METHOD FOR GENERATING ELECTRICAL AND / OR MECHANICAL ENERGY FOR A CONSUMER SYSTEM AND ASSOCIATED PRODUCTION SYSTEM

Description

[0001] The present invention relates to a method for producing electrical and / or mechanical energy for a consumer system, according to the preamble of claim 1.

[0002] A “consumer system” is, for example, a network, an installation and / or equipment capable of receiving electrical and / or mechanical energy and consuming it.

[0003] The power generated by the production system is, for example, electrical power. The consumer system is then advantageously an electrical network, in particular of a fluid production facility, in particular of an offshore hydrocarbon production facility.

[0004] Alternatively, the electrical network is that of an industrial installation, or / and a group of individuals or / and businesses.

[0005] Alternatively, the electricity grid is an interconnected national or transnational network.

[0006] Alternatively, the generated power is mechanical power. The consumer system is a rotating system of an industrial installation, in particular a compressor or a pump, especially in a fluid production installation.

[0007] Combustion turbines are used to produce electrical and / or mechanical energy in many industrial applications, notably for their good efficiency, compactness, reliability, ability to be relatively easily operated and maintained, operational flexibility and competitive costs.

[0008] Firstly, these turbines are flexible due to the nature of the fuel they are capable of burning, namely liquid (diesel, fuel oil, ammonia, etc.) or gaseous (hydrogen, natural gas, biomass gas, etc.).

[0009] These turbines also offer operational flexibility when the power required by the installation varies significantly over time.

[0010] This is particularly the case in fluid production installations, in which peaks in electrical demand and load shedding by the installation's electrical network are likely to occur over time.

[0011] Furthermore, in these installations, the average electrical power required over time varies significantly between the start and end of their operation.

[0012] Furthermore, when the electricity network is partially supplied by renewable energy sources, combustion turbines are able to supplement or supplement the production of renewable energy, when environmental conditions make this production insufficient for the needs of the installation.

[0013] When designing and sizing a power generation system with combustion turbines, the maximum electrical power required by the electricity grid is usually predefined.

[0014] A power generation unit (PGU) comprising a plurality of combustion turbines is then provided, with a dimensioning adapted so that the combustion turbines at their full load power are capable of providing the maximum electrical power required. The efficiency of the gas turbines is maximum when used at full load.

[0015] However, during the life of the installation and also depending on climatic conditions, the turbines operate rather at partial load, and rarely at full load.

[0016] This leads to adverse consequences, since the partial load operation of combustion turbines significantly degrades efficiency.

[0017] The fuel consumption required for power generation is therefore increased, and consequently, the generation of greenhouse gases in the case of fossil fuels.

[0018] To partially overcome this problem, it is known from the article "Proceedings of ECOS 2020, The 33rd International Conference on Efficiency, Cost Optimization Simulation and Environmental Impact of Energy Systems", June 29 - July 3 2020 Osaka, Japan" to increase the temperature of the inlet gases in the combustion turbine compressor at low load, in order to improve efficiency.

[0019] However, there remains a need to optimize the operation of the power generation unit over the entire range of electrical power that it is capable of providing.

[0020] US7065953, US2010 / 0146981 and EP2733318 describe other methods and systems for producing energy comprising turbines fed with gas by a combustion chamber.

[0021] An aim of the invention is to provide, while limiting investment, an energy production method, using a power generation unit comprising at least one combustion turbine, in which energy production is carried out with lower carbon gas emissions.

[0022] For this purpose, the invention relates to a method according to claim 1.

[0023] The method according to the invention may comprise one or more of the characteristics of claims 2 to 9 or the following characteristic, taken in isolation or in any technically possible combination: it includes a preliminary step of determining defined site conditions, and of defining and / or calculating the predefined maximum required electrical and / or mechanical power to be supplied to the consumer system under the defined site conditions.

[0024] The invention also relates to a system for producing electrical and / or mechanical energy intended for a consumer system according to claim 10.

