Patent Publication Number: US-2023142855-A1

Title: Systems for generating geothermal power in an organic rankine cycle operation during hydrocarbon production based on wellhead fluid temperature

Description:
CROSS REFERENCE TO RELATED APPLICATIONS 
     This application is a continuation of U.S. application Ser. No. 17/650,811, filed Feb. 11, 2022, titled “SYSTEMS FOR GENERATING GEOTHERMAL POWER IN AN ORGANIC RANKINE CYCLE OPERATION DURING HYDROCARBON PRODUCTION BASED ON WELLHEAD FLUID TEMPERATURE”, which is a continuation of U.S. application Ser. No. 17/305,298, filed Jul. 2, 2021, titled “SYSTEMS FOR GENERATING GEOTHERMAL POWER IN AN ORGANIC RANKINE CYCLE OPERATION DURING HYDROCARBON PRODUCTION BASED ON WELLHEAD FLUID TEMPERATURE”, now U.S. Pat. No. 11,280,322, issued Mar. 22, 2022, which claims priority to and the benefit of U.S. Provisional Application No. 63/200,908, filed Apr. 2, 2021, titled “SYSTEMS AND METHODS FOR GENERATING GEOTHERMAL POWER DURING HYDROCARBON PRODUCTION,” the entire disclosures of all of which are incorporated herein by reference. 
    
    
     FIELD OF DISCLOSURE 
     Embodiments of this disclosure relate to generating geothermal power during hydrocarbon production, and more particularly, to systems and methods for generating and controllers for controlling generation of geothermal power in an organic Rankine cycle (ORC) operation in the vicinity of a wellhead during hydrocarbon production to thereby supply electrical power to one or more of in-field operational equipment, a grid power structure, and an energy storage device. 
     BACKGROUND 
     Typically, geothermal generators include a working fluid loop that flows to varying depths underground, such that underground heat causes the working fluid in the loop to change phases from a liquid to a vapor. The vaporous working fluid may then flow to a gas expander, causing the gas expander to rotate. The rotation of the gas expander may cause a generator to generate electrical power. The vaporous working fluid may then flow to a condenser or heat sink. The condenser or heat sink may cool the working fluid, causing the working fluid to change phase from the vapor to the liquid. The working fluid may circulate through the loop in such a continuous manner, thus the geothermal generator may generate electrical power. 
     Heat exchangers within geothermal generators are not built to withstand high pressures. Typically, the working fluid does not flow through the loop under high pressure. Further, rather than including heat exchangers, typically, geothermal generators utilize geothermal heat from varying depths underground, the heat being transferred to the working fluid. For example, a geothermal generator may simply include a conduit or pipe buried deep underground. As working fluid flows through the conduit or pipe, the heat at such depths causes the working fluid to change to a vapor and the vapor may flow up to the gas expander. As the vapor is cooled, the vapor flows back underground, the cycle repeating. While old or non-producing wells have been utilized for geothermal power generation, no such solution is known to exist for generating geothermal power at a well during hydrocarbon production. 
     Accordingly, Applicants have recognized a need for systems and methods to generate geothermal power in an organic Rankine cycle (ORC) operation in the vicinity of a wellhead during hydrocarbon production to thereby supply electrical power to one or more of in-field operational equipment, a grid power structure, and an energy storage device. The present disclosure is directed to embodiments of such systems and methods 
     SUMMARY 
     The present disclosure is generally directed to systems and methods for generating and controlling generation of geothermal power in an organic Rankine cycle (ORC) operation in the vicinity of a wellhead during hydrocarbon production to thereby supply electrical power to one or more of in-field operational equipment, a grid power structure, and an energy storage device. The wellhead may produce a wellhead fluid. The wellhead fluid, as it exits the wellhead, may be under high-pressure and at a high temperature. The wellhead fluid&#39;s temperature may be determined, as well as the pressure, and based on such determinations, one or more heat exchanger valves may be actuated to partially open or completely open, thereby diverting a portion or all of the flow of wellhead fluid to the heat exchanger. The heat exchanger may be a high-pressure heat exchanger configured to withstand the high-pressure of the wellhead fluid from a wellhead. The heat exchanger may indirectly transfer heat from the flow of the wellhead fluid to the flow of a working fluid. As heat is transferred from the flow of the wellhead fluid to the flow of a working fluid, such a heat transfer may cause the working fluid to change phases from a liquid to a vapor. The vaporous working fluid may then flow through an ORC unit to cause a generator to generate electrical power via rotation of a gas expander of the ORC unit. Such an operation may be defined as or may be an ORC operation or process. The ORC unit may be an off-the-shelf unit, while the high-pressure heat exchanger may be a stand-alone component or device. In another embodiment, the ORC unit may be a high-pressure ORC unit and may include the high-pressure heat exchanger apparatus. 
     Accordingly, an embodiment of the disclosure is directed to a system for generating geothermal power in an organic Rankin cycle (ORC) operation in the vicinity of a wellhead during hydrocarbon production to thereby supply electrical power to one or more of in-field equipment, a grid power structure, and energy storage devices. The system may include a first temperature sensor to provide a first temperature. The first temperature may be defined by a temperature of wellhead fluid flowing from one or more wellheads. The system may include a heat exchange valve to divert flow of wellhead fluid from the one or more wellheads based on the first temperature. The system may include a high-pressure heat exchanger including a first fluid path to accept and output the flow of wellhead fluid from the heat exchange valve and a second fluid path to accept and output the flow of an organic working fluid, the high-pressure heat exchanger to indirectly transfer heat from the flow of wellhead fluid to the flow of the organic working fluid to cause the organic working fluid to change phases from a liquid to a vapor. The system may include an ORC unit. The ORC unit may include a generator, a gas expander, a condenser, a pump, and a partial loop for the flow of the organic working fluid. The partial loop may be defined by a fluid path through the condenser, generator, and pump, the partial loop forming a complete loop when connected to the fluid path of the high-pressure heat exchanger, the flow of the organic working fluid, as a vapor, to cause the generator to generate electrical power via rotation of a gas expander as defined by an ORC operation, the condenser to cool the flow of the organic working fluid, the cooling to cause the organic working fluid to change phases from the vapor to the liquid, the pump to transport the liquid state organic working fluid from the condenser for heating. 
     In another embodiment, the system may include a first wellhead fluid valve to adjust flow of wellhead fluid from the one or more wellheads based on the diversion of the flow of wellhead fluid to the heat exchange valve. The system may include a choke valve to accept and to reduce the pressure of the flow of wellhead fluid from the high-pressure heat exchanger thereby reducing the temperature of the flow of wellhead fluid. The system may include a condenser valve to divert flow of wellhead fluid from the choke valve based on whether the heat exchange valve is open. The system may include a second wellhead fluid valve to control flow of wellhead fluid from the choke valve based on a percentage that the condenser valve is open. 
     The system may include another one or more ORC units connected to the high-pressure heat exchanger. The ORC unit may include a working fluid reservoir to store organic working fluid flowing from the condenser. The first fluid path of the high-pressure heat exchanger may be configured to withstand corrosion caused by the wellhead fluid. The high-pressure heat exchanger may include vibration induction device to reduce scaling caused by the flow of the wellhead fluid. 
     Another embodiment is directed to a system for generating geothermal power in the vicinity of a wellhead during hydrocarbon production to thereby supply electrical power to one or more of in-field equipment, a grid power structure, and energy storage devices. The system may include a first pipe connected to and in fluid communication with the wellhead. The first pipe may be configured to transport wellhead fluid under high-pressure. The system may include a first temperature sensor connected to the first pipe. The first temperature sensor may provide a first temperature. The first temperature may be defined by a temperature of wellhead fluid flowing through the first pipe. The system may include a first wellhead fluid valve having a first end and second end. The first end of the first wellhead fluid valve may be connected to and in fluid communication with the first pipe. The first wellhead fluid valve may control flow of wellhead fluid based on the first temperature. The system may include a heat exchange valve connected to and in fluid communication with the first pipe. The heat exchange valve may control flow of wellhead fluid based on the first temperature. The system may include a high-pressure heat exchanger to accept the flow of wellhead fluid when the heat exchange valve is open. The high-pressure heat exchanger may include a first opening and a second opening connected via a first fluidic path and a third opening and a fourth opening connected via a second fluidic path, the first fluidic path and the second fluidic path to facilitate heat transfer from the flow of wellhead fluid to an organic working fluid, the transfer of heat from the wellhead fluid to the organic working fluid to cause the organic working fluid to changes phases from a liquid to a vapor, the flow of wellhead fluid flowing into the first opening of the high-pressure heat exchanger from the heat exchange valve through the first fluidic path and to the second opening of the high-pressure heat exchanger, and a flow of the organic working fluid flowing into the third opening through the second fluidic path and out of the fourth opening. The system may include a second pipe connected to and in fluid communication with the second end of the first wellhead fluid valve and connected to and in fluid communication with the second opening of the high-pressure heat exchanger. The system may include a choke valve connected to and in fluid communication with the second pipe to reduce the pressure of the flow of wellhead fluid thereby reducing the temperature of the wellhead fluid. The system may include a second wellhead fluid valve having a first end and second end, the first end of the second wellhead fluid valve connected to and in fluid communication with the choke valve. The second wellhead fluid valve may control flow of wellhead fluid based on whether the first wellhead fluid valve is open. The system may include a condenser valve connected to and in fluid communication with the choke valve. The condenser valve may control flow of wellhead fluid based on whether the first wellhead fluid valve is open. The system may include a generator connected to and in fluid communication with the fourth opening of the high-pressure heat exchanger. The organic working fluid may flow from the fourth opening to the generator and causing the generator to generate electrical power via rotation of a vapor expander as defined by an ORC operation. The system may include a condenser. The condenser may include a first opening and second opening connected via a first fluidic condenser path and a third opening and fourth opening connected via a second fluidic condenser path, the first opening connected to the condenser valve, the second opening connected to an output pipe, and the third opening connected to the expander to receive the organic working fluid, the first fluidic condenser path and the second fluidic condenser path to facilitate heat transfer from the organic working fluid to the flow of wellhead fluid. The system may include a pump connected to the fourth opening of the condenser to pump the organic working fluid from the condenser to the third opening of the high-pressure heat exchanger. 
     In another embodiment, the organic working fluid may include one of pentafluoropropane, carbon dioxide, ammonia and water mixtures, tetrafluoroethane, isobutene, propane, pentane, perfluorocarbons, and other hydrocarbons. The generator may include a rotation mechanism, a stator, and rotor, the rotor connected to the rotation mechanism, the rotor to rotate as the rotation mechanism spins via the flow of organic working fluid. The rotation mechanism may include one of a turbine expander, a positive displacement expander, or a twin-screw expander. The rotation mechanism may connect to the rotor via one of a transmission and gearbox. 
     In another embodiment, when the heat exchanger valve is opened, a portion of the flow of wellhead fluid may be diverted from the first wellhead fluid valve. 
     In another embodiment, the organic working fluid may change phase from liquid to vapor when the wellhead fluid is at a temperature from greater than or equal to about  50  degrees Celsius. After the organic working fluid flows through the expander, the organic working fluid may flow through a regenerator and, after the working fluid flows through the condenser, the organic working fluid may flow through the regenerator. The regenerator may pre-heat the organic working fluid from the condenser via heat of the organic working fluid from the generator. 
     In an embodiment, the high-pressure heat exchanger may be configured to withstand pressures up to about 15,000 pounds per square inch (PSI). The high-pressure heat exchanger may include pressure relief valves. The pressure relief valves may open or release pressure in the event that the high-pressure heat exchanger exhibits a pressure exceeding a maximum pressure rating of the high-pressure heat exchanger. 
