro security option (to either accept or deny macros), your computer needs to be configured for these macros to run. Macro security needs to be set at either medium or low.
If you are running Excel 2003 with a medium security setting, a dialog box asking if you want to run macros will appear each time you open a spreadsheet that contains macros (such as the H2 Delivery Models). With a low security setting, the macros will be allowed to run automatically. In Excel 2007 with a medium security setting, a shield will appear at the top of the screen each time you open the models. You must click on "options" and "enable content" for the macros to run. To access the Excel macro security option, use the following menu tree: Tools > Macros > Security.
Overview of H2 Delivery Analysis
There are three broad delivery pathways: gaseous hydrogen delivery, cryogenic liquid hydrogen delivery, and novel solid or liquid hydrogen carriers. The liquid and gaseous pathways transport pure hydrogen in its molecular form via truck or pipeline. A carrier is a material that carries hydrogen in a form other than free hydrogen molecules. Carrier pathways transport hydrogen via truck or pipeline and require the return of spent fuel for reprocessing.
To date, H2 delivery analysis has focused on liquid and gaseous pathways using currently available technologies. Future analysis will investigate emerging and longer-term options for hydrogen delivery. Detailed, comprehensive analysis of the potential cost and performance of future delivery technologies and systems will be required to better understand their advantages and disadvantages for both the transition to and long-term use of hydrogen as a major energy carrier.
H2 Delivery Components Model
In H2 delivery analyses, hydrogen delivery is defined as the complete set of equipment and processes used to move hydrogen from the point of production (larger central plant or small distributed production unit) to the nozzle of a dispenser. The feedstock, scale, and process used to produce hydrogen are outside the bounds of delivery; so too is the operation of the hydrogen-fueled vehicle.
Within the bounds of the delivery system, hydrogen is conditioned to permit bulk transport as a compressed gas or as a liquid; shipped via a bulk transport mode (e.g., transmission pipeline or truck) to a terminal where it may be further conditioned, stored, or transferred to a local distribution mode; and delivered to a refueling station where it is dispensed onto vehicles.
The H2 Delivery Components model focuses on components required to deliver liquid hydrogen or compressed hydrogen gas from a central production plant or distributed production unit to the nozzle of the dispenser. At this point, novel storage and delivery technologies, such as hydrogen carriers, are not modeled. The components that are modeled in Version 2.0 of the tool are listed below.
Truck—compressed hydrogen gas tube trailer (2700 psi)
Truck—liquid hydrogen tanker
Compressor (single-stage or multi-stage units)
Bulk Storage Components
Compressed gas tube
Bulk liquid tank
Transmission/Distribution Interface Components
Pipeline to gas terminal (with either geologic or liquid storage for plant outages and demand surges)
Pipeline to liquid terminal (with either geologic or liquid storage for plant outages and demand surges)
"Pure" liquid H2 terminal (with either geologic or liquid storage for plant outages and demand surges)
"Pure" gaseous H2 terminal (with either geologic or liquid storage for plant outages and demand surges)
Refueling Station Components
Daily storage (either in low-pressure vessels or as components of cascade charging system)
Integrated Refueling Station
Gaseous (containing integrated compressor, cascade compression/dispensing, and storage)
Liquid (containing integrated storage, vaporizer, and cascade compression/dispensing)
The model is written as a Microsoft Excel spreadsheet with a separate tab for each of the delivery components. The model calculates the cost contribution of each component within the delivery infrastructure to the $/kg cost of delivering hydrogen. This cost contribution is based on inputs provided by the user describing the amount of hydrogen to be delivered and basic capital and operating costs for the component.
Version 2.0 contains default values that represent currently available (2005) technologies and costs. These parameters can be changed by the user to simulate advancements in technology and changes in other costs.
