CN114616453A

CN114616453A - Automatic analysis of drilling fluids

Info

Publication number: CN114616453A
Application number: CN202080071557.8A
Authority: CN
Inventors: C·斯图尔特; Z·奇若夫; J·T·康诺顿; N·麦克弗森; T·福斯达尔; R·谢拉迪亚; R·梅尔茨
Original assignee: Schlumberger Technology Corp
Current assignee: Schlumberger Technology Corp
Priority date: 2019-09-23
Filing date: 2020-08-06
Publication date: 2022-06-10
Also published as: BR112022005450A2; WO2021061288A1; GB2602910B; US20210088499A1; GB2602910A; GB202204086D0; NO20220353A1

Abstract

A system includes a fluid conduit, a fluid chamber in communication with the fluid conduit, a rheological sensor in communication with the fluid chamber, and an electronic temperature controller in communication with the fluid chamber. The fluid chamber is cooled or heated in response to a first control signal from the electronic temperature controller.

Description

Automatic analysis of drilling fluids

Cross Reference to Related Applications

This application claims priority to U.S. patent application No. 16/578,570 filed on 23/9/2019, which is a continuation-in-part application to international application No. PCT/2018/040769 filed on 3/7/2018, which claims benefit to U.S. provisional application No. 62/529,454 filed on 6/7/2017. Each of the above-mentioned patent applications is incorporated by reference in its entirety.

Background

As the wellbore is drilled, drilling fluid is pumped into the center of the downhole drill string. The drilling fluid flows down the drill string and exits the drill string through nozzles at the drill bit. The drilling fluid then enters the annulus of the wellbore and returns to the drilling equipment at the surface. The drilling fluid provides lubrication and cooling to the components during drilling. The drilling fluid also carries drill cuttings out of the wellbore, controls wellbore pressure, and performs many other functions related to drilling the wellbore. To ensure that the performance of the drilling fluid is adequate, engineers will continually check the properties of the drilling fluid. For example, the viscosity of the drilling fluid must be high enough to carry the cuttings out of the wellbore, while low enough to allow the cuttings and entrained gas to escape from the surface of the drilling fluid. Depending on the operating conditions, the engineer may check the properties of the drilling fluid several times over twenty-four (24) hours.

Conventional fluid analyzers suffer from several disadvantages in use. For example, conventional fluid analyzers have operational limitations that do not allow analysis of particularly gel-like fluids. When using a conventional fluid analyzer in such a situation, the internal pump used to deliver the drilling fluid can over-operate and fail. For such failures, conventional fluid analyzers must be disassembled to clean the internal components.

It would be desirable to provide a fluid analyzer that will automatically analyze fluids without the constant attention of a technician, and wherein the fluid analyzer can provide rheological parameters of fluids, particularly gels.

Disclosure of Invention

So that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized below, may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this disclosure and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments without specific recitation. Thus, the following summary merely provides several aspects of the specification and should not be used to limit the described embodiments to a single concept.

In one embodiment, a test device is disclosed. The testing apparatus may include a fluid collection vessel configured to contain drilling fluid and a first fluid conduit connected to the fluid collection volume. The testing apparatus may also include a second fluid conduit connected to the fluid collection volume and a fluid chamber configured to receive drilling fluid from both the first fluid conduit and the second fluid conduit. The testing apparatus may further include a first pump configured to move drilling fluid from the fluid collection volume to the fluid chamber, the first pump connected to the first fluid conduit, and a second pump configured to move drilling fluid from the bottle to the fluid chamber, the second pump connected to the second fluid conduit. The testing apparatus may also include a rheological sensor in communication with the fluid chamber and a user interface configured to accept user-defined data. The testing device may also include an electrical system connected to the user interface and configured to process user-defined data, wherein the testing device is configured to receive user data regarding a test to be performed by the testing device and control the first pump, the second pump, and the rheological sensor to automatically test the drilling fluid according to the user-defined data.

In another embodiment, a method of automatically testing a fluid sample is disclosed. The method may include supplying a drilling fluid sample into the fluid chamber by action of at least two pumps and receiving instructions to test the drilling fluid sample at least two temperatures. The method may also provide automatically adjusting the temperature of the drilling fluid sample to a first temperature of the at least two temperatures and testing the fluid sample at the first temperature. The method may also provide automatically adjusting the temperature of the drilling fluid sample to a second temperature of the at least two temperatures and testing the fluid sample at the second temperature.

In another embodiment, a test device is disclosed. The testing apparatus may include a fluid collection container configured to contain drilling fluid. The testing apparatus may further comprise a first fluid conduit connected to the fluid collection volume. The testing apparatus may further comprise a second fluid conduit connected to the fluid collection volume. The testing apparatus may also include a fluid chamber configured to receive drilling fluid from the fluid conduit. The testing apparatus may also include a first pump configured to move drilling fluid from the bottle to the fluid chamber. The testing apparatus may also include a second pump configured to move drilling fluid from the bottle to the fluid chamber. The testing apparatus may also include a rheological sensor in communication with the fluid chamber and a user interface configured to accept user-defined data. The testing device may also include an electrical system connected to the user interface and processing user-defined data, wherein the testing device is configured to receive the user data and control the first pump, the second pump, and the rheological sensor to automatically test the drilling fluid according to the user-defined data, the electrical system further configured with a memory to store and transmit data related to parameters of the test fluid. The testing device may also include at least two fans configured to move a volume of air and at least one device thermometer connected to at least one of the rheological sensor, the first pump, and the second pump. The testing device may also include a housing configured to house the first pump, the second pump, the rheological sensor, the user interface, the electrical system, the at least one device thermometer, and the at least two fans.

Drawings

So that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this disclosure and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments.

Fig. 1 depicts a perspective view of an exemplary fluidic testing device according to the present disclosure.

Fig. 2 depicts a schematic diagram of an example of internal components of a fluid testing apparatus according to the present disclosure.

Fig. 3 depicts a detailed view of a fluid chamber of a fluid testing apparatus according to the present disclosure.

Fig. 4 depicts an example of a user interface of a fluid testing apparatus according to the present disclosure.

FIG. 5 depicts a schematic diagram of a system for regulating the temperature of a fluid sample according to the present disclosure.

Fig. 6 depicts an example of a method of automatically testing a fluid sample at different temperatures according to the present disclosure.

Fig. 7 depicts an example of components of a fluid testing apparatus having a side loop for controlling fluid temperature for density measurement according to the present disclosure.

Fig. 8 depicts an example of components of a fluid testing apparatus without a density sensor according to the present disclosure.

Fig. 9 depicts a dual pump automatic fluid testing apparatus according to the present disclosure.

Fig. 9A depicts an enlarged view of the automated fluid testing apparatus of fig. 9.

Fig. 10 depicts a method of automatically testing a fluid sample with a dual pump automatic fluid testing apparatus according to the present disclosure.

