DRILLING

TECHNICAL FIELD

The present disclosure relates generally to system for managing a mass of fluid within a fluid evaluation system.

BACKGROUND

When an oil well or other effluent well (gas, vapor, water) is drilled, an analysis of the gaseous compounds contained in the drilling muds emerging from the well. This analysis enables the geological succession of the formations traversed during drilling to be reconstituted and is involved in the determination of the possibilities of working the fluid deposits encountered.

This analysis, which is carried out continuously, comprises two main stages. The first stage consists in extracting the gases conveyed by the mud (for example, hydrocarbon compounds, carbon dioxide, hydrogen sulfide, etc.). The second stage consists in qualifying and quantifying the gases extracted.

BRIEF DESCRIPTION OF THE DRAWINGS

A more complete understanding of the present disclosure and its features and advantages thereof may be acquired by referring to the following description, taken in conjunction with the accompanying drawings, which are not necessarily to scale, in which like reference numbers indicate like features, and wherein:

FIG. l is a schematic diagram of an example of a drilling system in which a downhole drilling tool of the present disclosure may be used;

FIGs. 2A-2H are respective schematic diagrams of a system for managing a mass of fluid within a fluid evaluation system, using a feedback signal.

FIGs. 3 A-3H are respective schematic diagrams of a system for managing a mass of fluid within a fluid evaluation system, using a feedforward signal.

FIG. 4 is a flow chart illustrating an exemplary method for managing a mass of fluid within a fluid evaluation system, using a feedback signal.

FIG. 5 is a flow chart illustrating an exemplary method for managing a mass of fluid within a fluid evaluation system, using a feedforward signal. DETAILED DESCRIPTION

The present disclosure relates to a system including a downhole drilling tool for drilling a wellbore including a plurality of formations, the drilling tool configured to obtain a formational fluid from the wellbore; a fluid evaluation system, including: a pump configured to receive drilling fluid that includes the formational fluid from the drilling tool and pump the drilling fluid downstream within the evaluation system; a mass flow meter coupled to the output of the pump, the mass flow meter configured to provide a feedback signal to the pump to adjust one or more parameters of the pump such that a constant mass of the drilling fluid is pumped through the pump; a gas extractor coupled to the output of the mass flow meter, the gas extractor configured to separate gas from the drilling fluid; and a gas analytic detector coupled to the output of the gas extractor, the gas analytic detector configured to receive the gas and identify one or more characteristics of the gas.

The present disclosure further relates to a system including a downhole drilling tool for drilling a wellbore including a plurality of formations, the drilling tool configured to obtain a formational fluid from the wellbore; a fluid evaluation system, including: a mass flow meter configured to receive drilling fluid that includes the formational fluid from the drilling tool; a pump coupled to the output of the mass flow meter, the pump configured to pump the drilling fluid downstream within the evaluation system; a gas extractor coupled to the output of the pump, the gas extractor configured to separate gas from the drilling fluid; and a gas analytic detector coupled to the output of the gas extractor, the gas analytic detector configured to receive the gas to identify one or more characteristics of the gas, wherein the mass flow meter is configured to provide a feedforward signal to the pump to adjust one or more parameters of the pump such that a predetermined constant mass of the drilling fluid is pumped through the pump.

Embodiments of the present disclosure and its advantages are best understood by referring to FIGURES 1, 2A-2H, 3A-3H,4, and 5 where like numbers are used to indicate like and corresponding parts.

FIGURE 1 is an elevation view of an example drilling system 100. Drilling system 100 is configured to drill into one or more geological formations. Drilling system 100 may include well surface or well site 106. Various types of drilling equipment such as a rotary table, mud pumps and mud tanks (not expressly shown) may be located at a well surface sometimes referred to as “well site” 106. For example, well site 106 may include drilling rig 102 that may have various characteristics and features associated with a “land drilling rig.” However, downhole drilling tools incorporating teachings of the present disclosure may be satisfactorily used with drilling equipment located on offshore platforms, drill ships, semi- submersibles and drilling barges (not expressly shown).

Drilling system 100 may include drill string 103 associated with rotary drill bit 101 that may be used to rotate rotary drill bit 101 in radial direction 105 around bit rotational axis 104 of form a wide variety of wellbores 114 such as generally vertical wellbore 114a or generally horizontal wellbore 114b as shown in FIG. 1. Various directional drilling techniques and associated components of bottom hole assembly (BHA) 120 of drill string 103 may be used to form generally horizontal wellbore 114b. For example, lateral forces may be applied to drill bit 101 proximate kickoff location 113 to form generally horizontal wellbore 114b extending from generally vertical wellbore 114a. Wellbore 114 is drilled to a drilling distance, which is the distance between the well surface and the furthest extent of wellbore 114, and which increases as drilling progresses.

BHA 120 may be formed from a wide variety of components configured to form a wellbore 114. For example, components 122a, 122b and 122c of BHA 120 may include, but are not limited to rotary drill bit 101, drill collars, rotary steering tools, directional drilling tools, downhole drilling motors, reamers, hole enlargers or stabilizers. The number of components such as drill collars and different types of components 122 included in BHA 120 may depend upon anticipated downhole drilling conditions and the type of wellbore that will be formed by drill string 103 and fixed-cutter drill bit 101.