[0025] The system according to the invention may comprise one or more of the features of claims 11 to 15.

[0026] The invention will be better understood by reading the following description, given solely by way of example, and made with reference to the appended drawings, in which: [ Fig 1 ] there figure 1 is a schematic view of a first energy production system according to the invention; [ Fig 2 ] there figure 2is a diagram illustrating the implementation of the system of the figure 1 with multiple combustion turbines; [ Fig 3 ] there figure 3 is a view of a graph illustrating strategies for controlling the cooling of the air flow introduced into the combustion turbine, in the implementation of the method according to the invention; [ Fig 4 ] there figure 4 is a comparison of the yields obtained between a state-of-the-art process and a process according to the invention; [ Fig 5 ] there Figure 5 is a view of a graph illustrating an example of an electrical power demand required by an electrical network over time; [ Fig 6 ] there figure 6is a view illustrating the percentage of load developed by the power generation unit of a power generation system according to the state of the art and of a power generation system according to the invention with respect to the defined electrical power of the site as a function of time, to meet the demand for electrical power illustrated in the Figure 5 ; [ Fig 7 ] there figure 7 illustrates the efficiency over time of a state-of-the-art power generation system, in comparison with a power generation system according to the invention, in response to the electrical power demand illustrated in the Figure 5 .

[0027] An energy production method according to the invention is implemented in an energy production system 10 shown schematically in the figures 1 And 2 .

[0028] In this example, the energy produced by the production system 10 is electrical energy, intended to be supplied to an electrical energy consuming system, such as an electrical network 12. Alternatively, as will be described below, the energy produced by the production system 10 is mechanical energy intended for a mechanical energy consuming system, in particular within a fluid exploitation installation.

[0029] In this example, the method is intended to produce electrical energy to supply an electrical network 12 requiring electrical power to operate equipment.

[0030] The electrical network 12 is, for example, an electrical supply network for a fluid exploitation installation, or more generally for an industrial installation. Alternatively, the electrical network is a network intended to supply electricity to individuals and / or businesses, or on an interconnected national or transnational network.

[0031] The electrical network 12 requires at all times the supply of electrical power which is generated by the production system 10.

[0032] In particular, the electrical network 12 is configured to require from the production system 10, under defined site conditions in temperature, pressure, and advantageously humidity, a predefined maximum required site power Pmax, which is used to design the electrical energy production system 10.

[0033] The predefined maximum required site power Pmax at the defined site conditions is advantageously calculated during the design of the production system 10, from the characteristics of the electrical network 12 and the utilities connected to it.

[0034] The defined site conditions or "site rated conditions" are advantageously those defined in API 616 and API RP11 PGT standards. They are previously determined during the design of the installation, based on the meteorological and atmospheric conditions on the site.

[0035] The defined site temperature conditions are, for example, a maximum temperature encountered at the installation and / or an average temperature encountered at the installation, these temperatures being advantageously defined at the turbine inlet.

[0036] The defined site pressure conditions are, for example, a minimum and / or maximum atmospheric pressure encountered at the installation, and / or an average atmospheric pressure encountered at the installation, these pressures being advantageously defined at the turbine inlet and / or at the turbine outlet.

[0037] The defined site humidity conditions are for example a maximum humidity encountered at the installation level, and / or an average humidity encountered at the installation level, these humidities being advantageously defined at the turbine inlet.

[0038] Defined site conditions are, for example, the ambient design conditions used in engineering.

[0039] For example, a power generation unit installed on a floating support off the coast of Nigeria, in the Gulf of Guinea, for example, can be sized taking into account the following site conditions: sea ​​level pressure varying between 0.9989 bar a and 1.017 bar a; ambient temperature varying between 18.9°C and 33.7°C; relative humidity varying between 46.23% and 92.96%.