Using the H2 Delivery Carriers Components Model
Hydrogen carriers have been under intense investigation for their potential to meet the DOE on-board storage goals. Potential alternative hydrogen carriers include metal hydrides, chemical hydrides, high-surface-area carbon sorbents, and liquid-phase hydrocarbons. While these alternative hydrogen carriers have the potential to provide on-board storage, they may also be used to improve the efficiency and cost of hydrogen delivery to refueling stations. Certain hydrogen storage technologies may not meet all of the requirements for use on-board vehicles but may be viable for hydrogen delivery because delivery components have less restrictive requirements than on-board storage regarding their volumetric and gravimetric capacity.
A hydrogen carriers' model was developed in Microsoft Excel to evaluate the cost associated with various carriers' delivery pathways. It serves as a tool to examine the cost of components associated with different pathways (liquid truck, solid-state truck, pipeline, etc) in which various carriers can be used for hydrogen delivery, to establish which components contribute significantly to the delivery cost, and to provide ranges for the characteristics of each component. The model has been developed in the H2A tools format and incorporates many of their features. The model contains macros that are necessary for proper operation.
H2 Delivery Scenarios Analysis Model
Like other H2-developed tools, the Hydrogen Delivery Scenario Analysis Model (HDSAM) uses an engineering economics approach to cost estimation. For a given scenario (discussed below), a set of "components" (e.g., compressors, tanks, tube trailers, etc.) is specified, sized, and linked into a simulated delivery system or pathway infrastructure. Financial, economic, and technological assumptions are then used to compute the levelized cost of those components and their overall contribution to the delivered cost of hydrogen. Version 2.0 contains default values that represent currently available (2005) technologies and costs and current population and infrastructure characteristics. These parameters can be changed by the user to simulate advancements in technology and changes in other costs or relevant characteristics.
As in the H2 Delivery Components model, hydrogen delivery is defined to include the entire process of moving hydrogen from the gate of a central production plant onto a vehicle. Thus, delivery includes all transport, storage, and conditioning (e.g., compression, liquefaction, or for hydrogen carriers, hydrogenation/reprocessing of spent material) from the outlet of a centralized hydrogen-production facility to and including a refueling station that compresses, stores, and dispenses the hydrogen. Hydrogen delivery could also include compression, storage, and dispensing of hydrogen produced on site at a forecourt (e.g., distributed production). The current version of HDSAM (V2.0) does not model distributed production scenarios or hydrogen carrier pathways. Future versions of the model will include these options.
HDSAM draws upon the engineering economics calculations in the H2 Delivery Components Model. In effect, many of the "component" spreadsheets (or tabs) within the Delivery Components Model are embedded in HDSAM, which links them into appropriate combinations to define a delivery pathway, size the individual components consistent with a scenario's demand estimate, and calculate the cost associated with delivering a given quantity of hydrogen via the specified pathway.
The user defines a scenario by selecting a market type (e.g., urban, rural interstate, or a combination of the two); specifying its size, location (either a generic urbanized area of defined population or any of over 400 urbanized areas contained in a drop-down menu), and the market penetration of hydrogen-fueled vehicles in the total population of light-duty vehicles; selecting delivery modes for bulk transport from a production facility to a city gate and for local distribution; specifying a type of storage for plant downtimes and surge demands; and indicating a desired refueling station size.
Market size can vary from an urbanized area of 50,000 people to one of over 20 million people, and from an interstate highway segment of 10 mi. to 300 mi. (1000 mi. for pipeline delivery). Market penetration can vary from 1% to 100%. Bulk transport can be via gaseous tube trailer, liquid hydrogen truck, or gaseous pipeline. Local distribution is generally via the same mode; however, for bulk transport via pipeline, local delivery may also be accomplished by any other mode.
Storage for plant outages and surge demands can be in geologic formations or as liquid hydrogen, and refueling stations can range from 50 kg to 6000 kg of hydrogen dispensed per day. Thus, delivery scenarios are combinations of (a) markets, (b) market penetrations, (c) delivery modes, (d) downtime storage, and (e) refueling station size, with an associated set of assumptions about market demand and infrastructure.
