CA2511632A1 - Energy network - Google Patents
Energy network Download PDFInfo
- Publication number
- CA2511632A1 CA2511632A1 CA002511632A CA2511632A CA2511632A1 CA 2511632 A1 CA2511632 A1 CA 2511632A1 CA 002511632 A CA002511632 A CA 002511632A CA 2511632 A CA2511632 A CA 2511632A CA 2511632 A1 CA2511632 A1 CA 2511632A1
- Authority
- CA
- Canada
- Prior art keywords
- demand
- electricity
- availability
- electrolyser
- hydrogen
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 230000005611 electricity Effects 0.000 claims abstract 41
- 239000001257 hydrogen Substances 0.000 claims abstract 33
- 229910052739 hydrogen Inorganic materials 0.000 claims abstract 33
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims abstract 32
- 239000000446 fuel Substances 0.000 claims abstract 10
- 238000000034 method Methods 0.000 claims 26
- 238000003860 storage Methods 0.000 claims 8
- 230000003213 activating effect Effects 0.000 claims 5
- 238000004519 manufacturing process Methods 0.000 claims 4
- 230000003247 decreasing effect Effects 0.000 claims 3
- 238000005457 optimization Methods 0.000 claims 3
- 208000022361 Human papillomavirus infectious disease Diseases 0.000 claims 2
- 230000008696 hypoxemic pulmonary vasoconstriction Effects 0.000 claims 2
- 229910052987 metal hydride Inorganic materials 0.000 claims 2
- 150000004681 metal hydrides Chemical class 0.000 claims 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims 2
- 239000003245 coal Substances 0.000 claims 1
- 239000003344 environmental pollutant Substances 0.000 claims 1
- 229930195733 hydrocarbon Natural products 0.000 claims 1
- 150000002430 hydrocarbons Chemical class 0.000 claims 1
- 150000002431 hydrogen Chemical class 0.000 claims 1
- 125000004435 hydrogen atom Chemical group [H]* 0.000 claims 1
- 238000005259 measurement Methods 0.000 claims 1
- 239000003345 natural gas Substances 0.000 claims 1
- 231100000719 pollutant Toxicity 0.000 claims 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims 1
Classifications
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
- Y02E60/30—Hydrogen technology
- Y02E60/50—Fuel cells
Landscapes
- Supply And Distribution Of Alternating Current (AREA)
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
Abstract
An energy network is provided. An embodiment includes a network having a plurality of power stations and a plurality of loads interconnected by an electricity grid. The loads include electrolysers. The network also includes a controller that is connected to both the stations and the loads. The controller is operable to vary the available power from the power stations and/or adjust the demand from the electrolysers to provide a desired match of availability with demand and produce hydrogen as a transportation fuel with specific verifiable emission characteristics.
Claims (49)
1. An energy network comprising:
a plurality of electricity generating stations;
a plurality of variable power loads connected to said generating stations by a grid; and, a controller connected to said grid and operable to adjust demand from said power loads to approach a match of said demand with an availability of power from said generating stations.
a plurality of electricity generating stations;
a plurality of variable power loads connected to said generating stations by a grid; and, a controller connected to said grid and operable to adjust demand from said power loads to approach a match of said demand with an availability of power from said generating stations.
2. The network of claim 1 further comprising at least one generating station having a variable availability such that said controller is operable to adjust availability from said generating station to match said demand.
3. The network of claim 2 further comprising a data network connected to said controller, said network providing additional information about said demand and said availability to said controller and which is used by said controller to determine whether to adjust at least one of said demand and said availability to approach a match there between.
4. The network of claim 3 wherein said match is based at least in part on determining which of a plurality of adjustments produces a reduced amount of harmful emissions in comparison to another adjustment.
5. The network of claim 3 wherein said match is based at least in part on determining which of a plurality of adjustments has a least amount of financial cost in the marginal cost required to produce electricity.
6. The network of claim 3 wherein said variable power loads include at least one water electrolyser for converting electricity into hydrogen.
7. The network of claim 6 wherein said electrolyser has a known schedule of production.
8. A controller for an energy network having a plurality of electrical generating stations and a plurality of power loads connected to said generating stations by a grid, said controller comprising a processor having a plurality of programming instructions operable to adjust demand from said power loads to match said demand with an availability of power from said generating stations.
9. The controller of claim 8 wherein said network further includes at least one generating station having a variable availability such that said processor is operable to adjust availability from said generating station to match said demand.
