Drilling system and method

Abstract

Drilling system and method. A drilling system for drilling an unfinished well. The drilling system includes an operable drilling fluid pump to circulate fluid through the unfinished well and a fluid analysis system to analyze fluid returned from the unfinished well. The fluid analysis system includes a sensor system, a recirculation system, and a control system in electronic communication with the drilling fluid pump and the recirculation system. The sensor system is operable to measure one or more properties of the returned fluid. The recirculation system includes a controllable pump and valves and is operable to control the flow of returned fluid through the fluid analysis system.

Description

/ 22 DRILLING SYSTEM AND METHOD FUNDAMENTALS

[001] This section is intended to provide relevant background information to facilitate a better understanding of the various aspects of the modalities described. Therefore, these statements should be read in this light, and not as admissions of prior art.

[002] In the oil and gas industry, many different types of fluids are circulated in a well and subsequently returned to the surface. Such fluids, often referred to as “return fluid,” may include, but are not limited to, drilling fluid, completion fluids, fracturing fluids, stimulation fluids, detection fluids, well treatment fluids, etc. Fluid returns are frequently analyzed by well operators in order to determine various unfinished well parameters.

[003] For example, while a well is being drilled, various measurements can be obtained from fluid returns of a drilling fluid. For example, these measurements provide a run profile or record of the drilling operation, which allows a well operator to analyze the earth formations that are being progressively penetrated by the drill bit. The run profile generated from the measurements can be particularly important because it can allow the well operator to verify the presence of oil, gas, and / or other formation fluids in the formations being penetrated. For example, it is possible to compare the methane ratios with each of the various other hydrocarbon gases present in the fluid return, such as ethane, propane, butane, and pentane, to estimate whether a well will be productive and, if so, whether the well will produce oil, gas, or water.Furthermore, the execution profile can be advantageous in providing ratios for total gas content to oil content, water content, location relative to the formation, deposition environment, and aid. Petition 870260030053, dated 03 / 31 / 2026, page 11 / 80 / 22 additional on drilling optimization.

[004] In order to measure the type and quantity of a fluid found in the particular formation being drilled, the drilling fluid returning to the surface can be continuously or discretely sampled and introduced into the fluid analysis system. However, the drilling fluid is not returned to the surface and sampled when a new drill pipe is being added to the drill string. This pause in the flow of drilling fluid returned to the fluid analysis system can lead to inaccurate results from the fluid analysis system because the gas within the fluid is not being adequately extracted. BRIEF DESCRIPTION OF THE DRAWINGS

[005] Fluid analysis system embodiments are described with reference to the following figures. The same numbers are used in all figures to refer to similar features and components. The features represented in the figures are not necessarily shown to scale. Certain features of the embodiments may be shown exaggerated to scale or in a somewhat schematic way, and some element details may not be shown in the interest of clarity and conciseness.

[006] FIG. 1 is a schematic view of a drilling system according to one or more modalities; FIG. 2 is a schematic diagram of a fluid analysis system in normal mode, according to one or more modalities; FIG. 3 is a schematic diagram of the fluid analysis system of FIG. 2 in recirculation mode; FIG. 4 is a block diagram of a computer system, according to one or more modalities; and FIG. 5 is a flowchart of a method for drilling a well according to one or more modalities; and FIG. 6 is a flowchart of a method for drilling a Petition 870260030053, dated 03 / 31 / 2026, page 12 / 80 / 22 well in accordance with one or more modalities. DETAILED DESCRIPTION

[007] This disclosure describes a drilling system with a fluid analysis system. The fluid analysis system includes sensors, a thermal energy device, a degassing system, and a recirculation system. The fluid analysis system operates in a normal mode while fluid is flowing up the well and operates in a recirculation mode when fluid flow is paused, such as when a new drill pipe is added to the drill string.

