GB2625423A - Methods to mitigate black burn - Google Patents

Abstract

A method for reducing emissions from a surface well testing system comprising controlling a rate of emissions from a plurality of emissions sources. The plurality of emissions sources comprises a burner configured to burn fluids. The method includes determining that the fluids will not completely burn in the burner, calculating estimated emissions rates from the plurality of emissions sources, determining a first burn configuration for the emissions sources based, at least in part, on the determination that the fluids will not completely burn in the burner and the calculated emission rates, and controlling the rate of emissions from the plurality of emissions sources according to the first burn configuration. Determining fluid will not completely burn may be based on sensor data and skid states or on user input. Determining first burn configuration includes adjusting system controls including set points, parameters and setting for at least one burner, a separator, a tank a pump, a diverter manifold, a choke, and a plurality of motorised valves. To improve burn conditions natural gas may be supplied to the burner via a first flow line and water via second flow line. Incomplete burning gives rise to black burn.

Description

METHODS TO MITIGATE BLACK BURN

IECHNICAL FIELD

[0001] The disclosure generally relates to the field of surface well testing equipment and, more specifically, automating techniques to reduce emissions from surface testing equipment.

BACKGROUND

[0002] Black burn, a scenario when an oil-to-air ratio creates conditions for incomplete burning of hydrocarbons, is one of the main contributors to the generation of unwanted gas emissions during surface well testing. Currently, black burn is manually mitigated with adjustments based upon experiential knowledge and is inconsistently mitigated. Therefore, techniques to automate and optimize the mitigation of black burn and reduce site-wide emissions may prove operationally and financially advantageous.

BRIEF DESCRIPTION OF THE DRAWINGS

[0003] Embodiments of the disclosure may be better understood by referencing the accompanying drawings.

[0004] Figure 1 depicts a first example process flow diagram describing a surface well testing facility, according to some embodiments.

[0005] Figure 2 depicts a second example process flow diagram, according to some embodiments [0006] Figure 3 depicts a diagram of burner position tracking, according to some embodiments [0007] Figure 4 depicts an example interface for the burner position tracking, according to some embodiments.

[0008] Figure 5 depicts an example burner head, according to some embodiments. [0009] Figure 6 depicts an example computer, according to some embodiments.

[0010] Figure 7 depicts a first flowchart of example operations, according to some embodiments.

[0011] Figure 8 depicts a second flowchart of example operations, according to some embodiments.

DESCRIPTION OF EMBODIMENTS

[0012] The description that follows includes example systems, methods, techniques, and program flows that embody embodiments of the disclosure. However, it is understood that this disclosure may be practiced without these specific details.

Overview [0013] Conditions that cause black burn to occur may change quickly and therefore necessitate similarly dynamic intervention to mitigate it. In some embodiments, sensor data may be combined with skid state status data from at least a burner, separator, and/or choke to determine if black burn is occurring or likely occurring. A new configuration for the burner and separator may be determined from the status data that may eliminate the black burn, and these parameters may be set throughout the system. New mechanical elements may be introduced to facilitate system-wide automation that enable automated control to optimize and execute parameters leading to a cleaner burn. An automated control system may track various parameters to understand over time what affects black burn and different system configurations which may be used to mitigate its future occurrence. A new method of introducing (such as mixing) natural gas into the oil prior to combustion to facilitate a clean burner may also be included to mitigate occurrences of black burn.

Example Illustrations [0014] Figure 1 depicts a first example process flow diagram describing a surface well testing facility, according to some embodiments. The surface well testing facility may comprise at least a choke proximate to a producing wellhead, a separator, and a burner 159. A transfer pump and tank system 100 may be configured to receive well fluids from a producing well and/or the separator. The transfer pump and tank system 100 may comprise a transfer pump skid including, for example, motorized valves 121, 123, 127, 133, and H5, a pump assembly 125, flow control valves (FCVs) 137, 139, and a turbine flow meter 141. The transfer pump skid, when activated, may convey the fluid through the surface well testing facility from a tank 111 (such as a surge tank or any other suitable tank) to a diverter manifold leading to at least one of burners 159, 189. In some embodiments, the tank 111 may be configured receive well fluids from the separator (not depicted) that is coupled with a producing wellhead. In some embodiments, the tank 111 may be replaced by a second separator or similar vessel. Fluid may be pumped to the tank 1 1 1 via an inlet 101 and through a motorized valve 102 when the motorized valve 102 is open and a motorized valve 103 is closed. In some embodiments, the fluid may alternatively bypass the transfer pump skid by opening the motorized valve 103 at the tank 111. In bypassing the transfer pump skid, fluid flow from the separator may be sent directly to the diverter manifold and burners 159, 189 via flow lines 131 and 143. In normal operation, the fluid may travel from the inlet 101 into the tank 111 via the open motorized valve 102 and along flow line 109. In some embodiments, the fluid may comprise water and hydrocarbons in either a vapor (gas) or liquid state, where the liquid state includes oil. The oil may further comprise dissolved gases within. Water may be drained from the tank 111 via a motorized drain valve 105. In some embodiments, the motorized drain valve 105 may lead to a flow line coupled with flow line 143.

[0015] Gases may exit the tank 111 via a low-pressure line 117 and pass through a motorized pressure control valve 115. From the low-pressure line 117, the gases may travel through a flame arrester 145 to a low-pressure line 149 as part of the diverter manifold. The diverter manifold may comprise at least the low-pressure line 149, low-pressure flares 147, 179, high-pressure flares 175, 153, and burners 159, 189. The low-pressure line 149 may lead into the low-pressure flare 147 where the gases are burned. In some embodiments, the flame arrester 145 may be configured to halt a rogue flame from traveling upstream the low-pressure line 117 and causing a potential ignition of the tank 111. In a situation where the low-pressure flare 147 is inoperable or if a flow rate of gas within the system exceeds a limit of the low-pressure flare 147, the gases may be routed to a low-pressure flare 179. In normal operation, one of either burner 159 or 189 may be operational, and flow to either burner 159 or 189 may be adjusted by opening or closing motorized valves 146, 150. In some embodiments, valves such as the valves 146, 150 may instead be manual valves actuated by a user. In some embodiments, flow to the low-pressure flare 147 may be adjusted via the motorized pressure control valve 115.

[0016] Due to natural discrepancies in fluid densities, the gas, oil, and water may separate within the tank 111. An induction heater 112 may be positioned in the tank 111 near the bottom of an oil column within the tank 111. In some embodiments, if a medium or heavy oil is produced, the oil may be conditioned inside the tank 111 by controlling the induction heater 112 inside the tank, enabling further separation of the fluids and a viscosity reduction of the oil. Alternatively, or in addition, the oil may be conditioned by introducing additional chemicals (such as Diesel) for treatment with re-circulation prior to burn. For example, a motorized valve 133 may be actuated to a closed position such that when a motorized valve 113 is actuated to an open position, and fluid inside the tank 111 may be re-circulated on itself (not being pumped to the burner 159). Fluid may exit the tank 111, travel through motorized valves 113 and 123, and through the pump assembly 125 when a motorized valve 127 is closed. The pump assembly 125 may consist of a progressive cavity pump driven by a motor. In some embodiments, the pump may comprise a rotor and a stator, where the motor is coupled with the rotor such that reciprocation enables positive fluid displacement between the pump's rotor and stator. In other embodiments, the pump assembly may comprise a centrifugal pump, a diaphragm pump, etc. [0017] When the motorized valve 133 is closed, flow may be routed through a motorized valve 135 in the open position and continue to flow control valves (FCVs) 137 and 139. While the motorized valves may provide some flow control, the FCVs 137, 139 may offer a more precise regulation of a flow rate of the fluid. The fluid then travels from the FCVs along flow line 119, through a motorized valve 121, and back to the tank 111. During the recirculation process, fluid samples may be taken at the tank 111 to monitor properties of the oil such as, for example, an API gravity and viscosity of the oil. Additional chemicals or additional recirculation time may be added to ensure proper fluid (oil) properties are met prior to pumping the contents of the tank 111 to the burner 159 (this process is often called batch flaring). The recirculation process may be repeated until conditions for a burn condition that eliminates black burn is met. The modulation of the motorized valves such as the motorized valves 103, 133, for example, may be controlled by techniques including, but not limited to automatic control via an on-site computer, remote control, or automatic control via cloud computing. The transfer pump and tank system 100 may include a black burn optimizer (discussed later) or similar algorithm to control the motorized valves, pumps, and hardware within the transfer pump and tank system 100.