     In an embodiment, the choke valve may reduce the pressure of the flow of wellhead fluid to less than or equal to about 1,500 PSI. The reduction of pressure of the flow of wellhead fluid may reduce the temperature of the wellhead fluid to less than or equal to about 50 degrees Celsius. 
     The wellhead fluid may include one of a liquid and a gas. The wellhead fluid may include hydrocarbons. The wellhead fluid may further include a mixture of the hydrocarbons and one or more of water and other chemical residuals. 
     In another embodiment, the organic working fluid may be heated in the heat exchanger to the point of evaporation of the organic working fluid. The organic working fluid may be heated in the heat exchanger to saturation temperature under high-pressure. The working fluid may include a mixture of two or more fluids, each of the two or more fluids including different vaporous phase change points and different condensation points. 
     Another embodiment is directed to a system to generate geothermal power in the vicinity of one or more wellheads during hydrocarbon production to thereby supply electrical power to one or more of in-field operational equipment, a grid power structure, and energy storage devices. The system may include one or more wellheads. The system may include one or more ORC units. The system may include one or more high-pressure heat exchangers positioned to connect to piping at the one or more wellheads and to the one or more ORC units so that when one of the one or more ORC units is positioned at one of the one or more wellheads with one of the one or more high-pressure heat exchangers, the one or more ORC units generate geothermal power during hydrocarbon production at the one of the one or more wellheads, the geothermal power supplied to equipment at each of the one or more wellheads and excess geothermal power supplied to a grid. The one or more ORC units at one or more wellheads may connect to an electrical power grid via one or more transformer. 
     Still other aspects and advantages of these embodiments and other embodiments, are discussed in detail herein. Moreover, it is to be understood that both the foregoing information and the following detailed description provide merely illustrative examples of various aspects and embodiments, and are intended to provide an overview or framework for understanding the nature and character of the claimed aspects and embodiments. Accordingly, these and other objects, along with advantages and features of the present invention herein disclosed, will become apparent through reference to the following description and the accompanying drawings. Furthermore, it is to be understood that the features of the various embodiments described herein are not mutually exclusive and may exist in various combinations and permutations. 
    
    
     
       BRIEF DESCRIPTION OF DRAWINGS 
       These and other features, aspects, and advantages of the disclosure will become better understood with regard to the following descriptions, claims, and accompanying drawings. It is to be noted, however, that the drawings illustrate only several embodiments of the disclosure and, therefore, are not to be considered limiting of the scope of the disclosure. 
         FIG.  1 A  and  FIG.  1 B  are schematic top-down perspectives of novel implementations of a geothermal power generation enabled well, according to one or more embodiment of the disclosure. 
         FIG.  2 A ,  FIG.  2 B ,  FIG.  2 C ,  FIG.  2 D ,  FIG.  2 E ,  FIG.  2 F ,  FIG.  2 G , and  FIG.  2 H  are block diagrams illustrating novel implementations of a geothermal power generation enabled well to provide electrical power to one or more of in-field equipment, equipment at other wells, energy storage devices, and the grid power structure, according to one or more embodiment of the disclosure. 
         FIG.  3 A  and  FIG.  3 B  are block diagrams illustrating other novel implementations of a geothermal power generation enabled well to provide electrical power to one or more of in-field equipment, equipment at other wells, energy storage devices, and the grid power structure, according to one or more embodiment of the disclosure. 
         FIG.  4 A  and  FIG.  4 B  are simplified diagrams illustrating a control system for managing geothermal power production at a well, according to one or more embodiment of the disclosure. 
         FIG.  5    is a flow diagram of geothermal power generation in which, when a wellhead fluid is at or above a vaporous phase change temperature, heat exchanger valves may be opened to allow wellhead fluid to flow therethrough, thereby facilitating heating of a working fluid for use in an organic Rankine cycle (ORC) unit, according to one or more embodiment of the disclosure. 
         FIG.  6    is another flow diagram of geothermal power generation in which, when a wellhead fluid is at or above a vaporous phase change temperature, heat exchanger valves may be opened to allow wellhead fluid to flow therethrough, thereby facilitating heating of a working fluid for use in a ORC unit, according to one or more embodiment of the disclosure. 
         FIG.  7 A  is a flow diagram of geothermal power generation in which, when an ORC fluid is at or above a vaporous phase change temperature, heat exchanger valves may remain open to allow wellhead fluid to flow therethrough, thereby facilitating heating of a working fluid for use in an ORC unit, according to one or more embodiment of the disclosure. 
         FIG.  7 B  is another flow diagram of geothermal power generation in which, when an ORC fluid is at or above a vaporous phase change temperature, heat exchanger valves may remain open to allow wellhead fluid to flow therethrough, thereby facilitating heating of a working fluid for use in an ORC unit, according to one or more embodiment of the disclosure. 
         FIG.  8    is a flow diagram of geothermal power generation in which a working fluid flow is determined based on a preselected electrical power output threshold, according to one or more embodiment of the disclosure. 
         FIG.  9 A ,  FIG.  9 B ,  FIG.  9 C ,  FIG.  9 D ,  FIG.  9 E ,  FIG.  9 F , and  FIG.  9 G  are block diagrams illustrating novel implementations of one or more geothermal power generation enabled wells to provide electrical power to one or more of in-field equipment, equipment at one of the other wells, energy storage devices, and the grid power structure, according to one or more embodiment of the disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     So that the manner in which the features and advantages of the embodiments of the systems and methods disclosed herein, as well as others that will become apparent, may be understood in more detail, a more particular description of embodiments of systems and methods briefly summarized above may be had by reference to the following detailed description of embodiments thereof, in which one or more are further illustrated in the appended drawings, which form a part of this specification. It is to be noted, however, that the drawings illustrate only various embodiments of the systems and methods disclosed herein and are therefore not to be considered limiting of the scope of the systems and methods disclosed herein as it may include other effective embodiments as well. 
     The present disclosure is directed to systems and methods for generating geothermal power in an organic Rankine cycle (ORC) operation in the vicinity of a wellhead during hydrocarbon production to thereby supply electrical power to one or more of in-field equipment or operational equipment, a grid power structure, other equipment, and an energy storage device. Wellhead fluids flowing from a wellhead at a well are typically under high-pressure. In-field equipment at the well is not rated for such high pressures. Prior to further processing or transport, the pressure of the flow of the wellhead fluid may be reduced, e.g., from 15,000 PSI to 200 PSI, from 10,000 PSI to 200 PSI, from 2,000 PSI to 200 PSI, or any other range from 20,000 PSI to 100 PSI, based on the pressure rating of the in-field equipment at the well. As the wellhead fluid flows from the wellhead, the temperature of the flow of the wellhead fluid may be at a high temperature, at least partially due to the high pressure of the flow of the wellhead fluid. As the pressure is reduced, the wellhead fluid temperature may also be reduced, as result of the pressure drop. Typically, the heat of the flow of wellhead fluid from the wellhead is not utilized and may be considered heat waste. 
     Geothermal power generators typically use a looping pipe or pipeline buried at depths with sufficient temperature to allow a working fluid to change phase from liquid to vapor. As the working fluid changes phase from a liquid to a vaporous state, the vaporous state working fluid may flow up the pipe or pipeline to a gas expander. The vaporous state working fluid may flow through and cause the gas expander to rotate. The rotation of the gas expander may cause a generator to generate electrical power, as will be described below. The vaporous state working fluid may flow through the gas expander to a heat sink, condenser, or other cooling apparatus. The heat sink, condenser, or other cooling apparatus may cool the working fluid thereby causing the working fluid to change phases from a vapor to a liquid. Heat exchangers of typical geothermal generators are not rated for high-pressure operations and usually geothermal generators obtain heat from varying underground depths. 
     In the present disclosure, a high-pressure heat exchanger may be placed or disposed at the well and/or in the vicinity of one or more wellheads. The high-pressure heat exchanger may be connected to the wellhead and may accept a high temperature or heated flow of wellhead fluid. A working fluid may flow through the heat exchanger. As the wellhead fluid and working fluid flows through the high-pressure heat exchanger, the high-pressure heat exchanger may facilitate transfer of heat from the wellhead fluid to the working fluid. A heat exchanger may include two fluidic paths, one for a heated fluid and another for a cool fluid. The fluidic paths may be in close proximity, allowing heat to transfer from the heated fluid to the cool fluid. The fluidic paths may be loops, coils, densely packed piping, tubes, chambers, some other type of path to allow for fluid to flow therethrough, and/or a combination thereof, as will be understood by those skilled in the art. As fluids flow through the heat exchanger, the cool liquid&#39;s temperature may increase, while the heated liquid&#39;s temperature may decrease. 
     Additionally, a geothermal generator unit or ORC unit may be disposed, positioned, or placed at the wellhead. The geothermal generator unit or ORC unit may directly connect to the high-pressure heat exchanger, include the high-pressure heat exchanger, or may connect to the high-pressure heat exchanger via an intermediary heat exchanger. As the hot wellhead fluid heats the working fluid, either via direct connection or through an intermediary heat exchanger, the working fluid may change phases from a liquid to a vapor. In such examples, the working fluid utilized may be chosen based on a low boiling point and/or high condensing point. The vaporous state working fluid may flow through the geothermal generator unit or ORC unit to a generator, e.g., a gas expander and generator. The vaporous state working fluid may then flow to a condenser or heat sink, thereby changing state from the vapor to the liquid. Finally, the liquid may be pumped back to the high-pressure heat exchanger. Such a cycle, process, or operation may be considered a Rankine cycle or ORC. 
     Such systems may include various components, devices, or apparatuses, such as temperature sensors, pressure sensors or transducers, flow meters, control valves, smart valves, valves actuated via control signal, controllers, a master or supervisory controller, other computing devices, computing systems, user interfaces, in-field equipment, and/or other equipment. The controller may monitor and adjust various aspects of the system to ensure that hydrocarbon production continues at a specified rate, that downtime is limited or negligible, and that electrical power is generated efficiently, optimally, economically, and/or to meet or exceed a preselected electrical power output threshold. 
       FIGS.  1 A and  1 B  are schematic top-down perspectives of novel implementations of a geothermal power generation enabled well, according to one or more embodiment of the disclosure. As illustrated in  FIG.  1 A , a well  100  may include various components or equipment, also referred to as in-field equipment. Such in-field equipment may include fracturing equipment, field compressors, pump stations, artificial lift equipment, drilling rigs, data vans, and/or any other equipment utilized or used at a well  100 . For example, the well  100  may include one or more pumpjacks  108 , one or more wellhead compressors  110 , various other pumps, various valves, and/or other equipment that may use electrical power or other type of power to operate. To generate power from otherwise wasted heat, the well  100  may additionally include a high-pressure heat exchanger  104 , one or more geothermal generators, one or more ORC units  106 , a high-pressure geothermal generator, a high-pressure ORC unit, and/or some combination thereof. As wellhead fluid flows from one of the one or more wellheads  102 , a portion of the flow of wellhead fluid or all of the flow of wellhead fluid may flow through the high-pressure heat exchanger  104 , high-pressure geothermal generator, a high-pressure ORC unit, or some combination thereof. As the hot and high-pressure wellhead fluid flows through, for example, the high-pressure heat exchanger  104 , the high-pressure heat exchanger  104  may facilitate a transfer of heat from the wellhead fluid to a working fluid flowing through the high-pressure heat exchanger  104 . In other words, the wellhead fluid may heat the working fluid. Such a heat transfer may cause the working fluid to change phases from a liquid to a vapor. The vaporous state working fluid may flow from the high-pressure heat exchanger to the one or more ORC units  106 . The one or more ORC units  106  may then generate power using the vaporous state working fluid. The electrical power may be transferred to the in-field equipment at the well  100 , to an energy storage device (e.g., if excess power is available), to equipment at other wells, to the grid or grid power structure (e.g., via a transformer  116  through power lines  118 ), or some combination thereof. 