While the embodiments described herein are susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and will be described in detail herein. However, the embodiments described herein are not intended to be limited to the particular forms disclosed. On the contrary, the disclosure is to cover all modifications, equivalents, and alternatives falling within the scope of the appended claims.

Detailed Description

Hereinafter, reference is made to embodiments of the present disclosure. It should be understood, however, that the disclosure is not limited to the specifically described embodiments. Rather, it is contemplated that any combination of the following features and elements, whether related to different embodiments or not, will enable and practice the present disclosure. Moreover, although embodiments of the disclosure may achieve advantages over other possible solutions and/or over the prior art, whether or not a particular advantage is achieved by a given embodiment is not limiting of the disclosure. Thus, the following aspects, features, embodiments and advantages are merely illustrative and are not considered elements or limitations of the claims except where explicitly recited in a claim. Likewise, references to "the present disclosure" should not be construed as a generalization of the inventive subject matter disclosed herein and should not be considered to be an element or limitation of the claims except where explicitly recited in a claim.

Although the terms first, second, third, etc. may be used herein to describe various elements, components, regions, layers and/or sections, these elements, components, regions, layers and/or sections should not be limited by these terms. These terms may be only used to distinguish one element, component, region, layer or section from another element, component, region, layer or section. Terms such as "first," "second," and other numerical terms, as used herein, do not imply a sequence or order unless clearly indicated by the context. Thus, a first element, component, region, layer or section discussed herein could be termed a second element, component, region, layer or section without departing from the teachings of the example embodiments.

When an element or layer is referred to as being "on," "engaged to," "connected to" or "coupled to" another element or layer, it can be directly on, engaged, connected or coupled to the other element or layer or intervening elements or layers may be present. In contrast, when an element is referred to as being "directly on," "directly engaged to," "directly connected to" or "directly coupled to" another element or layer, there may be no intervening elements or layers present. Other words used to describe the relationship between elements should be interpreted in a similar manner. As used herein, the term "and/or" includes any and all combinations of one or more of the associated listed terms.

Some embodiments will now be described with reference to the accompanying drawings. For purposes of consistency, like elements in the various figures will be referenced by like numerals. In the following description, numerous details are set forth to provide an understanding of various embodiments and/or features. However, it will be understood by those skilled in the art that some embodiments may be practiced without many of these details and that numerous variations or modifications from the described embodiments are possible. As used herein, the terms "above" and "below," "upper" and "lower," "upward" and "downward" and other similar terms indicating relative positions above or below a given point are used in this specification to more clearly describe certain embodiments.

Drilling fluid circulates down the drill string, out nozzles located in the drill bit, and up the annulus of the wellbore. The drilling fluid may be used to remove drill cuttings from the bottom of the wellbore. The physical properties of the drilling fluid are monitored during the drilling operation to determine whether the drilling fluid is functioning adequately and to make any desired changes as drilling progresses. The drilling fluid circulated through the wellbore and drilling equipment may be defined as "drilling mud". Drilling fluids may have different physical properties to perform different functions. Aspects of the disclosure presented herein provide apparatus and methods that provide the ability to automatically test the physical properties of drilling fluids having high viscosities that cannot be tested by conventional equipment.

The drilling fluid may be tested to determine or measure physical properties of the drilling fluid, such as testing rheology. The rheological test may be performed with a rheometer, such as a viscometer, rheometer, or other type of sensor. These tests may be conducted at the wellsite, such as in a mobile laboratory. The fluid testing apparatus 100 depicted in fig. 1 may sequentially complete a series of tests on drilling fluid without further indication by the user between tests. Other types of fluid property tests that may be performed with the fluid testing apparatus 100 include measuring drilling fluid weight, rheology, density, water-oil content, emulsion electrical stability, fluid conductivity, and particle size distribution. Based on the principles described in this disclosure, the fluid testing device 100 may automatically perform at least one or more fluid property tests. These automatic tests may be performed at a temperature different from or similar to the temperature of the drilling fluid advancing through the wellbore and drilling equipment.

The fluid testing apparatus 100 may include a housing 102, a user interface 104, and a bottle receiver 106. The drilling fluid sample may be collected into the bottle 108 from a circulating drilling fluid within the drilling system or from another location. Although described as a bottle 108, other configurations may be defined as a fluid collection container having an outer surface and an interior volume for storing drilling fluid. As an example, the collection of drilling fluid may be done automatically by using a pump. The bottle 108 may be connected to the bottle receiver 106. When the bottle 108 is connected to the bottle receiver 106, the fluid conduit may be suspended from the bottle receiver 106 and submerged in the drilling fluid sample. The pump 200 may actively convey at least a portion of the drilling fluid sample from the bottle 108 into the fluid testing apparatus 100 where testing may be performed. As will be described, a single pump system as disclosed in fig. 2, as well as a dual pump system as described in fig. 9, may be used.

The bottle 108 may be secured to the bottle receiver 106 via an interface. In some embodiments, the bottle receiver 106 has internal threads that can engage with external threads of the bottle 108. In other embodiments, the bottle 108 is snapped into place, held in place by compression, or interlocked with the bottle receiver 106, or connected to the bottle receiver 106 by another type of attachment. In some embodiments, the bottle 108 may be insulated to maintain a constant temperature for testing. The bottle 108 may also be transparent or translucent to allow a technician or engineer to identify the amount of drilling fluid placed within the bottle. The bottle 108 may have a scale on the side to enable a technician or engineer to visually identify the amount of volume present within the bottle 108 being tested.

The user interface 104 may allow a user to instruct the fluid testing apparatus 100 to perform a desired test. In some examples, the fluid testing apparatus 100 presents options for testing a drilling fluid sample through the user interface 104. In some instances, the user may indicate the types of tests to be performed and the parameters for performing these types of tests. For example, a user may instruct the fluid testing apparatus 100 through the user interface 104 to perform viscosity tests at multiple temperatures. The user may also specify desired temperatures for these tests via the user interface 104. In other embodiments, the user may specify the amount of time to perform the test.

Any type of user interface 104 may be used in accordance with the principles described in this disclosure. In some embodiments, the user interface 104 is a touch screen component that is accessible from the housing 102. In this embodiment, a user may interact with the touch screen to input information and provide instructions to the fluid testing device 100. In other embodiments, the fluid testing device 100 may include a wireless receiver, wherein a user may wirelessly provide information and/or send instructions to the fluid testing device 100. For example, a user may send information and/or provide instructions with a mobile device, an electronic tablet, a laptop computer, a networked device, a desktop computer, a computing device, another type of device, or a combination thereof. In instances where the user may be in wireless communication with the fluid testing device 100, the user may be located on-site, or the user may be located remotely from the vicinity of the wellbore. In some embodiments, the engineer may be located at a remote location and a local technician may fill the bottle 108 for the engineer so that the engineer does not have to evaluate the drilling fluid and make recommendations on site. In another exemplary embodiment, the user interface may include a keyboard, a mouse, buttons, a dial, switches, a slider, another type of physical input mechanism, or a speaker for voice-operated commands, or a combination of the above, to assist the user in inputting information or providing instructions to the fluid testing device 100. In some cases, the fluid testing device 100 may include a camera that allows a user to communicate with the fluid testing device 100 through actions/gestures.