Wellbore 114 may be defined in part by casing string 110 that may extend from well site 106 to a selected downhole location. Various types of drilling fluid may be pumped from well site 106 through drill string 103 to attached drill bit 101. Such drilling fluids may be directed to flow from drill string 103 to respective nozzles included in rotary drill bit 101.

The drilling fluid may be circulated back to well surface 106 through annulus 108 defined in part by outside diameter 112 of drill string 103 and inside diameter 111 of casing string 110.

Drilling system 100 may also include rotary drill bit (“drill bit”) 101. Drill bit 101, discussed in further detail in FIGURE 2, may include one or more blades 126 that may be disposed outwardly from exterior portions of rotary bit body 124 of drill bit 101. Rotary bit body 124 may have a generally cylindrical body and blades 126 may be any suitable type of projections extending outwardly from rotary bit body 124. Drill bit 101 may rotate with respect to bit rotational axis 104 in a direction defined by directional arrow 105. Blades 126 may include one or more cutting elements 128 disposed outwardly from exterior portions of each blade 126. Blades 126 may include one or more depth of cut controllers (not expressly shown) configured to control the depth of cut of cutting elements 128. Blades 126 may further include one or more gage pads (not expressly shown) disposed on blades 126. Drill bit 101 may be designed and formed in accordance with teachings of the present disclosure and may have many different designs, configurations, and/or dimensions according to the particular application of drill bit 101.

FIG. 2A is a block diagram of a system 200. The system 200 can include a drilling system 202 (including a downhole drilling tool) and a fluid evaluation system 204. The fluid evaluation system 204 can include a pump 206, a mass flow meter 208, a heater 210, a gas extractor 212, a carrier gas source 214, a gas sample system 216, and a gas analytic detector 218. The mass flow meter 208 can be in communication with the pump 206. In some examples, the drilling system 202 is the same, or substantially the same, as the drilling system 100 of FIGURE 1. For example, the system 200 can be positioned at a surface of the well site 106 ( e.g before pumps that pump the drilling fluid through the drill string 203, or after circulation of the drilling fluid back through the annulus 108).

The drilling system 202 can obtain a formational fluid from a wellbore (e.g., wellbore 114a, 114b). In some examples, the formational fluid can include the drilling fluid that is circulated back to well surface 106 through annulus 108 as described with respect to FIGURE 1

The pump 206 can be configured to receive fluid from the drilling system 202. The fluid from the drilling system 202 can include drilling fluid and/or formational fluid (e.g, formational fluid (liquid and/or gas) and cuttings from formation by the drilling system 202 (e.g, from the drill bit 101)). In some examples, the drilling fluid can include the formational fluid. The pump 206 can pump the drilling fluid downstream (along the direction Dl) within the evaluation system 204.

The mass flow meter 208 can be configured to receive fluid from the pump 206. For example, the mass flow meter 208 is coupled to the output of the pump 206 to receive the fluid. The mass flow meter 208 can further be communicatively coupled to the pump 206.

For example, the mass flow meter 208 can be configured to provide a signal to the pump 206 to adjust one or more parameters of the pump 206. In some examples, the mass flow meter 208 is configured to provide a feedback signal to the pump 206. The mass flow meter 208 can provide the feedback signal to the pump 206 to adjust (or control, or manage) parameters of the pump 206 such that a constant mass of the fluid is pumped through (or by) the pump 206 downstream (along the direction Dl) within the evaluation system 204.

Specifically, the mass flow meter 208 can determine (or calculate) the quantity of mass of the fluid that is being pumped by the pump 206 downstream ( e.g ., along the direction Dl to the remaining components of the evaluation system 204). The mass flow meter 208 can adjust parameters of the pump 206 (via the feedback signal) such that the quantity of mass of the fluid that is being pumped by the pump 206 downstream (the output of the pump 206) is constant (or substantially constant). In other words, the mass flow meter 208 can adjust parameters of the pump 206 (via the feedback signal) such that the quantity of mass of the fluid that is being pumped by the pump 206 downstream (the output of the pump 206) is within a threshold (or tolerance).

In some examples, the mass flow meter 208 can provide the feedback signal to the pump 206, based on the mass of the fluid output by the pump 206, to adjust a rotation rate (rotations per minute) of the pump 206. For example, the mass flow meter 208 can provide the feedback signal to the pump 206 to increase or decrease the rotation rate (rotations per minute) of the pump 206 such that the mass of the fluid output by the pump 206 is constant, substantially constant, or within a threshold (or tolerance). For example, the mass flow meter 208 can provide the feedback signal to the pump 206 to increase or decrease the rotation rate of the pump 206 such that the fluid output by the pump 206 is, for example, 10 to 100 pounds per min and, for example, +/- 1% to 2% of set point.