[0018] In some embodiments, fluids may be routed directly from the tank 111 to the burner 159. For example, in a scenario in which recirculating to the tank 111 is not the most viable option, fluids may be conveyed through motorized valves 113 and 123 actuated in the open position, through the pump assembly 125, and through the motorized valve 133 actuated in the open position. From the motorized valve 133, flow may continue through a check valve 129 configured to prevent reverse flow. In some embodiments, the turbine flow meter 141 may be configured to measure the flow rate of fluid sent from the transfer pump skid to the burners 159, 189. Other safety related features surrounding the stoppage of flow along flow line 143 may include, but are not limited to: remote/automatic operation of valve 127 (valve to bypass the pump assembly 125), high pump differential pressure automatic pump shut-down of the pump assembly 125, fluid temperature (Tout) monitoring to trigger pump shut-down, liquid level monitoring in tank 111 triggering automatic pump shut-down, fluid detection via a sensor at an inlet of the pump assembly 125 detecting a dry running condition and triggering automatic pump shut-down, thermal sensing via a thermal sensor coupled to the motor of pump assembly 125 to trigger pump shut-down, leak detection via a sensor at the pump assembly 125 with the option to shut-down, etc. [0019] From the turbine flow meter 141, oil flow may continue to the flow line 143 and to an oil output 156 comprising a check valve (for reverse flow prevention) via a motorized valve 155 in the open position. In other embodiments, the tank 111 may be bypassed entirely, and the motorized valve 103 may be actuated to the open position to allow flow along flow lines 131 and 143 directly to the oil output 156 of the burner 159. In some embodiments, the oil may be sent to the burner 189 via a check valve 173 and a motorized valve 171 depending on factors such as the operational viability of each of the burners 159, 189, wind conditions favorable to combustion (discussed later), etc. In some embodiments, the motorized valve 171 may instead comprise a manual valve configured for actuation by a user.

[0020] In some embodiments, the transfer pump and tank system 100 may be configured to send fluids to the burner 159 and recirculate the fluids to the tank 111 at the same time. Figure 1 details two paths for oil flowing from the tank 111. A recirculation flow path encompasses the transfer pump skid, where fluid may exit the tank 111, traveling through motorized valves 113, 123, 121 and 135 as well as FCVs 137, 139, and flow through flow line 119 back to the tank III. A combustion flow path leading to the burners 159, 189 may comprise fluid flow exiting the tank 111 through motorized valves 133, flow line 143, motorized valve 155, and out of the oil output 156 to the burner 159. In some embodiments, flow may also be routed to the burner 189. This second, combustion flow path may completely bypass the FCVs 137, 139 and send fluid to the diverter manifold comprising at least the burners 159, 189. As depicted in Figure 1, the motorized valves such as the motorized valve 133 are depicted as open, whereas valves such as motorized drain valve 105 are depicted as closed. Thus, the system configuration depicted in Figure 1 describes a transfer pump and tank system 100 configured to both recirculate fluid to the tank 111 and send a portion of the fluid to the burner 159 simultaneously. The amount of fluid sent to the burner 159 and recirculated to the tank 111 may be determined via a user or via a computer on or off-site.

[0021] Other components or fluids may be input into the transfer pump and tank system 100. For example, Nitrogen -(N2) may be introduced via an N2 input 162 if a motorized valve 161 is actuated to the open position. Similarly, high-pressure gas from a separator may enter the system via a separator gas input 180. This gas may exhibit a higher pressure than the low-pressure gas flared at the low-pressure flare 147 because the high-pressure gas from the separator is driven by a bottomhole pressure of the well connected to the separator. In normal operation, a motorized valve 169 may be actuated to the closed position, and the high-pressure gas from the separator may be flared at a high-pressure flare 153. Flow to the high-pressure flare 153 may be adjusted via actuation of the choke and/or the separator. In some embodiments, the high-pressure gas may instead be routed to the high-pressure flare 175 by closing a motorized valve 151 and opening a motorized valve 177. The burners 159, 189, the low-pressure flares 147, 179, and the high-pressure flares 153, 175 may each or together be referred to as emissions sources. In some embodiments, flow rates of fluids output at the emissions sources may be each or together be referred to as rates of emissions (e.g., a flow rate of gas through the motorized valve 146, a flow rate of oil to either the burner 159 or the burner 189, a combined flow rate of fluid burned at the burners 159, 189, etc.) [0022} In some embodiments, air may be added to the system via an air input 163 at a given pressure. If black burn is detected at either of the burners 159, 189, additional air may be introduced to the burner via an air output 158, and air may be routed to the burner via a motorized valve 157. In some embodiments, a motorized valve 181 may similarly be opened or closed to allow air flow to the burner 189, depending on which burner is in use. The oil-to-air ratio achieved at the burner may affect the burn condition of the burner 159 or burner 189. An optimized oil-to-air ratio may eliminate or mitigate a proximate occurrence of black burn at the burner.

[0023] In some embodiments, high-pressure natural gas from the separator may be piped from the separator gas input 180 to the diverter manifold comprising the burners 159, 189 to aid in oil combustion to minimize black smoke at the burner. For example, Figure 2 depicts a second example process flow diagram of the surface well testing facility, according to some embodiments. In some embodiments, high-pressure gas may be readily available from a separator on site and may be connected to the flow line 143 comprising oil leading to the diverter manifold (or anywhere downstream of the flow lines leading to the burners 159, 189 but placed upstream of the burners), such that the high-pressure gas may be mixed with oil flowing within flow line 143 before reaching a burner head and ignition source of either burner. A motorized valve 210 may be opened in an automated fashion if black smoke is detected at either of the burners 159, 189. In some embodiments, a water line may also be coupled to the flow line 143 Water may be introduced to the oil within the flow line 143 to aid in combustion at the burner in use.