After inputting the information and instructing the fluid testing apparatus 100 to initiate the test, the fluid testing apparatus 100 may complete the test without further user involvement. When the test is completed, the fluid testing apparatus 100 may automatically transition from one type of test to another. Further, the fluid testing apparatus 100 may automatically adjust the temperature of the drilling fluid sample between tests without user involvement. Typically, drilling fluids are tested after circulating through a drill string in a hot downhole environment. In those cases where it is desirable to test the drilling fluid at a temperature below the current temperature of the drilling fluid, the drilling fluid is cooled prior to conducting the test. The fluid testing apparatus 100 may lower the temperature of the drilling fluid sample and enable the user to perform other tasks.

Fig. 2 and 3 depict schematic diagrams of examples of internal components of a fluidic testing device 100 according to the present disclosure. FIG. 3 details a portion of the internal components depicted in FIG. 2. In this example, the fluid testing apparatus 100 includes a bottle receiver 106, a pump 200, a fluid conduit 204, a density sensor 216 connected to the fluid conduit 204, a fluid chamber 218, and a rheological sensor 220 connected to the fluid chamber 218.

The bottle receiver 106 may be any suitable attachment external to the fluid testing apparatus 100 to which the bottle 108 may be connected and which includes a mechanism for moving the drilling fluid sample 230 from the bottle 108. In the depicted example, a portion of the fluid conduit 204 is suspended a distance from the bottle receiver 106 such that the inlet 206 is submerged within the drilling fluid sample 230 when the bottle 108 is attached. A filter 202 is connected to the drilling fluid conduit 204 and surrounds the inlet 206 to prevent solid particles and/or unwanted debris from entering the fluid conduit 204.

A first portion 210 of the fluid conduit 204 connects the inlet 206 to the pump 200. The pump 200 may be used to draw at least a portion of the drilling fluid sample 230 from the bottle 108 into the fluid conduit 204. In some examples, the pump 200 is a peristaltic pump, however, any suitable type of pump may be used in accordance with the principles described in this disclosure.

A second portion 212 of the fluid conduit 204 may connect the fluid conduit 204 to the pump 200 and the density sensor 216. In some cases, the height of pump 200 is higher than density sensor 216. For this type of example, the pump 200 may release the drilling fluid sample 230 and allow gravity to push the drilling fluid sample 230 to the density sensor 216. In other examples, the pump 200 may actively push the drilling fluid sample 230 through the density sensor 216.

Any suitable type of density sensor 216 may be used. In one example, the density sensor 216 may be a coriolis densitometer that measures a characteristic of the drilling fluid sample 230 as fluid passes through it. The coriolis densitometer may measure the motion/vibration of components internal to the densitometer. These movements may be measured as the drilling fluid sample 230 passes through the density sensor 216. This frequency is related to the density of the drilling fluid sample. In one or more of the depicted embodiments, the density sensor 216 may be a Rheonik Model RHM 04.

A third portion 214 of the fluid conduit 204 connects the fluid conduit 204 from the density sensor 216 to a fluid chamber 218. Fluid chamber 218 may include a chamber wall 236 defining an opening 242. The outlet 208 of the fluid chamber 218 terminates at the opening 242 of the fluid chamber 218 and directs the drilling fluid sample 230 into the fluid chamber 218.

When the level 232 is at the appropriate height, the level detection sensor 222 may send a signal to the pump 200 to stop pumping the drilling fluid sample 230. Any suitable type of level detection sensor 222 may be used. A non-exhaustive list of level detection sensors that may be used include ultrasonic sensors, fluid conductivity sensors, capacitive sensors, inductive sensors, microwave sensors, laser sensors, float switches, thermal flow switches, hydrostatic pressure sensors, radar-based sensors, magnetoresistive sensors, optical sensors, weighing sensors, other time-of-flight sensors, or combinations thereof.

While each of the above-described level detection sensors may be used in some applications, some of the above-described level detection sensors may not be as effective as other types of sensors for certain types of drilling fluids. In some examples, if a thermal diffusion level detection sensor is incorporated into the fluid chamber 218, the sensor may be effective for a variety of different types of drilling fluids. Thermal diffusion level detection sensors can effectively determine the level of a fluid regardless of the fluid dielectric strength, tendency to create optical interference, and other characteristics of the drilling fluid that make level detection challenging.

In one or more embodiments, thermal diffusion techniques may be used to measure characteristics of fluid flow rates. Generally, the fluid is cooler in temperature when flowing than under static conditions. Traditionally, thermal diffusion techniques analyze the temperature of a fluid to determine the flow rate or other characteristic of the fluid. An example of using thermal diffusion techniques in the fluid testing apparatus 100 may be determining the fluid level 232.

Level detection using thermal diffusion techniques may be accomplished by actively moving the drilling fluid sample 230 as fluid enters the fluid chamber 218 and measuring the temperature difference at different heights along the fluid chamber 218. In some examples, the rotor 248 may rotate the drilling fluid sample 230 within the fluid chamber 218 as the fluid chamber 218 fills. The rotation of the drilling fluid sample 230 by the rotor 248 may produce a cooling effect on the portion of the chamber wall 236 that is in direct contact with the fluid. The liquid level 232 may be determined by comparing the temperature along the fluid chamber wall and identifying the liquid level 232 at the height where the temperature differential occurs.

In the example of fig. 2 and 3, the liquid level detection sensor 222 includes a first liquid level detector 224, a second liquid level detector 226, and a third liquid level detector 228. In some cases, each of the first, second, and third

liquid level detectors

224, 226, and 228 is a thermal diffusion liquid level detector. In other examples, at least one of the detectors is a different type of sensor. For those liquid level detectors that are hot liquid level detectors, each may include two or more liquid level thermometers for detecting the temperature of chamber wall 236, the temperature adjacent the exterior of chamber wall 236, the temperature adjacent the interior of chamber wall 236, or combinations thereof. Each level thermometer of the level detector may be adjacent to each other, but at a different height. When the lower of the two thermometers is at a different temperature than the higher thermometer, the level detector may send a signal to stop the pump 200. This temperature difference may indicate that the fluid level 232 is between the lower and upper thermometers.

If the first level detector 224 fails to operate properly under such conditions, the second level detector 226 may be used as a backup; the second level detector 226 may send a signal to stop the pump 200.