In some examples, the mass flow meter 208 can provide the feedback signal to the pump 206, based on the mass of the fluid output by the pump 206, to adjust a mass flow rate of the pump 206. For example, the mass flow meter 208 can provide the feedback signal to the pump 206 to increase or decrease the mass flow rate of the pump 206 such that the mass of the fluid output by the pump 206 is constant, substantially constant, or within a threshold (or tolerance). For example, the mass flow meter 208 can provide the feedback signal to the pump 206 to increase or decrease the mass flow rate of the pump 206 such that the fluid output by the pump 206 is, for example, 10 to 100 pounds per min and +/- 1% to 2% of set point.

In some examples, the mass flow rate of the fluid that is being pumped by the pump 206 downstream is based on a mass of the formational fluid obtained by the drilling system 202. In other words, the mass flow rate of the fluid that is being pumped by the pump 206 downstream is based on a mass of cuttings (formational cuttings) returning to the surface by the drilling system 202 and provided to the pump 206. For example, the mass flow meter 208 can provide the feedback signal to the pump 206 to increase or decrease the mass flow rate of the pump 206 based on the mass of the formational fluid obtained by the drilling system 202 such that the mass of the fluid output by the pump 206 is constant, substantially constant, or within a threshold (or tolerance). For example, the mass flow meter 208 can provide the feedback signal to the pump 206 to increase or decrease the mass flow rate of the pump 206 such that the fluid output by the pump 206 is, for example, 10 to 100 pounds per min and +/- 1% to 2% of set point.

In some examples, the mass flow rate of the fluid that is being pumped by the pump 206 downstream is based on a ratio of the mass of the drilling fluid to be analyzed by the gas analytic detector 218 to a mass flow rate of the formational fluid ( e.g ., within the wellbore 114). For example, the mass flow meter 208 can provide the feedback signal to the pump 206 to increase or decrease the mass flow rate of the pump 206 based on the ratio of the mass of the drilling fluid to be analyzed by the gas analytic detector 218 to the mass flow rate of the formational fluid (within the wellbore 114) (e.g., formational fluid (liquid and/or gas) and cuttings from formation by the drilling system 202) such that the mass of the fluid output by the pump 206 is constant, substantially constant, or within a threshold (or tolerance). For example, the mass flow meter 208 can provide the feedback signal to the pump 206 to increase or decrease the mass flow rate of the pump 206 such that the fluid output by the pump 206 is, for example, 10 to 100 pounds per min and +/- 1% to 2% of set point.

The mass flow meter 208 can adjust parameters of the pump 206 (via the feedback signal) such that the quantity of mass of the fluid that is being pumped by the pump 206 downstream (the output of the pump 206) is within a threshold (or tolerance) with the parameters of the pump 206 can be independent of the pressure and/or the temperature of fluid that is being pumped. Specifically, the mass of the fluid that is being pumped by the pump 206 can be independent of the pressure and/or temperature of the fluid. As a result, the pump 206 can operate (pump the fluid) independent of the pressure and/or the temperature of the fluid. Thus, the mass flow meter 208 can provide the feedback signal to the pump 206 to adjust (or control, or manage) parameters of the pump 206 such that a constant mass of the fluid is pumped through (or by) the pump 206 downstream (along the direction Dl) within the evaluation system 204 independent of the pressure and/or temperature of the fluid. The mass flow rate of the pump 206 can be adjusted (by the mass flow meter 208) based on the mass of the fluid pumped by the pump 206, and is independent of the volume of the fluid pumped by the pump 206.

The process heater 210 is configured to receive the fluid that is output by the mass flow meter 208. The process heater 210 can be configured to increase a temperature of the fluid that is pumped downstream in the evaluation system 204 toward a predetermined set point. For example, the predetermined set point of the temperature can be the maximum temperature of the fluid that allows extraction that will not flash water or make the fluid unstable. For example, the operating set point for the fluid (for hydrocarbon based drilling fluids) can be between 80 to 90 degrees Celsius. For example, the operating set point for the fluid (for water based fluids) is a maximum of 70 degrees Celsius.

The gas extractor 212 is configured to receive the fluid that is output by the process heater 210. The process heater 210 can be configured to separate gas from the fluid that is pumped downstream in the evaluation system 204. In other words, the gas extractor 212 separates dissolved gas from the fluid. In some examples, the gas extractor 212 can return (a portion or an entirety of) the separated fluid to the drilling system 202, along the direction D2 (opposite to the direction Dl).

The carrier gas source 214 can provide a carrier gas to the gas extractor 212. For example, the gas extractor 212 is further configured to receive a carrier gas from the carrier gas source 214. The carrier gas source 214 can provide the carrier gas to the gas extractor 212 to maintain a constant mass of the gas provided to the gas sample system 216 and the gas analytic detector 218 by the gas extractor 212. In some examples, the pressure of the gas extractor 212 is based on a mass flow rate of the carrier gas provided by the carrier gas source 214. For example, the carrier gas source 214 can adjust the mass of the carrier gas to maintain a constant mass of the gas at the gas extractor 212. The carrier gas source 214 can hold the carrier gas at a constant mass, or adjust the mass of the carrier gas based on the mass of the gas at the gas extractor 212. By introducing the carrier gas by the carrier gas source 214, the gas extractor 212 can be operated at a predetermined pressure to maximize hydrocarbon extraction. The fluid that enters the gas extractor 212 can be agitated to increase the surface area exposed to the carrier gas to allow the extraction of formational fluids.