[008] When operating in normal mode, the fluid analysis system analyzes the returned fluid from the well, gas is removed from the analyzed fluid, and the analyzed fluid is transferred to a storage tank. Occasionally, the drilling system pauses operation, such as when an additional drill pipe must be added to the drill string, causing the flow of returned drilling fluid to stop. When fluid flow is interrupted, the fluid analysis system can switch to recirculation operation. When operating in recirculation mode, the fluid within the fluid analysis system is circulated through the fluid analysis system instead of being transferred to the tank. Recirculation allows the sensors to continue operating instead of pausing operation until fluid flow through the drilling system is restored.Allowing continuous operation of the sensors increases sensor accuracy, since the sensors do not need to re-establish themselves after the flow through the fluid sensor system is restored following a pause.

[009] By way of definition, a main well may, in some cases, be formed in a substantially vertical orientation relative to a wellbore surface, and a side well may, in some cases, be formed in a substantially horizontal orientation relative to the wellbore surface. However, reference in this document to the main well or side well will be made to the same person. Petition 870260030053, dated 03 / 31 / 2026, page 13 / 80 / 22. The lateral orientation is not intended to imply any specific orientation, and the orientation of each of these wells may include vertical, non-vertical, horizontal, or non-horizontal portions. Furthermore, the term "well top" refers to a direction that is toward the well surface, while the term "well bottom" refers to a direction that is away from the well surface.

[0010] FIG. 1 is a schematic view of a drilling system 100 according to one or more embodiments. The drilling system 100 includes a drilling platform 102 supporting a tower 104 having a kelly 106 for raising and lowering a drill string 108. The drill string 108 may include, but is not limited to, drill pipe and spiral tubing, as is generally known to those skilled in the art. A kelly 110 supports the drill string 108 as it is lowered through a rotary table 112. A drill bit 114 is attached to the distal end of the drill string 108 and is driven by a wellbore motor and / or by means of the rotation of the drill string 108 from the wellbore surface. As the drill bit 114 rotates, it creates a wellbore 116 that penetrates various subsurface formations 118.

[0011] It should be noted that although FIG. 1 generally represents a land-based drilling system 100, those skilled in the art will readily recognize that the principles described in this document are equally applicable to subsea drilling operations employing floating or sea-based platforms and rigs without departing from the scope of disclosure. The principles may also be applicable to other forms of drilling including, but not limited to, double gradient drilling, managed pressure drilling and unbalanced drilling to the lesser.

[0012] A drilling fluid pump 120 (e.g., a mud pump) circulates a fluid 122 through a feed pipe 124 and into the drill string 108. In some embodiments, the Petition 870260030053, dated 31 / 03 / 2026, p. 14 / 80 / 22 Fluid 122 may be a drilling fluid used in the drilling system 100 described herein. However, it should be noted that the principles of this disclosure are equally applicable to any type of fluid return or sampled fluid derived from a well. Therefore, the use of “fluid 122” is intended to encompass, without limitation, any other type of fluid that may be circulated through a well, produced at the surface on or near the platform 102, or sampled at the bottom of the well and subsequently supplied to the fluid analysis system 142. For example, “fluid 122” may equally apply to reservoir fluids, gases, oils, water, and any other fluid that may be produced from an unfinished well.Furthermore, the 100 drilling system can also be substituted for, or otherwise equated to, any well fluid analysis system, such as a wellhead installation used to produce fluids for the surface.

[0013] In the drilling system 100, fluid 122 can be transported through the drill string 108 to the drill bit 114 and out of at least one hole in the drill bit 114. The fluid 122 is then recirculated back to the surface through an annular space 126 defined between the drill string 108 and the walls of the unfinished well 116. At the surface, the recirculated or spent fluid 122 exits the annular space 126 and can be transported to one or more fluid processing units 128 by means of a fluid return line 130. After passing through the fluid processing unit(s) 128, a “clean” fluid 122 is deposited in a nearby holding well 132 (i.e., a mud well). One or more chemicals, fluids or additives may be added to fluid 122 by means of a mixing funnel 134 coupled in a communicating manner to, or otherwise in fluid communication with, the retention well 132.