[0024] In some embodiments, a plurality of sensors may be disposed throughout the system to collect information and relay the information to a computer on or off-site. The sensors may collect information including, but not limited to high-pressure (HP) Gas Pressure (Separator Pressure), Oil Line Pressure (Po), Air Line Pressure (Pa), Oil Pressure at Burner (Pob), Air pressure at Burner (Pab), etc. For example, pressure transmitters may be disposed along the flow line 143 to measure a pressure of the oil, a pressure transmitter may be disposed along a flow line 232 or 271 to measure the high-pressure separator gas, and pressure transmitters may be disposed beyond a check valve 256 and a check valve 258 to measure an oil pressure at the burner 159 and an air pressure at the burner 159. Pressure transmitters may also be disposed similarly near the check valves 173, 167 of the burner 189. In some embodiments, the check valves may prevent reverse flow from the burners. The sensors may further include temperature sensors on flow lines for oil (143), gas (232, 271), and at the burners 159, 189 to ensure adequate mixing and a prevention of reverse oil or gas flow (enabling or disabling the opening of the motorized valve 210 to ensure process flow and safety). The above sensors may also be disposed at similar locations with reference to the burner 189. Furthermore, mechanical design elements such as check valves, automated choke/flow control valves, restrictor plates, and mixing elements may be used to ensure adequate mixing of oil and gas before reaching a burner head of either the burner 159 or the burner 189 and to prevent reverse flow of fluids within flow lines. For example, an automated pressure or flow control valve 240 may be incorporated upstream of the air output 158 to provide additional flow control of air supplied to the burner. A pressure or flow control valve 220 (or restrictor) may be disposed proximate to the motorized valve 210 (as depicted) or along the flow line 271 comprising high-pressure gas upstream of a mixing point 234 to adjust a flow rate of the high-pressure separator gas. In some embodiments, the flow lines 143, 271 may comprise internals designed to induce fluid turbulence prior to reaching the mixing point 234. The fluid turbulence may create a mixing effect and better combine the oil and natural gas prior to reaching the burner. Using an accelerant such as the produced, high-pressure gas from the separator (that may have been flared regardless) rather than air to atomize the oil at the burner may reduce a reliance on compressors, thus reducing job-site emissions. The compressors may be used to compress the air conveyed via the air input 163. Because the compressors may likely operate using either diesel or natural gas as fuel, the compressors may become emissions sources at the surface well testing facility. Using the produced gas from the separator may offer an overall emissions reduction compared to a solely oil and air-based burner system.

[0025] The above example sensor and mechanical elements are examples; however, other sensor or mechanical element configurations may be possible to fulfill the same purpose (ensuring mixing without reverse flow) For example, a vibrating piezoelectric tuning fork switch may be placed along the flow line 143 comprising oil and along the flow line 271 comprising high-pressure separator gas upstream of the mixing point 234. The vibrating piezoelectric tuning fork switch may be configured to send a switching signal in the presence or absence of a liquid (triggering a reverse flow event, which would in-turn automatically trigger a closure of the motorized valve 210). In some embodiments, flow elements 230 may include the vibrating piezoelectric tuning fork switch to detect a presence or absence of liquid. Additional sensors may include, for example, a dynamic light scatterer, optically integrating sphere, methane/ethane/hydrocarbon MEMS sensor, gravimetric balances, acoustic sensors, temperature sensors, thermal imagers, spectrometers, mass spectrometers, electrochemical sensors, electric and magnetic field sensors, etc. The sensors may transmit data to a computer on site comprising a black burn optimizer (described later) or may transmit data to an off-site computer for processing. The sensor data may be used by the computer to make automatic adjustments to various components, motorized valves, or FCVs on site to eliminate a presence of black burn or mitigate a predicted occurrence of black burn.

[0026] While natural gas may be introduced to intensify a burn at the burner, the supply of air from the air input 163 may also greatly affect a condition of the burn at the burner. In some embodiments, the air supply may require automatic adjustments to mitigate black burn at the burners 159 or 189. For example, if there is a lack of air supplied to the air output 158 at the burner 159, a choke bean position of the choke proximate to the producing well may be adjusted to change the fluid flowrate, and hence the oil/air ratio in the presence of black burn. In this scenario, black burn may be indicative of having insufficient air supply to satisfy a rate of oil burn. A computer comprising a black burn optimizer (discussed in Figure 6) may recommend reducing the produced flow rate (from the well) to satisfy clean burn requirements (often described as a burn with a Ringelmann smoke scale <1).

[0027] Conversely, combustion at the burners 159, 189 may be negatively affected by excess air supply (e.g., fixed compressor output) given a fixed (lower) oil flow rate. In such a scenario, known as a lean burning condition, burner heads of the burner and nearby equipment may be negatively affected by excess heat. For example, seals or elastomers at or near burner heads on burner may be subject to premature failure in the presence of excess heat. This may lead to burner head failure and even further environmental/emissions release. In the event that a lean burn from the burner 159 or 189 is detected, an automatic regulation of air supply via the air input 163 may be controlled via the automated FCV 240 such that excess air is choked, therefore reducing utility consumption and minimizing emissions. The automated FCV 240 (choke valve or valve with variable orifice control) may regulate the air supply to the burners 159, 189 in an automated fashion to satisfy an optimal (prescribed) air supply given the system burn condition.

[0028] In a lean burning condition or other sub-optimal burn condition, constituent components of the air, oil, and gas may not completely combust. An ideal burn yields only carbon dioxide and water as its products. Largely incomplete burns may fail to combust some of these constituent components, some of which pose environmental and safety concerns. For example, the high-pressure gas from the separator may comprise hydrogen sulfide, which poses known environmental and workplace hazards. A proper burn condition or optimized burn condition may largely reduce or eliminate a presence of hydrogen sulfide emissions from the burner 159, 189. However, a poor burn condition may leave much of the hydrogen sulfide emissions intact, which may lead to fines or increase a risk of operator exposure to the gas.

[0029] In some embodiments, a burn condition at the burner may be affected by external factors such as a wind direction and wind speed. A wind direction transmitter (WDT) instrument 107 may be included in the transfer pump and tank system 100. The WDT instrument 107 may be used to monitor wind speed and direction in relation to the orientation of the burner 159, 189. In some embodiments, the burner 159, 189 may be configured to automatically adjust its orientation depending on properties of the wind.

[0030] Figure 3 depicts a diagram of burner position tracking, according to some embodiments. A wind speed 310 and wind direction 301 may be determined by the WDT instrument 107 of Figure 1. A burner 305 and a burner 303 may be affected differently by the wind speed 310 and wind direction 301 depicted in Figure 3. In some embodiments, the burners 303, 305 may be similar to the burners 159, 189, respectively. In the event that the wind speed 310 or wind direction 301 are not optimal to facilitate a clean burn, a burner may be controlled to rotate to a direction (angle) that satisfies constraints defining a safe/clean burn condition. In other embodiments, the burner and WDT instrument 107 may be coupled to the above-mentioned computer used to actuate various pieces of equipment. The computer may alert a user via user alerts, either on-site or remote, to use an alternate burner if the current burner is not in an optimal configuration. For example, the burner 305 may be oriented to face an acceptable burn zone 307. The burner 303 may be oriented to face an acceptable burn zone 308. Given the depicted wind direction 301, the user may be instructed via a user interface to use the burner 303 and deactivate the burner 305. For example, a burner experiencing crosswinds or winds that would direct uncombusted fluid/gas back toward the equipment or wellsite may be avoided. If no safe wind speed or direction exist, the above-mentioned computer may alert the user not to initiate the burn, so as to avoid incomplete combustion, black smoke, an oil spill, or other emissions (considered loss of containment and subject to considerable environmental/governmental repercussions). In this scenario, the computer may recirculate fluids back to the tank 111. The above-described user alerts may be sent to a user interface 400, as depicted in Figure 4.