The gas sample system 216 can be configured to receive the gas from the gas extractor 212. The gas sample system 216 can facilitate movement of the gas to the gas analytic detector 218. The gas sample system 216 conditions the gas, removes excess moisture and/or particles from the gas. The gas sample system 216 can include a pump, filters, pressure control, and a flow rate controller.

The gas analytic detector 218 can receive the gas from the gas sample system 216.

The gas analytic detector 218 is configured to identify one or more characteristics of the gas. In some examples, the gas analytic detector 218 can perform gas chromatography, high trim analysis, isotopic ratio identification, and/or other characteristic identifying operations. To that end, by managing a mass of fluid within the system 200, the gas analytic detector 218 can provide an improved (increased accuracy) relationship to mass in the wellbore ( e.g ., wellbore 114) by removing errors due to pressure and temperature corrections that may be needed (e.g., when performing volume calculations of the fluid within the system 200).

In some implementations, referring to FIG. 2B, the system 200 can be independent of the process heater 210. For example, the gas extractor 212 can be configured to receive the fluid that is output of the mass flow meter 208 directly. The gas extractor 212 can receive the fluid that is independent of an increase of temperature of the fluid by the process heater 210. In other words, the temperature of the fluid is not increased prior to the gas extractor 212 receiving the fluid from the mass flow meter 208.

In some implementations, referring to FIG. 2C, the system 200 can further include an additional pump 250. The pump 250 can be coupled between the gas extractor 212 and the drilling system 202. The pump 250 is configured to pump the separated fluid to the drilling tool 202. For example, the pump 250 receives the separated fluid from the gas extractor 212, and can pump the separated fluid (a portion or an entirety thereof) to the drilling system 202, along the direction D2.

In some examples, the mass flow meter 208 can further be communicatively coupled to the additional pump 250. For example, the mass flow meter 208 can be configured to provide a signal to the additional pump 250 to adjust one or more parameters of the additional pump 250. The mass flow meter 208 can provide the feedback signal to the additional pump 250 to adjust (or control, or manage) parameters of the additional pump 250 such that a constant mass of the separated fluid is pumped through (or by) the additional pump 250 to the drilling system 202, along the direction D2.

In some examples, the mass flow meter 208 can provide an additional feedback signal to the additional pump 250, based on the mass of the fluid output by the pump 206, to adjust a mass flow rate of the additional pump 250. For example, the mass flow meter 208 can provide the feedback signal to the additional pump 250 to increase or decrease the mass flow rate of the additional pump 250 such that the fluid output by the additional pump 250 (the separated fluid) is constant, substantially constant, or within a threshold (or tolerance).

In some examples, the signal provided by the mass flow meter 208 to the additional pump 250 is the same as the signal that is provided to the pump 206.

In some implementations, referring to FIG. 2D, the system 200 can include the additional pump 250 and further be independent of the process heater 210. For example, i) the gas extractor 212 can be configured to receive the fluid that is output of the mass flow meter 208 directly, and ii) include the additional pump 250 to receive the separated fluid from the gas extractor 212, and pump the separated fluid (a portion or an entirety thereof) to the drilling system 202.

In some implementations, referring to FIG. 2E, the system 200 can further include a pressure sensor 260. The pressure sensor 260 can be coupled to the output of the gas extractor 212. The pressure sensor 260 is configured to detect (sense) the pressure at the gas extractor 212. The pressure sensor 260 can provide a feedback signal to the carrier gas source 214 to adjust the mass flow rate of the carrier gas provided by the carrier gas source 214 to the gas extractor 212. Specifically, the feedback signal from the pressure sensor 260 to the carrier gas source 214 can indicate a mass of the carrier gas to be provided by the carrier gas source 214 to the gas extractor 212 based on the gas output by the gas extractor 212. The feedback signal can indicate the mass flow rate of the carrier gas provided by the carrier gas source 214 to maintain a constant mass of the gas at the gas extractor 212.

In some implementations, referring to FIG. 2F, the system 200 can further include the pressure sensor 260 and be independent of the process heater 210. For example, i) the gas extractor 212 can be configured to receive the fluid that is output of the mass flow meter 208 directly, and ii) include the pressure sensor 260 to detect (sense) the pressure at the gas extractor 212 and provide the feedback signal to the carrier gas source 214 to adjust the mass flow rate of the carrier gas provided by the carrier gas source 214 to the gas extractor 212.