10. The controller of claim 9 wherein said network further includes a data network connected to said controller, said network providing, additional information about said demand and said availability to said controller and which is used by said controller to determine whether to adjust at least one of said demand and said availability to approach a match there between.
11. The controller of claim 9 wherein said match is based at least in part on determining which of a plurality of adjustments produces a reduced amount of harmful emissions in comparison to another adjustment.
12. The controller of claim 9 wherein said match is based at least in part on determining which of a plurality of adjustments has a least amount of financial cost in the marginal cost required to produce electricity.
13. The controller of claim 9 wherein said variable power loads include at least one electrolyser for converting electricity into hydrogen.
14. The controller of claim 13 wherein said electrolyser has a known schedule of production.
15. An electrolyser for receiving electrical power from a grid and for converting electricity into hydrogen, said electrolyser including a means to, report a demand for electricity needed to generate hydrogen at said electrolyser to a controller connected to said grid, such that when said demand is reported to said controller, said controller is operable to adjust availability of power from said grid to meet said demand based on said reported demand.
16. The electrolyser of claim 15 wherein said grid includes a plurality of electrical generating stations and said controller is operable to increase availability from a selected one of said generating stations to match said demand.
17. The electrolyser of claim 16 wherein said electrical generating stations include at least one of a nuclear power plant, a coal fired power plant, a natural gas power plant, a wind farm, a solar power farm, a hydroelectric dam, and a hydrogen cell for converting hydrogen to electricity.
18. The electrolyser of claim 16 wherein said match, is based at least in part on determining which of a plurality of adjustments produces a reduced amount of harmful emissions from at least one of said generating stations in comparison to another adjustment.
19. The electrolyser of claim 18 further comprising a means for determining a fee charged for HPVs obtaining fuel from said electrolyser, said fee being determined at least in part based on a cost associated with said emissions.
20. The electrolyser of claim 19 wherein said fee is based on a fuel tax-exemption based on fuel having emission characteristic better than a pre-defined profile of an existing fuel for existing vehicles that consume substantially the same amount of energy as said HPVs.
21. The electrolyser of claim 15 wherein said match is based at least in part on determining which of a plurality of adjustments results in a least amount of financial cost in the marginal cost of electricity required to produce hydrogen from said electrolyser.
22. The electrolyser of claim 15 wherein said demand is based on a known schedule of production.
23. A method of transferring hydrogen comprising the steps of:
converting, at a first location, a predefined quantity of hydrogen into electricity;
introducing said electricity into a electricity grid;
notifying a second location of a quantity of said electricity;
drawing, at said second location, said quantity of electricity from said grid; and, converting, at said second location, said drawn quantity of electricity into hydrogen.
converting, at a first location, a predefined quantity of hydrogen into electricity;
introducing said electricity into a electricity grid;
notifying a second location of a quantity of said electricity;
drawing, at said second location, said quantity of electricity from said grid; and, converting, at said second location, said drawn quantity of electricity into hydrogen.
24. A method of transferring hydrogen comprising the steps of:
receiving at a first hydrogen storage station a request to transfer hydrogen to a second storage station;
converting a predefined quantity of hydrogen into electricity corresponding to said request;
introducing said electricity into an electricity grid.
receiving at a first hydrogen storage station a request to transfer hydrogen to a second storage station;
converting a predefined quantity of hydrogen into electricity corresponding to said request;
introducing said electricity into an electricity grid.
25. A method of generating hydrogen comprising the steps of:
receiving at a hydrogen storage station a notification that a predefined quantity of electricity has been introduced into an electricity grid connected to said hydrogen storage station;
drawing, of said hydrogen storage station, said quantity of electricity from said grid; and, converting, at said hydrogen storage station, said drawn quantity of electricity into hydrogen.
receiving at a hydrogen storage station a notification that a predefined quantity of electricity has been introduced into an electricity grid connected to said hydrogen storage station;
drawing, of said hydrogen storage station, said quantity of electricity from said grid; and, converting, at said hydrogen storage station, said drawn quantity of electricity into hydrogen.
26. A method of controlling an energy network comprising the steps of:
receiving demand information representing an amount of electricity in demand by at least one electrical load, said at least one electrical load including an electrolyser for converting electricity into hydrogen;
receiving availability information representing an amount of electricity availability from at least one electrical generating station; and, adjusting operation of said at least one of electrical load and said at least one electrical generating such that said demand information and said availability information approach a match there between.
receiving demand information representing an amount of electricity in demand by at least one electrical load, said at least one electrical load including an electrolyser for converting electricity into hydrogen;
receiving availability information representing an amount of electricity availability from at least one electrical generating station; and, adjusting operation of said at least one of electrical load and said at least one electrical generating such that said demand information and said availability information approach a match there between.