The third level detector 228 may be used to indicate that the fluid level 232 is too high. In some examples, the rheological sensor 220 is placed at a location above the working fluid level 232 in the fluid chamber 218 at which other components of the fluid testing apparatus 100 are bonded. If the level 232 becomes too high, the drilling fluid sample 230 may enter these components and interfere with their operation. In one such example, the slew bearing may be above the working fluid level 232 in the fluid chamber 218, and if the fluid level 232 exceeds the fluid working level, the drilling fluid sample 230 may enter the slew bearing. In some cases, viscometers have rotational bearings that are fine tuned to obtain accurate measurement readings. The drilling fluid in these trim bearings can cause inaccuracies in the measurement output of the viscometer. When activated, the third level detector 228 may communicate to the user that the equipment needs to be checked before the test is performed. In some examples, the third level detector 228 may also send a signal to stop the pump 200.

In the example of fig. 2 and 3, the rheological sensor 220 is a viscometer. An exemplary viscometer used in all embodiments described may be a Grace Instrument Company M3600 viscometer. The rheological sensor 220 may include a rotor 248 suspended in the opening 242 of the fluid chamber 218 to contact and/or be submerged in the drilling fluid sample 230 when the fluid chamber 218 is filled. In some exemplary embodiments, the rotor 248 is an outer cylinder that rotates over a bob (bob) (not shown) in an inner cylinder. The drilling fluid sample 230 fills the annular space between the rotor 248 and the pendulum. When activated, the rotor 248 rotates at a known speed and produces a shear stress on the pendulum through the drilling fluid sample 230. The torsion spring limits the motion of the pendulum and measures the stress. The viscometer can run the test at any of a variety of rotor speeds (revolutions per minute or RPM). In some cases, the tests were performed at 600, 300, 200, 100, 6, and 3 RPM.

An electronic temperature controller may be in communication with the fluid chamber 218. Any suitable type of electronic temperature controller may be used in accordance with the principles described in this disclosure. In some examples, the electronic temperature controller includes thermoelectric material 256 having a characteristic that generates an electrical current in response to a temperature difference. The thermoelectric material 256 may include a first side 258 in contact with the outer surface 238 of the fluid chamber 218. In some cases, thermoelectric material 256 includes a second side 260 opposite first side 258 and in contact with heat sink 268.

Thermoelectric material 256 may be part of an electrical circuit that may pass an electrical current through thermoelectric material 256 to simultaneously create a heated region 262 and a cooled region 264 within thermoelectric material 256. A polarity switch may be incorporated into the circuit to change the direction of current flow through thermoelectric material 256. When current is passed through thermoelectric material 256 in a first direction, a heating region 262 is created near fluid chamber 218, and a cooling region 264 is created near heat sink 268. When the heating zone 262 is actively generated adjacent to the fluid chamber 218, the electronic temperature controller actively controls the temperature of the fluid chamber 218. In some cases, when the heating zone 262 is created adjacent to the fluid chamber 218, the temperature of the fluid chamber is raised to a higher temperature, or the temperature of the fluid chamber may be maintained at a desired temperature for performing the test on the drilling fluid sample 230. Where current is passed through thermoelectric material 256 in a second direction opposite the first direction, heating region 262 is generated adjacent fluid chamber 218, and heating region 262 is generated adjacent heat sink 268. In those instances where the cooling region 264 is actively created adjacent to the fluid chamber 218, the temperature of the drilling fluid sample 230 is reduced to a cooler temperature, or the temperature of the drilling fluid sample 230 may be maintained at a desired temperature for performing the test on the drilling fluid sample 230.

The temperature of the heating and

cooling zones

262, 264 may be controlled with a pulse width modulator 570, as shown in FIG. 5. The pulse width modulator 570 may switch the current on and off at a frequency that produces an average current. The longer the pulse width modulator causes current to flow through thermoelectric material 256, the higher the total power supplied to thermoelectric material 256, resulting in a higher temperature generated in heating zone 262 and a lower temperature generated in cooling zone 264, as compared to the time period during which current flow ceases. The temperature difference between the heating region 262 and the cooling region 264 can be reduced by increasing the period of time that the current stops flowing through the thermoelectric material 256. Pulse width modulator 570 may cause thermoelectric material 256 to adjustably heat or cool fluid chamber 218 to a desired temperature for each test to be performed using fluid chamber 218.

The fluid chamber 218 may be made of a thermally conductive material that dissipates the temperature generated by the first side 258 of the thermoelectric material 256. In these embodiments, the fluid chamber 218 is made of aluminum, but the fluid chamber 218 may be made of other types of thermally conductive materials. A non-exhaustive list of thermally conductive materials that may be used to fabricate the fluid chamber 218 includes aluminum, copper, gold, magnesium, beryllium, tungsten, other metals, mixtures thereof, alloys thereof, or combinations thereof. In some cases, the fluid chamber 218 is made entirely of a material having a substantially uniform thermal conductivity. In some examples, the inner surface of the chamber wall 236 is lined with a material having a different thermal conductivity than other materials that comprise different portions of the fluid chamber 218.

The contact surface 240 of the outer surface 238 of the fluid chamber 218 adjacent the thermoelectric material 256 may include a smooth surface roughness in thermal contact with the thermoelectric material 256. In some cases, the contact surface 240 may comprise a polished surface. Further, in some embodiments, the contact surface 240 comprises a smoother finish than other portions of the outer surface 238 of the fluid chamber 218. The smooth finish of contact surface 240 may reduce the gap between thermoelectric material 256 and outer surface 238 of fluid chamber 218. In some examples, a thermally conductive paste may be used to fill the gap between the contact surface 240 and the thermoelectric material 256. Even in instances where contact surface 240 has a smooth finish, contact surface 240 may have a small gap that may minimize heat transfer between thermoelectric material 256 and fluid chamber 218, and a thermally conductive paste may be used to increase heat transfer in these instances.

The outer surface 238 of the fluid chamber 218 may be at least partially surrounded by an insulating layer 244. The insulating layer 244 may minimize environmental conditions that would otherwise heat or cool the fluid chamber 218. For example, the insulating layer 244 may prevent ambient temperatures outside the fluid chamber 218 from heating or cooling the fluid chamber 218 away from a desired temperature for performing rheological tests. In some cases, the insulating layer 244 may prevent condensation from forming outside of the fluid chamber 218, which may result in undesirable cooling of the fluid chamber 218 when the drilling fluid sample 230 is brought to or attempted to be maintained at a higher temperature.

The fluid chamber 218 may include at least one fluid thermometer 250 that measures the temperature of the drilling fluid sample 230. The fluid chamber 218 may also include at least one equipment thermometer 252 that may measure the temperature of at least one piece of equipment associated with the drilling fluid sample 230. For example, the device thermometer 252 may measure the temperature of the material forming the fluid chamber 218. Temperature measurement of the fluid chamber material may prevent overheating of the fluid chamber 218.