In some implementations, referring to FIG. 2G, the system 200 can further include the additional pump 250 and the pressure sensor 260. For example, the system 200 can include i) the additional pump 250 to receive the separated fluid from the gas extractor 212, and pump the separated fluid (a portion or an entirety thereof) to the drilling system 202, and ii) the pressure sensor 260 to detect (sense) the pressure at the gas extractor 212 and provide the feedback signal to the carrier gas source 214 to adjust the mass flow rate of the carrier gas provided by the carrier gas source 214 to the gas extractor 212. In some implementations, referring to FIG. 2H, the system 200 can further include the additional pump 250, the pressure sensor 260, and be independent of the process heater 210. For example, the system 200 can include i) the additional pump 250 to receive the separated fluid from the gas extractor 212, and pump the separated fluid (a portion or an entirety thereof) to the drilling system 202, ii) the pressure sensor 260 to detect (sense) the pressure at the gas extractor 212 and provide the feedback signal to the carrier gas source 214 to adjust the mass flow rate of the carrier gas provided by the carrier gas source 214 to the gas extractor 212; and iii) the gas extractor 212 can be configured to receive the fluid that is output of the mass flow meter 208 directly.

FIG. 3A is a block diagram of a system 300. The system 300 can include a drilling system 302 (including a downhole drilling tool) and a fluid evaluation system 304. The fluid evaluation system 304 can include a pump 306, a mass flow meter 308, a heater 310, a gas extractor 312, a carrier gas source 314, a gas sample system 316, and a gas analytic detector 318. The mass flow meter 308 can be in communication with the pump 306. In some examples, the drilling system 302 is the same, or substantially the same, as the drilling system 100 of FIGURE 1. For example, the system 300 can be positioned at a surface of the well site 106 ( e.g before pumps that pump the drilling fluid through the drill string 203, or after circulation of the drilling fluid back through the annulus 108).

The drilling system 302 can obtain a formational fluid from a wellbore (e.g., wellbore 114a, 114b).

The mass flow meter 308 can be configured to receive fluid from the drilling system 302. The fluid from the drilling system 302 can include drilling fluid and/or formational fluid (e.g, formation fluid (liquid and/or gas) and cuttings from formation by the drilling system 302 (e.g, from the drill bit 101)). In some examples, the drilling fluid can include the formational fluid. The pump 306 can be configured to receive fluid from the mass flow meter 308. The pump 306 can pump the fluid downstream (along the direction Dl) within the evaluation system 304.

The mass flow meter 308 can further be communicatively coupled to the pump 306. For example, the mass flow meter 308 can be configured to provide a signal to the pump 306 to adjust one or more parameters of the pump 306. In some examples, the mass flow meter 308 is configured to provide a feedforward signal to the pump 306. The mass flow meter 308 can provide the feedforward signal to the pump 306 to adjust (or control, or manage) parameters of the pump 306 such that a constant mass of the fluid is pumped through (or by) the pump 306 downstream (along the direction Dl) within the evaluation system 304.

Specifically, the mass flow meter 308 can determine (or calculate) the quantity of mass of the fluid that is being pumped by the pump 306 downstream. The mass flow meter 308 can adjust parameters of the pump 306 (via the feedforward signal) such that the quantity of mass of the fluid that is being pumped by the pump 306 downstream (the output of the pump 306) is constant (or substantially constant). In other words, the mass flow meter 308 can adjust parameters of the pump 306 (via the feedforward signal) such that the quantity of mass of the fluid that is being pumped by the pump 306 downstream (the output of the pump 306) is within a threshold (or tolerance).

In some examples, the mass flow meter 308 can provide the feedforward signal to the pump 306, based on the mass of the fluid output by the pump 306, to adjust a rotation rate (rotations per minute) of the pump 306. For example, the mass flow meter 308 can provide the feedforward signal to the pump 306 to increase or decrease the rotation rate (rotations per minute) of the pump 306 such that the mass of the fluid output by the pump 306 is constant, substantially constant, or within a threshold (or tolerance). For example, the mass flow meter 308 can provide the feedforward signal to the pump 306 to increase or decrease the rotation rate of the pump 306 such that the fluid output by the pump 236 is, for example, 10 to 100 pounds per min and +/- 1% to 2% of set point.

In some examples, the mass flow meter 308 can provide the feedforward signal to the pump 306, based on the mass of the fluid output by the pump 306, to adjust a mass flow rate of the pump 306. For example, the mass flow meter 308 can provide the feedforward signal to the pump 306 to increase or decrease the mass flow rate of the pump 306 such that the mass of the fluid output by the pump 306 is constant, substantially constant, or within a threshold (or tolerance). For example, the mass flow meter 308 can provide the feedforward signal to the pump 306 to increase or decrease the mass flow rate of the pump 306 such that the fluid output by the pump 236 is, for example, 10 to 100 pounds per min and +/- 1% to 2% of set point.

In some examples, the mass flow rate of the fluid that is being pumped by the pump 306 downstream is based on a mass of the formational fluid obtained by the drilling system 302. In other words, the mass flow rate of the fluid that is being pumped by the pump 306 downstream is based on a mass of cuttings (formational cuttings) returning to the surface by the drilling system 302 and eventually provided to the pump 306. For example, the mass flow meter 308 can provide the feedforward signal to the pump 306 to increase or decrease the mass flow rate of the pump 306 based on the mass of the formational fluid obtained by the drilling system 302 such that the mass of the fluid output by the pump 306 is constant, substantially constant, or within a threshold (or tolerance). For example, the mass flow meter 308 can provide the feedforward signal to the pump 306 to increase or decrease the mass flow rate of the pump 306 such that the fluid output by the pump 236 is, for example, 10 to 100 pounds per min and +/- 1% to 2% of set point.