27. The method of claim 26 wherein said adjusting step comprises the steps of:
determining if said demand exceeds said availability, in which case performing the steps of:
(i) increasing availability if additional availability is available;
(ii) decreasing said demand if said availability is not available;
determining if said availability exceeds said demand, in which case performing the steps of:
(i) increasing demand if additional demand is available;
(ii) decreasing availability if additional demand is not available.
determining if said demand exceeds said availability, in which case performing the steps of:
(i) increasing availability if additional availability is available;
(ii) decreasing said demand if said availability is not available;
determining if said availability exceeds said demand, in which case performing the steps of:
(i) increasing demand if additional demand is available;
(ii) decreasing availability if additional demand is not available.
28. The method of claim 26 wherein said availability information includes a cost associated with producing electricity and said adjusting step includes a determination of a desired cost optimization based on said cost and a decision whether to adjust availability or demand based 'on said cost optimization.
29. The method of claim 28 wherein said cost is determined based on a marginal cost of electricity to produce hydrogen.
30. The method of claim 28 wherein said cost is determined based on an emission cost associated with producing electricity.
31. The method of claim 28 wherein said cost is determined based on a emission cost associated with the application using hydrogen produced by said electrolyser.
32. The method of claim 31 wherein said application is a hydrogen powered vehicle and said emission cost is determined based on at least one of a) associating a emission cost associated with a non-hydrogen vehicle with a emission profile generated by a power station producing electricity for said electrolyser and b) comparing said emission cost with forms of hydrogen generation other than said electrolyser.
33. The method of claim 26 wherein said at least one electrical load additionally includes a set of conventional loads.
34. The method of claim 26 wherein said at least one generating station includes a first power station having an availability profile that is substantially fixed and a second power station having an availability profile that is substantially random.
35. The method of claim 34 wherein when electricity from said second power station is available and if said availability exceeds said demand then at said operating step said demand from said electrolyser is increased.
36. The method of claim 34 wherein when electricity from said second power station is unavailable and if said demand exceeds said availability then at said operating step said demand from said electrolyser is decreased.
37. The method of claim 34 wherein said first power station is a nuclear power station and said second power station is a wind farm.
38. The method of claim 26 wherein said electrical load includes a plurality ("K") of electrolysers and said demand is based at least in part on the following:
TotalElectricPowerDemandOfElectrolysers(t) =
.SIGMA.~=1(RateOfFuelProduction k (t) ×
SpecificEnergyConsumptionForHydrogenProductionAtStation k (t)) wherein .SIGMA.~=1RateOfFuelProduction k (t) = TotalRateOfHydrogenProduction(t) where K = number of electrolysers; and t = time.
which is in balance with power supplied by captive power sources, J in number, and available power from the grid:
TotalElectricPowerDemandOfElectrolysers(t) =
.SIGMA.~=1PowerForElectrolysisFromCaptivePowerSource j (t) +
PowerForElectrolysisFromGrid(t) where J = number of captive generators; and t = time.
such that over a predefined period the following requirements are met, acting as constraints to RateOfFuelProduction and the optimization process:
FuelAvailableInStation k (t + .DELTA.t) = FuelInventory k (t) +
(RateOfFuelProduetion k (t) -RateOfFuelConsumption k (t)) × .DELTA.t >= CustomerDemandForFuelAtStation k (t + .DELTA.t, FuelSellingPrice) <= MaximumStorageCapacityOfStation k where t = time.
TotalElectricPowerDemandOfElectrolysers(t) =
.SIGMA.~=1(RateOfFuelProduction k (t) ×
SpecificEnergyConsumptionForHydrogenProductionAtStation k (t)) wherein .SIGMA.~=1RateOfFuelProduction k (t) = TotalRateOfHydrogenProduction(t) where K = number of electrolysers; and t = time.
which is in balance with power supplied by captive power sources, J in number, and available power from the grid:
TotalElectricPowerDemandOfElectrolysers(t) =
.SIGMA.~=1PowerForElectrolysisFromCaptivePowerSource j (t) +
PowerForElectrolysisFromGrid(t) where J = number of captive generators; and t = time.
such that over a predefined period the following requirements are met, acting as constraints to RateOfFuelProduction and the optimization process:
FuelAvailableInStation k (t + .DELTA.t) = FuelInventory k (t) +
(RateOfFuelProduetion k (t) -RateOfFuelConsumption k (t)) × .DELTA.t >= CustomerDemandForFuelAtStation k (t + .DELTA.t, FuelSellingPrice) <= MaximumStorageCapacityOfStation k where t = time.