     As illustrated in  FIG.  1 B , one or more wells  100 A,  100 B,  100 C may be nearby or in close proximity to each of the other one or more wells  100 A,  100 B,  100 C. Further, each of the one or more wells  100 A,  100 B,  100 C may utilize different amounts of electrical power, in addition to generating different amounts of electrical power. As such, one well (e.g., well  100 A, well  100 B, and/or well  100 C) of the one or more wells  100 A,  100 B,  100 C may generate a surplus of electrical power or utilize electrical power from other sources. In an example, a controller may determine if a well (e.g., well  100 A, well  100 B, and/or well  100 C) of the one or more wells  100 A,  100 B,  100 C generates a surplus. If a surplus is generated, the controller may determine which, if any, of the other one or more wells  100 A,  100 B,  100 C may have a deficit of electrical power. The controller may then transmit signals to equipment at the one or more wells  100 A,  100 B,  100 C to enable electrical power transfer between the one or more wells  100 A,  100 B,  100 C with excess and deficits, e.g., a well with a deficit may receive electrical power from a well with a surplus (see  120 ). In another example, the one or more wells  100 A,  100 B,  100 C may include energy storage devices e.g., batteries, battery banks, or other solutions to store energy for short or long term time periods. The energy storage devices may be placed, disposed, or installed at one or more of the one or more wells  100 A,  100 B,  100 C or at points in between the one or more wells  100 A,  100 B,  100 C. As surplus electrical power is generated, that surplus electrical power may be transmitted and stored in the energy storage devices. The energy storage devices may be accessible by the in-field equipment of each of the one or more wells  100 . 
     As illustrated in  FIGS.  1 A and  1 B , the one or more wells  100 A,  100 B,  100 C may include a high-pressure heat exchanger  104  and ORC units  106 . In an example, the ORC units  106  may be modular and/or mobile. The ORC units  106  may be mounted to a vehicle, such as a truck or other vehicle type, or skid and transported to the well  100 . Further, the high-pressure heat exchanger  104  may be modular and/or mobile. The high-pressure heat exchanger  104  may be mounted to a vehicle and/or skid. Upon arrival at one of the one or more wells  100 A,  100 B,  100 C, the high-pressure heat exchanger  104  may be removed from the vehicle or the vehicle may be left on-site or at least while the one or more wells  100 A,  100 B,  100 C are producing hydrocarbons. In an example, during hydrocarbon production, operation of the high-pressure heat exchanger  104  and ORC unit  106  may occur. After hydrocarbon production has ceased, none, some, or all of the equipment may be removed from the well  100 . For example, the well  100  may be re-used for generating geothermal energy via a different method. In such examples the ORC units  106  and high-pressure heat exchanger  104  may remain on-site. 
       FIG.  2 A ,  FIG.  2 B ,  FIG.  2 C ,  FIG.  2 D ,  FIG.  2 E ,  FIG.  2 F ,  FIG.  2 G , and  FIG.  2 H  are block diagrams illustrating novel implementations of a geothermal power generation enabled well to provide electrical power to one or more of in-field equipment, equipment at other wells, energy storage devices, and the grid power structure, according to one or more embodiment of the disclosure. As illustrated in the  FIGS.  2 A through  2 H , different embodiments may be utilized for geothermal power generation at the surface of a well during hydrocarbon production. As illustrated in  FIG.  2 A , a well  200  may include a wellhead  202 . The wellhead  202  may produce a stream or flow of wellhead fluid. The wellhead fluid may flow from a first pipe  215 . The first pipe  215  may include, at various positions along the length of the pipe  215 , sensors, meters, transducers, and/or other devices to determine the characteristics of the wellhead fluid flowing through pipe  215 . Further, sensors, meters, transducers and/or other devices may be included at various positions within the high-pressure heat exchanger  250  and/or ORC unit  203  to determine the characteristics of the working fluid or ORC fluid flowing through the high-pressure heat exchanger  250  and/or ORC unit  203 . Based on the determined characteristics of the wellhead fluid, working fluid, and/or ORC fluid and/or characteristics of other aspects of the well  200 , e.g., temperature, pressure, flow, power demand and/or power storage or transmission options and/or other factors, a first heat exchanger valve  208  connected to the first pipe  215  may be opened, e.g., partially opened or fully opened. 
     Further, when the first heat exchanger valve  208  is opened, a second heat exchanger valve  222  connected to a second pipe  217  may be opened, e.g., partially opened or fully opened. The second heat exchanger valve  222  may allow the flow of wellhead fluid to exit the high-pressure heat exchanger  250 . Based on the opening of the first heat exchanger valve  208  and second heat exchanger valve  222 , a first wellhead fluid valve  210  may be adjusted. Such adjustment may occur to ensure that the production of the wellhead  202  or the production of wellhead fluid from the wellhead  202  may not be impeded or slowed based on a diversion of the flow of the wellhead fluid to the high-pressure heat exchanger  250 . Downstream of the first wellhead fluid valve  210 , but prior to where the diverted portion of the flow of wellhead fluid is reintroduced to the primary or bypass wellhead fluid flow, a pressure sensor  212  may be disposed, e.g., the pressure sensor  212  may be disposed along pipe  217 . In another example, rather than a pressure sensor  212 , a flow meter may be disposed along pipe  217 , e.g., a wellhead fluid flow meter and/or a downstream flow meter. The wellhead fluid flow meter may measure the flow rate of a fluid exiting the wellhead  202 . A downstream flow meter may measure the flow rate of the wellhead fluid at a point downstream of the first wellhead fluid valve  210 . Such a pressure sensor  212  or flow meter may be utilized to determine whether the flow of wellhead fluid is at a pressure or flow that does not impede hydrocarbon production. In an example, where the flow is impeded to a degree that the production of hydrocarbons may be inhibited, the first wellhead fluid valve  210  may be opened further, if the first wellhead fluid valve  210  is not already fully opened. If the first wellhead fluid valve  210  is fully opened, the first heat exchanger valve&#39;s  208  and second heat exchanger valve&#39;s  222  percent open may be adjusted. Other factors may be taken into account for such determinations, such as the pressure or flow from the high-pressure heat exchanger  250 , the pressure or flow at the point of a choke valve located further downstream along the second pipe  217 , a pressure rating for downstream equipment, and/or the temperature of the wellhead fluid within the high-pressure heat exchanger  250 . Once the flow of wellhead fluid passes through the first wellhead fluid valve  210  and/or the second heat exchanger valve  222 , the wellhead fluid may flow to in-field equipment  270  for further processing or transport. 
     Each of the valves described herein, e.g., first heat exchanger valve  208 , second heat exchanger valve  222 , first wellhead fluid valve  210 , and other valves illustrated in the  FIG.  2 B  through  FIG.  9 G , may be control valves, electrically actuated valves, pneumatic valves, or other valves suitable to receive signals and open and close under, potentially, high pressure. The valves may receive signals from a controller or other source and the signals may cause the valves to move to a partially or fully opened or closed position. The signal may indicate the position that the valve may be adjusted to, e.g., a position halfway open, a position a third of the way open, a position a particular degree open, or completely open, such positions to be understood as non-limiting examples. In such examples, as the valve receives the signal indicative of a position to adjust to, the valve may begin turning to the indicated position. Such an operation may take time, depending on the valve used. To ensure proper operation and prevent damage (e.g., damage to the high-pressure heat exchanger  250 , such as when pressure of the wellhead fluid exceeds a pressure rating of the high-pressure heat exchanger  250 ), the valve may be configured to close in a specified period of time while high-pressure fluid flows therethrough. Such a configuration may be based on a torque value of the valve, e.g., a valve with a higher torque value may close faster than that of a control valve with a lower torque value. Such a specified period of time may be 5 seconds to 10 seconds, 5 seconds to 15 seconds, 5 seconds to 20 seconds, 10 seconds to 15 seconds, 10 seconds to 20 seconds, or 15 seconds to 20 seconds. For example, if a wellhead fluid flow exceeds a pressure of 15,000 PSI, the first heat exchanger valve  208  may close within 5 seconds of the pressure sensor  214  indicating the pressure exceeding 15,000 PSI. In other embodiments, the valves may either fully open or fully close, rather than open to positions in between. In yet other examples, the valves may be manually or physically opened by operators or technicians on-site. 
     As illustrated in  FIG.  2 A , pressure sensors  204 ,  212 ,  214 ,  222 ,  207  and/or temperature sensors  206 ,  216 ,  218 ,  226 ,  218  may be disposed at various points on or along different pipes, equipment, apparatuses, and/or devices at the well. Each sensor may provide information to adjust and/or control various aspects of the wellhead fluid flow. For example, pressure sensors  204 ,  212  may provide pressure measurements to determine whether a flow of wellhead fluid is not impeded in relation to hydrocarbon production targets. Pressure sensors  214 ,  220  may provide measurements to ensure that the flow of wellhead fluid through the high-pressure heat exchanger  250  is sufficient to facilitate heat transfer from the wellhead fluid to a working fluid in a ORC loop  221  and/or that the pressure within the high-pressure heat exchanger  250  does not exceed a pressure rating of the high-pressure heat exchanger  250 . In another example, temperature sensor  206  may provide data to control flow of the wellhead fluid. For example, if the flow of wellhead fluid is at a temperature sufficient to cause the working fluid to exhibit a vaporous phase change, then the first heat exchanger valve  208  and second heat exchanger valve  222  may be opened. Further, temperature sensors  216 ,  218 ,  226 ,  248  may provide measurements to ensure that the temperatures within the heat exchanger, of the flow of wellhead fluid, and of the flow of working fluid, are above the thresholds or within a range of thresholds, e.g., above a vaporous phase change threshold. For example, rather than or in addition to using temperature of the wellhead fluid as measured by temperature sensor  206 , the temperature of the working fluid as measured by temperature sensor  226  may be utilized to determine whether to maintain an open position of an already open first heat exchanger valve  208 . In such examples, the first heat exchanger valve  208  may initially be fully or partially open, e.g., prior to flow of the wellhead fluid. 
     In another embodiment, in addition to the first heat exchanger valve  208  and second heat exchanger valve  222 , the well  200  may include a first ORC unit valve  295  and a second ORC unit valve  296 . Such ORC unit valves  295 ,  296  may be utilized to control flow of working fluid flowing into the ORC unit  203 . Further the ORC unit valves  295 ,  296  may be utilized when more than one high-pressure heat exchanger  250  corresponding to one or more wellheads are connected to the ORC unit  203 . The ORC unit valves  295 ,  296  may be utilized to optimize or to enable the ORC unit  203  to meet a preselected electrical power output threshold via the flow of working fluid from one or more high-pressure heat exchangers into the ORC unit  203 , as will be understood by a person skilled in the art. The flow of working fluid may be adjusted to ensure that the ORC unit  203  produces an amount of electrical power greater than or equal to a preselected electrical power output threshold, based on various factors or operating conditions (e.g., temperature of wellhead fluid flow, temperature of working fluid flow, electrical output  236  of the ORC unit  203 , electrical rating of the ORC unit  203 , flow and/or pressure of the wellhead fluid, and/or flow and/or pressure of the working fluid). In some examples, the ORC unit valves  295 ,  296  may initially be fully open or at least partially open and as various factors or operating conditions are determined, then the ORC unit valves  295 ,  296  for one or more heat exchangers may be adjusted to enable the ORC unit  203  to meet a preselected electrical power output threshold, as will be understood by a person skilled in the art. The preselected electrical power output threshold may be set by a user or may be a predefined value generated by a controller (e.g., controller  272 ) based on various factors. The various factors may include an ORC unit electrical power rating or output rating or maximum potential temperature of the wellhead fluid and/or working fluid. 