[0031] Figure 4 depicts an example interface for the burner position tracking, according to some embodiments. A user interface 400 may display multiple properties of the burners 303, 305 of Figure 3. For example, the user interface 400 may display an acceptable cross wind 402, a burner rotation 404, a burner position 406, and wind conditions 408 for both the burners 303, 305. A user, either on-site or remote, may manually adjust settings within the user interface 400, or the computer may automatically perform adjustments and output changes and/or recommendations to the user interface 400.

[0032] Figure 5 depicts an example burner head, according to some embodiments. In some embodiments, natural gas may be introduced to the burner head 500 via a natural gas line 506. The natural gas may mix with oil from an oil line 504 within or prior to reaching an atomization chamber 510 of the burner head 500. In other embodiments, the burner head 500 includes an air flow line 502 such that air mixes with oil from the oil line 504 and natural gas from the natural gas line 506 directly in the atomization chamber 510 prior to exiting the burner head 500. Multiple burner heads may be included in the burner, similar to the burner 159 of Figure 1. In some embodiments, the natural gas is sourced from a high-pressure (HIP) gas line and communicated independently to individual burner heads or to a manifold plenum. The manifold plenum may then communicate the natural gas to individual burner heads. The addition of produced gas from the on-site separator to the burner head 500 may atomize the oil and result in a cleaner, higher temperature burn which may aid in mitigating or eliminating a black burn scenario. In some embodiments, the oil line 504 may be coupled with a water line, similar to the water line discussed prior. Water from the water line, in addition to the produced gas from the separator, may enhance an atomization of the oil within the atomization chamber 510 and improve burn condition at the burner head 500. In some embodiments, a hydrogen line may also carry pressurized hydrogen to the burner head 500 to improve combustion at the burner and reduce overall emissions.

[0033] Figure 6 depicts an example computer system, according to some embodiments. The computer system may include a processor 601 (possibly including multiple processors, multiple cores, multiple nodes, and/or implementing multi-threading, etc.). The computer system may include memory 607. The memory 607 may be system memory or any one or more of the above already described possible realizations of machine-readable media. The computer system may also include a bus 603 and a network interface 605. The system may communicate via transmissions to and/or from remote devices via the network interface 605 in accordance with a network protocol corresponding to the type of network interface, whether wired or wireless and depending upon the carrying medium. In addition, a communication or transmission may involve other layers of a communication protocol and or communication protocol suites (e.g., transmission control protocol, Internet Protocol, user datagram protocol, virtual private network protocols, etc.). The system also includes an emission optimizer, such as a black burn optimizer 611. The black burn optimizer 611 may create new system controls by selecting new set points, choosing new operational states, or adjusting other parameters or settings of various vessels and equipment to mitigate black burn based on a confirmed or predicted presence of black burn at the burner. The black burn optimizer 611 may additionally be configured to receive data from various sensors, receive an external confirmation of black burn by a user or operator, propose the new system controls to a user/operator for approval, and adjust various motorized valves or flow control valves (as described herein) to achieve emissions reductions via the new system controls. In some embodiments, the black burn optimizer 611 may be configured to actuate or adjust the equipment depicted in Figures 1-5. The black burn optimizer 611 may actuate motorized valves coupled with the burner, the separator, the tank, the pump of the transfer pump skid, a choke of the well, various flow lines, the diverter manifold, or any combination therein. Any one of the previously described functionalities may be partially (or entirely) implemented in hardware and/or on the processor 601. For example, the functionality may be implemented with an application specific integrated circuit, in logic implemented in the processor 601, in a coprocessor on a peripheral device or card, etc. Further, realizations may include fewer or additional components not illustrated in Figure 6 (e.g., video cards, audio cards, additional network interfaces, peripheral devices, etc.). The processor 601 and the network interface 605 are coupled to the bus 603. Although illustrated as being coupled to the bus 603, the memory 607 may be coupled to the processor 601.

[0034] figure 7 depicts a first flowchart of example operations, according to some embodiments. The operations in Figure 7 are described with reference to a plurality of sensors, a computer, and a surface well testing facility similar to the transfer pump and tank system 100 of Figure 1. These names are for reading convenience and the operations in Figure 7 may be performed by any component with the functionality described below. Operations of a flowchart 700 begin at block 701.

[0035] At block 701, an emission optimizer (such as a black burn optimizer) may determine skid states and associated parameters. The skid states may include a number of nozzles in use, a status of the valves on a separator, whether flow is bypassing the separator, and may provide status on a choke (whether the choke is adjustable or a positive choke, whether the choke is functioning properly, etc.). The choke may be coupled with or proximate to a producing wellhead, and the separator may be coupled downstream of the choke manifold d. In some embodiments, the tank 111 of Figure 1 may be replaced by a separator, and the inlet 101 may convey fluids directly from the choke manifold rather than from a test separator. The skid states of block 701 may also provide information regarding the statuses of other equipment. In some embodiments, the skid states may provide information such as whether the well is shut in or if an SSV is active. A state of the burner may also be included in the skid states and provide information such as how many nozzles are open, which nozzles are functional, etc. [0036] At block 703, the sensors provide sensor data. The sensor data may comprise data including, but not limited to fluid pressures/rates within the system (of which may include oil, air, natural gas, and water rates/pressures or fluid mixtures thereof), an air temperature at the burner, an API gravity of the oil, and various fluid viscosities within the system. In some embodiments, the sensors may also be configured to determine differential pressures within the system or determine various other fluid properties. The sensors providing the sensor data may additionally provide information regarding oil samples in the separator and a bean position and/or hardware configuration of the choke. In some embodiments, the sensor data may be input into one or more models/algorithms to simulate fluid parameters within the burner, separator, choke, or broader system. In some embodiments, the above-mentioned skid states, the sensor data, and mechanical design components from the tank, diverter manifold, and transfer pump skid may be used to further optimize combustion at the emissions sources.

[0037] At junction 705, the black burn optimizer may merge the skid states of block 701 and sensor data of block 703. The black burn optimizer may be identical to the black burn optimizer 611 described in Figure 6. Flow progresses to block 707.

[0038] At block 707, the black burn optimizer 611 may determine if sensor data indicates black burn or a likely occurrence of black burn. The black burn optimizer 611 may compare the sensor data to known thresholds indicative of black burn, and the black burn optimizer 611 may compare the current skid states with historical data comprising skid states indicative of a black burn scenario or poor burn condition. The black burn optimizer 611 may also perform calculations with sensor and skid state input data to determine whether black burn is occurring.

In some embodiments, the black burn optimizer 611 may receive data from a black burn sensor placed proximate to the burner 159 which may analyze characteristics of a flame emitted by the burner 159. In some embodiments, the black burn optimizer 611 may determine that black burn is occurring and may via (or output this determination directly to) a programmable logic controller (PLC) at the surface well testing facility. In other embodiments, the black burn optimizer 611 may make the black burn determination at a separate edge box, or the black burn optimizer 611 may utilize a remote cloud platform (such as AWS) to perform calculations and output the results to any capable user interface. In other embodiments, the calculations may be performed via a remote supercomputer. Flow progresses to block 709.