[0040] The predefined maximum site power Pmax is then calculated at the following defined site conditions: pressure = 0.9989 bar a; temperature = 30°C; relative humidity = 92.96%.

[0041] The defined site conditions are generally recorded in the design files of the installation 10. They are sometimes communicated to the governmental authorities in the regulatory files attached to the production system 10.

[0042] The power demanded by the electrical network 12 from the production system 10 over time is therefore between zero power, in the event of a total shutdown of the turbines and takeover by emergency generators, a predefined standby power for the electrical network 12, and the predefined maximum electrical power required Pmax of the site, under the defined site conditions mentioned above.

[0043] In reference to the figure 1 , the energy production system 10 comprises a power generation unit 14, comprising at least one combustion turbine 16, the power generation unit 14 being capable of producing, under defined site conditions, a defined site power Pn lower than the predefined maximum required site power Pmax for the electrical network 12.

[0044] The energy production system 10 further comprises a heat exchange system 18, capable of cooling or heating an air flow 20 intended to supply the or each combustion turbine 16, and a control system 22, capable of enabling the control of the heat exchange system 18 and of the or each gas turbine 16, to control the temperature of the gas flow circulating within each gas turbine 16.

[0045] In reference to the figures 1 And 2 , the power generation unit 14 comprises at least one combustion turbine 16, preferably several parallel combustion turbines 16.

[0046] The number of combustion turbines 16 is generally between 1 and 10, for example between 3 and 8. A higher number of combustion turbines 16 can be provided for installations requiring more electrical power.

[0047] Each combustion turbine 16 is capable of generating, under defined site conditions, a defined site power Pnt, resulting from its construction.

[0048] The defined site power or “site rated power” is advantageously defined in the API 616 and API RP 11 PGT standards or is the “in situ power” defined in the ISO 3977-2 standard, at site conditions.

[0049] According to the invention, the sum of the defined site powers Pnt capable of being generated by each of the turbines 16 under the defined site conditions, which constitutes the defined site power Pn of the power generation unit 14, is less than the maximum required power Pmax predefined under the defined site conditions.

[0050] For example, the defined site power Pn capable of being generated by the power generation unit 14 under the defined site conditions is between 70% and 90%, advantageously between 75% and 85% of the maximum required power Pmax predefined for the electrical network 12 under the defined site conditions.

[0051] Each combustion turbine 16 is a gas turbine. Each combustion turbine 16 comprises a compressor 30, intended to compress the incoming air flow 20, to produce a compressed air flow 32, a combustion chamber 34, adapted to allow the mixing of the compressed air flow 32 with a fuel, and the combustion of the fuel in the combustion chamber 34 to produce a turbine feed flow 36.

[0052] The combustion turbine 16 further comprises a dynamic expansion turbine 38, capable of receiving the turbine feed flow 36 and dynamically expanding it to produce an expanded flow 40.

[0053] The combustion turbine 16 also comprises a shaft 42 driven in rotation by the dynamic expansion turbine 38, and a generator 44 having a rotor driven in rotation by the dynamic expansion turbine 38 via the shaft 42. In this example, the compressor 30 is also mounted on the same shaft 42.

[0054] In particular, the combustion turbine 16 comprises a single shaft 42 having a constant rotational speed.

[0055] Advantageously, to ensure control of the flow rate of the compressed air flow 32 supplied to the combustion chamber 34, the compressor 30 comprises a plurality of guide vanes 46 for the air flow 20, defining between them a variable opening VIGV%. The variable opening VIGV% of the guide vanes 46 controls the flow rate of the air flow 20 admitted into the compressor 30.

[0056] The combustion chamber 34 is connected to a fuel source 48 via a fuel injection flow rate adjustment valve 50. The quantity of fuel injected into the combustion chamber 34 is thus adjustable by controlling the valve 50.

[0057] The fuel present in source 48 and injected into the combustion chamber is preferably natural gas.