     As shown, several pairs of sensors may be located adjacent to one another. In other examples, those positions, for example, the pressure sensor&#39;s  204  and the temperature sensor&#39;s  206  location, may be reversed. In yet another example, each one of the sensors may provide measurements for multiple aspects of the wellhead fluid, e.g., one sensor to provide a combination of flow, pressure, temperature, composition (e.g., amount of components in the wellhead fluid, such as water, hydrocarbons, other chemicals, proppant, etc.), density, or other aspect of the wellhead fluid or working fluid. Each sensor described above may be integrated in or within the pipes or conduits of each device or component, clamped on or over pipes or conduits, and or disposed in other ways, as will be understood by those skilled in the art. Further, the determinations, adjustments, and/or other operations described above may occur or may be performed by or in a controller. 
     As noted, a high-pressure heat exchanger  250  may be disposed, placed, or installed at a well. The high-pressure heat exchanger  250  may be disposed nearby or at a distance from the wellhead  202 . The high-pressure heat exchanger  250  may be a modular and/or mobile apparatus. In such examples, the high-pressure heat exchanger  250  may be brought or moved to a well or site (e.g., via a vehicle, such as a truck), placed at the well or site during hydrocarbon production, and then moved to another well or site at the end of hydrocarbon production. The high-pressure heat exchanger  250  may be disposed on a skid, a trailer, a flatbed truck, inside a geothermal generator unit, or inside an ORC unit  203 . Once brought to a well or site, the high-pressure heat exchanger  250  may be secured to the surface at the well. The high-pressure heat exchanger  250  may be configured to withstand pressures in excess of about 5,000 PSI, about 10,000 PSI, about 15,000 PSI, and/or greater. In an example, the high-pressure heat exchanger  250  may be a high-pressure shell and tube heat exchanger, a spiral plate or coil heat exchanger, a heliflow heat exchanger, or other heat exchanger configured to withstand high pressures. In another example, portions of the high-pressure heat exchanger  250  may be configured to withstand high-pressures. For example, if a shell and tube heat exchanger is utilized, the shell and/or tubes may be configured to withstand high-pressures. 
     In another embodiment, at least one fluidic path of the high-pressure heat exchanger  250  may be coated or otherwise configured to reduce or prevent corrosion. In such examples, a wellhead fluid may be corrosive. To prevent damage to the high-pressure heat exchanger  250  over a period of time, the fluid path for the wellhead fluid may be configured to withstand such corrosion by including a permanent, semi-permanent, or temporary anti-corrosive coating, an injection point for anti-corrosive chemical additive injections, and/or some combination thereof. Further, at least one fluid path of the high-pressure heat exchanger  250  may be comprised of an anti-corrosive material, e.g., anti-corrosive metals or polymers. As noted, the wellhead fluid may flow into the high-pressure heat exchanger  250  at a high pressure. As the high-pressure heat exchanger  250  may operate at high pressure, the high-pressure heat exchange may include pressure relief valves to prevent failures if pressure within the high-pressure heat exchanger  250  were to exceed the pressure rating of the high-pressure heat exchanger  250 . Over time, wellhead fluid flowing through the high-pressure heat exchanger  250  may cause a buildup of deposits or scaling. To prevent scaling and/or other related issues, the high-pressure heat exchanger  250  may be injected with scaling inhibitors or other chemicals or may include vibration or radio frequency induction devices. 
     Once the high-pressure heat exchanger  250  facilitates heat transfer from the wellhead fluid to the working fluid, the working fluid may partially, substantially, or completely change phases from a liquid to a vapor, vaporous state, gas, or gaseous state. The vapor or gas may flow to the ORC unit  203  causing an expander to rotate. The rotation may cause a generator to generate electricity, as will be further described and as will be understood by those skilled in the art. The generated electricity may be provided as an electrical output  236 . The electricity generated may be provided to in-field equipment, energy storage devices, equipment at other wells, or to a grid power structure. The working fluid in the high-pressure heat exchanger may be a working fluid to carry heat. Further, the working fluid of the high-pressure heat exchanger  250  may or may not exhibit a vaporous phase change. The working fluid may carry heat to another heat exchanger  205  of the ORC unit  203 . As such, heat may be transferred from the wellhead fluid to the working fluid of the high-pressure heat exchanger  250  and heat may be transferred from the working fluid of the high-pressure heat exchanger  250  to the working fluid of the ORC unit  203 . 
     In an example, the working fluid may be a fluid with a low boiling point and/or high condensation point. In other words, a working fluid may boil at lower than typical temperatures, while condensing at higher than typical temperatures. The working fluid may be an organic working fluid. The working fluid may be one or more of pentafluoropropane, carbon dioxide, ammonia and water mixtures, tetrafluoroethane, isobutene, propane, pentane, perfluorocarbons, other hydrocarbons, a zeotropic mixture of pentafluoropentane and cyclopentane, other zeotropic mixtures, and/or other fluids or fluid mixtures. The working fluid&#39;s boiling point and condensation point may be different depending on the pressure within the ORC loop  221 , e.g., the higher the pressure, the lower the boiling point. 
       FIG.  2 B  illustrates an embodiment of the internal components of an ORC unit  203 .  FIG.  2 B  further illustrates several of the same components, equipment, or devices as  FIG.  2 A  illustrates. As such, the numbers used to label  FIG.  2 B  may be the same as those used in  2 A, as those number correspond to the same component. The ORC unit  203  as noted may be a modular or mobile unit. As power demand increases, additional ORC units  203  may be added, installed, disposed, or placed at the well. The ORC units  203  may stack, connect, or integrate with each other ORC unit. In an example, the ORC unit  203  may be a modular single-pass ORC unit. 
     An ORC unit  203  may include a heat exchanger  205  or heater. Connections to the heat exchanger  205  or heater may pass through the exterior of the ORC unit  203 . Thus, as an ORC unit  203  is brought or shipped to a well or other location, a user, technician, service person, or other person may connect pipes or hoses from a working fluid heat source (e.g., the high-pressure heat exchanger  250 ) to the connections on the ORC unit  203 , allowing a heat source to facilitate phase change of a second working fluid in the ORC unit  203 . In such examples, the working fluid flowing through ORC loop  221  may include water or other organic fluid exhibiting a higher vaporous phase change threshold than the working fluid of the ORC unit  203 , to ensure proper heat transfer in heat exchanger  205 . Further, the heat exchanger  205  may not be a high-pressure heat exchanger. In such examples, the high-pressure heat exchanger  250  allows for utilization of waste heat from high-pressure wellhead fluids. In another embodiment and as will be described, a high-pressure heat exchanger  250  may be included in the ORC unit  203 . 
     In yet another embodiment, the high-pressure heat exchanger  250  may be considered an intermediary heat exchanger or another intermediary heat exchanger (e.g., intermediary heat exchanger  219 ) may be disposed between the high-pressure heat exchanger  250  and the ORC unit  203  (as illustrated in  FIG.  2 C  and described below). The working fluid flowing through the high-pressure heat exchanger  250  may be sufficient to heat another working fluid of the ORC unit  203 . The working fluid of such an intermediary heat exchanger may not physically flow through any of the equipment in the ORC unit  203 , except for heat exchanger  205 , thereby transferring heat from the working fluid in ORC loop  221  to an ORC working fluid in a loop defined by the fluid path through the heat exchanger  205 , condenser  211 , expander  232 , working fluid reservoir  298 , and/or pump  244 . 
     The ORC unit  203  may further include pressure sensors  228 ,  238 ,  246  and temperature sensors  230 ,  240  to determine whether sufficient, efficient, and/or optimal heat transfer is occurring in the heat exchanger  205 . A sensor or meter may further monitor electrical power produced via the expander  232  and generator  234 . Further, the ORC unit  203  may include a condenser or heat sink  211  to transfer heat from the second working fluid or working fluid of the ORC unit  203 . In other words, the condenser or heat sink  211  may cool the second working fluid or working fluid of the ORC unit  203  causing the second working fluid or working fluid of the ORC unit  203  to condense or change phases from vapor to liquid. The ORC unit  203  may also include a working fluid reservoir  298  to store an amount of working fluid, e.g., in a liquid state, to ensure continuous operation of the ORC unit  203 . The liquid state working fluid, whether from the working fluid reservoir  298  or directly form the condenser/heat sink  211 , may be pumped, via pump  244 , back to the heat exchanger  205 . Further, the pressure prior to and after pumping, e.g., as measured by the pressure sensors  238 ,  246 , may be monitored to ensure that the working fluid remains at a ORC unit or working fluid loop pressure rating. 
     As illustrated in  FIG.  2 C , the well may include an intermediary heat exchanger  219 . In such examples, an ORC unit  203  may not be configured for high-pressure heat exchange. As such, an intermediary heat exchanger  219  may be disposed nearby the high-pressure heat exchanger  250 , nearby the ORC unit  203 , or disposed at some other point in between to alleviate such issues. The intermediary heat exchanger  219  may include a working fluid, also referred to as an intermediary working fluid, to flow through the intermediary loop  223 . The intermediary fluid may include water, a water and glycol mixture, or other organic fluid exhibiting a higher vaporous phase change threshold than the working fluid of the ORC unit  203 . In an embodiment, the intermediary heat exchanger  219  may include sensors, meters, transducers and/or other devices at various positions throughout to determine characteristic of fluids flowing therein, similar to that of the high-pressure heat exchanger  250 . 
     As illustrated in  FIG.  2 D , rather than utilizing an ORC unit  203  that may not withstand high pressure, a high-pressure ORC unit or an ORC unit with integrated high-pressure heat exchanger  250  may be utilized for geothermal power generation. In such examples, the components, equipment, and devices may be similar to those described above. In another example, such a system, as illustrated in  FIG.  2 D , may include a heat sink  236  utilizing a cooled flow of wellhead fluid to cool the flow of working fluid. In such examples, as the flow of wellhead fluid passes through a choke valve  252 , the pressure of the flow of wellhead fluid may be reduced, e.g., for example, from about 15,000 PSI to about 1,500 PSI, from about 15,000 PSI to about 200 PSI, from about 15,000 PSI to about 100 PSI, about 15,000 PSI to about 50 PSI or lower, from about 10,000 PSI to about 200 PSI or lower, from about 5,000 PSI to about 200 PSI or lower, or from 15,000 PSI to lower than 200 PSI. In such examples, the temperature from a point prior to the choke valve  252  and after the choke valve  252 , e.g., a temperature differential, may be about 100 degrees Celsius, about 75 degrees Celsius, about 50 degrees Celsius, about 40 degrees Celsius, about 30 degrees Celsius, and lower. For example, the temperature of the wellhead fluid prior to the choke valve  252  may be about 50 degrees and higher, while, after passing through the choke valve  252 , the temperature, as measured by the temperature sensor  259 , may be about 30 degrees Celsius, about 25 degrees Celsius, about 20 degrees Celsius, to about 0 degrees Celsius. 