In some examples, the mass flow rate of the fluid that is being pumped by the pump 306 downstream is based on a ratio of the mass of the drilling fluid to be analyzed by the gas analytic detector 318 to a mass flow rate of the formational fluid ( e.g ., within the wellbore 114). For example, the mass flow meter 308 can provide the feedforward signal to the pump 306 to increase or decrease the mass flow rate of the pump 306 based on the ratio of the mass of the drilling fluid to be analyzed by the gas analytic detector 318 to the mass flow rate of the formational fluid (e.g., within the wellbore 114) such that the mass of the fluid output by the pump 306 is constant, substantially constant, or within a threshold (or tolerance). For example, the mass flow meter 308 can provide the feedforward signal to the pump 306 to increase or decrease the rotation rate of the pump 306 such that the fluid output by the pump 236 is, for example, 10 to 100 pounds per min and +/- 1% to 2% of set point.

By the mass flow meter 308 can adjust parameters of the pump 306 (via the feedforward signal) such that the quantity of mass of the fluid that is being pumped by the pump 306 downstream (the output of the pump 306) is within a threshold (or tolerance), the parameters of the pump 306 can be independent of the pressure and/or the temperature of fluid that is being pumped. Specifically, the mass of the fluid that is being pumped by the pump 306 can be independent of the pressure and/or temperature of the fluid. As a result, the pump 306 can operate (pump the fluid) independent of the pressure and/or the temperature of the fluid. Thus, the mass flow meter 308 can provide the feedforward signal to the pump 306 to adjust (or control, or manage) parameters of the pump 306 such that a constant mass of the fluid is pumped through (or by) the pump 306 downstream (along the direction Dl) within the evaluation system 304 independent of the pressure and/or temperature of the fluid. The mass flow rate of the pump 306 can be adjusted (by the mass flow meter 308) based on the mass of the fluid pumped by the pump 306, and is independent of the volume of the fluid pumped by the pump 306. The process heater 310 is configured to receive the fluid that is output by the pump 306. The process heater 310 can be configured to increase a temperature of the fluid that is pumped downstream in the evaluation system 304 toward a predetermined set point. For example, the predetermined set point of the temperature can be the maximum temperature of the fluid that allows extraction that will not flash water or make the fluid unstable. For example, the operating set point for the fluid (for hydrocarbon based drilling fluids) can be between 80 to 90 degrees Celsius. For example, the operating set point for the fluid (for water based fluids) is a maximum of 70 degrees Celsius.

The gas extractor 312 is configured to receive the fluid that is output by the process heater 310. The process heater 310 can be configured to separate gas from the fluid that is pumped downstream in the evaluation system 304. In other words, the gas extractor 312 separates dissolved gas from the fluid. In some examples, the gas extractor 312 can return (a portion or an entirety of) the separated fluid to the drilling system 302, along the direction D2 (opposite to the direction Dl).

The carrier gas source 314 can provide a carrier gas to the gas extractor 312. For example, the gas extractor 312 is further configured to receive a carrier gas from the carrier gas source 314. The carrier gas source 314 can provide the carrier gas to the gas extractor 312 to maintain a constant mass of the gas provided to the gas sample system 316 and the gas analytic detector 318 by the gas extractor 312. In some examples, the pressure of the gas extractor 312 is based on a mass flow rate of the carrier gas provided by the carrier gas source 314. For example, the carrier gas source 314 can adjust the mass of the carrier gas to maintain a constant mass of the gas at the gas extractor 312. The carrier gas source 314 can hold the carrier gas at a constant mass, or adjust the mass of the carrier gas based on the mass of the gas at the gas extractor 312. By introducing the carrier gas by the carrier gas source 314, the gas extractor 312 can be operated at a predetermined pressure to maximize hydrocarbon extraction. The fluid that enters the gas extractor 312 can be agitated to increase the surface area exposed to the carrier gas to allow the extraction of formational fluids.

The gas sample system 316 can be configured to receive the gas from the gas extractor 312. The gas sample system 316 can facilitate movement of the gas to the gas analytic detector 318. The gas sample system 316 conditions the gas, removes excess moisture and/or particles from the gas. The gas sample system 316 can include a pump, filters, pressure control, and a flow rate controller. The gas analytic detector 318 can receive the gas from the gas sample system 316.

The gas analytic detector 318 is configured to identify one or more characteristics of the gas. In some examples, the gas analytic detector 318 can perform gas chromatography, high trim analysis, isotopic ratio identification, and/or other characteristic identifying operations. To that end, by managing a mass of fluid within the system 300, the gas analytic detector 318 can provide an improved (increased accuracy) relationship to mass in the wellbore ( e.g ., wellbore 114) by removing errors due to pressure and temperature corrections that may be needed (e.g., when performing volume calculations of the fluid within the system 300).

In some implementations, referring to FIG. 3B, the system 300 can be independent of the process heater 310. For example, the gas extractor 312 can be configured to receive the fluid that is output of the pump 306 directly. The gas extractor 312 can receive the fluid that is independent of an increase of temperature of the fluid by the process heater 310. In other words, the temperature of the fluid is not increased prior to the gas extractor 312 receiving the fluid from the pump 306.