[0058] The generator 44 comprises a rotor driven in rotation by the shaft 42, and a stator. It is capable of producing electrical power, which is transmitted to the electrical network 12 by an electrical connection.

[0059] The electrical power generated by the generator 44 depends in particular on the quantity of incoming air flow 20 introduced into the compressor 30, on the inlet temperature CIT of the air flow 20 in the compressor 30, on the quantity of fuel injected into the combustion chamber 34 which influences the turbine inlet temperature TIT of the turbine feed flow 36.

[0060] The heat exchange system 18 is capable, when the power required by the electrical network 12 is greater than the defined site power Pn at the defined site conditions, of cooling the air flow 20 to reduce the inlet temperature CIT in the compressor 30.

[0061] The heat exchange system 18 is, on the contrary, suitable for heating the air flow 20, in the case where the power required by the electrical network 12 is lower than the defined site power Pn at the defined site conditions, to increase the inlet temperature CIT in the compressor 30.

[0062] To this end, advantageously, the heat exchange system 18 comprises at least one heat exchanger 60A, 60B, capable of allowing contactless heat exchange between an initial air flow 62, intended to form the air flow 20, and respectively a cooling current 64, connected to a cold source 66, and a heating current 68, connected to a hot source 70.

[0063] Alternatively (not shown), the heat exchange system 18 is capable of mixing the initial air flow 62 with a hot fluid or with a cold fluid to heat or cool the air flow 20 introduced into the compressor 30.

[0064] In this purely illustrative example, the heat exchange system 18 comprises two separate heat exchangers 60A, 60B connected in series.

[0065] Alternatively, the exchangers 60A, 60B are mounted in parallel or are replaced by a single heat exchanger putting the streams 64, 68, and the flow 62 into heat exchange relation.

[0066] The cold source 66 is for example an absorption cooler, capable of producing by absorption the cooling current 64 from a hot flow coming from the hot source 70. The absorption cooler is for example a water / LiBr type cooler.

[0067] The hot source 70 is for example a source of a fluid heated by the expanded flow 40 coming from the dynamic expansion turbine 38. In one embodiment, the expanded flow 40 enters into a heat exchange relationship with a current intended to be heated within the hot source 70. As a variant, the expanded flow 40 is used directly to constitute all or part of the heating current 68.

[0068] The control system 22 comprises, for example, at least one computer comprising a memory containing software modules, and a processor capable of executing the software modules present in the memory.

[0069] The control system 22 is capable of controlling the power generation unit 14, and the heat exchange system 18 to supply the electrical network 12 with the electrical power required at all times.

[0070] It is suitable for receiving, from the electrical network 12, information on the electrical power required at each instant by the electrical network 12.

[0071] The control system 22 is connected to sensors for measuring the compressor inlet temperature CIT, the opening VIGV% of the blades 46 and the calculated turbine inlet temperature TIT.

[0072] It is also connected to a system for controlling the opening of the valves 46, to a system for adjusting the quantity of fuel added to the combustion chamber 34, and to a system for controlling the temperature of the streams 64, 68.

[0073] As indicated above, as soon as the electrical power requested by the electrical network 12 is greater than the defined site power Pn under the defined site conditions, the control system 22 is able to activate cooling of the incoming air flow 20 using the heat exchange system 18, to provide a cooled incoming air flow 20.

[0074] On the contrary, as soon as the electrical power requested by the electrical network 12 is lower than the defined site power Pn at the defined site conditions, the control system 22 is able to activate heating of the incoming air flow 20 using the heat exchange system 18, to provide a heated incoming air flow 20.

[0075] Advantageously, the control system 22 is capable of controlling the compressor inlet temperature CIT and the turbine inlet temperature TIT to maximize the efficiency of each combustion turbine 16, on the basis of delivered iso-power curves 100 illustrated by the figure 3 .

[0076] The efficiency R GT obtained on each of the delivered iso-power curves 100 is calculated as a function of the compressor inlet temperature CIT and the turbine inlet temperature TIT.