The heat sink 268 may be constructed of a thermally conductive material and include fins 270 to increase the surface area of the heat sink 268. The fins 270 may be used to exchange temperature with a fluid medium, such as air or a liquid. In the example where the heating zones 262 are generated on the second side 260, the heat generated by the heating zones 262 may be distributed throughout the heat sink 268 and transferred to the fluid medium through the fins 270. In some cases, a fan 272 is positioned adjacent to the heat sink 268 to flow air over the fins 270, thereby increasing the rate at which heat is dissipated into the air. In other examples, water or other types of liquids may pass through fins 270 as the fluid medium. In this example, the liquid medium is not in contact with the fluid chamber 218, but rather in contact with the fins 270 of the heat sink 268.

Fig. 4 depicts an example of a user interface 104 of a fluid testing apparatus 100 according to many embodiments described in the present disclosure. The user interface 104 may also be used with the fluid testing apparatus 900 depicted in fig. 9. The user may enter user data into the user interface 104 to instruct the fluid testing apparatus 900 to perform a particular test. The user data may be different for each test performed by the fluid testing apparatus. In the exemplary embodiment, user interface 104 presents a format to a user to instruct fluid testing device 100 to perform a test. In this example, the format includes a sample source option 400 to select a source of the drilling fluid sample 230, a temperature set point option 402 for each test, and a duration option 404 for each test. In addition, the user interface 104 presents controls for sending instructions to the fluid testing device 100.

In this example, the user is provided with five temperature set points for performing the test. While the illustrated example depicts five different temperatures for conducting the test, any suitable temperature value may be presented to the user, and any suitable number of temperature set point options may be presented.

In this example, the test duration is depicted as a 10 second option or a 10 minute option. It should be understood that any suitable test duration may be presented in accordance with the principles disclosed herein. In addition, any suitable number of test duration options 400 are presented via the user interface 104.

While the example of fig. 4 depicts a format that presents a limited number of options that a user may select, in other examples, the format presents open fields that a user may specify a temperature, test duration, or value of other test parameters. Further, some examples may provide a user with the ability to add any number of tests to be performed by the fluid testing device 100.

The controls provided in the depicted example include a start command 406, a stop command 408, a repeat command 410, and a reset command 412. When the user wishes to start the test, he or she may select the start command 406. In some examples, in response to sending the start command 406, the fluid testing device performs each test in sequence without additional involvement of the user. In some examples, the test sequence includes performing a first test at the lowest selected temperature set point and a second test at a second, lower selected temperature set point, and so on until a final test is performed at the highest selected temperature set point. In fig. 4, a touch capacitive screen or a physical button may be used.

Fig. 5 depicts a schematic diagram of an electrical system 500 for testing a drilling fluid sample. The electrical system 500 may be used with the embodiment depicted in fig. 1, or with the embodiment depicted in fig. 9. The electrical system 500 may be built into the user interface 104 to allow for compact packaging of the associated system. System 500 includes processor 515, I/O controller 520, memory 525, user interface 526 (which may be user interface 104), polarity switch 530, rheological sensor 535, and electronic temperature controller 540. These components may communicate wirelessly through a hard-wired connection or a combination thereof. Memory 525 of system 500 may include a test temperature determiner 545, a temperature adjuster 550, a temperature verifier 555, a test initiator 560, and an end of test determiner 565. The temperature regulator 550 includes a pulse width modulator 570 and a polarity changer 575.

The processor 515 may include intelligent hardware devices (e.g., general processor, Digital Signal Processor (DSP), Central Processing Unit (CPU), microcontroller, Application Specific Integrated Circuit (ASIC), Field Programmable Gate Array (FPGA), programmable logic device, discrete gate or transistor logic, discrete hardware components, or any combination thereof. in some cases, the processor 515 may be configured to operate a memory array using a memory controller. in other cases, a memory controller may be integrated into the processor 515. the processor 515 may be configured to execute computer readable instructions stored in memory to perform various functions. in some embodiments, the processor 515 may be configured to provide instructions to start or stop to a device, such as one or more pumps 200 described in FIG. 9.

I/O controller 520 may represent or interact with a modem, keyboard, mouse, touch screen, or similar device. In some cases, I/O controller 520 may be referred to as part of the processor. In some cases, a user may interact with the system via the I/O controller 520 or via hardware components controlled by the I/O controller 520. I/O controller 520 may communicate with any suitable input and any suitable output.

Memory 525 may include Random Access Memory (RAM) and Read Only Memory (ROM). The memory 525 may store computer-readable, computer-executable software comprising instructions that, when executed, cause the processor to perform various functions described herein. In some cases, memory 525 may contain a basic input/output system (BIOS), or the like, that may control basic hardware and/or software operations, such as interaction with peripheral components or devices.

Test temperature determiner 545 represents program instructions that cause processor 515 to determine the temperature at which a test is to be performed. In some examples, the test temperature is determined by accessing information entered into the user interface 526 by a user.

The temperature regulator 550 represents program instructions that cause the processor 515 to regulate the temperature of the drilling fluid sample 230. Part of the process of adjusting the temperature may include determining the current temperature of the drilling fluid sample and determining whether the desired temperature for the next test is above or below the current temperature of the drilling fluid sample 230. Based on whether the temperature of drilling fluid sample 230 is increasing or decreasing, polarity changer 535 may cause processor 515 to send instructions to polarity switch 530 to direct current in the appropriate direction through thermoelectric material 256. Pulse width modulator 570 may send instructions to electronic temperature controller 540 to adjust the intensity of current flowing through thermoelectric material 256. When the temperature of the drilling fluid sample is actively changed, the pulse width modulator 570 may cause the signal strength to be greater than when the signal strength is intended to only maintain the drilling fluid sample 230 at its current temperature for testing.

The temperature verifier 555 represents program instructions that cause the processor 515 to determine the current temperature of the drilling fluid sample 230. The temperature regulator 550 may reference this information to determine when to change the signal strength from actively changing the temperature of the drilling fluid sample 230 to maintaining the temperature of the drilling fluid sample 230.

The test launcher 560 represents programming instructions that cause the processor 515 to perform a test using the rheological sensor 535. The test initiator 560 may also reference information from the temperature validator 555 to determine if the drilling fluid sample is at an appropriate temperature to perform the test.

End of test determiner 565 represents programming instructions that cause processor 515 to determine when a test is complete. In some examples, end of test determiner 565 sends a signal to thermostat 550 at the end of the test at the first temperature. In response, the temperature regulator 550 may begin the process of changing the temperature of the drilling fluid sample 230 for the next test at a different desired temperature.

Fig. 6 depicts an example of a method 600 for automatically testing a fluid sample at different temperatures according to the present disclosure. In this example, the method 600 includes supplying 605 a drilling fluid sample 230 into a fluid chamber 605, receiving 610 instructions to test the drilling fluid sample 230 at two or more temperatures, bringing 615 the temperature of the drilling fluid sample 230 through the fluid chamber with an electronic temperature controller to a first temperature of the two or more temperatures, testing 620 the drilling fluid sample 230 with a rheological sensor incorporated into the fluid chamber at the first temperature, automatically bringing 625 the temperature of the drilling fluid sample 230 to a second temperature after the testing at the first temperature with the electronic temperature controller is completed, and testing 630 the drilling fluid sample 230 with the rheological sensor at the second temperature. At least some portions of the method may be performed according to principles described in this disclosure.