[0039] At block 709, a user or operator may indicate a presence of black burn. In some embodiments, a user or operator may visually identify black burn at the burner 159. The user may confirm a black burn indication via a user interface (such as to the black bum optimizer 611) either on-site or remote. In some embodiments, the user may indicate the presence of black burn based on sensor data indicating conditions such as heat, recirculation, mixing gas with oil after measurement, wind velocity, independent burner head/nozzle control, or any other relevant condition which may be used to facilitate a clean burn. In some embodiments, the user may be at a location other than the surface well-testing facility and may identify a presence of black bum via a video feed streamed from a camera oriented to face the burner 159. Flow progresses to block 711.

[0040] At block 711, the black burn optimizer 611 may make a decision depending on sensor or user indication of black bum. If black burn is detected by a user or by the sensor data, flow progresses to block 713. If black burn is not detected by either a user or the sensor data, then flow proceeds to block 719 where a well test may continue without modification Assuming a detection of black burn, flow progresses to block 713.

[0041] At block 713, the black burn optimizer 611 may determine an optimal configuration for the burner and the separator. The black burn optimizer 611 may factor a combination of the skid state data and sensor data when determining an optimal configuration to reduce black burn In some embodiments, the optimal configuration may be determined using workflows developed by subject matter experts, an operational parameter space calculated by CFD models or other physical models, estimations based upon machine learning algorithms, curve-fitting algorithms, Bayesian statistics, Monte Carlo simulations (or any suitable algorithm), reliability equations, other statistical techniques, or a feedback control mechanism.

[0042] The optimal configuration may comprise one or more optimal flow rates, with some fluid routed to either the burner 159 or 189 and some recirculated to the tank 111 (or separator, in some embodiments). When oil is ready to be sent to the burners, the transfer pump and tank system 100 of Figure 1, with oversight from the black burn optimizer 611, may enable precise flow control (volume flow rate control) of oil being pumped to the burner 159 via the FCVs 137, 139 (assuming both motorized valves 133, 135 are open) The black burn optimizer 611 may utilize the one or more optimal flow rates, sensor data measuring an API gravity or viscosity of the oil (measures that indicate an extent of conditioning of the oil), and wind data collected by the WDT instrument 107 to determine a desired oil rate to flow to the burner with excess fluid to be recirculated back to the tank 111.

[0043] In some embodiments, an optimal configuration may not be entirely reliant on a presence of black burn. Instead, the black burn optimizer 611 may decide that an optimal configuration is one that reduces overall emissions from the surface well testing facility. For example, the black burn optimizer 611 may be configured to reduce a orifice size at the choke manifold to reduce an overall oil flow-rate from the well, route flow from the well to a tank such as a surge tank (or series of tanks for large volume storage) until collected fluids are able to be disposed with minimal emissions release (burn process or tank transport to oil process pipeline), or the black burn optimizer may shut-in the well at the choke manifold (cease/stop flowing from the well) until safe burning conditions exist.

[0044] In some embodiments, the black burn optimizer 611 may be configured to increase oil throughput to the burner while mitigating black burn (Ringelmann scale <1) using an accelerant mixed with oil prior to burning. The accelerated mix, comprising natural gas, water, hydrogen, or a combination of the three may either be added via flow lines leading to a mixing point, similar to the mixing point 234 where oil and separator gas mix prior to entering the burner 159 or 189. In other embodiments, an accelerant may be added directly at the burner head 500, as depicted by the natural gas line 506. A combination of recirculation, oil conditioning, and modifying various flow rates across the system may be utilized to achieve extraneous emissions reductions (outside of the burner/flares) and black burn mitigation at the burner 159, 189 at the same time.

[0045] In other embodiments, the black burn optimizer 611 may output commands to system components or may output recommendations to a user interface on methods to reduce total site emissions. For example, the black burn optimizer 611 may calculate estimated rates of emissions from various sources based on flow rates detected via flow rate sensors. For example, the black burn optimizer 611 may determine that the best option to reduce total site emissions is to decrease an amount of time spent on a current job. Compressors, generators, trucks, and similar equipment may generate emissions in addition to those generated by the surface well testing facility or the transfer pump and tank system 100 comprising the burner 159. If total emissions may be reduced by hastening the current job, the black burn optimizer 611 may increase an oil flow rate along flow line 143 to the burner 159. This may be accomplished by opening motorized valves 113, 123, and 133, reducing a recirculation flow rate via the FCVs 137, 139, and opening the motorized valve 155 to allow increased flow out of the oil output 156 to the burner 159, for example. This process, also known as batch flaring, may allow the tank I I I to fill and subsequently activate the transfer pump skid comprising the pump assembly 125 to send fluids to the burners 159, 189. The flow rate to the burners may be increased by reducing the recirculation to the tank 111 or by closing the motorized valve 135 and sending the entire transfer pump rate to the burner in use (without recirculation). In other embodiments, the oil flow rate may be increased through bypassing the tank 111 and transfer pump skid by closing the motorized valve 102 and opening the motorized valve 103. In this scenario, the black burn optimizer 611 may route flow directly from the separator to one of the burners 159, 189. This flow rate may be further increased by increasing a flow rate to the separator through choke orifice size increases at the choke manifold. In some embodiments, the black burn optimizer 611 may increase a separator pressure and reduce a separator level setpoint to achieve an increased oil flow rate. Various measures may be taken by the black burn optimizer 611 to reduce emissions, whether at the burners 159, 189 or when considering external sources entered via a user/operator. Flow continues to block 715.

[0046] At block 715, a user interface receives user data indicating a decision indicating whether the new configuration from block 713 is approved for implementation or disapproved. The black burn optimizer 611 may output the optimal configuration for the burner and the separator to a user interface. The user interface may be accessed via secure login to a cloud computing service, the user interface may be output to an on-site computer, or the user interface may be output to a remote device. If the user data indicates approval of the optimized configuration, flow progresses to block 717. If the user data indicates disapproval, flow regresses to block 713 where the black burn optimizer 611 may determine an alternate configuration for the burner and separator. Feedback from the user and data from the sensors on the burner may provide information as to whether a burn condition of the burner has been optimized -if not, the system may loop between blocks 713 and 715 until an adequate configuration has been approved for implementation. Assuming the new configuration was approved by the user, flow progresses to block 717.