[0077] Preferably, to maximize the efficiency of the combustion turbine 16, the minimum achievable compressor inlet temperature CIT is chosen. This temperature is limited by the relative humidity of the air, to avoid any condensation in the compressor 30. The compressor inlet temperature CIT is for example between 5°C and 50°C.

[0078] At the same time, the TIT turbine inlet temperature is adjusted according to the power required by the electrical network, maintaining the TIT turbine inlet temperature between a low limit and an upper limit. The lower limit is the limit at which combustion flame stability is achieved. The upper limit is a temperature dependent on the characteristics of the materials forming the turbine, and the machine specification constraints.

[0079] The TIT turbine inlet temperature is for example between 800°C and 1700°C.

[0080] In case the lower limit of turbine inlet temperature TIT is reached and the supplied power is not achievable, the compressor inlet temperature CIT is increased by one increment.

[0081] Cooling the air flow 20 in the heat exchange system 18, and consequently the compressor inlet temperature CIT, increases the amount of material supplied to the dynamic expansion turbine 38.

[0082] This allows the combustion turbine 16 to provide a power greater than the defined site power that it provides at the defined site conditions. This power provided in the presence of the cooling of the air flow 20 is for example between 101% and 120% of the defined site power Pn that it provides at the defined site conditions. Furthermore, the efficiency of the combustion turbine 16 is increased when the power provided is greater than 100% of the defined site power.

[0083] Thus, when designing the production system 10, it is possible to undersize the power generation unit 14, so that it provides, under defined site conditions, a defined site power Pn lower than the predefined maximum required power Pmax under site conditions.

[0084] When implementing an energy production method using the production system 10 according to the invention, the missing power is compensated by the control system 22 which applies cooling to the air flow 20 introduced into the compressor 30 of the combustion turbine 16, as soon as the power required by the electrical network 12 is greater than the defined site power Pn.

[0085] In the same way, as soon as the power required by the electrical network 12 is lower than the defined site power Pn, the control system 22 increases the compressor inlet temperature CIT by heating the air flow 20, for example in a range from 15°C to 50°C. It advantageously reduces the turbine inlet temperature TIT, for example by 100°C, while simultaneously increasing the opening VIGV% of the blades 46. This leads to operation, with increased efficiency at low delivered powers, without the reduction in the maximum power of the combustion turbine 16, induced by the heating of the air, posing a problem, since the operation is in partial operation.

[0086] Furthermore, as illustrated by the numerical example of the figure 4, this limits the number of 16 combustion turbines required, (here going from 5 turbines to 4 turbines), which reduces investment and operating costs. The limited number of 16 combustion turbines is compensated by a wider operating range, which produces surprisingly better efficiency.

[0087] Overall, thanks to the synergistic use of cooling the air flow 20 when the required power is above the set site power Pn and heating the air flow 20 when the required power is below the set site power Pn, the combustion turbine 16 operates in the widest possible range of delivered powers starting from the predefined maximum required power Pmax, up to a minimum power, determined by the operating limits of the combustion chamber 34.

[0088] It is thus possible to adapt to varied loads, despite undersizing of the power generation unit 14, which produces an overall reduction in investments to construct and operate the energy production system 10.

[0089] Furthermore, the energy production system 10 according to the invention is capable of adapting and integrating energetically into an energy or heat cogeneration installation. In particular, as shown in the figure 1 , the heat produced at the outlet of the gas turbine 16 is suitable for being used directly or indirectly (in the case of steam heating in cogeneration of energy or heating) to heat the air flow 20 at the inlet of the turbine, as well as to cool it, using a cooler operating for example using an absorption cycle.

[0090] The efficiency obtained by the electrical production system 10 according to the invention is improved over the entire range of delivered powers. Furthermore, the power delivered to the electrical network 12 by the production system 10 being most of the time lower than the predefined maximum required power Pmax, each combustion turbine 16 of the power generation unit 14 is likely to operate more often in the vicinity of their defined site power Pn, which improves the efficiency.