     The system may include, as noted, a temperature sensor  259  and pressure sensor  257  to determine the temperature of the wellhead fluid after the choke valve  252 . The system may include temperature sensor  240  to determine the temperature of the working fluid or ORC fluid exiting the heat sink  236  and temperature sensor  238  to determine the temperature of the working fluid or ORC fluid entering the heat sink  236 . The pressure and/or temperature of the wellhead fluid may be used to determine whether the heat sink  236  may be utilized based on pressure rating of the heat sink  236  and/or a liquid phase change threshold of the working fluid. In other words, if the flow of wellhead fluid is at a temperature sufficient to cool the working fluid and/or below a pressure rating of the heat sink  236 , the heat sink valve  254  may open to allow wellhead fluid to flow through the heat sink  236  to facilitate cooling of the working fluid. In another embodiment, the heat sink valve  254  may initially be fully or partially open. The temperature of the working fluid or ORC fluid may be measured as the fluid enters the heat sink  236  and exits the heat sink  236 . If the temperature differential indicates that there is no change or an increase in temperature, based on the temperature of the working fluid or ORC fluid entering the heat sink  236  and then leaving the heat sink  236 , then the heat sink valve  254  may be closed. Temperature sensors  238 ,  240 ,  256 ,  262 , and pressure sensors  258 ,  260  may be disposed within the heat sink  236  to ensure that the temperature of the wellhead fluid is suitable for cooling the working fluid and that the pressure of wellhead fluid does not exceed the pressure rating of the heat sink  236 . 
       FIG.  2 D  also illustrates two flow meters  277 ,  279  disposed prior to the first wellhead fluid valve  210  and first heat exchanger valve  208 . Such flow meters may measure the flow of the wellhead fluid at the point where the meter is disposed. Utilizing flow measurements may allow for fine-tuning or adjustment of the open percentage or position of the valves included in the system. Such fine-tuning or adjustment may ensure that the production of hydrocarbons at the well is not impeded by the use of the high-pressure heat exchanger. Other flow meters may be disposed at various other points of the system, e.g., after the first wellhead fluid valve  210 , prior to or after the choke valve  252 , at a point after the heat sink  236 , and/or at various other points in the system. As stated, these flow meter may be utilized to ensure proper flow wellhead fluid throughout the system. In an example, the sensors and/or meters disposed throughout the system may be temperature sensors, densitometers, density measuring sensors, pressure transducers, pressure sensors, flow meters, mass flow meters, Coriolis meters, spectrometer, other measurement sensors to determine a temperature, pressure, flow, composition, density, or other variable as will be understood by those skilled in the art, or some combination thereof. Further, the sensors and/or meters may be in fluid communication with a liquid to measure the temperature, pressure, or flow or may indirectly measure flow (e.g., an ultrasonic sensor). In other words, the sensors or meters may be a clamp-on device to measure flow indirectly (such as via ultrasound passed through the pipe to the liquid). 
     As illustrated in  FIG.  2 E , a controller  272  may be included at the well. The controller  272  may be utilized in any of the previous or following drawings. The controller  272  may include one or more controllers, a supervisory controller, and/or a master controller. The controller  272  may connect to all the equipment and devices shown, including additional equipment and devices not shown, and may transmit control signals, receive or request data or measurements, control pumps, monitor electricity generated, among other things (see  274 ). The controller  272  may, in another example, control a subset of the components shown. In another example, a controller may be included in an ORC unit (see  203  in  FIGS.  2 A through  2 C ). The controller  272  may connect to and control the controller in the ORC unit  203 . The controller  272  may transmit signals to the various control valves to open and close the valves by determined amounts or percentages or fully open or close the valves. The controller  272  may further determine, via a meter or other device or sensor, an amount of electrical power generated or being generated by the generator  234  or ORC unit  203 . 
     As illustrated in  FIG.  2 F , the system may include another heat sink  241 , in the case that the cooling offered by the flow of wellhead fluid in heat sink  236  is not sufficient. In an example, the heat sink  241  may be a fin fan cooler, a heat exchanger, a condenser, any other type of heat sink, a sing-pass parallel flow heat exchanger, a 2-pass crossflow heat exchanger, a 2-pass countercurrent heat exchanger, or other type of apparatus. As illustrated in  FIG.  2 G , the system may include a regenerator  290 . In such examples, the working fluid may flow through a first fluid path of the regenerator  290 . After the working fluid is cooled by a primary heat sink (e.g., heat sink  236 ), the working fluid may flow back through another fluid path of the regenerator  290 . As such, the heat from the first fluid path may pre-heat the working fluid, while the second fluid path may offer some level of cooling to the working fluid. 
     As illustrated in  FIG.  2 H , the system may include a gas expander  291 . In an example, the gas expander  291  may be a turbine expander, positive displacement expander, scroll expander, screw expander, twin-screw expander, vane expander, piston expander, other volumetric expander, and/or any other expander suitable for an ORC operation or cycle. For example and as illustrated, the gas expander  291  may be a turbine expander. As gas flows through the turbine expander, a rotor  293  connected to the turbine expander may begin to turn, spin, or rotate. The rotor  293  may include an end with windings. The end with windings may correspond to a stator  294  including windings and a magnetic field. As the rotor  293  spins within the stator  294 , electricity may be generated. Other generators may be utilized, as will be understood by those skilled in the art. The generator  293  may produce DC power, AC power, single phase power, or three phase power. 
       FIG.  3 A  and  FIG.  3 B  are block diagrams illustrating other novel implementations of a geothermal power generation enabled well to provide electrical power to one or more of in-field equipment, equipment at other wells, energy storage devices, and the grid power structure, according to one or more embodiment of the disclosure.  FIGS.  3 A and  3 B  may represent a side-view perspective block diagram of a well and the components at the well. In an example, wellhead fluid may flow from underground  304 . The wellhead fluid flow  308  may include hydrocarbons or a mixture of hydrocarbons and other fluids, e.g., water, chemicals, fluids leftover from fracturing operations, other residuals, and/or other fluids as will be understood by those skilled in the art. The wellhead fluid may flow from a wellbore. 
     As the wellhead fluid flows from the wellhead  306 , the wellhead fluid may flow to the high-pressure heat exchanger, through a bypass pipe, and/or a combination thereof based on various factors or characteristics, e.g., wellhead fluid temperature and/or pressure and/or working fluid temperature. For example, if the wellhead fluid flow  308  is above a vaporous phase change threshold for a working fluid flow  310 , then valve  332  may open, at least partially, to allow the wellhead fluid flow to the high pressure heat exchanger  312 . In such examples, the wellhead fluid may continue to flow through the primary or bypass wellhead fluid pipe. As such, valve  330  may remain open, whether completely or at a certain percentage. From the high-pressure heat exchanger  312 , the wellhead fluid may flow back to the primary or bypass wellhead fluid pipe, to a condenser  316  or other cooling apparatus, and/or a combination thereof. If the wellhead fluid is at a temperature to provide cooling to the working fluid flow  310 , then valve  336  may open to allow wellhead fluid to flow therethrough. In such examples, the valve  334  may close to prevent wellhead fluid from flowing back. If the wellhead fluid is not at a temperature to allow for cooling of the working fluid flow  310 , then valve  336  may close or remained closed and valve  334  may open or remain open. From the condenser  316  or the primary or bypass wellhead fluid pipe, the wellhead fluid may flow to in-field equipment  316 , storage tanks, and/or other processing equipment at the well. The valves described above may be controlled via controller  320 . 
     In another embodiment, rather than basing the opening and closing of valve  332  and/or valve  336  on wellhead fluid flow  308  temperature, the valve  332  and/or valve  336  may be opened or closed based on the temperature of the working fluid flow  310 . For example, prior to activating the wellhead  306  (e.g., allowing wellhead fluid to flow or pumping wellhead fluid from the wellhead  306 ), valve  332  may be open, fully or partially. As the wellhead fluid flows through the high-pressure heat exchanger  312 , the temperature of the working fluid flow  310  may be measured. Based on the working fluid flow  310  temperature, taken at continuously or at periodic intervals, and after a specified period of time, if the working fluid flow  310  does not reach a vaporous phase change temperature, then valve  332  may be closed. Further, such operations may be performed in conjunction with measuring wellhead fluid flow  308  and opening or closing valve  332  based on such measurements. 
     The wellhead fluid flowing through the high-pressure heat exchanger  312  may be at a temperature to facilitate heat transfer to a working fluid flow  310 . The working fluid may further flow, as a vaporous state working fluid flow to an ORC expander/generator  314 . The vaporous state working fluid may cause the ORC expander/generator  314  to generate electrical power to be utilized at equipment at the well (e.g., in-field equipment), energy storage device, or a grid power structure (via a transformer and power lines). The working fluid may then flow to a condenser  316  or other cooling apparatus. The condenser  316  or other cooling apparatus may facilitate cooling of the working fluid flow  310  via the wellhead fluid flow, air, another liquid, and/or other types of heat sinks or heat exchangers. The liquid state working fluid may then flow back to the high-pressure heat exchanger  312 . 
     In another embodiment, the high-pressure heat exchanger  312  may connect to an ORC unit/module  340  or one or more ORC units or modules. The number of ORC units/modules may scale based on power to be utilized by in-field equipment, the amount or potential capacity of electricity generation at the well, and/or other factors. After production of hydrocarbons begins, additional ORC units/modules may be added at the well or existing ORC units/modules may be removed from the well. 
       FIG.  4 A  and  FIG.  4 B  are simplified diagrams illustrating a control system for managing the geothermal power production at a well, according to one or more embodiment of the disclosure. A master controller  402  may manage the operations of geothermal power generation at a wellhead during hydrocarbon production. The master controller  402  may be one or more controllers, a supervisory controller, programmable logic controller (PLC), a computing device (such as a laptop, desktop computing device, and/or a server), an edge server, a cloud based computing device, and/or other suitable devices. The master controller  402  may be located at or near the well. The master controller  402  may be located remote from the well. The master controller  402 , as noted, may be more than one controller. In such cases, the master controller  402  may be located near or at various wells and/or at other off-site locations. The master controller  402  may include a processor  404 , or one or more processors, and memory  406 . The memory  406  may include instructions. In an example, the memory  406  may be a non-transitory machine-readable storage medium. As used herein, a “non-transitory machine-readable storage medium” may be any electronic, magnetic, optical, or other physical storage apparatus to contain or store information such as executable instructions, data, and the like. For example, any machine-readable storage medium described herein may be any of random access memory (RAM), volatile memory, non-volatile memory, flash memory, a storage drive (e.g., hard drive), a solid state drive, any type of storage disc, and the like, or a combination thereof. As noted, the memory  406  may store or include instructions executable by the processor  404 . As used herein, a “processor” may include, for example one processor or multiple processors included in a single device or distributed across multiple computing devices. The processor may be at least one of a central processing unit (CPU), a semiconductor-based microprocessor, a graphics processing unit (GPU), a field-programmable gate array (FPGA) to retrieve and execute instructions, a real time processor (RTP), other electronic circuitry suitable for the retrieval and execution instructions stored on a machine-readable storage medium, or a combination thereof. 
     As used herein, “signal communication” refers to electric communication such as hard wiring two components together or wireless communication for remote monitoring and control/operation, as understood by those skilled in the art. For example, wireless communication may be Wi-Fi®, Bluetooth®, ZigBee, cellular wireless communication, satellite communication, or forms of near field communications. In addition, signal communication may include one or more intermediate controllers or relays disposed between elements that are in signal communication with one another. 