[0047] At block 717, the black burn optimizer 611 may adjust system controls by selecting new set points, choosing new operational states, or adjusting other parameters or settings for various vessels and equipment to mitigate black burn based on a confirmed or predicted presence of black burn at the burner. The system controls may place new set points regarding the tank, separator, burner, choke, transfer pump skid, diverter manifold, and associated motorized valves. For example, with reference to Figure 1, the black burn optimizer 611 may open or close various motorized valves to achieve an improved burn condition. The adjustments to the valves may be automated and alter oil recirculation to the tank I I I, change the burner in-use based on wind direction/velocity, adjust a flow rate of oil, water, natural gas, or hydrogen to each individual burner head after measurements are taken, etc. In some embodiments, the black burn optimizer 611 may output a single set point via a command to the skids. In some embodiments, the skids may be fully automated, and the separator, choke, tank, transfer pump, diverter manifold and burner(s) may communicate within a cloud server or any suitable communication medium. The black burn optimizer 611 may output the single set point command to the separator, choke, and burner (if applicable) to maintain a 1,000 barrel per day (bpd) flow rate at 50% oil fill level within the separator. One or more control programs in each skid may open, close, or adjust various motorized valves, FCVs, or an aperture of the choke via electrical commands to achieve the desired, single set point. A vessel pressure within the separator may be another single set point output by the black burn optimizer 611. In other embodiments, multiple set points may be output by the black burn optimizer to adjust individual components/equipment. For example, the black burn optimizer 611 may modulate FCVs 137, 139 of Figure 1 to adjust a flow rate of oil to the burner 159. Further, the black burn optimizer 611 may also boost (increase) a discharge pressure from the pump (of the pump assembly 125) and consequently to the burner head by controlling the pressure inside the tank 111 using the pressure control valve (PCV) 115; in this way, atomization efficiency may be improved at the burner, enabling a more efficient burn based on an optimal atomization pressure given the flow rate and fluid properties. The black burn optimizer 611 may also open or close nozzles at the burners depending on the extent of black burn identified at block 711. In other embodiments, the black burn optimizer 611 may output all set points to a user interface rather than enacting automatic changes. Some surface well testing facilities may not yet comprise a burner, choke, separator, other skids, or valves capable of automatic actuation, and the black burn optimizer 611 may instead output some or all of the set points as recommendations to the user interface so an on-site user may enact the changes instead. For example, at a surface well testing facility comprising an automated separator and burner but manual choke, the black burn optimizer 611 may output recommendations to the user interface as to the extent the choke may be opened or closed. The black burn optimizer 611 may confirm the user's actions via changes in sensor data (such as a flow rate sensor or choke bean position), and upon the user completing the recommendation, the black burn optimizer 611 may output the remaining system controls or set points to trigger an automated response at the other skids. In other embodiments, the black burn optimizer 611 may output valve actuation recommendations to an operator if valves such as valves 113, 123, 133, etc are not motorized or configured for remote actuation.

[0048] In some embodiments, the new system controls may comprise controlling flow rates between the separator (or tank 111 of Figure 1) to the burner, and various motorized valves and/or FCVs may be actuated to maintain the flow rate set points. Example flow rate set points may include an air flow rate to the burner, an oil flow rate to the burner, a high-pressure gas flow rate to the burner, etc. In some embodiments, the high-pressure gas flow rate may be controlled via the FCV 220 of Figure 2, and a gas flow rate sensor may be placed proximate to or within the FCV 220. The flow rate set points may control flow rates of various emissions sources including, but not limited to, the above-mentioned burners 159, 189. A rate of emissions from a plurality of emissions sources may be controlled according to the new set points set by the black burn optimizer 611.

[0049] In some embodiments, the new system controls may additionally comprise a flow rate or desired injection volume of chemicals to condition oil sent to the burner 159. The conditioning may reduce the viscosity of the oil and allow for greater control on a flow rate to the burner 159. The chemical injection may be done via an automated chemical injection pump on site or done manually by a user. Flow progresses to block 719.

[0050] At block 719, the surface well testing facility may conduct a well test. The well test may introduce fluids into the separator, tank 111, choke, transfer pump skid, and the diverter manifold comprising the burners 159, 189 during normal operation. The well test may be performed until completion, or until a presence of black burn is again detected. If black burn occurs after placing the new set points at block 717, flow progresses to block 707 where a black burn mitigation procedure from blocks 707-717 may repeat. If black burn is not detected again, the well test may go to completion, and flow of the flowchart 700 ceases.

[0051] Figure 8 depicts a second flowchart of example operations, according to some embodiments. The operations in Figure 8 are described with reference to Figures 1-7. The operations of Figure 8 may be performed by any component with the functionality described below. Operations of a flowchart 800 begin at block 801.

[0052] At block 801, a method may comprise controlling a rate of emissions from a plurality of emissions sources, wherein the plurality of emissions sources comprises a burner configured to burn fluids. The burner may be similar or identical to the burners 159, 189 and the plurality of emissions sources may comprise the burners 159, 189, the low-pressure flares 147, 179, the high-pressure flares 153, 175, and any supplemental compressors, trucks, generators, other fuel-driven apparatuses, etc. used at the surface well testing facility. Flow progresses to block 803.

[0053] At block 803, the method may further comprise determining that the fluids will not completely burn in the burner. The black burn optimizer 611 may make this determination through a combination of sensor data and skid state data, or a poor burning condition (black burn) may be determined by an operator. Flow progresses to block 805 [0054] At block 805, the method comprises calculating estimated emissions rates from the plurality of emissions source. The black burn optimizer 611 may utilize a plurality of sensors as well as user data entry to determine approximate emissions rates for various emissions sources based on their correlated flow rates (e.g., a flow rate of gas into a compressor, a flow rate of gases sent to the flares, a flow rate of fluids sent to the burners 1_59, 189, etc.). The black burn optimizer 611 may use the calculated emissions rates to prioritize which emissions sources and/or rates of emissions warrant immediate attention. Flow progresses to block 807.

[0055] At block 807, the method comprises determining a first burn configuration for the emissions sources based, at least in part, on the determination that the fluids will not completely burn in the burner and the calculated emissions rates. The first burn configuration may comprise determining the optimal configuration for the burner as discussed in block 713 of Figure 7. Flow progresses to block 809.

[0056] At block 809, the method comprises controlling the rate of emissions from the plurality of emissions sources according to the first burn configuration. For example, the black burn optimizer 611 may output a command or commands comprising new system controls which may be enacted upon the burners 159, 189, the choke, the separator, the transfer pump skid, other components of the diverter manifold, various FCDs or motorized valves between them, or other hardware components. The new system controls may mitigate a presence of black burn at the burner 159 and/or may aim to reduce emissions from a different emissions source. The black burn optimizer 611 may also control the rate of emissions and optimize the burn at the burner(s) through a series of system parameters (enabled through hardware design and sensor data). Such optimization measures by the black burn optimizer 611 may include measures such as fluid conditioning of the oil prior to burn, fluid pressure control at the burner, selection of active burner nozzles based on fluid rates, burner rotation and selection based on wind velocity monitoring, introducing accelerants to oil stream to improve combustion/reduce smoke, etc. In some embodiments, the black burn optimizer 611 may output user recommendations for the first bum configuration to a user interface. Flow of flowchart 800 ceases.

[0057] While the aspects of the disclosure are described with reference to various implementations and exploitations, it will be understood that these aspects are illustrative and that the scope of the claims is not limited to them. In general, techniques for black burn mitigation via automated systems as described herein may be implemented with facilities consistent with any hardware system or hardware systems. Many variations, modifications, additions, and improvements are possible.

[0058] Plural instances may be provided for components, operations or structures described herein as a single instance. Finally, boundaries between various components, operations and data stores are somewhat arbitrary, and particular operations are illustrated in the context of specific illustrative configurations. Other allocations of functionality are envisioned and may fall within the scope of the disclosure. In general, structures and functionality presented as separate components in the example configurations may be implemented as a combined structure or component. Similarly, structures and functionality presented as a single component may be implemented as separate components. These and other variations, modifications, additions, and improvements may fall within the scope of the disclosure.

[0059] Use of the phrase "at least one of' preceding a list with the conjunction 'and" should not be treated as an exclusive list and should not be construed as a list of categories with one item from each category, unless specifically stated otherwise. A clause that recites "at least one of A, B, and C" may be infringed with only one of the listed items, multiple of the listed items, and one or more of the items in the list and another item not listed.

[0060] Example Embodiments [0061] Embodiment 1: A method for reducing emissions from a surface well testing system, comprising: controlling a rate of emissions from a plurality of emissions sources, wherein the plurality of emissions sources comprises a burner configured to burn fluids; determining that the fluids will not completely burn in the burner; calculating estimated emissions rates from the plurality of emissions sources, determining a first burn configuration for the emissions sources based, at least in part, on the determination that the fluids will not completely burn in the burner and the calculated emission rates; and controlling the rate of emissions from the plurality of emissions sources according to the first burn configuration.