In reality, however, delivery scenarios are even more variable. The user can define a scenario further by changing such default values as the distance from a central production facility to the edge of the urban area, the average fuel economy of hydrogen and conventional light-duty vehicles, the city's rates of motorization (e.g., vehicles per person) and vehicle utilization (e.g., miles driven per vehicle per year), financial assumptions, and the characteristics and cost of any component in the delivery pathway.
Within HDSAM, user selection of a delivery mode invokes an associated chain of delivery "components" or processes required to satisfy market demand. For example, if the user selects liquid hydrogen truck delivery (with liquid storage for plant downtimes and demand surges) for a given market, penetration rate, and refueling station size, the model calculates not only the number and cost of the trucks required to deliver the fuel to refueling stations, but also the cost of appropriately-sized liquefiers, pumps, vaporizers, dispensers, truck loading facilities, and storage vessels at terminals and refueling stations. Collectively, these steps or "components" are known as a pathway.
The figure below illustrates three broad liquid hydrogen pathways contained in Version 2.0 of the model. Note that because delivery is broken down into bulk transmission and local distribution—each of which can be by a different mode—loading, conditioning, and storage activities normally associated with a terminal or depot can be located anywhere between the production plant and the city gate. In Pathway 1, they are co-located with production; in Pathways 2 and 3, they are at the city gate.
Version 2.0 of the model contains a revised demand profile that is used to calculate average and peak demand. Storage needs are computed to satisfy peak summer demand (e.g., the first five minutes of the peak hour of the peak day) as well as scheduled maintenance and other plant downtimes. Equipment sizing versus storage needs is optimized within the model—that is, components are sized so that their total cost (capital and operating cost of equipment and associated storage) is minimized.
H2 Refueling Station Analysis Model
Researchers at Argonne National Laboratory (ANL) have developed the Hydrogen Refueling Station Analysis Model (HRSAM), which calculates the cost of hydrogen refueling as a function of various fueling station capacities and design configurations. HRSAM is an abbreviated version of HDSAM that focuses solely on near term refueling station costs.
HRSAM incorporates the significant design aspects of refueling stations, including the size and cost of capital equipment, and the costs of operation and maintenance. Default values for model inputs are based on early market data, but they can be modified by a user to evaluate different refueling options. Station design parameters that are particularly significant to operators are highlighted in a separate easy-to-use interface; these parameters include annual projections of station utilization, the number of hoses a station has, the number of consecutive fills a station can complete, and the modes of hydrogen delivery the stations accepts. Users can also specify economic inputs, such as rate of return and debt-to-equity ratio.
Using discounted cash flow analysis, HRSAM then outputs the annual and cumulative cash flows, cost of refueling per kilogram of hydrogen, years required to break even on investment, total capital investment, and land area a given station requires.
Fuel Cell Power Analysis
FCPower Model New Releases
Molten carbonate fuel cell, version 2.0
Phosphoric acid fuel cell, version 2.0
Solid oxide fuel cell, version 2.0
The Fuel Cell Power (FCPower) Model is a financial tool for analyzing high-temperature, fuel cell-based tri-generation systems. It uses a discounted cash flow rate of return methodology to determine the cost of delivered energy, and it quantifies energy inputs/outputs and greenhouse gas emissions.
Tri-generation systems provide onsite-generated heat and electricity to large stationary end users (e.g., office complexes) and produce hydrogen that can be used for fueling vehicles or stored and later converted to electricity. These systems can play an important role in early fuel cell markets by lowering hydrogen production costs, enabling distributed hydrogen production, lowering fossil energy use and greenhouse gas emissions, reducing electricity transmission congestion, lowering capital investment risk, and providing backup power functionality.