[0091] This is illustrated by the figure 4, which shows that for a delivered power Pmed corresponding to 80% of the predefined maximum required power Pmax, this delivered power leads to partial load operation at 80% of the defined site power Pn for a state-of-the-art system with 5 turbines, with a degraded efficiency compared to operation at the defined site power Pn. On the contrary, for the production system 10 according to the invention, which comprises only 4 turbines, the delivered power Pmed corresponds to approximately 100% of the defined site power Pn for the production system 10, and the increase in efficiency is 3%.

[0092] Furthermore, an increase in efficiency is also observed when the power generation unit 14 provides a delivered power Pmax beyond its defined site power Pn, by cooling the incoming air flow 20, or a delivered power Plow further below its defined site power Pn, by heating the incoming air flow 20.

[0093] The values ​​of the power P GT delivered by each combustion turbine 16, of the total power P TOTAL corresponding to the product of the power P GT by the number of turbines installed and of the efficiency R GT of the combustion turbine 16 are given on the figure 4 for each operating point.

[0094] There is therefore an operating synergy using both cooling and heating of the air flow 20 to achieve improved plant efficiency and better operability, while reducing the investment required.

[0095] This is illustrated by the numerical simulation of an implementation of the energy production process reported on the figures 5 to 7 .

[0096] There Figure 5 illustrates the average electrical power demand of the electrical network 12 over time, for an offshore fluid exploitation installation. In this example, the defined site conditions of the installation include an ambient temperature of 30 °C, a relative humidity of 60 %, and a standard atmospheric pressure of 760 millimeters of mercury, or 101325 Pa.

[0097] The power generation unit 14 comprises three combustion turbines 16 operating simultaneously, and one on standby. The electrical demand is simulated over twenty years.

[0098] As illustrated by the Figure 5, the maximum electrical demand is 285 MW at the predefined site conditions defined above. The minimum electrical demand is 177 MW, with an average electrical demand equal to 236 MW.

[0099] The predefined maximum electrical power Pmax at defined site conditions is predefined as being equal to 315 MW. The state-of-the-art electrical power generation system is designed to provide, at defined site conditions, a defined site power Pn equal to Pmax.

[0100] In this example, the state-of-the-art electrical power generation system comprises three GT11N2 combustion turbines marketed by GE, each having a defined site power Pn equal to 105 MW at 30°C.

[0101] On the contrary, the combustion turbines 16 of the production system 10 according to the invention are smaller in size than those of the system of the prior art. They produce a defined site power Pn at defined site conditions lower than the maximum power Pmax, here substantially equal to 79% of the maximum power Pmax.

[0102] In this example, the production system 10 according to the invention comprises three Frame 7F.03 combustion turbines marketed by the company GE, each having a defined site power Pn equal to 83 MW at 30°C.

[0103] For the implementation of the method using the production system 10 according to the invention, as soon as the required charge percentage (noted “% CH” on the figure 6), corresponding to the ratio of the required power to the defined site power Pn, is greater than 100%, a cooling of the incoming air flow 20 is generated by the heat exchange system 18, and as soon as the percentage of required load is less than 100%, a reheating of the temperature of the incoming air flow 20 is carried out.

[0104] There figure 6 illustrates the load percentage of each combustion turbine 16 for the state-of-the-art system (EDT curve) and for the production system 10 according to the invention (INVENTION curve).

[0105] During the first years of operation (from approximately 2013 to 2019), the power required by the electrical network 12 is greater than the defined site power Pn produced by the power generation unit 14 of the production system 10 according to the invention.

[0106] The production system 10 according to the invention operates with cooling of the incoming air flow 20, which improves the yield.

[0107] Then, the required power is lower than the defined site power, and decreases significantly over time, leading to load percentages significantly lower than 100%. The production system 10 according to the invention then operates with reheating of the incoming air flow 20.