Fig. 7 depicts an example of components of a fluid testing apparatus 100 having a side loop 800 for controlling fluid temperature for density measurements according to the present disclosure. In the depicted example, the side loop 800 is incorporated into the fluid testing apparatus 100. A second pump 806 and density sensor 216 are incorporated into the side loop 800. The second pump 806 may cause a portion of the drilling fluid sample 230 to enter the side loop 800 from the fluid chamber 218 when the drilling fluid is at a desired temperature for testing the density of the drilling fluid sample 230.

In some examples, the user interface presents the user with the option of testing the rheology of the drilling fluid sample 230, testing the density of the drilling fluid sample 230, or a combination thereof. The user may instruct the fluid testing apparatus 100 to test the drilling fluid sample 230 at the same temperature at which the rheological sensor 220 tests the drilling fluid sample 230. In other examples, the density of the drilling fluid sample 230 may be tested at a different temperature than at least one test performed with the rheological sensor 220. In some cases, the electronic heating controller brings the drilling fluid sample 230 to the temperature of the test performed by the rheological sensor 220, the density sensor 216, another type of sensor incorporated into the fluid chamber 218, or a combination thereof. In the example of fig. 8, the fluid testing apparatus 100 does not include a density sensor 216 according to the present disclosure.

Referring to fig. 9 and 9A, a dual pump automatic fluid measuring device 900 is disclosed. As in the previous embodiments, the drilling fluid sample 930 may be contained within a bottle. In this example, the fluid testing apparatus 900 includes a bottle receiver 906, a first pump 901A, a second pump 901B, a fluid conduit 904, a density sensor 916 connected to the fluid conduit 904, a fluid chamber 918, and a rheology sensor 920 connected to the fluid chamber 918.

In this embodiment, two

pumps

901A and 901B are provided for passing fluid through the attached system, rather than a single pump 200 as depicted in fig. 2. In the embodiment of fig. 9 and 9A, the rheological measurements are made by using a rheological sensor 920. Similar to fig. 2, in one embodiment, the rheological sensor 920 may be a viscometer. The use of two

pumps

901A and 901B allows the drilling fluid to be tested at faster intervals than a single pump unit, and the presence of the pump 901B allows for ensuring that the fluid chamber 918 is not overfilled during a fill cycle. The draining and refilling of the fluid chamber 918 may occur at a faster rate than if the fluid were to be drained using only gravity means. The use of two

pumps

901A and 901B also increases the redundancy of the testing device 900 compared to a single pump unit, thereby allowing greater availability of the unit. In an embodiment, pump 901B may run at a higher speed than pump 901A. In this case, the presence of the pump 901B prevents overfilling of the fluid chamber 918. The pump 901A may be controlled to shut down if the pump 901B encounters fluid that is pumped through the fluid conduit to the fluid chamber 918. In other embodiments, a sensor in the fluid chamber 918 or near the fluid chamber 918 may be used to shut down the pump 901A to prevent overfilling.

The rheological sensor 920 may include a rotor 948 suspended in an opening 942 of the fluid chamber 918. The rotor 948 is in contact with the drilling fluid sample 930 by full or partial submersion. In one embodiment, the rotor 948 has an outer cylinder that rotates over a pendulum (not shown) placed within an inner cylinder. The drilling fluid sample 930 fills the annular space between the rotor 948 and the pendulum. The motor may drive the rotor 948. The motor may be a variable speed motor that may be controlled by user action. By controlling the motor, the rotor 948 rotates at a known speed and creates shear stress on the pendulum as it contacts the drilling fluid sample 930. The torsion spring measures the stress exerted by the fluid on the pendulum. The rheological sensor 920 may run tests at different rotor speeds (revolutions per minute or RPM). In some cases, the tests were performed at 600, 300, 200, 100, 6, and 3 RPM. Other rotor speed values may be used. When the drilling fluid is particularly gel-like, in conventional devices, it is not possible for the pendulum to rotate at such a value within the drilling fluid sample 930. To this end, the test apparatus 900 is provided with a powerful motor that allows the pendulum, which is subjected to high shear stresses, to rotate.

As depicted in fig. 5, an electronic temperature controller provided in the electrical system 500 is used to heat or cool the fluid chamber 918 containing the drilling fluid sample 930. Any type of electronic temperature controller 540 may be used in accordance with the principles described in this disclosure. In some examples, electronic temperature controller 540 includes thermoelectric material 956 that generates an electrical current in response to a temperature difference. In this embodiment, the thermoelectric material 956 has a first side 958 in contact with an outer surface 938 of the fluid chamber 918. In some embodiments, the thermoelectric material 956 can include a second side 960 opposite the first side 958 and in contact with the heat sink 968.

In some embodiments, the thermoelectric material 956 is part of an electrical circuit used to heat or cool the drilling fluid sample 930. An electric current is passed through the thermoelectric material 956 to simultaneously create a heated region 962 and a cooled region 964 within the thermoelectric material 956. In some embodiments, a polarity switch located in electrical system 500 may be installed within the circuit to change the direction of current through thermoelectric material 956. When current is passed through thermoelectric material 956 in a first direction, a heated region 962 is created. The heating region 962 is located adjacent to the fluid chamber 918. At the same time, a cooling region 964 is also created adjacent to the heat sink 968. While the heating zone 962 is actively created adjacent to the fluid chamber 918, the electronic temperature controller 540 actively maintains the fluid chamber 918 at a specified temperature. In some embodiments, when the heating zone 962 is created adjacent to the fluid chamber 918, the temperature of the fluid chamber is raised to a higher temperature, or the temperature of the fluid chamber may be maintained at a desired temperature for performing the test on the drilling fluid sample 930. With current passing through the thermoelectric material 956 in a second direction opposite the first direction, a heated region 962 is created adjacent the fluid chamber 918, and the heated region 962 is created adjacent the heat sink 968. With the cooled region 964 created adjacent to the fluid chamber 918, the drilling fluid sample temperature is reduced to a cooler temperature. In other embodiments, the drilling fluid sample temperature may be maintained at a desired temperature.

In one or more embodiments, the pulse width modulator 570, as provided in the electrical system 500, may be used to control the temperature of the heating and

cooling zones

962, 964. The pulse width modulator 570 can switch the current on and off at a frequency to produce an average current in the thermoelectric material 956. In an exemplary embodiment, the longer the pulse width modulator 570 passes current through the thermoelectric material 956, the higher the total electrical power supplied to the thermoelectric material 956 as compared to the time period when current ceases to flow. This higher overall power supply results in higher temperatures in the heating zone 962 and lower temperatures in the cooling zone 964. The temperature difference between the heating region 962 and the cooling region 964 may be reduced by increasing the period of time that the current stops flowing through the thermoelectric material 956. The pulse width modulator 570 may cause the thermoelectric material 956 to adjustably heat or cool the fluid chamber 918 to a desired temperature for each test to be performed using the fluid chamber 918.