Version 2.0 of the FCPower Model was released in September 2012 and includes the ability to analyze three fuel cell technologies: molten carbonate, phosphoric acid, and solid oxide. Compared with the previous version, version 2.0 features enhanced usability, expanded functionality, and updated technical and financial assumptions. In addition, the solid oxide fuel cell analysis is available for the first time in version 2.0. An updated user guide includes technical and modeling details for each fuel cell technology as well as case studies for each technology's application in a hypothetical large hotel in Los Angeles.
Choose from the links below to download the three versions of the FCPower Model and user guide. Each version of the model includes an analysis of a tri-generation system for a large hotel in Los Angeles. These analyses can be used as starting points for new analyses.
Downloading the models is free, but registration is required.
FCPower Model, molten carbonate fuel cell, version 2.0 (Excel 14.7 MB)
FCPower Model, phosphoric acid fuel cell, version 2.0 (Excel 14.8 MB)
FCPower Model, solid oxide fuel cell, version 2.0 (Excel 14.8 MB)
FCPower Model user guide, version 2
Well-to-Wheels Case Studies for Hydrogen Pathways
The ultimate goal is for hydrogen to be produced and delivered utilizing several feedstocks, processing methods, and delivery options at a variety of scales ranging from large central production to very small local (distributed) production, depending on what makes the most economic and logistical sense for a given location. These parameters and the technological impact on key strategic issues, such as petroleum use and greenhouse gas emissions, were examined for several hydrogen pathways with hydrogen fuel cell vehicles (FCVs) through a well-to-wheels analysis and compared to current (2005) gasoline internal combustion engines and hybrid vehicles.
The case studies provided below include several potential options for hydrogen production and delivery.
Two time frames are examined for the hydrogen cases:
The "current" cases represent 2005 technology in the laboratory; however, this technology has not been validated at full scale.
The "future" cases examine 2015 potential technology for distributed production of hydrogen at refueling stations and 2030 central hydrogen production options.
Projected costs are presented for the hydrogen FCV cases.
The hydrogen production and delivery analyses presented here utilize the H2A production and delivery model approach and tools. In some cases, the results differ slightly from the targets in the Hydrogen Program Posture Plan; this is due to differences in the assumptions used. A significant attempt was made to document all the major assumptions used in the case studies. Continuing analysis will be conducted to revise, refine, and expand these preliminary calculations.
For the central hydrogen production cases, two delivery technologies are analyzed:
For the current cases, it's assumed that the hydrogen is liquefied and transported by cryogenic liquid trucks to the forecourt station. At the station, it's stored and then vaporized under pressure and dispensed as a high pressure gas to the FCV. The cost of hydrogen delivery used for the current central hydrogen production cases is $3.50/gge of hydrogen. This includes liquefaction, truck transport, and forecourt operations. This is based on the H2A delivery scenario.
For the 2030 future cases, it's assumed that a hydrogen pipeline infrastructure is available to transport the hydrogen to the forecourt. The hydrogen is first compressed from its assumed production pressure of 300 psi to a pipeline pressure of 1,000 psi. At the forecourt it's further compressed, stored, and charged as a high pressure gas to the FCV at a 5,000 psi fill. The cost of hydrogen delivery used for the future central hydrogen production cases is $1.00/gge of hydrogen. This includes compression, pipeline transport, and forecourt operations of compression, storage, and dispensing. This is based on the Hydrogen Program's targeted cost for hydrogen delivery technology.
Note: All costs are expressed in real 2005 dollars.
Well-to-Wheels Case Studies
Centralized Hydrogen Production from Solar
Distributed Hydrogen Production from Solar
Distributed Hydrogen Production from Geothermal
Centralized Hydrogen Production from GeoThermal
Distributed Hydrogen Production from HydroPower
Centralized Hydrogen Production from HydrogenPower
Power to gas (often abbreviated P2G) is a technology that converts electrical power to a gas fuel. There are currently three methods in use; all use electricity to split water into hydrogen and oxygen by means of electrolysis.
In the first method, the resulting hydrogen is injected into the natural gas grid or is used in transport or industry.