39. The method of claim 26 wherein said demand information is based at least in part on a measured amount of stored hydrogen fuel available at said electrolyser, said measured amount being based at least one of a) pressure, temperature, volume in compressed storage tanks and b) pressure, temperature, volume, mass of metal hydride in metal hydride hydrogen gas storage.
40. The method of claim 26 wherein said availability information includes at least one of a type of emission created by each power station, a type of fuel used by each power station, an efficiency rating for each power station, and a response time for deactivating or activating each power station.
41. The method of claim 26 wherein said availability information includes one or more types and quantities of emission produced per unit of electricity produced for each power station.
42. The method of claim 41 wherein said power station burns hydrocarbons and said types and quantities of emissions includes a measurement in mass of emitted CO2, NO, CO per kWh of electricity produced by said power station.
43. The method of claim 42 wherein said demand information includes an emission penalty associated with that load and said adjusting step is made at least in part by adjusting availability at one of said power stations having a reduced amount of pollutants produced per kWh in relation to another one of said power stations.
44. The method of claim 26 wherein said demand information includes at least one of a type for each load, and whether an emission penalty is associated with that type of said load.
45. The method of claim 26 wherein said demand information for an electrolyser includes an amount of hydrogen currently being stored at said electrolyser and a consumption forecast for said stored hydrogen.
46. An energy network comprising:
a plurality of generating stations;
a plurality of power loads connected to said generating stations by a grid, said power loads including at least one electrolyser;
a fuel cell connected to at least one of said electrolysers for converting hydrogen back into electricity for reintroduction to said grid; and, a controller connected to said grid and operable to adjust demand from said power loads to approach a match of said demand with an availability of power from said generating stations, wherein said adjustment of availability includes activating said fuel cell for delivery of electricity to said grid.
a plurality of generating stations;
a plurality of power loads connected to said generating stations by a grid, said power loads including at least one electrolyser;
a fuel cell connected to at least one of said electrolysers for converting hydrogen back into electricity for reintroduction to said grid; and, a controller connected to said grid and operable to adjust demand from said power loads to approach a match of said demand with an availability of power from said generating stations, wherein said adjustment of availability includes activating said fuel cell for delivery of electricity to said grid.
47. An energy network comprising:
a plurality of generating stations;
a plurality of power loads connected to said generating stations by a grid, said power loads including at least one electrolyser; and, a controller connected to said grid and operable to adjust demand from said power loads to approach a match of said demand with an availability of power from said generating stations, wherein said adjustment of demand includes activating one or more of said electrolysers to absorb excess availability from said generating stations.
a plurality of generating stations;
a plurality of power loads connected to said generating stations by a grid, said power loads including at least one electrolyser; and, a controller connected to said grid and operable to adjust demand from said power loads to approach a match of said demand with an availability of power from said generating stations, wherein said adjustment of demand includes activating one or more of said electrolysers to absorb excess availability from said generating stations.
48. A method of increasing, stability in an electricity grid comprising the steps of:
receiving demand information representing a change in the amount of electricity in demand by at least one conventional electrical load connected to said grid;
receiving availability information from a plurality of electrical generating stations connected to said grid representing a potential instability in adjusting said availability from said generating stations to accommodate said change;
absorbing a decrease in demand causing said instability by activating at least one electrolyser connected to said grid; and, absorbing a decrease in availability causing said instability by activating at least one fuel cell or turning down one electrolyser connected to said grid.
receiving demand information representing a change in the amount of electricity in demand by at least one conventional electrical load connected to said grid;
receiving availability information from a plurality of electrical generating stations connected to said grid representing a potential instability in adjusting said availability from said generating stations to accommodate said change;
absorbing a decrease in demand causing said instability by activating at least one electrolyser connected to said grid; and, absorbing a decrease in availability causing said instability by activating at least one fuel cell or turning down one electrolyser connected to said grid.