In some implementations, referring to FIG. 3C, the system 300 can further include an additional pump 350. The pump 350 can be coupled between the gas extractor 312 and the drilling system 302. The pump 350 is configured to pump the separated fluid to the drilling tool 302. For example, the pump 350 receives the separated fluid from the gas extractor 312, and can pump the separated fluid (a portion or an entirety thereof) to the drilling system 302, along the direction D2.

In some examples, the mass flow meter 308 can further be communicatively coupled to the additional pump 350. For example, the mass flow meter 308 can be configured to provide a signal to the additional pump 350 to adjust one or more parameters of the additional pump 350. The mass flow meter 308 can provide the signal to the additional pump 350 to adjust (or control, or manage) parameters of the additional pump 350 such that a constant mass of the separated fluid is pumped through (or by) the additional pump 350 to the drilling system 302, along the direction D2.

In some examples, the mass flow meter 308 can provide an additional signal to the additional pump 350, based on the mass of the fluid output by the pump 306, to adjust a mass flow rate of the additional pump 350. For example, the mass flow meter 308 can provide the signal to the additional pump 350 to increase or decrease the mass flow rate of the additional pump 350 such that the fluid output by the additional pump 350 (the separated fluid) is constant, substantially constant, or within a threshold (or tolerance). In some examples, the signal provided by the mass flow meter 308 to the additional pump 350 is the same as the signal that is provided to the pump 306.

In some implementations, referring to FIG. 3D, the system 300 can include the additional pump 350 and be independent of the process heater 310. For example, i) the gas extractor 312 can be configured to receive the fluid that is output of the pump 306 directly, and ii) include the additional pump 350 to receive the separated fluid from the gas extractor 312, and pump the separated fluid (a portion or an entirety thereof) to the drilling system 302.

In some implementations, referring to FIG. 3E, the system 300 can further include a pressure sensor 360. The pressure sensor 360 can be coupled to the output of the gas extractor 312. The pressure sensor 360 is configured to detect (sense) the pressure at the gas extractor 312. The pressure sensor 360 can provide a feedback signal to the carrier gas source 314 to adjust the mass flow rate of the carrier gas provided by the carrier gas source 314 to the gas extractor 312. Specifically, the feedback signal from the pressure sensor 360 to the carrier gas source 314 can indicate a mass of the carrier gas to be provided by the carrier gas source 314 to the gas extractor 312 based on the gas output by the gas extractor 312. The feedback signal can indicate the mass flow rate of the carrier gas provided by the carrier gas source 314 to maintain a constant mass of the gas at the gas extractor.

In some implementations, referring to FIG. 3F, the system 300 can further include the pressure sensor 360 and be independent of the process heater 310. For example, i) the gas extractor 312 can be configured to receive the fluid that is output of the pump 306 directly, and ii) include the pressure sensor 360 to detect (sense) the pressure at the gas extractor 312 and provide the feedback signal to the carrier gas source 314 to adjust the mass flow rate of the carrier gas provided by the carrier gas source 314 to the gas extractor 312.

In some implementations, referring to FIG. 3G, the system 300 can further include the additional pump 350 and the pressure sensor 360. For example, the system 300 can include i) the additional pump 350 to receive the separated fluid from the gas extractor 312, and pump the separated fluid (a portion or an entirety thereof) to the drilling system 302, and ii) the pressure sensor 360 to detect (sense) the pressure at the gas extractor 312 and provide the feedback signal to the carrier gas source 314 to adjust the mass flow rate of the carrier gas provided by the carrier gas source 314 to the gas extractor 312.

In some implementations, referring to FIG. 3H, the system 300 can further include the additional pump 350, the pressure sensor 360, and be independent of the process heater 310. For example, the system 300 can include i) the additional pump 350 to receive the separated fluid from the gas extractor 312, and pump the separated fluid (a portion or an entirety thereof) to the drilling system 302, ii) the pressure sensor 360 to detect (sense) the pressure at the gas extractor 312 and provide the feedback signal to the carrier gas source 314 to adjust the mass flow rate of the carrier gas provided by the carrier gas source 314 to the gas extractor 312; and iii) the gas extractor 312 can be configured to receive the fluid that is output of the pump 306 directly.

In some implementations, in the system 200 of FIGS. 2A-2H and/or the system 300 of FIGS. 3 A-3H, a notification can be provided indicating an error when the mass flow meter (mass flow meter 208, mass flow meter 308) detects that the mass of the fluid pumped downstream is out of range or out of threshold. For example, the notification can include an alarm, push notification, or other communication means to alert one or more computing systems of such error.