The second method is to combine the hydrogen with carbon dioxide and convert the two gases to methane (see natural gas) using a methanation reaction such as the Sabatier reaction, or biological methanation resulting in an extra energy conversion loss of 8%. The methane may then be fed into the natural gas grid.
The third method uses the output gas of a wood gas generator or a biogas plant, after the biogas upgrader is mixed with the produced hydrogen from the electrolyzer, to upgrade the quality of the biogas.
Impurities, such as carbon dioxide, water, hydrogen sulfide, and particulates, must be removed from the biogas if the gas is used for pipeline storage to prevent damage.
Power-to-gas systems may be deployed as adjuncts to wind parks or solar-electric and Battery Bank Power generation. Or Even deployed to Main Power Grid in Strategic locations.
The excess power or off-peak power generated by wind generators or solar arrays may then be used at a later time for load balancing in the energy grid. Stored as a Gas.
Before switching to natural gas, the German gas networks were operated using towngas, which for 50-60 % consisted of hydrogen.
The storage capacity of the German natural gas network is more than 200,000 GW·h which is enough for several months of energy requirement.
By comparison, the capacity of all German pumped storage power plants amounts to only about 40 GW·h.
The storage requirement in Germany is estimated at 16GW in 2023, 80GW in 2033 and 130GW in 2050. The transport of energy through a gas network is done with much less loss (<0.1%) than in a power network (8%).
The storage costs per kilowatt hour are estimated at €0.10 for hydrogen and €0.15 for methane.
The use of the existing natural gas pipelines for hydrogen was studied by the EU NaturalHy project and US DOE.
The blending technology is also used in HCNG.
In 2015 a study published in Energy and Environmental Science found that by using reversible solid oxide electrochemical cells and recycling waste heat in the storage process a round-trip efficiency electricity to electricity of more than 70% can be reached at low cost.
Power to hydrogen
In this method, electricity is used to split water into hydrogen and oxygen by means of electrolysis.
The resulting hydrogen is injected into the natural gas grid or is used in transport or industry. Secure Supplies very compeditive equipment solutions using alkaline process. No Compressor or psa is required to make fuel purity 99.9% at 16 Bar pressure. 100cm3.hr at
520 kw per hr power use. Lead time is 60 days to loading in 40 fcl shipping container.
Examples of this cutting edge technology being used today.
In March 2013 a Thüga Group project, supplied a 360 kW self-pressurising high pressure electrolysis rapid response PEM electrolyser Rapid Response Electrolysis Power-to-Gas energy storage plant.
The unit produces 125 kg/day of hydrogen gas and incorporates AEG power electronics.
It will be situated at a Mainova AG site in the Schielestraße, Frankfurt in the state of Hessen.
The operational data will be shared by the whole Thüga group – the largest network of energy companies in Germany with around 100 municipal utility members.
The project partners include: badenova AG & Co. kg, Erdgas Mittelsachsen GmbH, Energieversorgung Mittelrhein GmbH, erdgas schwaben GmbH, Gasversorgung Westerwald GmbH, Mainova Aktiengesellschaft, Stadtwerke Ansbach GmbH, Stadtwerke Bad Hersfeld GmbH, Thüga Energienetze GmbH, WEMAG AG, e-rp GmbH, ESWE Versorgungs AG with Thüga Aktiengesellschaft as project coordinator.
Scientific partners will participate in the operational phase. It can produce 60 cubic metres of hydrogen per hour and feed 3,000 cubic metres of natural gas enriched with hydrogen into the grid per hour.
An expansion of the pilot plant is planned from 2016, facilitating the full conversion of the hydrogen produced into methane to be directly injected into the natural gas grid.
Secure Supplies Fuel Maker generates hydrogen to be directly injected into the gas network as Power to Gas.
And Can be Power from Power grid or by renewable power sources at 520 kw dc per hr.