[0014] The 100 drilling system may also include a Petition 870260030053, dated 31 / 03 / 2026, page 15 / 80 / 22 downhole assembly (BHA) 136 disposed in the drill string 108 at or near the drill bit 114. The BHA 136 may include any of a series of sensor modules 138 (one shown) which may include formation evaluation sensors and directional sensors, such as measurement tools during drilling and / or logging during drilling. The BHA 136 may also contain a telemetry system 140 that induces pressure oscillations in the fluid flow. Data from the downhole sensor modules 138 are encoded and transmitted to the surface via the telemetry system 140 whose pressure oscillations, or “pulses”, propagate to the surface through the fluid flow column in the drill string 108.On the surface, pulses are detected by one or more surface sensors (not shown), such as a pressure transducer, a flow transducer, or a combination of a pressure transducer and a flow transducer.

[0015] During drilling operations, a discrete or continuous sample of the fluid 122 returning to the surface (i.e., fluid returns) can be obtained and transported to a fluid analysis system 142 located on or near the drilling platform 102. The sample can be transported to the fluid analysis system 142 via a suction tube 144 fluidically coupled to a source of the fluid 122 returning to the surface. In some embodiments, for example, the suction tube 144 can be fluidically coupled to the fluid return line 130. In other embodiments, however, the suction tube 144 can be directly coupled to the annular space 126 so that a sample of the fluid 122 can be obtained directly from the well at or near the well surface.For example, the fluid analysis system 142 may alternatively be disposed within the fluid return line 130 before the fluid processing unit(s) 128 and the suction tube 144 may be omitted. Alternatively, the suction tube 144 may be coupled to the rotating tank in the slurry tanks or... Petition 870260030053, dated 31 / 03 / 2026, p. 16 / 80 / 22 a collection box associated with fluid processing unit(s) 128, without departing from the scope of disclosure.

[0016] Now returning to FIGS. 2 and 3, FIGS. 2 and 3 are schematic diagrams of a fluid analysis system 242 operating in normal mode and recirculation mode, respectively, according to one or more modalities. As shown in FIG. 2, the fluid analysis system 242 receives a fluid sample 200 extracted from a source of unfinished well fluid, as generally described above. The fluid sample 200 can be any type of well fluid including, but not limited to, a completion fluid, a hydraulic fracturing fluid, a well treatment fluid, a reservoir fluid, a gas, oil, water, and any combination thereof. The fluid sample 200 can alternatively be derived from production fluids being withdrawn from the unfinished well.

[0017] The fluid analysis system 242 includes a sensor system 202, thermal power devices 204, a degassing system 206, a storage tank 208, a control system 210, and a recirculation system 212. The recirculation system 212 includes a pumping system 214, an inlet valve 216, and an outlet valve 218. The inlet valve 216 and the outlet valve 218 are in electronic communication with the control system to control the fluid flow through the fluid analysis system 242, as described in more detail below. The inlet valve 216 and the outlet valve 218 shown in FIGS. 2 and 3 are three-way valves; however, two two-way valves (not shown) may be used in place of the three-way valves. Furthermore, although two thermal energy devices 204 are shown in FIGS. 2 and 3, other embodiments may include none, one, three, or more thermal energy devices 204.In addition, there is additional equipment such as valves (not shown), storage tanks (not shown). Petition 870260030053, dated 31 / 03 / 2026, page 17 / 80 / 22 pumping systems (not shown) or sensor systems (not shown) may be included in fluid analysis system 242 to perform additional functions, receive fluid from additional sources and / or further control the flow of fluid through fluid analysis system 242.

[0018] In addition to the inlet valve 216 and the outlet valve 218, the control system 210 is in electronic communication with a pump circulating fluid for a drill string, such as the drilling fluid pump 120 described above with reference to FIG. 1. The control system 210 monitors one or more properties of the drilling fluid pump to determine if they are above the threshold(s) indicative of sufficient fluid flow so that a fluid sample can be taken from the returned fluid. The control system 210 can monitor the drilling fluid pump 120 directly or indirectly by receiving information from another control system (not shown) or device in electronic communication with the drilling fluid pump 120 and the control system 210.The property or properties being monitored include, but are not limited to, the flow rate produced by the drilling fluid pump and / or the RPM of the drilling fluid pump. In addition to or instead of monitoring the drilling fluid pump, the 210 control system may also monitor other pieces of drilling equipment or monitor the flow rate of circulating fluid at one or more locations within the drilling system.