     The master controller  402  may include instructions  408  to measure temperature at various points or locations of the system (e.g., as illustrated in, for example,  FIG.  2 E ). For example, temperature may be measured at a wellhead fluid temperature sensor  1   416 , heat exchanger temperature sensors  418 , wellhead fluid temperature sensor  2   420 , condenser temperature sensors  422 , and/or at various other points in the system  400 . Other characteristics may be measured as well, such as flow, density, pressure, composition, or other characteristics related to the wellhead fluid and/or working fluid. 
     Utilizing the characteristics noted above, the master controller  402  may control various aspects of the system  400 . For example, the master controller  402  may include flow control adjustment instructions  412 . The system  400  may include one or more valves placed in various locations (For example, but not limited to,  FIGS.  2 A through  2 H ). Valves of the system  400  may include a wellhead fluid valve  1   426 , heat exchanger valves  428 , wellhead fluid valve  2   430 , and condenser valves  432 . As noted other valves may be included in the system and controlled by the master controller  402 . The valves may operate to adjust flow based on a number of factors. Such factors may include temperature of a wellhead fluid, flow rate of the wellhead fluid, temperature of the working fluid, flow rate of the working fluid, pressure of the wellhead fluid at various points in the system, pressure of the working fluid at various points in the system, and/or some combination thereof. 
     In an example, the system  400  may include a user interface  436 , e.g., such as a monitor, display, computing device, smartphones, tablets, and other similar devices as will be understood by those skilled in the art. A user may view data, enter thresholds or limits, monitor status of the equipment, and perform other various tasks in relation to the equipment at the well. For example, a specific flow rate may be set for hydrocarbon production. As a wellhead begins producing hydrocarbons (e.g., wellhead fluids begin flowing from a wellhead), the master controller  402  may monitor flow rate and compare the flow rate to the threshold either set by a user or pre-set in the master controller  402 . If the master controller  402  determines that the heat exchanger valves  428  (e.g., via flow control adjustment instructions  412 ) should be open or are open and that the flow of wellhead fluid is higher or lower than the threshold, the master controller  402  may adjust the appropriate valves, e.g., wellhead fluid valve  426  and/or heat exchanger valves  428 . The valve associated with the primary or bypass wellhead fluid pipe, e.g., wellhead fluid valve  426 , may open or close by varying degrees based on such determinations. 
     In another example, the master controller  402  may include instructions  410  to control a pump for the ORC unit, e.g., working fluid pump  424 . If heat exchanger valves  428  and condenser valves  432  are closed, the master controller  402  may transmit a signal to shut down or cease operation of the working fluid pump  424 , if the working fluid pump  424  is operating. The master controller  402  may further transmit a signal, based on the heat exchanger valves  428  being open, to initiate or start operations of the working fluid pump  424 . The working fluid pump  424  may be a fixed pressure pump or a variable frequency pump. The master controller  402  may further include instructions  414  to monitor the power output from an ORC unit or from expanders/generators  434  (e.g., expander/generator A  434 A, expander/generator B  434 B, and/or up to expander/generator N  434 N). If the system  400  utilizes ORC units, the master controller  402  may determine the electrical power generated or output based on an output from, for example, ORC unit controller A  438 A, ORC unit controller B  438 B, and/or up to ORC unit controller N  438 N. If the power output drops to an un-economical or unsustainable level or electrical power generation ceases completely while the heat exchanger valves  428  are open, the master controller  402  may transmit signals to close the heat exchanger valves  428 . In another example, the master controller  402  may monitor electrical power output from other wells. The master controller  402  may monitor or meter the amount of electrical power being utilized at each of the wells and/or the amount of electrical power being generated at each of the wells. If an excess of electrical power exists, the master controller  402  may transmit signals causing the excess energy at any particular well to be stored in energy storage devices, transmitted to the grid, and/or transmitted to another well. If a deficit of electrical power exists, the master controller  402  may transmit a signal causing other wells to transmit electrical power to the well experiencing an electrical power deficit. In another example, the metered electrical power may be utilized for commercial trade, to determine a cost of the electricity generated, and/or for use in determining emissions or emission reductions through use of an alternate energy source (e.g., geothermal power). 
     In another example, the master controller  402  may include instructions to maximize energy output from an ORC unit. In such examples, the ORC unit may be connected to a plurality of high-pressure heat exchangers. Further, each of the high-pressure heat exchangers may connect to one or more wellheads. As a wellhead produces a wellhead fluid, the pressure and temperature of the wellhead fluid may vary, over time, as well as based on the location of the wellhead. The master controller  402  may determine the temperature of the wellhead fluid at each high-pressure heat exchanger and/or the temperature of the working fluid in each high-pressure heat exchanger. Based on these determinations, the master controller  402  may open/close valves associated with one or more particular high-pressure heat exchangers to ensure the most efficient heat transfer. Further, the master controller  402  may determine the amount of electrical power output from the ORC unit. Based on a power rating of the ORC unit (e.g., the maximum power output the ORC unit is able to produce) and/or the amount of electrical power output from the ORC unit, the master controller  402  may adjust valves associated with the one or more particular high-pressure heat exchangers to thereby increase electrical power output. Additional ORC units may be utilized and electrical power output for each may be optimized or efficiently generated. The master controller  402  may determine, for each ORC unit, the optimal amount or efficient amount of heated working fluid flowing from each high-pressure heat exchanger to ensure the highest amount of electrical power possible is generated per ORC unit or that each ORC unit meets a preselected electrical power output threshold. In such examples, each ORC unit may be connected to each high-pressure heat exchanger and the master controller  402  may determine which set of valves to open/close based on such an optimization or electrical power output threshold. 
     In another example, the master controller  402  may include failover instructions or instructions to be executed to effectively reduce or prevent risk. The failover instructions may execute in the event of ORC unit and/or high-pressure heat exchanger failure or if an ORC unit and/or high-pressure heat exchanger experiences an issue requiring maintenance. For example, the ORC unit and/or high-pressure heat exchanger may have various sensors or meters. Such sensors or meters, when providing measurement to the master controller  402 , may indicate a failure in the ORC unit and/or high-pressure heat exchanger. In another example, the master controller  402  may include pre-determined parameters that indicate failures. If the master controller  402  receives such indications, the master controller  402  may open, if not already open, the wellhead fluid valve  1   426  and wellhead fluid valve  2   430 . After the wellhead fluid valve  1   426  and wellhead fluid valve  2   430  are opened, the master controller  402  may close the heat exchanger valves  428 , the condenser valves  432 , or any other valve associated with the flow of fluid to the ORC unit and/or high-pressure heat exchanger. In such examples, the master controller  402  may prevent further use of the ORC unit and/or high-pressure heat exchanger until the issue or failure indicated is resolved. Such a resolution may be indicated by a user via the user interface  436  or based on measurements from sensors and/or meters. 
     In another example, the master controller  402  may, as noted, determine an amount of electrical power output by an ORC unit. The master controller  402  may additionally determine different characteristics of the electrical power output. For example, the master controller  402  may monitor the output voltage and frequency. Further, the master controller  402  may include pre-set or predetermined thresholds, limits, or parameters in relation to the monitored characteristics of the electrical power output. Further still, the master controller  402  may connect to a breaker or switchgear. In the event that the master controller  402  detects that an ORC unit exceeds any of the thresholds, limits, and/or parameters, the master controller  402  may transmit a signal to the breaker or switchgear to break the circuit (e.g., the flow of electricity from the ORC unit to a source) and may shut down the ORC unit (e.g., closing valves preventing further flow to the ORC unit, as described above). 
       FIG.  5    is a flow diagram of geothermal power generation in which, when a wellhead fluid is at or above a vaporous phase change temperature threshold, heat exchanger valves may be opened to allow wellhead fluid to flow therethrough, thereby facilitating heating of a working fluid for use in a ORC unit, according to one or more embodiment of the disclosure. The method is detailed with reference to the master controller  402  and system  400  of  FIGS.  4 A and  4 B . Unless otherwise specified, the actions of method  500  may be completed within the master controller  402 . Specifically, method  500  may be included in one or more programs, protocols, or instructions loaded into the memory of the master controller  402  and executed on the processor or one or more processors of the master controller  402 . The order in which the operations are described is not intended to be construed as a limitation, and any number of the described blocks may be combined in any order and/or in parallel to implement the methods. 
     At block  502 , the master controller  402  may determine whether the wellhead is active. Such a determination may be made based on sensors located at or near the wellhead, e.g., a pressure sensor indicating a pressure or a flow meter indicating a flow of a wellhead fluid or hydrocarbon stream from the wellhead. In other examples, a user may indicate, via the user interface  436 , that the wellhead is active. If the wellhead is not active, the master controller  402  may wait for a specified period of time and make such a determination after the period of time. In an example, the master controller  402  may continuously check for wellhead activity. 
     At block  504 , in response to wellhead activity or during hydrocarbon production, the master controller  402  may determine a wellhead fluid temperature. The wellhead fluid temperature may be measured by a wellhead fluid temperature sensor  1   416  disposed at or near the wellhead. The wellhead fluid temperature sensor  1   416  may be disposed on or in a pipe. In an example, various other temperature sensors may be disposed at other points in the system  400 , e.g., heat exchanger temperature sensor  418 , wellhead fluid temperature sensor  2   420 , condenser temperature sensor  422 , and/or other temperature sensors. The temperature measurements provided by such sensors may be utilized by the master controller  402  to determine which valves to open or close. 
     At block  506 , the master controller  402  may determine whether the wellhead fluid is at or above a vaporous phase change temperature threshold of a working fluid. In such examples, the vaporous phase change temperature may be based on the working fluid of the ORC unit. For example, for pentafluoropropane the vaporous phase change temperature or boiling point may be  15 . 14  degrees Celsius. In another example, or factors may be taken into account when determining whether to open heat exchanger valves  428 . For example, whether the pressure is within operating range of a high-pressure heat exchanger, whether the flow rate at a primary or bypass pipeline is sufficient to prevent impedance of hydrocarbon production, whether power generation costs are offset by power generation needs, among other factors. 
     At block  508 , if the wellhead fluid is at or above the vaporous phase change temperature, the master controller  402  may transmit a signal to heat exchanger valves  428  to open to a specified degree. In an example, the heat exchanger valves  428  may be may be fully opened or partially opened. The degree to which the heat exchanger valves  428  opens may depend on the temperature of the wellhead fluid, the flow rate of the wellhead fluid, and/or the pressure of the wellhead fluid. 
     At block  510 , the master controller  402  may close wellhead fluid valves (e.g., wellhead fluid valve  1   426 ) to divert a portion of the flow of wellhead fluids to the high-pressure heat exchanger. The wellhead fluid valves (e.g., wellhead fluid valve  1   426 ) may close partially or completely, depending on various factors, such as heat exchanger flow capacity, current flow rate, current pressure, current temperature, among other factors. Once the wellhead fluid valves (e.g., wellhead fluid valve  1   426 ) are closed, at block  512 , a working fluid pump  424  of the ORC unit may begin pumping the working fluid through the ORC loop. At block  514 , the master controller  402  may determine whether electricity is being generated. If not, the master controller  402  may check if the wellhead is still active and, if the wellhead is still active, the master controller  402  may adjust the valves (e.g., wellhead fluid valve  1   426  and heat exchanger valves  428 ) as appropriate (e.g., increasing flow through the heat exchanger to facilitate an increase in heat transfer). 