In December 2013, a Power to Gas Unit , Mainova, and NRM Netzdienste Rhein-Main GmbH began injecting hydrogen into the German gas distribution network P2G Power to gas ON demand hydrogen unit, which is a rapid response electrolyser plant.
The power consumption of the electrolyser is 315 kilowatts.and is using more power than the Secure Supplies unit.
It produces about 60 cubic meters per hour of hydrogen and thus in one hour can feed 3,000 cubic meters of hydrogen-enriched natural gas into the network. This is also less than the 100 cm3.hr the Secure Supplies Product produces. Which is aprox 5000 cubic meters of hydrogen -enriched natural gas into the network.
On August 28, 2013, a Fuel Maker P2G , Solvicore, and Swissgas inaugurated a commercial power-to-gas unit in Falkenhagen, Germany. The unit, which has a capacity of two megawatts, can produce 360 cubic meters of hydrogen per hour.
The plant uses wind power and and several 2 + Power to Gas units ( electrolysis equipment) to transform water into hydrogen, which is then injected into the existing regional natural gas transmission system.
Swissgas, which represents over 100 local natural gas utilities, is a partner in the project with a 20 percent capital stake and an agreement to purchase a portion of the gas produced.
A second 800 kW power-to-gas project has been started in Hamburg/Reitbrook district and is expected to open in 2015.
In August 2013, a 140 MW wind park in Grapzow, Mecklenburg-Vorpommern ,received an electrolyser.
The hydrogen produced can be used in an internal combustion engine or can be injected into the local gas grid.
The hydrogen compression and storage system stores up to 27 MWh of energy and increases the overall efficiency of the wind park by tapping into wind energy that otherwise would be wasted.
The electrolyser produces 210 Nm3/h of hydrogen and is operated by RH2-WKA.
In January 2011, Secure Supplies Hydrogen,a international certified engineering and warrantied power to gas vendor.Producing quality Australian and USA made Hydrogen Fueling equipment,Hydrogen Fueled Engines and Hydrogen Home /Business Solar fuel cell Kits entered the market. Project's deploying are focused on value adding renewablesolar /wind /geothermal/hydropower power investments.
Value adding Sites to produce a Hydrogen fuel gas and transfer storage gas to forecourt vending stations.
Secure Supplies value adds all solar wind, geo thermal and hydropower projects. Enabling Businesses and groups of renewable owners to achieve a higher ROI, to produce hydrogen gas grids to fuel industry and a variety of applications emission free.
End users include Port Operators, Farms, Green Community residential development or and Renewable power operators. Gas is sold to gas grid or transported and used to fuel fixed engines or fuel cell that run 24r to pump water or make power for business and communities projects.
Hydrogen Equipment along with Engineering and Service provision makes Secure Supplies is well positioned to supply key markets globally.
The INGRID project started in 2013 in Apulia, Italy. It is a four-year project with 39 MWh storage and a 1.2 MW electrolyser for smart grid monitoring and control.
The hydrogen is used for grid balancing, transport, industry, and injection into the gas network.
The surplus energy from the 12 MW Prenzlau Windpark in Brandenburg, Germany will be injected into the gas grid from 2014 on.
The 6 MW Energiepark Mainz from Stadtwerke Mainz, RheinMain University of Applied Sciences, Linde and Siemens in Mainz (Germany) will open in 2015.Power to gas and other energy storage schemes to store and utilize renewable energy are part of Germany's Energiewende (energy transition program).
Grid injection without compression
The core of the system is a proton exchange membrane (PEM) electrolyser. The electrolyser converts electrical energy into chemical energy, which in turn facilitates the storage of electricity.
A gas mixing plant ensures that the proportion of hydrogen in the natural gas stream does not exceed two per cent by volume, the technically permissible maximum value when a natural gas filling station is situated in the local distribution network.
The electrolyser supplies the hydrogen-methane mixture at the same pressure as the gas distribution network, namely 3.5 bar.
Secure Supplies is a Plug and PLay equipment vendor
we can supply engineers on site to aid install.
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