[0019] While the drilling fluid pump property is above a predetermined threshold (e.g., 50 gpm or 10 RPM), indicating that there is sufficient returned fluid to take a fluid sample 200, the fluid analysis system 242 operates in normal mode, as shown in FIG. 2. When the drilling fluid pump property falls below the predetermined threshold, there would not be sufficient returned fluid to take a fluid sample 200 and the control system 210 Petition 870260030053, dated 03 / 31 / 2026, page 18 / 80 / 22, transitions to operate in recirculation mode. To do this, control system 210 actuates inlet valve 216 and outlet valve 218 to receive fluid from a different valve inlet, as shown in FIG. 3. This can occur when a new pipe is added to the drill string or when fluid flow is paused, thus resulting in the monitored property falling below the threshold. When the drilling fluid pump property returns above the predetermined threshold, control system 210 transitions the fluid analysis system back to normal mode by actuating inlet valve 216 and outlet valve 218 to accept fluid from the previous valve inlet, as shown in FIG. 2.

[0020] In addition to actuating inlet valve 216 and outlet valve 218, control system 210 may generate an indication, such as, but not limited to, an audible alarm, a message on a display, electronic communication such as a text message or email, or any combination thereof, to alert an operator when the fluid analysis system transitions between normal mode and recirculation mode, the property falls below a predetermined threshold, and / or the drilling fluid pump property rises above a predetermined threshold. In other embodiments, control system 210 may not actuate inlet valve 216 and / or outlet valve 218. Instead, the indication generated by control system 210 may alert the operator that inlet valve 216 and outlet valve 218 need to be actuated to transition from one operating mode to the other.

[0021] When operating in normal mode, as shown in FIG. 2, fluid sample 200 is continuously withdrawn from a drilling system, as described above with reference to FIG. 1. Sample pumping system 214 receives fluid sample 200 and pumps fluid sample 200 through the fluid analysis system at a constant flow rate, for example, a constant mass flow rate or a constant flow rate. Petition 870260030053, dated 03 / 31 / 2026, page 19 / 80 / 22 volumetric constant. The fluid sample 200 is pumped through the sensor system 202, which includes sensors that measure the fluid flow rate, fluid temperature, fluid density, and / or other fluid properties appropriate for analyzing the drilling fluid. For example, the sensor system 202 includes a Coriolis-type flow meter. Alternatively, the sensor system 202 includes other types of sensors, in addition to or in place of the Coriolis-type flow meter, to measure the properties of the fluid flowing through it.

[0022] The fluid sample 200 then flows through the thermal energy devices 204. The thermal energy devices 204 impart a known quantity of thermal energy (i.e., heat) to the fluid sample 200. For example, the thermal energy devices 204 may be heaters, such as resistance coil heaters or heat exchangers, which raise the temperature of the fluid sample 200 to a predetermined gas extraction temperature. The predetermined gas extraction temperature, for example, may be any temperature that does not exceed a critical temperature threshold in the fluid sample 200, after which the fluid sample 200 may begin to break down and begin to form scale or dehydrate bentonite. In some fluid samples 200, for example, the critical temperature threshold may be at or around 90 °C.Alternatively, thermal energy devices 204 can be cooling devices, such as heat exchangers, evaporation units or refrigeration units. Cooling devices may be required, for example, in applications where the fluid 122 (FIG. 1) is returned to the surface at high temperatures, such as above 100 °C.

[0023] After passing through the thermal energy devices 204, the fluid sample enters the degassing system 206. The degassing system 206 extracts gases from the fluid sample 200 and analyzes the Petition 870260030053, dated 03 / 31 / 2026, page 20 / 80 / 22 chemical composition of the extracted gases. Alternatively, the gases are extracted by the degassing system 206 and transported to a different location for analysis. The degassing system 206 can operate using the flow energy of the incoming sample fluid to generate increased fluid velocities that help intensify the separation process. The degassing system 206 can also be configured to extract gases from the sample fluid based on a density and / or viscosity differential between the various fluidic components of the sample fluid. Once the gases have been extracted from fluid sample 200, fluid sample 200 can be drained out of outlet valve 218 and into a storage tank 208. Alternatively, fluid sample 200 can be drained into a holding well, such as the holding well 132 described above, or similar fluid storage areas.