As with some embodiments described above, the fluid chamber 918 may be made of a thermally conductive material that can dissipate the temperature generated by the first side 958 of the thermoelectric material 956. In one embodiment, the fluid chamber 918 is made of aluminum. As will be appreciated, the fluid chamber 918 may be made of other types of thermally conductive materials. A non-exhaustive list of thermally conductive materials that may be used to fabricate the fluid chamber 918 includes aluminum, copper, gold, magnesium, beryllium, tungsten, titanium, other metals, mixtures thereof, alloys thereof, or combinations thereof. In some embodiments, the fluid chamber 918 is constructed of a material having a substantially uniform thermal conductivity. In some exemplary embodiments, the inner surface of the chamber wall 936 is lined with a material having a different thermal conductivity than the other materials that make up different portions of the fluid chamber 918.

An outer surface 938 is disposed over the fluid chamber 918 adjacent the thermoelectric material 956. The contact surface 940 is located on a portion of the outer surface 938. Contact surface 940 may include a smooth surface roughness in thermal contact with thermoelectric material 956. In some embodiments, the contact surface 940 comprises a polished surface. In other embodiments, the contact surface 940 includes a smoother finish than other portions of the outer surface 938 of the fluid chamber 918. Where a smooth finish of the contact surface 940 is used, the smooth finish may reduce the gap between the thermoelectric material 956 and the outer surface 938 of the fluid chamber 918. If there is a gap between the contact surface 940 and the thermoelectric material 956, a thermally conductive paste may be used to fill the gap.

An outer surface 938 of the fluid chamber 918 may be partially surrounded by an insulating layer 944. The insulating layer 944 may minimize environmental conditions that would otherwise heat or cool the fluid chamber 918.

The fluid chamber 918 may include at least one fluid thermometer 950 that measures the temperature of the drilling fluid sample 930. The fluid chamber 918 may also include at least one equipment thermometer 952 that may measure a temperature of at least one piece of equipment associated with the drilling fluid sample 930. For example, the device thermometer 952 may measure the temperature of the material forming the fluid chamber 918. Temperature measurements of the fluid chamber material may prevent overheating of the fluid chamber 918. Data from the at least one device thermometer 952 and the at least one fluid thermometer 950 may be monitored by circuitry configured to receive such data inputs. In one embodiment, when the level 932 is at an appropriate height, the level detection sensor may signal the pump 901B to stop pumping the drilling fluid sample 930.

The heat sink 968 may include fins 970 to increase the surface area of the heat sink 968. The fins may be located on the inner portion 970A and the outer portion 970B. The heat sink 970 may be used to exchange temperature with a fluid medium, such as air or a liquid. In instances where the heating region 962 is produced on the second side 960, heat generated by the heating region 962 may be dispersed throughout the heat sink 968 and transferred to the fluid medium by the heat sink 970. In some exemplary embodiments, a fan 972A is positioned adjacent the heat sink 968 to flow air over the fins 970 to increase the rate at which heat is dissipated to the air. A second fan 972B may also be used to provide cooling within the housing containing the fluid measurement device 900. The presence of the second fan provides greater cooling for configurations using one fan. As will be appreciated, the presence of such a fan may limit heat build-up within the fluid measurement device 900, thereby providing a more robust ability to withstand temperature variations.

In other examples, water or other types of liquids may pass through the fins 970 to provide additional cooling capacity. In this example, the liquid medium does not contact the fluid chamber 918, but rather contacts the fins 970 of the heat sink 968. The liquid medium may be, for example, water or a glycol solution.

In the embodiment of fig. 9, two

pumps

901A and 901B are used to transport fluids within the drilling fluid analyzer. In the disclosed embodiment, the pump may be a peristaltic pump. A pump 901A is connected to a sample bottle 908, to the filter 902 via a first line portion 910 and to a density sensor 916 via a second line portion 912. The second pump 901B is connected to the sample bottle 908 and the fluid chamber 918 via a line 929. The second pump 901B is also connected to the fluid chamber 918 by a line 931, where the flow direction 922 is indicated. The density sensor 916 is then connected to the fluid chamber 918 through the third portion 914. The use of two

pumps

901A and 901B allows for the sampling of more gel-like solutions that previously could not be sampled and analyzed by a conventional analyzer. Unlike other disclosed embodiments, the first pump 901A is positioned proximate to the sample vial 908 and the density sensor 916, allowing a density reading of the fluid sample to be obtained. The density sensor 916 is in turn connected to the fluid chamber 918 through a third portion 914. The first pump 901A may provide the motive force for moving the fluid sample from the sample bottle 908. The level of fluid within the fluid chamber 918 is measured by a first level detector 926A. A second liquid level detector 926B is located in the line from the second pump 901B to the fluid chamber 918. The density sensor 916 in FIG. 9 may be a Rheonik Model RHM 04. At the end of the test, the fluid may be returned to the bottle for storage. The data obtained during the test may be transmitted to a computer via a wired or wireless connection for viewing by an engineer. In an embodiment, the data may be provided via the WITS protocol or provided by geoservices (schlumberger company) to the GN5 data acquisition system. As will be appreciated, the wired connection may be ethernet communication enabled.

In other embodiments, a warning of an overfill condition or degraded component of the fluid measurement device 900 can be provided wirelessly or through a wired connection to allow an engineer to monitor ongoing assessments. In the embodiment shown in fig. 1 and 9, a memory in the provided electrical system 500 may non-volatile store data from the tests performed.

Referring to fig. 10, an example of a method 1000 for automatically testing a fluid sample at different temperatures is disclosed in accordance with the present disclosure. In this example, the method 1000 includes supplying 1010 a drilling fluid sample into the fluid chamber by the action of two pumps. In this supply 1010, a first pump 901A may supply fluid to the fluid chamber 918, and a second pump 901B may remove excess fluid sample to prevent it from accumulating within the fluid chamber 918. This ensures that an appropriate amount of fluid enters the fluid chamber 918 for testing. At 1020, the method continues with receiving instructions to test the drilling fluid sample at two or more temperatures. At 1030, the method continues with increasing or decreasing the temperature of the drilling fluid sample to a first temperature of the two or more temperatures through the fluid chamber. The raising or lowering may be performed by a circuit. The method continues at 1040 with testing the drilling fluid sample at a first temperature with a rheological sensor 535 incorporated into the fluid chamber. The method continues at 1050, after the test at the first temperature is completed, automatically bringing the temperature of the drilling fluid sample to a second temperature. The method continues at 1060 where the drilling fluid sample is tested with the rheological sensor 535 at a second temperature. At least some portions of the method may be performed according to principles described in this disclosure.