[0108] As illustrated by the figure 7 , whatever the percentage of load required, the efficiency of the power generation unit 14 according to the invention is significantly higher than the efficiency of that of the state of the art.

[0109] The absolute increases in efficiency are in the order of 0.4% to 1.1%, or between 1% and 3.6% in relative terms, which is considerable, given the electrical power consumed over time.

[0110] Table 1 below illustrates the gains produced by an energy production system 10 according to the invention, using a fuel formed by natural gas having a low calorific value of 50.048 MJ / kg.

[0111] As shown in this table, the amount of fuel saved is of the order of 1.112 MT, which avoids producing 3.087 MT of carbon dioxide. This result is further achieved with a lower investment, since the combustion turbines 16 used in the production system 10 according to the invention are smaller in size. [Table 1] Average demand for electrical power from the network 12 235 MW Total electrical power generated 4716 MW Fuel saved by the production system 10 according to the invention compared to the system of the state of the art 1,112 MT Carbon dioxide not emitted by the production system 10 according to the invention compared to the system of the state of the art 3,087 Mt

[0112] In a variant not shown mentioned above, the production system 10 produces mechanical energy intended for a mechanical energy consuming system, in particular within a fluid exploitation installation. The consuming system is then a system comprising a member driven in rotation in an industrial installation, in particular a compressor or a pump.

[0113] As before, the power generation unit 14 is a mechanical power generation unit configured to generate, at the defined site conditions, without cooling or heating of the incoming air flow 20, a defined site mechanical power less than the predefined maximum required mechanical power to be supplied to the mechanical energy consuming system at the defined site conditions by the power generation unit 14.

[0114] Cooling or heating of the incoming air flow 20 is implemented when the power demanded by the consumer system is different from the site-defined power of the power generation unit 14.

Claims

1. A method for producing electrical and / or mechanical energy intended for a consumer system, including the following step: - generation of electrical and / or mechanical power via a power generation unit (14) including at least one combustion turbine (16), the combustion turbine (16) including a compressor (30), a combustion chamber (34), a dynamic expansion turbine (38), and a component rotated by the dynamic expansion turbine (38), the electrical and / or mechanical power generation including the compression of an air flow (20) entering the compressor (30), the heating of the compressed air flow (32) coming from the compressor (30) in the combustion chamber (34), so as to form a flow feeding the turbine (36), and the expansion, in the dynamic expansion turbine (38), of the flow feeding the turbine (36) so as to rotate the dynamic expansion turbine (38). characterized in that the power generation unit (14) is configured for generating, under defined site conditions, without any cooling or heating of the incoming air flow (20), a defined site electrical and / or mechanical power less than a predefined maximum required electrical and / or mechanical power, to be supplied to the consumer system at the defined site conditions, by the power generation unit (14), the method including the following steps: - cooling of the incoming air flow (20) when the power requested by the consumer system is greater than the defined site power of the power generation unit (14) at the defined site conditions, and is lower than or equal to the predefined maximum required power; - heating of the incoming air flow (20) when the power requested by the consumer system is lower than the defined site power of the power generation unit (14) at the defined site conditions.

2. The method according to claim 1, wherein the defined site power of the power generation unit (14) at the defined site conditions is comprised between 70% and 90%, in particular between 75% and 85%, of the maximum required power predefined by the consumer system at the defined site conditions.

3. The method according to any of claims 1 or 2, wherein cooling of the incoming air flow (20) is implemented as soon as the power requested by the consumer system is greater than the defined site power of the power generation unit (14) at the defined site conditions, the heating of the incoming air flow (20) being implemented as soon as the electrical power demanded by the consumer system is less than the defined site power of the power generation unit (14) at the defined site conditions.