[0024] FIG. 3 shows the fluid analysis system 242 transitioning to recirculation mode where the inlet valve 216 and outlet valve 218 are actuated so that fluid is no longer received from the drilling system and fluid from the degassing system 206 flows back to the pumping system 214 through the inlet valve 216, instead of to the storage tank 208. The recirculation mode allows fluid to continue flowing through the fluid analysis system 242 at a constant flow rate, even when fluid is not being sampled from the drilling system. Maintaining a constant flow rate through the fluid analysis system 242 allows the sensors (not shown) of the sensor system 202 to continue operating normally when fluid samples 200 are not being taken.Continuous operation of the sensors increases sensor accuracy, specifically when fluid sampling is resumed, since the sensors do not need to re-establish themselves, as they would during a pause and resumption of fluid flow through the fluid analysis system 242. Petition 870260030053, dated 31 / 03 / 2026, page 21 / 80 / 22

[0025] In one or more embodiments, the control system 210 may also be in electronic communication with the thermal power devices 204 and / or the degassing system 206. If so, when the fluid analysis system 242 is operating in recirculation mode, the control system 210 may adjust or pause the operation of the thermal power devices 204 and / or the degassing system 206 until the fluid analysis system 242 transitions back to normal mode, once the gases have been extracted from the fluid circulating through the fluid analysis system 242.

[0026] Returning now to FIG. 4, FIG. 4 is a computer system 400, according to one or more embodiments. The computer system 400 or a similar computer system may be used by the fluid analysis control system, such as the control system 210 described above, in controlling the operating mode of the fluid analysis system. In addition, the computer system 400 or a similar computer system may be used by a control system to control drilling operations. The computer system includes at least one processor 402, a non-transient computer-readable storage 404, a network communication module / transceiver 406, optional input / output devices 408 and an optional display 410 all interconnected via a system bus 412.The software instructions executable by processor 402 to implement software instructions stored in computer system 400 according to the illustrative embodiments described herein may be stored in storage 404 or in some other non-transient computer-readable medium.

[0027] Although not explicitly shown in FIG. 4, it will be recognized that the 400 computer system can be connected to one or more public and / or private networks by means of appropriate network connections. It will also be recognized that software instructions can also be Petition 870260030053, dated 03 / 31 / 2026, page 22 / 80 / 22 loaded into storage 404 from a CD-ROM or other appropriate storage media by wired or wireless means.

[0028] Returning now to FIG. 5, FIG. 5 is a flowchart of a method for drilling a well. The method can be performed by a computer system, such as the computer system 400 described above. The illustrated method allows an operator to determine a fluid analysis system, such as the fluid analysis system 242 described above with reference to FIGS. 2 and 3, where the transition from normal mode to recirculation mode must be made.

[0029] In step 500, a drilling system is operated to drill a well, as described above with reference to FIG. 1.

[0030] In step 502, a fluid analysis system is operated in normal mode, as discussed above with reference to FIG. 2. The fluid analysis system takes fluid samples from the fluid returned from the well, measures the fluid properties, heats or cools the fluid, and extracts gases from the fluid. The fluid is then drained into a storage tank.

[0031] In step 504, a property of the drilling fluid pump that circulates fluid through the drill string and wellbore is monitored. The fluid analysis system control system monitors the drilling fluid pump directly or indirectly by receiving information from another control system or device in electronic communication with the drilling fluid pump and the control system.

[0032] In step 506, if the drilling fluid pump property has not fallen below a predetermined threshold, the fluid analysis system continues to operate in normal mode and the fluid analysis control system continues to monitor the drilling fluid pump property. If the drilling fluid pump property has fallen below the predetermined threshold, the fluid analysis control system may optionally generate an indication to an operator that the property of the Petition 870260030053, dated 31 / 03 / 2026, page 23 / 80 / 22: The drilling fluid pump is below the predetermined threshold, as shown in step 508. The indication may be an audible alarm, a message on a display, an electronic communication such as a text message or email, or any combination thereof.