     At block  516 , if the wellhead fluid is lower than the vaporous phase change temperature, the master controller  402  may open or check if the wellhead fluid valves (e.g., wellhead fluid valve  1   426 ) are open. Further, the wellhead fluid valves may already be open to a degree and, at block  516 , may open further or fully open, depending on desired wellhead fluid flow. In an example, the wellhead fluid valve (e.g., wellhead fluid valve  1   426 ) may be used, with or without a separate choke valve, to choke or partially choke the wellhead fluid flow. Further, once the wellhead fluid valves are open, at block  518 , the master controller  402  may close the heat exchanger valves  428  fully or partially in some cases. 
       FIG.  6    is another flow diagram of geothermal power generation in which, when a wellhead fluid is at or above a vaporous phase change temperature, heat exchanger valves may be opened to allow wellhead fluid to flow therethrough, thereby facilitating heating of a working fluid for use in a ORC unit, according to one or more embodiment of the disclosure. The method is detailed with reference to the master controller  402  and system  400  of  FIGS.  4 A and  4 B . Unless otherwise specified, the actions of method  600  may be completed within the master controller  402 . Specifically, method  600  may be included in one or more programs, protocols, or instructions loaded into the memory of the master controller  402  and executed on the processor or one or more processors of the master controller  402 . The order in which the operations are described is not intended to be construed as a limitation, and any number of the described blocks may be combined in any order and/or in parallel to implement the methods. 
     Blocks  602  through  610  correspond to blocks  502  through  610 , as described above. Once it has been determined that the heat exchanger valves  428  should be open and after the heat exchanger valves  428  open, wellhead fluid may flow through the heat exchanger and/or the primary or bypass wellhead fluid pipe to a choke valve. The choke valve may reduce the pressure of the wellhead fluid and, thus, reduce the temperature of the wellhead fluid. At block  612 , the master controller  402  may determine the reduced pressure wellhead fluid temperature at or near a condenser or heat sink valve based on a measurement from the condenser temperature sensors  422 . The master controller  402  may, at block  614 , determine whether the wellhead fluid is at cool enough temperatures to facilitate cooling of a working fluid flow. The working fluid may have a condensation point or a temperature at which the working fluid changes phase from a vapor to a liquid. Such a temperature may be utilized as the threshold for such determinations. 
     At block  616 , if the temperature is cool enough, the master controller  402  may open the condenser valves  432 , allowing wellhead fluid to flow through the condenser or other cooling apparatus. At block  617  the master controller  402  may transmit a signal to the working fluid pump  424  to start or begin pumping working fluid through an ORC loop. In another example, at block  619 , if the temperature of the working fluid is not cool enough to facilitate cooling of the working fluid to any degree, the master controller  402  may close the condenser valves  432 . In another example, the master controller  402  may determine the temperature of the reduced pressure wellhead fluid flow and whether the temperature of the reduced pressure wellhead fluid flow, in conjunction with a primary or secondary cooler, may cool the working fluid to a point. The master controller  402 , in such examples, may consider the temperature of the working fluid entering the condenser and the temperature of the reduced pressure wellhead fluid flow at or near the condenser valve  432 . 
     As noted and described above, the master controller  402  may, at block  618 , determine whether electric power is generated. In another example, if the wellhead temperature is not high enough to produce geothermal power, the master controller  402  may, at block  620 , open the wellhead fluid valves. At block  622 , the master controller  402  may close, if the heat exchanger valves  428  are open, the heat exchanger valves  428 . Finally, at block  624 , the master controller  402  may close condenser valves  432 . 
       FIG.  7 A  is a flow diagram of geothermal power generation in which, when a working fluid or ORC fluid is at or above a vaporous phase change temperature threshold, heat exchanger valves may remain open to allow wellhead fluid to flow therethrough, thereby facilitating heating of the working fluid or ORC fluid for use in an ORC unit, according to one or more embodiment of the disclosure. The method is detailed with reference to the master controller  402  and system  400  of  FIGS.  4 A and  4 B . Unless otherwise specified, the actions of method  700  may be completed within the master controller  402 . Specifically, method  700  may be included in one or more programs, protocols, or instructions loaded into the memory of the master controller  402  and executed on the processor or one or more processors of the master controller  402 . The order in which the operations are described is not intended to be construed as a limitation, and any number of the described blocks may be combined in any order and/or in parallel to implement the methods. 
     At block  702 , the master controller  702  may determine whether the wellhead is active. Such a determination may be made based on sensors located at or near the wellhead, e.g., a pressure sensor indicating a pressure or a flow meter indicating a flow of a wellhead fluid or hydrocarbon stream from the wellhead. In other examples, a user may indicate, via the user interface  436 , that the wellhead is active. If the wellhead is not active, the master controller  402  may wait for a specified period of time and make such a determination after the specified period of time. In an example, the master controller  402  may continuously check for wellhead activity. 
     At block  704 , in response to wellhead activity or during hydrocarbon production, the master controller  402  may open heat exchanger valves  428 . At block  706 , the master controller  402  may close wellhead fluid valve  1   426 , at least partially. At block  708 , when the heat exchanger valves  428  is open and wellhead fluid valve  1   426  is fully or partially closed, working fluid or ORC fluid may be pumped through the ORC unit. 
     At block  710 , the master controller  402  may measure the temperature of the working fluid or ORC fluid. At block  712 , the master controller  402  may determine whether the wellhead fluid is at or above a vaporous phase change temperature threshold. In such examples, the vaporous phase change may include when the working fluid or ORC fluid changes from a liquid to a vapor or gas. For example, for pentafluoropropane the vaporous phase change temperature or boiling point may be 15.14 degrees Celsius. In another example, other factors may be taken into account when determining whether to maintain an open percentage of the heat exchanger valves  428 . For example, whether the pressure is within operating range of a high-pressure heat exchanger, whether the flow rate at a primary or bypass pipeline is sufficient to prevent impedance of hydrocarbon production, whether power generation costs are offset by power generation needs, among other factors. 
     At block  712 , if the working fluid or ORC fluid is at or above the vaporous phase change temperature, the master controller  402  may determine whether electricity is generated at the ORC unit. If electricity is not generated, the master controller  402  may check, at block  702 , whether the wellhead is active and perform the operations of method  700  again. 
     If the working fluid or ORC fluid, at block  712  is not at a vaporous phase change temperature, then, at block  714 , the master controller  402  may first determine whether a first specified period of time has lapsed. The first period of time may be period of time of sufficient length to determine whether or not the working fluid or ORC fluid may reach a vaporous phase change state. Such a first specified period of time may be about an hour or more, two hours, three hours, four hours, or some other length of time during wellhead activity. 
     If the first specified period of time has not lapsed, at block  716 , the master controller  402  may wait a second specified period of time before measuring the temperature of the working fluid or ORC fluid The second specified period of time may be less than the first specified period of time. 
     If the first specified period of time has lapsed, then the master controller  402  may have determined that, based on the temperature of the working fluid or ORC fluid, that the wellhead fluid may not reach temperatures sufficient to cause a vaporous phase change of the working fluid or ORC fluid. As such, at block  718 , the master controller may close the open wellhead fluid valves and, at block  720 , close the heat exchanger valves  428 . 
       FIG.  7 B  is another flow diagram of geothermal power generation in which, when a working fluid or ORC fluid is at or above a vaporous phase change temperature threshold, heat exchanger valves may remain open to allow wellhead fluid to flow therethrough, thereby facilitating heating of the working fluid or ORC fluid for use in an ORC unit, according to one or more embodiment of the disclosure. The method is detailed with reference to the master controller  402  and system  400  of  FIGS.  4 A and  4 B . Unless otherwise specified, the actions of method  701  may be completed within the master controller  402 . Specifically, method  701  may be included in one or more programs, protocols, or instructions loaded into the memory of the master controller  402  and executed on the processor or one or more processors of the master controller  402 . The order in which the operations are described is not intended to be construed as a limitation, and any number of the described blocks may be combined in any order and/or in parallel to implement the methods. 
     Blocks for  FIG.  7 B  may perform the same functions as described for blocks of  FIG.  7 A . As such, those blocks include the same numbers, such as block  702  through block  722 . In addition to those operations, at block  724  the master controller  402  may check whether the heat exchanger vales may be open. If they are not the master controller  402  may open the heat exchanger valves and close, at least partially, the wellhead fluid valves. If the heat exchanger valves are open, the master controller  402  may not change or adjust any of the valves open percentage, but rather continue to or start pumping the working fluid or ORC unit through the ORC unit. 
     In addition, after the master controller  402  closes the heat exchanger valves at block  720 , the master controller  402  may determine, at block  726 , the wellhead fluid temperature at the heat exchanger. At block  728 , the master controller may determine whether the wellhead fluid is at a vaporous phase change temperature of the working fluid or ORC fluid. If the wellhead fluid temperature is less than such a value, the master controller  402  may wait and measure the temperature again after a period of time. If the wellhead fluid temperature is greater than or equal to such a value, the master controller  402  may perform the operations of method  701  starting at block  724  again. 
       FIG.  8    is a flow diagram of geothermal power generation in which a working fluid flow is determined based on a preselected electrical power output threshold, according to one or more embodiment of the disclosure. The method is detailed with reference to the master controller  402  and system  400  of  FIGS.  4 A and  4 B . Unless otherwise specified, the actions of method  800  may be completed within the master controller  402 . Specifically, method  800  may be included in one or more programs, protocols, or instructions loaded into the memory of the master controller  402  and executed on the processor or one or more processors of the master controller  402 . The order in which the operations are described is not intended to be construed as a limitation, and any number of the described blocks may be combined in any order and/or in parallel to implement the methods. 
     At block  802 , each of one or more heat exchangers may be connected to one or more wellhead fluid lines. Each of the one or more wellhead fluid lines may correspond to a wellhead. At block  804 , an ORC unit may be connected to the one or more heat exchangers. In another example, the system  400  may include one or more ORC units and each of the one or more ORC units may connect to one or more heat exchangers or two or more heat exchangers. 
     At block  806 , heat exchanger valves positioned between the one or more heat exchangers and the one or more wellhead fluid lines may be opened. Once opened, the heat exchanger valves may allow for continuous diversion of the flow of wellhead fluid through the heat exchanger. The flow of wellhead fluid through the heat exchanger may facilitate transfer of heat from the flow of wellhead fluid to a flow of working fluid or intermediate working fluid. 
     At block  808 , ORC unit valves may be opened. The ORC unit valves may initially be fully opened or partially opened. The ORC unit valves, when open, may allow for working fluid from each of the heat exchangers to flow into the ORC unit. Each working fluid flow may be combined and may pass through the ORC unit. 
     At block  810 , the master controller  402  may determine one or more operating conditions of the ORC unit and/or the system  400 . The one or more operating conditions may include the flow rate and/or pressure of working fluid flowing through each of the one or more heat exchangers, the flow rate and/or pressure of wellhead fluid flowing through each of the one or more heat exchangers or at any other point downstream of the wellhead, the temperature of the working fluid in each of the one or more heat exchangers, the temperature of wellhead fluid at each of the one or more heat exchangers, the temperature of the combined working fluid flow at the ORC unit, the electrical power output from the ORC unit, and/or the open position of each of the valves included in the system  400 . 