[0062] Embodiment 2: The method of Embodiment 1 wherein determining the fluids will not completely burn is based on sensor data and skid states.

[0063] Embodiment 3. The method of any one of Embodiments 1-2 wherein determining the fluids will not completely burn is based on user input.

[0064] Embodiment 4: The method of any one of Embodiments 2-3, wherein determining the first burn configuration includes: adjusting system controls based on the first burn configuration; and configuring the skid states based on the system controls, wherein the system controls include set points, parameters, and settings for at least one of the burner, a separator, a tank, a pump, a diverter manifold, a choke, and a plurality of motorized valves.

[0065] Embodiment 5: The method of Embodiment 4, further comprising: adding, via a first flow line from the separator to the burner, natural gas to improve a burn condition of the fluids in the burner; and adding, via a second flow line, water to improve the burn condition of the fluids in the burner.

[0066] Embodiment 6: The method of any one of Embodiments 1-5 further comprising: recirculating, while controlling the rate of emissions, a first portion of the fluids to and from a tank at the surface well testing system, wherein the fluids include oil, and wherein the method further includes conditioning the oil via chemical additives added during the recirculating; and sending, while recirculating the first portion of the fluids to and from the tank, a second portion of the fluids to the burner.

[0067] Embodiment 7: The method of any one of Embodiments 4-6, wherein controlling the rate of emissions from the plurality of emissions sources according to the first burn configuration comprises: modifying a flow rate of oil to the burner, wherein modifying the flow rate of the oil comprises reducing an orifice size of the choke, recirculating oil to the tank, or shutting in a well of the surface well testing system during unsafe burning conditions; activating one or more nozzles of the burner based on the sensor data and flow rates of the fluids to improve a burn condition at the burner; controlling a fluid pressure at the burner; and rotating the burner based, at least in part, on a wind direction and wind speed.

[0068] Embodiment 8: A system configured to reduce emissions from a surface well testing system, the system comprising: a burner comprising one or more nozzles; a plurality of motorized valves; a processor; a machine-readable medium including instructions executable by the processor, the instructions comprising instructions to: control, via the plurality of motorized valves, a rate of emissions from a plurality of emissions sources, wherein the plurality of emissions sources comprises the burner configured to burn fluids; determine that the fluids will not completely burn in the burner; calculate estimated emissions rates from the plurality of emissions sources; determine a first burn configuration for the emissions sources based, at least in part, on the determination that the fluids will not completely burn in the burner and the calculated emission rates; and control the rate of emissions from the plurality of emissions sources according to the first burn configuration.

[0069] Embodiment 9: The system of Embodiment 8, wherein the instructions to determine the fluids will not completely burn is based on both sensor data and skid states or based on user input.

[0070] Embodiment 10: The system of Embodiment 9, further comprising at least one of a separator, a choke, a tank, a pump, and a diverter manifold, wherein the instructions to determine the first burn configuration comprise instructions to: adjust system controls in the surface well testing system based on the first burn configuration; configure the skid states based on the system controls, wherein the system controls include set points, parameters, and settings for the burner, separator, choke, tank, pump, diverter manifold, and the plurality of motorized valves; and modify, while controlling the rate of emissions from the plurality of emissions sources according to the first burn configuration, a flow rate of oil to the burner, wherein the instructions to modify the flow rate of oil comprise instructions to reduce an orifice size of the choke, recirculate oil to the tank, or shut in a well of the surface well testing system during unsafe burning conditions.

[0071] Embodiment 11: The system of any one of Embodiments 8-10 further comprising sensors to produce sensor data about the surface well testing system, wherein the instructions further to: based on the sensor data, control a fluid pressure at the burner; and activate the one or more nozzles of the burner to improve a burn condition at the burner based, at least in part, on the sensor data and flow rates of the fluids.

[0072] Embodiment 12: The system of any one of Embodiments 10-11, wherein the instructions to determine that the fluids will not completely burn in the burner comprising instructions to: add, via a flow line from the separator to the burner, natural gas to improve a burn condition of the fluids in the burner; and add, via a second flow line, water to improve the burn condition of the fluids in the burner.

[0073] Embodiment 13: The system of any one of Embodiments 8-12, further comprising instructions to: recirculate a first portion of the fluids to and from a tank in the surface well testing system, wherein the fluids include oil; condition the oil via chemical additives added during the recirculation; and send, while recirculating the first portion of the fluids to and from the tank, a second portion of the fluids to the burner.

[0074] Embodiment 14: The system of any one of Embodiments 8-13, further comprising: a wind direction transmitter (WDT) instrument, the WDT instrument configured to determine a wind direction and wind speed, wherein the instructions to determine the first burn configuration for the burner comprise instructions to rotate the burner based on the wind direction and the wind speed.

[0075] Embodiment 15: One or more non-transitory, machine-readable media including program code configured to reduce emissions from a surface well testing system, the program code executable by a processor, the program code comprising instructions to: control, via a plurality of motorized valves, a rate of emissions from a plurality of emissions sources, wherein the plurality of emissions sources comprises a burner configured to burn fluids; determine that the fluids will not completely burn in the burner; calculate estimated emissions rates from the plurality of emissions sources, determine a first burn configuration for the emissions sources based, at least in part, on the determination that the fluids will not completely burn in the burner and the calculated emission rates; and control the rate of emissions from the plurality of emissions sources according to the first burn configuration [0076] Embodiment 16: The machine-readable media of Embodiment 15, wherein the instructions to determine the fluids will not completely burn is based on both sensor data and skid states or based on user input.

[0077] Embodiment 17: The machine-readable media of Embodiment 16, wherein the instructions to determine the first burn configuration comprise instructions to: adjust system controls in the surface well testing system based on the first burn configuration; configure the skid states based on the system controls, wherein the system controls include set points, parameters, and settings for at least the burner, separator, a choke, a tank, a pump, a diverter manifold, and the plurality of motorized valves; and modify, while controlling the rate of emissions from the plurality of emissions sources according to the first burn configuration, a flow rate of oil to the burner, wherein the instructions to modify the flow rate of oil comprise instructions to reduce an orifice size of the choke, recirculate oil to the tank, or shut in a well of the surface well testing system during unsafe burning conditions.

[0078] Embodiment 18: The machine-readable media of any one of Embodiments 16-17, further comprising instructions to: based on sensor data, control a fluid pressure at the burner; and activate one or more nozzles of the burner to improve a burn condition at the burner based, at least in part, on the sensor data and flow rates of the fluids.

[0079] Embodiment 19: The machine-readable media of any one of Embodiments 15-18, further comprising instructions to: add, via a flow line from a separator to the burner, natural gas to improve a burn condition of the fluids in the burner; add, via a second flow line, water to improve the burn condition of the fluids in the burner; recirculate a first portion of the fluids to and from a tank in the surface well testing system, wherein the fluids include oil; condition the oil via chemical additives added during the recirculation; and send, while recirculating the first portion of the fluids to and from the tank, a second portion of the fluids to the burner.

[0080] Embodiment 20: The machine-readable media of any one of Embodiments 15-19, wherein the instructions to control the rate of emissions from the plurality of emissions sources according to the first burn configuration comprise instructions to: determine, via a wind direction transmitter (WDT) instrument, a wind direction and a wind speed; and rotate the burner based on the wind direction and wind speed.