[0033] In step 510, the fluid analysis system is switched to recirculation mode, as discussed above with reference to FIG. 3. The fluid analysis system control system can actuate an inlet valve and an outlet valve to recirculate fluid within the fluid analysis system. In other embodiments, an operator can actuate the inlet valve and / or the outlet valve based on the indication from the fluid analysis system control system.

[0034] Returning now to FIG. 6, FIG. 6 is a flowchart of a method for drilling a well. The method can be performed by a computer system, such as the computer system 400 described above. The illustrated method allows an operator to determine, using a fluid analysis system, such as the fluid analysis system 242 described above with reference to FIGS. 2 and 3, that the transition from recirculation mode to normal mode must be made.

[0035] In step 600, a drilling system is operated to drill a well, as described above with reference to FIG. 1.

[0036] In step 602, a fluid analysis system is operated in recirculation mode, as discussed above with reference to FIG. 3. The fluid within the fluid analysis system is recirculated through the fluid analysis system at a constant flow rate. This allows a sensor system within the fluid analysis system to continue to operate normally while fluid samples are not being collected.

[0037] In step 604, a property of the circulating fluid from the drilling fluid pump through the drill string and wellbore is monitored. The fluid analysis system control system monitors the Petition 870260030053, dated 03 / 31 / 2026, page 24 / 80 / 22 pump directly or indirectly receiving information from another system or control device in electronic communication with the drilling fluid pump and the control system.

[0038] In step 606, if the drilling fluid pump property has not increased above a predetermined threshold, the fluid analysis system continues to operate in recirculation mode and the fluid analysis control system continues to monitor the drilling fluid pump property. If the drilling fluid pump property has increased above the predetermined threshold, the fluid analysis control system may optionally generate an indication to an operator that the drilling fluid pump property is above the predetermined threshold, as shown in step 608. The indication may be an audible alarm, a message on a display, an electronic communication such as a text message or email, or any combination thereof.

[0039] In step 610, the fluid analysis system is switched to normal mode, as discussed above with reference to FIG. 2. The fluid analysis system control system can actuate an inlet valve and an outlet valve to collect fluid samples and flow the fluid samples through the fluid analysis system.

[0040] Additional examples include: Example 1 is a drilling system for drilling an unfinished well. The drilling system includes an operable drilling fluid pump to circulate fluid through the well and a fluid analysis system to analyze fluid returned from the unfinished well. The fluid analysis system includes a sensor system, a recirculation system, and a control system in electronic communication with the drilling fluid pump and the recirculation system. The sensor system is operable to measure one or more properties of the returned fluid. Petition 870260030053, dated 31 / 03 / 2026, p. 25 / 80 / 22 The recirculation system includes a pump and controllable valves and is operable to control the flow of returned fluid through the fluid analysis system. The control system is programmed to operate the fluid analysis system in a normal mode to take fluid samples from the returned fluid and analyze the fluid samples. The control system is further programmed to monitor a property of the drilling fluid pump. The control system is also programmed to determine if the drilling fluid pump property falls below a predetermined threshold indicative of sufficient fluid flow so that fluid samples can be taken from the returned fluid.The control system is also programmed to transition the fluid analysis system from normal mode to a recirculation mode based on the determination to recirculate fluid through the fluid analysis system when the fluid sample cannot be withdrawn due to a reduction in the flow of returned fluid.

[0041] In Example 2, the modalities of any preceding paragraph or combination thereof also include wherein the control system is also programmed to generate an indication based on the determination.

[0042] In Example 3, the embodiments of any preceding paragraph or combination thereof further include wherein the control system is further programmed to determine whether the drilling fluid pump property rises above the predetermined threshold. The control system is also programmed to transition the fluid analysis system from recirculation mode to normal mode based on the determination of the property rising above the predetermined threshold.