     At block  812 , based on the determined operating conditions, the master controller  402  may determine an optimal or efficient working fluid flow of the ORC unit. The optimal or efficient working fluid flow may depend on the temperature of the combined working fluid flowing to the ORC unit. The other operating conditions, described above, may be utilized to determine the optimal or efficient working fluid flow. The optimal or efficient working fluid flow may comprise the combined flow of working fluid flowing into the ORC unit to thereby produce a maximum amount of electrical power possible or to enable the ORC unit to meet a preselected electrical power output threshold. The optimal or efficient working fluid flow may be at a temperature sufficient to produce such an amount of electrical power (e.g., a temperature greater than or equal to the boiling point of the working fluid within the ORC unit). The optimal or efficient working fluid flow may be indicated by the master controller  402  as one or more open positions for each of the ORC unit valves and/or heat exchanger valves. 
     At block  814 , the master controller  402  may, based on a determined optimal or efficient working fluid flow, determine whether to adjust the one or more ORC unit valves. Other valves within the system  400  may be adjusted based on the optimal or efficient working fluid flow, such as one or more heat exchanger valves and/or one or more wellhead fluid valves. If it is determined that the ORC unit valves or any other valves are to be adjusted, the master controller  402 , at block  816 , may transmit a signal to the valve to be adjusted indicating a new open position or closed position for the valve to adjust to. After the signal is transmitted, the valve may automatically adjust to the position indicated. If the valve is not to be adjusted or after the valves have been adjusted, the master controller  402  may determine operating conditions again. In an example, the master controller  402  may wait for a period of time, allowing the system to adjust to the new temperatures and flow rates or to reach equilibrium, prior to determining the operating conditions. 
       FIG.  9 A ,  FIG.  9 B ,  FIG.  9 C ,  FIG.  9 D , and  FIG.  9 E  are block diagrams illustrating novel implementations of one or more geothermal power generation enabled wells to provide electrical power to one or more of in-field equipment, equipment at one of the other wells, energy storage devices, and the grid power structure, according to one or more embodiment of the disclosure. As illustrated in  FIG.  9 A , various wells  902 A,  902 B, up to  902 N may be positioned in proximity to one another. For example, one well (e.g., well A  902 A may be located at a distance of over about 1 mile, about 5 miles, about 10 miles, about 25 miles, or more to another well (e.g., well B  902 B or well N  902 N). Each well  902 A,  902 B,  902 N may include various in-field equipment  910 A,  910 B,  910 N. Each well  902 A,  902 B,  902 N may include one or more wellheads  904 A,  904 B,  904 N. Each wellhead  904 A,  904 B,  904 N may connect to a high-pressure heat exchanger  906 A,  906 B,  906 N and the high-pressure heat exchanger  906 A,  906 B,  906 N may connect to ORC equipment  908 A,  908 B,  908 N. The ORC equipment  908 A,  908 B,  908 N may generate electrical power. The electrical power may be provided to the in-field equipment  910 A,  910 B,  910 N. A surplus of electrical power may be provided to an energy storage device  920 A,  920 B,  920 N. The ORC equipment  908 A,  908 B,  908 N may also transmit electrical power energy to other wells, energy storage devices, or to a grid power structure  912 . 
     As noted and as illustrated in  FIG.  9 B , the high-pressure heat exchanger N  906 N may connect to one or more wellheads  904 A,  904 B,  904 N. For example, a well N  902  may include 1, 2, 3, or more wellheads (e.g., wellhead A  904 A, wellhead B  904 B, and/or up to wellhead N  904 N). All of the wellheads  904 A,  904 B,  904 N may connect to one high pressure heat exchanger N  906 N. In another example, a well N  902 N may include one or more high-pressure heat exchangers, as illustrated in  FIG.  9 D  and  FIG.  9 E . In such examples, the wellheads  904 A,  904 B,  904 N may connect to one or more of the high-pressure heat exchangers. 
     As described and as illustrated in  FIG.  9 C , the well N  902 N may include one or more wellheads (e.g., wellhead A  904 A, wellhead B  904 B, and/or up to wellhead N  904 N), one or more sets of ORC equipment (e.g., ORC equipment A  908 A, ORC equipment B  908 B, and/or up to ORC equipment N  908 N), and one or more sets of in-field equipment (e.g., in-field equipment A  910 A, in-field equipment B  910 B, and/or up to in-field equipment N  910 N). As noted, a well N  902 N may include one high-pressure heat exchanger, as illustrated in in  FIG.  9 D  and  FIG.  9 E . The well  902  may further include additional high-pressure heat exchangers  906 . 
     As illustrated in  FIGS.  9 D and  9 E , a well N  902 N may include one or more wellheads (e.g., wellhead A  904 A, wellhead B  904 B, and/or up to wellhead N  904 N). Each of the one or more wellheads  904 A,  904 B,  904 N may correspond to a high-pressure heat exchanger (e.g., heat exchanger A  906 A, heat exchanger B  906 B, and/or up to heat exchanger N  906 N). In other examples, two or more high-pressure heat exchangers may correspond to a particular wellhead, while in other examples, two or more wellheads may correspond to a high-pressure heat exchanger. Further, a well N  902 N may include one ORC equipment A  908 A or unit, as illustrated in  FIG.  9 D . A well N  902 N may include two ORC equipment (e.g., ORC equipment A  908 A and ORC equipment B  908 B) or units or, in some cases, more. In such examples, each ORC equipment  908 A,  908 B may connect to each of the high-pressure heat exchangers  906 A,  906 B,  906 N. As wellhead fluid flows from a wellhead  904 A,  904 B,  904 N, the temperature and pressure may vary based on a number of factors (e.g., production, type of fluids, distance from the high-pressure heat exchanger, among other factors). 
     As such, a working fluid of a particular high-pressure heat exchanger  906 A,  906 B,  906 N may be heated to a degree sufficient, insufficient, or more than sufficient to cause the working fluid of the ORC equipment  908 A,  908 B to exhibit a vaporous phase change. Since the temperature of the wellhead fluid varies, a controller (e.g., controller  916 A,  916 B, up to  916 N or master controller  918 , as illustrated in  FIG.  9 F ) may determine the temperature of working fluid at each high-pressure heat exchanger  906  and determine the most efficient and/or optimal combination to be utilized for generating the most electrical power or for generating an amount of electrical power to meet a preselected electrical power output threshold at the ORC equipment  908 A,  908 B. The electrical power output by the ORC equipment  908 A,  908 B may be measured by, for example, an electrical power meter or other device suitable to determine electrical power output. The controller may also determine the temperature of the combination of working fluid or intermediate working fluid entering the ORC equipment  908 A,  908 B, via, for example, one or more temperature sensors positioned at or near an inlet of the ORC equipment  908 A,  90 B. The inlet may allow working fluid or intermediate working fluid to flow into the ORC equipment  908 A,  908 B. The controller may determine the most efficient and/or optimal combination or amount of working fluid or intermediate working fluid from the one or more high-pressure heat exchangers  906 A,  906 B,  906 N based on a variety of factors noted above. For example, the most efficient and/or optimal combination or amount may be based on wellhead fluid temperature from each of the one or more wellheads  904 A,  904 B,  904 N, the working fluid or intermediate working fluid temperature at each of the high-pressure heat exchangers  906 A,  906 B,  906 N, and/or electrical power output (e.g., a measurement indicative of the electrical power generated) by the ORC equipment  908 A,  908 B. Other factors may include flow rate and pressure of each of the high-pressure heat exchangers  906 A,  906 B,  906 N, current open positions high-pressure heat exchanger valves, and/or current open positions of other valves included at the well N  902 N. 
     For example, if high-pressure heat exchanger A  906 A includes a working fluid at a temperature slightly less than a temperature to cause vaporous phase change, then valves providing working fluid or intermediate working fluid from the high-pressure heat exchanger A  906 A to the ORC equipment  908 A,  908 B may be closed. In another example, if high-pressure heat exchanger B  906 B is providing working fluid at a temperature well above a temperature to cause vaporous phase change, then valves providing working fluid or intermediate working fluid from high-pressure heat exchanger B  906 B to ORC equipment A  908 A and/or to ORC equipment B  908 B may be adjusted to positions such that a greater portion of the working fluid or intermediate working fluid is transported to ORC equipment A  908 A and/or to ORC equipment B  908 B. 
     In yet another example, all valves for allowing flow of working fluid or intermediate working fluid to the ORC equipment A  908 A and/or ORC equipment B  908 B may be, at least, in a partially open position. The temperature of the wellhead fluid and/or working fluid of each heat exchanger  906 A,  906 B,  906 N may be determined or measured. Further, the electrical power output of the ORC equipment A  908 A and/or ORC equipment B  908 B may be determined. The positions of each valve for allowing flow of working fluid or intermediate working fluid to the ORC equipment A  908 A and/or ORC equipment B  908 B may be adjusted to different partially open positions, fully opened positions, or fully closed positions. Such valve adjustments may be based on maximization of the resultant temperature and heat delivered to the ORC equipment A  908 A and/or ORC equipment B  908 B once the combined working fluid flows into the ORC equipment  908  A  908 A and/or ORC equipment B  908 B. The valve adjustments may be based on, rather than or in addition to other factors, the maximization of the electrical power output from the ORC equipment A  908 A and/or ORC equipment B  908 B.Valve adjustments may further be based on wellhead fluid temperature and/or some combination of the factors described herein. 
     As noted and described above and as illustrated in  FIG.  9 F , a controller (e.g., controller A  916 A, controller B  916 B, and/or up to controller N  916 N) may be included at one or more of the wells  902 A,  902 B,  902 N. The controller  916 A,  916 B,  916 N may control and monitor various aspects of the well  902 A,  902 B,  902 N. The controller  916 A,  916 B,  916 N of each well  902 A,  902 B,  902 N may connect to a master controller  918 , the master controller  918  may control the operations of the ORC equipment  908 A,  908 B,  908 N, as well as other equipment (e.g., valves and/or pumps) at each of the wells  902 A,  902 B,  902 N. As described above and illustrated in  FIG.  9 G , the master controller  918  may connect to one or more wellheads  904 A,  904 B,  904 N. The ORC enabled wells  902 A,  902 B,  902 N may provide power to one or more of in-field equipment at the ORC enabled well  902 A,  902 B,  902 N, to an energy storage device, and/or a grid structure device (see  912 ). 
     This application is a continuation of U.S. application Ser. No. 17/650,811, filed Feb. 11, 2022, titled “SYSTEMS FOR GENERATING GEOTHERMAL POWER IN AN ORGANIC RANKINE CYCLE OPERATION DURING HYDROCARBON PRODUCTION BASED ON WELLHEAD FLUID TEMPERATURE”, which is a continuation of U.S. application Ser. No. 17/305,298, filed Jul. 2, 2021, titled “SYSTEMS FOR GENERATING GEOTHERMAL POWER IN AN ORGANIC RANKINE CYCLE OPERATION DURING HYDROCARBON PRODUCTION BASED ON WELLHEAD FLUID TEMPERATURE”, now U.S. Pat. No. 11,280,322, issued Mar. 22, 2022, which claims priority to and the benefit of U.S. Provisional Application No. 63/200,908, filed Apr. 2, 2021, titled “SYSTEMS AND METHODS FOR GENERATING GEOTHERMAL POWER DURING HYDROCARBON PRODUCTION,” the entire disclosures of all of which are incorporated herein by reference. 
     In the drawings and specification, several embodiments of systems and methods to provide geothermal power in the vicinity of a wellhead during hydrocarbon production have been disclosed, and although specific terms are employed, the terms are used in a descriptive sense only and not for purposes of limitation. Embodiments of systems and methods have been described in considerable detail with specific reference to the illustrated embodiments. However, it will be apparent that various modifications and changes can be made within the spirit and scope of the embodiments of systems and methods as described in the foregoing specification, and such modifications and changes are to be considered equivalents and part of this disclosure.