Although the fluid testing apparatus has been described above as having a bottle receiver for connecting to a bottle containing a drilling fluid sample, in some examples, the bottle receiver is not included in the fluid testing apparatus. For example, a user may pour a drilling fluid sample into a tank incorporated into a fluid testing apparatus. In some examples, where a drilling fluid sample is incorporated into the fluid testing apparatus, a filter may be incorporated into the outlet of the tank to filter out sand, debris, other types of solids, or combinations thereof. In some cases, a user may pour a sample of drilling fluid directly into a fluid chamber connected to a viscometer or other rheological sensor. As will be appreciated, the

field test apparatus

100, 900 may be mobile so that a user may bring the

apparatus

100, 900 to different field locations. In an embodiment, a battery pack may be provided to provide the current required to operate the

device

100, 900. In other embodiments, the housing 102 may have wires for plugging the

apparatus

100, 900 into the electrical system of a drilling rig.

In the described embodiments, the automatic analysis of the drilling fluid may be performed over a long period of time. In some embodiments, the analyzer may perform the analysis of the drilling fluid between 2 and 6 days without cleaning. Cleaning of the interior of the analyzer can be accomplished without passing the demineralizing aqueous solution through the analyzer. In a sample cleaning routine, fluid within the analyzer may be heated to a specified value to allow for evacuation and cleaning of the analyzer components. As will be appreciated, in the embodiment provided in fig. 9, either of the

pumps

901A or 901B may be used to power the fluid within the

apparatus

100, 900. In one embodiment, a single pump (pump 901A or 901B) may be used to drive the drilling fluid in the first direction. After the first pump run cycle, the alternative pump 901B may be used to drive the drilling fluid in a second direction, where the second direction is opposite the first direction. The alternative pump 901B may then run a second pump run cycle.

In the described embodiment, the use of a heat sink and multiple fans can increase or decrease the temperature by 30 degrees celsius over a time frame of five (5) minutes.

The foregoing description, for purpose of explanation, has been described with reference to specific embodiments. However, the illustrative discussions above are not intended to be exhaustive or to limit the disclosure to the precise forms disclosed. Many modifications and variations are possible in light of the above teaching. The embodiments were chosen and described in order to best explain the principles of the present systems and methods and their practical applications, to thereby enable others skilled in the art to best utilize the present systems and methods and various embodiments with various modifications as may be suited to the particular use contemplated.

Claims

1. A test apparatus, comprising:

a fluid collection vessel configured to contain a drilling fluid;

a first fluid conduit connected to the fluid collection volume;

a second fluid conduit connected to the fluid collection volume;

a fluid chamber configured to receive drilling fluid from the first and second fluid conduits;

a first pump configured to move the drilling fluid from the fluid collection volume to the fluid chamber, the first pump connected to the first fluid conduit;

a second pump configured to move the drilling fluid from a bottle to the fluid chamber, the second pump connected to the second fluid conduit;

a rheological sensor in communication with the fluid chamber;

a user interface configured to accept user-defined data; and

an electrical system connected to the user interface and configured to process the user-defined data,

wherein the testing apparatus is configured to receive user data regarding a test to be performed by the testing apparatus and to control the first pump, the second pump and the rheological sensor to automatically test the drilling fluid according to the user-defined data.

2. The test apparatus of claim 1, further comprising:

an electrical circuit configured to at least one of heat and cool the drilling fluid within the fluid chamber, and wherein the electrical system further comprises an electronic temperature controller configured to generate a control signal to control the electrical circuit.

3. The testing device of claim 2, wherein the electrical circuit is configured to heat and cool the fluid chamber containing a fluid sample.

4. The test apparatus of claim 2, wherein the circuit further comprises:

a thermoelectric material disposed on an outer surface of the fluid chamber.

5. The test apparatus of claim 4, wherein the thermoelectric material is configured to produce a heating region and a cooling region on opposite sides of the thermoelectric material.

6. The test apparatus of claim 1, further comprising:

at least one thermometer connected to the electrical system and configured to obtain a fluid temperature within the fluid chamber.

7. The test apparatus of claim 1, further comprising:

a filter positioned within the fluid collection volume, wherein at least one of the first fluid conduit and the second fluid conduit is connected to the filter.

8. The test apparatus of claim 1, further comprising:

at least one level detector connected to the fluid chamber and configured to measure a level of fluid within the fluid chamber when fluid is present.

9. The test apparatus of claim 1, wherein the user interface is a capacitive screen.

10. The test apparatus of claim 1, further comprising:

a housing configured to house the first fluid conduit, the second fluid conduit, the fluid chamber, the first pump, the second pump, the rheological sensor, the electrical system, and the user interface.

11. The test apparatus of claim 10, further comprising:

at least two fans configured to move air through the enclosure.

12. The test apparatus of claim 1, wherein the rheological sensor is a viscometer.

13. A method of automatically testing a fluid sample, comprising:

supplying a drilling fluid sample into the fluid chamber by action of at least two pumps;

receiving instructions to test the drilling fluid sample at least two temperatures;

automatically adjusting the temperature of the drilling fluid sample to a first temperature of the at least two temperatures;

testing the fluid sample at the first temperature;

automatically adjusting the temperature of the drilling fluid sample to a second temperature of the at least two temperatures; and

testing the fluid sample at the second temperature.

14. The method of claim 13, wherein the testing of the fluid sample is performed with a rheological sensor.

15. The method of claim 14, wherein the rheological sensor is a viscometer.

16. The method of claim 13, wherein the drilling fluid sample is provided directly from a drilling operation.

17. A test apparatus, comprising:

a fluid collection vessel configured to contain a drilling fluid;

a first fluid conduit connected to the fluid collection volume;

a second fluid conduit connected to the fluid collection volume;

a fluid chamber configured to receive drilling fluid from the fluid conduit;

a first pump configured to move the drilling fluid from a bottle to the fluid chamber;

a second pump configured to move the drilling fluid from the bottle to the fluid chamber;

a rheological sensor in communication with the fluid chamber;

a user interface configured to accept user-defined data;

an electrical system connected to the user interface and processing the user-defined data, wherein the testing device is configured to receive user data and control the first pump, the second pump, and the rheological sensor to automatically test the drilling fluid according to the user-defined data, the electrical system further configured with a memory to store and transmit data relating to parameters of a test fluid;

at least two fans configured to move a volume of air;

at least one equipment thermometer connected to at least one of the rheological sensor, the first pump, and the second pump; and

a housing configured to house the first pump, the second pump, the rheological sensor, the user interface, the electrical system, the at least one equipment thermometer, and the at least two fans.

18. The test apparatus of claim 17, wherein the rheological sensor is a viscometer.

19. The test apparatus of claim 18, wherein the fluid chamber is a component of the viscometer.

20. The test device of claim 17, wherein the electrical system is configured with a processor configured to perform processing of the user-defined data and a non-volatile memory configured to store data obtained from the processor and the user interface.