FIG. 4 is a flow chart illustrating an exemplary method for managing a mass of fluid within a fluid evaluation system. Method 400 may begin at step 410. In step 410, the drilling tool 202 obtains formational fluid. In step 420, the pump 206 receives drilling fluid that includes the formational fluid from the drilling tool 202. In step 430, the pump 206 pumps the drilling fluid downstream within the evaluation system 204. In step 440, the mass flow meter 208 provides a feedback signal to the pump 206 to adjust one or more parameters of the pump 206 to maintain a constant mass of the drilling fluid pumped by the pump 206. In step 450, the gas extractor 212 separates gas from the drilling fluid. In step 460, the gas analytic detector 218 identifies characteristics of the gas.

FIG. 5 is a flow chart illustrating an exemplary method for managing a mass of fluid within a fluid evaluation system. Method 500 may begin at step 510. In step 510, the drilling tool 202 obtains formational fluid. In step 520, the mass flow meter 308 receives drilling fluid that includes the formational fluid from the drilling tool 202. In step 530, the mass flow meter 308 provides a feedforward signal to the pump 306 to adjust one or more parameters of the pump 306 to maintain a constant mass of the drilling fluid pumped by the pump 306. In step 540, the pump 306 pumps the drilling fluid downstream within the evaluation system 304. In step 550, the gas extractor 312 separates gas from the drilling fluid. In step 560, the gas analytic detector 318 identifies characteristics of the gas

In an embodiment A, the present disclosure provides a system that includes: a downhole drilling tool for drilling a wellbore including a plurality of formations, the drilling tool configured to obtain a formational fluid from the wellbore; a fluid evaluation system, including: a pump configured to receive drilling fluid that includes the formational fluid from the drilling tool and pump the drilling fluid downstream within the evaluation system; a mass flow meter coupled to the output of the pump, the mass flow meter configured to provide a feedback signal to the pump to adjust one or more parameters of the pump such that a constant mass of the drilling fluid is pumped through the pump; a gas extractor coupled to the output of the mass flow meter, the gas extractor configured to separate gas from the drilling fluid; and a gas analytic detector coupled to the output of the gas extractor, the gas analytic detector configured to receive the gas and identify one or more characteristics of the gas.

The present disclosure further provides in an embodiment B a system comprising: a downhole drilling tool for drilling a wellbore including a plurality of formations, the drilling tool configured to obtain a formational fluid from the wellbore; a fluid evaluation system, including: a mass flow meter configured to receive drilling fluid that includes the formational fluid from the drilling tool; a pump coupled to the output of the mass flow meter, the pump configured to pump the drilling fluid downstream within the evaluation system; a gas extractor coupled to the output of the pump, the gas extractor configured to separate gas from the drilling fluid; and a gas analytic detector coupled to the output of the gas extractor, the gas analytic detector configured to receive the gas to identify one or more characteristics of the gas, wherein the mass flow meter is configured to provide a feedforward signal to the pump to adjust one or more parameters of the pump such that a predetermined constant mass of the drilling fluid is pumped through the pump.

The present disclosure further provides in an embodiment C a method including obtaining, by a downhole drilling tool, formational fluid from a wellbore; pumping, by a pump, drilling fluid that includes the formational fluid downstream through a fluid evaluation system; separating, by a gas extractor, gas from the drilling fluid that is pumped; analyzing, by a gas analytic detector, the dissolved gas to identify one or more characteristics of the dissolved gas; and providing, by a mass flow meter, a signal to the pump to adjust one or more parameters of the pump such that a constant mass of the drilling fluid is pumped through the pump.

Each of embodiments A, B, and C may have one or more of the following additional elements in any combination: Element 1: further including: a carrier gas source coupled to the gas extractor, the carrier gas source providing a carrier gas to the gas extractor to maintain a constant mass of the gas provided to the gas analytic detector by the gas extractor. Element 2: wherein a pressure of the gas extractor is based on a mass flow rate of the carrier gas provided by the carrier gas source. Element 3: further including a pressure sensor coupled to the output of the gas extractor, the pressure sensor configured to provide a signal to the carrier gas source to adjust the mass flow rate of the carrier gas provided by the carrier gas source to the gas extractor. Element 4: wherein the one or more parameters includes a mass flow rate. Element 5 : wherein the mass flow rate is based on a mass of the formational fluid obtained by the drilling tool. Element 6: wherein the mass flow rate is based on a ratio of a mass of the drilling fluid to be analyzed to a mass flow rate of the formational fluid within the wellbore. Element 7: further including a process heater coupled between the pump and the gas extractor, the process heater configured to increase a temperature of the drilling fluid to a predetermined set point. Element 8: further including an additional pump coupled between the gas extractor and the drilling tool, the additional pump configured to pump the separated drilling fluid to the drilling tool. Element 9: the mass flow meter further configured to provide an additional feedback signal to the additional pump to adjust one or more parameters of the additional pump such that a constant mass of the separated drilling fluid is pumped through the additional pump. Element 10: wherein the signal is a feedforward signal. Element 11: wherein the signal is a feedback signal.

Although the present disclosure has been described with several embodiments, various changes and modifications may be suggested to one skilled in the art. For example, although the present disclosure describes configurations of strain pucks with respect to earth-boring drill bits, the same principles may be used to identify downhole forces applied to any suitable downhole drilling tool according to the present disclosure. It is intended that the present disclosure encompasses such changes and modifications as fall within the scope of the appended claims.