49. A method of controlling an energy network comprising the steps of:
receiving demand information representing an amount of electricity in demand by at least one electrical load, said at least one electrical load including an industrial electrolyser for converting electricity into hydrogen;
receiving availability information representing an amount of electricity availability from at least one electrical generating station; and, instructing said industrial electrolyser to reduce production of hydrogen based on said availability information being less than said demand information according to an interuptibility contract.
receiving demand information representing an amount of electricity in demand by at least one electrical load, said at least one electrical load including an industrial electrolyser for converting electricity into hydrogen;
receiving availability information representing an amount of electricity availability from at least one electrical generating station; and, instructing said industrial electrolyser to reduce production of hydrogen based on said availability information being less than said demand information according to an interuptibility contract.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2511632A CA2511632C (en) | 2004-01-23 | 2004-10-07 | Energy network |
Applications Claiming Priority (6)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002455689A CA2455689A1 (en) | 2004-01-23 | 2004-01-23 | System for controlling hydrogen network |
| CA2,455,689 | 2004-01-23 | ||
| US10/890,162 | 2004-07-14 | ||
| US10/890,162 US20050165511A1 (en) | 2004-01-23 | 2004-07-14 | Energy network |
| CA2511632A CA2511632C (en) | 2004-01-23 | 2004-10-07 | Energy network |
| PCT/CA2004/001806 WO2005071815A1 (en) | 2004-01-23 | 2004-10-07 | An energy network using electrolysers and fuel cells |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2511632A1 true CA2511632A1 (en) | 2005-08-04 |
| CA2511632C CA2511632C (en) | 2011-02-22 |
Family
ID=34890685
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2511632A Expired - Lifetime CA2511632C (en) | 2004-01-23 | 2004-10-07 | Energy network |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA2511632C (en) |
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2013128023A3 (en) * | 2012-03-02 | 2013-11-21 | Wobben Properties Gmbh | Method for operating a combined cycle power plant, and combined cycle power plant |
| WO2013177700A1 (en) * | 2012-05-28 | 2013-12-05 | Hydrogenics Corporation | Electrolyser and energy system |
| CN114139830A (en) * | 2021-12-10 | 2022-03-04 | 国网浙江省电力有限公司经济技术研究院 | Optimal scheduling method and device for intelligent energy station and electronic equipment |
| WO2023089184A1 (en) * | 2021-11-22 | 2023-05-25 | Catagen Limited | Fluid processing system for renewable energy power supplies |
| CN116861627A (en) * | 2023-05-29 | 2023-10-10 | 河海大学 | Optimal dispatching method for electric power-traffic network carbon demand response considering hydrogen fuel automobile |
-
2004
- 2004-10-07 CA CA2511632A patent/CA2511632C/en not_active Expired - Lifetime
Cited By (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2013128023A3 (en) * | 2012-03-02 | 2013-11-21 | Wobben Properties Gmbh | Method for operating a combined cycle power plant, and combined cycle power plant |
| EP3968483A1 (en) | 2012-03-02 | 2022-03-16 | Wobben Properties GmbH | Method for operating a combined cycle power plant, and combined cycle power plant |
| US10435800B2 (en) | 2012-05-28 | 2019-10-08 | Hydrogenics Corporation | Electrolyser and energy system |
| US10214821B2 (en) | 2012-05-28 | 2019-02-26 | Hydrogenics Corporation | Electrolyser and energy system |
| US11268201B2 (en) | 2012-05-28 | 2022-03-08 | Hydrogenics Corporation | Electrolyser and energy system |
| WO2013177700A1 (en) * | 2012-05-28 | 2013-12-05 | Hydrogenics Corporation | Electrolyser and energy system |
| US11761103B2 (en) | 2012-05-28 | 2023-09-19 | Hydrogenics Corporation | Electrolyser and energy system |
| WO2023089184A1 (en) * | 2021-11-22 | 2023-05-25 | Catagen Limited | Fluid processing system for renewable energy power supplies |
| GB2628493A (en) * | 2021-11-22 | 2024-09-25 | Catagen Ltd | Fluid processing system for renewable energy power supplies |
| CN114139830A (en) * | 2021-12-10 | 2022-03-04 | 国网浙江省电力有限公司经济技术研究院 | Optimal scheduling method and device for intelligent energy station and electronic equipment |
| CN114139830B (en) * | 2021-12-10 | 2024-06-14 | 国网浙江省电力有限公司经济技术研究院 | Optimal scheduling method and device for intelligent energy station and electronic equipment |
| CN116861627A (en) * | 2023-05-29 | 2023-10-10 | 河海大学 | Optimal dispatching method for electric power-traffic network carbon demand response considering hydrogen fuel automobile |
| CN116861627B (en) * | 2023-05-29 | 2024-05-14 | 河海大学 | Optimal dispatching method for electric power-traffic network carbon demand response considering hydrogen fuel automobile |
Also Published As
| Publication number | Publication date |
|---|---|
| CA2511632C (en) | 2011-02-22 |
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| EEER | Examination request |