[0043] In Example 4, the embodiments of any preceding paragraph or combination thereof also include wherein the control system is further programmed to generate an indication based on the determination of the property rising above the predetermined threshold. Petition 870260030053, dated 31 / 03 / 2026, page 26 / 80 / 22

[0044] In Example 5, the embodiments of any preceding paragraph or combination thereof also include wherein the fluid analysis system further comprises an operable degassing system for extracting gases from the returned fluid.

[0045] In Example 6, the embodiments of any preceding paragraph or combination thereof further include wherein the fluid analysis system also comprises an operable thermal energy device for heating or cooling the returned fluid.

[0046] In Example 7, the embodiments of any preceding paragraph or combination thereof further include wherein the property of the drilling fluid pump includes at least one of a flow rate produced by the drilling fluid pump or an RPM of the drilling fluid pump.

[0047] Example 8 is a method for drilling an unfinished well. The method includes circulating fluid through a well using a drilling fluid pump. The method also includes operating a fluid analysis system in a normal mode to take fluid samples from the returned fluid in the unfinished well and analyzing the fluid samples. The method further includes monitoring a property of the drilling fluid pump. The method also includes determining whether the drilling fluid pump property falls below a predetermined threshold indicative of sufficient fluid flow so that fluid samples can be taken from the returned fluid. The method further includes transitioning the fluid analysis system from normal mode to a recirculation mode based on the determination to recirculate fluid through the fluid analysis system when the fluid sample cannot be taken due to a reduction in returned fluid flow.

[0048] In Example 9, the options in any preceding paragraph or combination thereof also include generating an indication based on Petition 870260030053, dated 03 / 31 / 2026, page 27 / 80 / 22 determination.

[0049] In Example 10, the modalities of any preceding paragraph or combination thereof further include determining whether the drilling fluid pump property rises above the predetermined threshold. The method also includes transitioning the fluid analysis system from recirculation mode to normal mode based on the determination of the property rising above the predetermined threshold.

[0050] In Example 11, the options in any preceding paragraph or combination thereof also include generating an indication based on the determination of the property that rises above the predetermined threshold.

[0051] In Example 12, the embodiments of any preceding paragraph or combination thereof further include operating a thermal energy device to heat or cool the returned fluid. The method also includes operating a degassing system to extract gases from the returned fluid.

[0052] In Example 13, the embodiments of any preceding paragraph or combination thereof further include wherein the property of the drilling fluid pump includes at least one of a flow rate produced by the drilling fluid pump or an RPM of the drilling fluid pump.

[0053] Example 14 is a fluid analysis system for use with a drilling system comprising an operable drilling fluid pump for circulating fluid through an unfinished well. The fluid analysis system includes a sensor system, a recirculation system, and a control system in electronic communication with the drilling fluid pump and the recirculation system. The sensor system is operable to measure one or more properties of the returned fluid. The recirculation system includes a controllable pump and valves and is operable to Petition 870260030053, dated 03 / 31 / 2026, page 28 / 80 / 22 to control the flow of returned fluid through the fluid analysis system. The control system is programmed to operate the fluid analysis system in a normal mode to take fluid samples from the returned fluid and analyze the fluid samples. The control system is also programmed to monitor a property of the drilling fluid pump. The control system is also programmed to determine if the drilling fluid pump property falls below a predetermined threshold indicative of sufficient fluid flow so that fluid samples can be taken from the returned fluid.The control system is also programmed to transition the fluid analysis system from normal mode to a recirculation mode based on the determination to recirculate fluid through the fluid analysis system when the fluid sample cannot be withdrawn due to a reduction in the flow of returned fluid.

[0054] In Example 15, the modalities of any preceding paragraph or combination thereof also include wherein the control system is further programmed to generate an indication based on the determination.

[0055] In Example 16, the embodiments of any preceding paragraph or combination thereof further include wherein the control system is further programmed to determine whether the drilling fluid pump property rises above the predetermined threshold. The control system is also programmed to transition the fluid analysis system from recirculation mode to normal mode based on the determination of the property rising above the predetermined threshold.

[0056] In Example 17, the embodiments of any preceding paragraph or combination thereof also include wherein the control system is further programmed to generate an indication based on the determination of the property rising above the predetermined threshold.