4. The method according to any of the preceding claims, wherein cooling the incoming air flow (20) includes adjusting the compressor (30) inlet temperature to a minimum acceptable temperature of the inlet gas flow (20), the method including the adjustment of the power delivered to the consumer system by controlling the temperature of the flow feeding the turbine (36) at the inlet of the dynamic expansion turbine (38).

5. The method according to claim 4, wherein, when the control of the temperature of the flow feeding the turbine (36) at the inlet of the dynamic expansion turbine (38) produces a power output less than the power required by the consumer system, the method includes the application of an increment of increase of the compressor (30) inlet temperature above the minimum acceptable temperature of the inlet gas flow (20), then a new adjustment of the power delivered to the consumer system by controlling the temperature of the flow feeding the turbine (36) at the inlet of the dynamic expansion turbine (38).

6. The method according to any of the preceding claims, wherein the heating of the incoming air flow (20) includes adjusting the delivered power to the power required by the consumer system by gradually increasing the compressor (30) inlet temperature.

7. The method according to claim 6, including, simultaneously with the gradual increase of the compressor (30) inlet temperature, a decrease of the inlet temperature at the dynamic expansion turbine (38).

8. The method according to any of claims 6 or 7, wherein the compressor (30) has guide vanes variable in position (46) defining an opening for the incoming air flow (20) into the compressor (30), the heating of the incoming air flow (20) including, simultaneously with the increase of the compressor (30) inlet temperature, an increase of the opening defined by the guide vanes (46).

9. The method according to any of the preceding claims, wherein the consumer system is an electrical grid (12), the power generated being an electrical power, the rotating component being a rotor of an electric generator of the combustion turbine (16) or wherein the consumer system is a system including a rotating component in an industrial installation, more particularly a compressor or a pump, the power generated being a mechanical power.

10. A system for producing electrical and / or mechanical power (10) for a consumer system, including: - a power generation unit (14) including at least one combustion turbine (16), the combustion turbine (16) including a compressor (30), a combustion chamber (34), a dynamic expansion turbine (38), and a component rotated by the dynamic expansion turbine (38), the power generation unit being suitable for generating an electrical and / or mechanical power by compressing an airflow (20) entering the compressor (30), by heating, in the combustion chamber (34), of the compressed air flow (32) coming from the compressor (30), so as to form a flow feeding the turbine (36), and by expansion, in the dynamic expansion turbine (38), of the flow feeding the turbine (36) so as to rotate the dynamic expansion turbine (38), characterized in that the power generation unit (14) is configured for generating, at defined site conditions, without any cooling or heating of the incoming air flow (20), a defined site electrical and / or mechanical power less than a predefined maximum required electrical and / or mechanical power to be supplied to the consumer system at the defined site conditions, by the power generation unit (14), the energy production system (10) including a control system (22) configured for controlling: - a cooling of the incoming air flow (20) when the power requested by the consumer system is greater than the defined site power of the power generation unit (14) at the defined site conditions, and is lower than or equal to the predefined maximum required power; - a heating of the incoming air flow (20) when the power requested by the consumer system is lower than the defined site power of the power generation unit (14) at the defined site conditions.

11. The energy production system (10) according to claim 10, wherein the power generation unit (14) includes multiple combustion turbines (16).

12. The energy production system (10) according to any one of claims 10 or 11, including a heat exchange system (18) mounted upstream of the compressor (30) for heating and / or cooling the incoming air flow (20).

13. The energy production system (10) according to claim 12, wherein the heat exchange system (18) is suitable for receiving a heating stream (68) produced from a flow coming from the combustion turbine (16) or having received calories from a flow coming from the combustion turbine (16), for heating the incoming air flow (20).

14. The energy production system (10) according to any one of claims 10 to 13 including an absorption chiller, the heat exchange system (18) being suitable for receiving a cooling stream (64) coming from the absorption chiller.

15. The energy production system (10) according to claim 14, wherein the cooling stream (64) is produced in the absorption chiller from calories of a flow coming from the combustion turbine (16).