Claims (20)

1. WHAT IS CLAIMED IS: 1 A method for reducing emissions from a surface well testing system, comprising: controlling a rate of emissions from a plurality of emissions sources, wherein the plurality of emissions sources comprises a burner configured to burn fluids; determining that the fluids will not completely burn in the burner; calculating estimated emissions rates from the plurality of emissions sources; determining a first burn configuration for the emissions sources based, at least in part, on the determination that the fluids will not completely burn in the burner and the calculated emission rates; arid controlling the rate of emissions from the plurality of emissions sources according to the first burn configuration.
2. 2. The method of claim 1 wherein determining the fluids will not completely burn is based on sensor data and skid states
3. 3. The method of claim 1 wherein determining the fluids will not completely burn is based on user input.
4. 4 The method of claim 2, wherein determining the first burn configuration includes: adjusting system controls based on the first burn configuration; and configuring the skid states based on the system controls, wherein the system controls include set points, parameters, and settings for at least one of the burner, a separator, a tank, a pump, a diverter manifold, a choke, and a plurality of motorized valves.
5. The method of claim 4, further comprising: adding, via a first flow line from the separator to the burner, natural gas to improve a burn condition of the fluids in the burner; and adding, via a second flow line, water to improve the burn condition of the fluids in the burner.
6. 6 The method of claim 1 further comprising: recirculating, while controlling the rate of emissions, a first portion of the fluids to and from a tank at the surface well testing system, wherein the fluids include oil, and wherein the method further includes conditioning the oil via chemical additives added during the recirculating, and sending, while recirculating the first portion of the fluids to and from the tank, a second portion of the fluids to the burner.
7. 7. The method of claim 4, wherein controlling the rate of emissions from the plurality of emissions sources according to the first burn configuration comprises: modifying a flow rate of oil to the burner, wherein modifying the flow rate of the oil comprises reducing an orifice size of the choke, recirculating oil to the tank, or shutting in a well of the surface well testing system during unsafe burning conditions; activating one or more nozzles of the burner based on the sensor data and flow rates of the fluids to improve a burn condition at the burner; controlling a fluid pressure at the burner; and rotating the burner based, at least in part, on a wind direction and wind speed.
8. 8. A system configured to reduce emissions from a surface well testing system, the system comprising: a burner comprising one or more nozzles; a plurality of motorized valves; a processor; a machine-readable medium including instructions executable by the processor, the instructions comprising instructions to: control, via the plurality of motorized valves, a rate of emissions from a plurality of emissions sources, wherein the plurality of emissions sources comprises the burner configured to burn fluids; determine that the fluids will not completely burn in the burner; calculate estimated emissions rates from the plurality of emissions sources; determine a first burn configuration for the emissions sources based, at least in part, on the determination that the fluids will not completely burn in the burner and the calculated emission rates; and control the rate of emissions from the plurality of emissions sources according to the first burn configuration.
9. 9. The system of claim 8, wherein the instructions to determine the fluids will not completely burn is based on both sensor data and skid states or based on user input.
10. 10. The system of claim 9, further comprising at least one of a separator, a choke, a tank, a pump, and a diverter manifold, wherein the instructions to determine the first burn configuration comprise instructions to: adjust system controls in the surface well testing system based on the first burn configuration; configure the skid states based on the system controls, wherein the system controls include set points, parameters, and settings for the burner, separator, choke, tank, pump, diverter manifold, and the plurality of motorized valves; and modify, while controlling the rate of emissions from the plurality of emissions sources according to the first burn configuration, a flow rate of oil to the burner, wherein the instructions to modify the flow rate of oil comprise instructions to reduce an orifice size of the choke, recirculate oil to the tank, or shut in a well of the surface well testing system during unsafe burning conditions.
11. 11. The system of claim 8 further comprising sensors to produce sensor data about the surface well testing system, wherein the instructions further to: based on the sensor data, control a fluid pressure at the burner; and activate the one or more nozzles of the burner to improve a burn condition at the burner based, at least in part, on the sensor data and flow rates of the fluids.
12. 12. The system of claim 10, wherein the instructions to determine that the fluids will not completely burn in the burner comprising instructions to: add, via a flow line from the separator to the burner, natural gas to improve a burn condition of the fluids in the burner; and add, via a second flow line, water to improve the burn condition of the fluids in the burner.
13. 13 The system of claim 8, further comprising instructions to: recirculate a first portion of the fluids to and from a tank in the surface well testing system, wherein the fluids include oil; condition the oil via chemical additives added during the recirculation and send, while recirculating the first portion of the fluids to and from the tank, a second portion of the fluids to the burner.
14. 14 The system of claim 8, further comprising: a wind direction transmitter (WDT) instrument, the WDT instrument configured to determine a wind direction and wind speed, wherein the instructions to determine the first burn configuration for the burner comprise instructions to rotate the burner based on the wind direction and the wind speed
15. 15. One or more non-transitory, machine-readable media including program code configured to reduce emissions from a surface well testing system, the program code executable by a processor, the program code comprising instructions to: control, via a plurality of motorized valves, a rate of emissions from a plurality of emissions sources, wherein the plurality of emissions sources comprises a burner configured to burn fluids; determine that the fluids will not completely burn in the burner; calculate estimated emissions rates from the plurality of emissions sources; determine a first burn configuration for the emissions sources based, at least in part, on the determination that the fluids will not completely burn in the burner and the calculated emission rates; and control the rate of emissions from the plurality of emissions sources according to the first burn configuration.
16. 16. The machine-readable media of claim 15, wherein the instructions to determine the fluids will not completely burn is based on both sensor data and skid states or based on user input.
17. 17. The machine-readable media of claim 16, wherein the instructions to determine the first burn configuration comprise instructions to: adjust system controls in the surface well testing system based on the first burn configuration; configure the skid states based on the system controls, wherein the system controls include set points, parameters, and settings for at least the burner, separator, a choke, a tank, a pump, a diverter manifold, and the plurality of motorized valves; and modify, while controlling the rate of emissions from the plurality of emissions sources according to the first burn configuration, a flow rate of oil to the burner, wherein the instructions to modify the flow rate of oil comprise instructions to reduce an orifice size of the choke, recirculate oil to the tank, or shut in a well of the surface well testing system during unsafe burning conditions.
18. 18. The machine-readable media of claim 16, further comprising instructions to: based on sensor data, control a fluid pressure at the burner; and activate one or more nozzles of the burner to improve a burn condition at the burner based, at least in part, on the sensor data and flow rates of the fluids.
19. 19 The machine-readable media of claim 15, further comprising instructions to: add, via a flow line from a separator to the burner, natural gas to improve a burn condition of the fluids in the burner; add, via a second flow line, water to improve the burn condition of the fluids in the burner; recirculate a first portion of the fluids to and from a tank in the surface well testing system, wherein the fluids include oil; condition the oil via chemical additives added during the recirculation; and send, while recirculating the first portion of the fluids to and from the tank, a second portion of the fluids to the burner.
20. 20. The machine-readable media of claim 15, wherein the instructions to control the rate of emissions from the plurality of emissions sources according to the first burn configuration comprise instructions to: determine, via a wind direction transmitter (WDT) instrument, a wind direction and a wind speed; and rotate the burner based on the wind direction and wind speed.