[0057] In Example 18, the modalities of any paragraph Petition 870260030053, dated 03 / 31 / 2026, page 29 / 80 / 22, the previous or a combination thereof also includes an operable degassing system to extract gases from the returned fluid.

[0058] In Example 19, the embodiments in any preceding paragraph or combination thereof further include an operable thermal energy device for heating or cooling the returned fluid.

[0059] In Example 20, the embodiments of any preceding paragraph or combination thereof further include wherein the property of the drilling fluid pump includes at least one of a flow rate produced by the drilling fluid pump or an RPM of the drilling fluid pump.

[0060] As used in this document, the term “approximately” includes all values ​​within 5% of the target value; for example, approximately 100 includes all values ​​from 95 to 105, including 95 and 105.

[0061] For the above embodiments and examples, a non-transient machine-readable storage device may comprise instructions stored therein, which, when executed by a machine, cause the machine to perform operations, the operations comprising one or more features similar or identical to the features of methods and techniques described above. The physical structures of such instructions may be operated by one or more processors. A system for implementing the described algorithm may also include an electronic apparatus and a communication unit. The system may also include a bus, wherein the bus provides electrical conductivity between the system components. The bus may include an address bus, a data bus, and a control bus, each configured independently.The bus can also use common conductive lines to provide one or more address, data, or control lines, the use of which can be regulated by one or more processors. The bus can be... Petition 870260030053, dated 03 / 31 / 2026, page 30 / 80 / 22 configured so that the system components can be distributed. The bus can also be organized as part of a communication network, allowing communication with control locations situated remotely from the system.

[0062] In various system embodiments, peripheral devices, such as monitors, additional storage memory, and / or other control devices, may operate in combination with one or more processors and / or memory modules. Peripheral devices may be arranged to operate in conjunction with display unit(s) with instructions stored in the memory module to implement the user interface for managing the display of anomalies. Such a user interface may operate in combination with the communications unit and the bus. Various system components may be integrated so that processing identical or similar to the processing schemes discussed with respect to various embodiments in this document may be performed.

[0063] As used in this document, the term “electronic communication” includes wired communication between electronic components and / or electronic devices and wireless communication between electronic components and / or electronic devices. “Electronic communication” also includes electronic components and / or electronic devices that are in electronic communication, wired or wireless, through intermediate electronic components and / or electronic devices.

[0064] In an effort to provide a concise description of these modalities, all the characteristics of an actual implementation may not be described in the descriptive report. It should be understood that in the development of any such implementation, as in any engineering project or undertaking, numerous implementation-specific decisions must be made to achieve the specific objectives of Petition 870260030053, dated 03 / 31 / 2026, page 31 / 80 / 22 developers, such as compliance with system-related and business-related constraints, which will vary from one implementation to another. Furthermore, it should be understood that such development effort may be complex and time-consuming, but despite this, it would be a routine design, fabrication, and manufacturing task for those skilled in the art, benefiting from this disclosure.

[0065] Certain terms are used throughout the description and claims to refer to particular features or components. As will be understood by one skilled in the art, different people may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name but not in function.

[0066] References throughout this descriptive report to “a modality”, “the modality”, “modalities”, “some modalities”, “certain modalities” or similar language mean that a particular feature, structure or characteristic described in relation to the modality may be included in at least one modality of this disclosure. Thus, these phrases or similar language throughout this descriptive report may, but do not necessarily, all refer to the same modality.

[0067] The embodiments disclosed should not be interpreted or otherwise used as limiting the scope of the disclosure, including claims. It will be fully recognized that the different teachings of the embodiments discussed can be employed separately or in any suitable combination to produce desired results. Furthermore, one skilled in the art will understand that the description has broad application and the discussion of any embodiment is intended only to be illustrative of that embodiment and is not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment. Petition 870260030053, dated 31 / 03 / 2026, p. 32 / 80

Claims

1 / 4 CLAIMS 1. Drilling system (100) for drilling an unfinished well (116), the drilling system (100) characterized in that it comprises: a drilling fluid pump (120) operable for circulating fluid (122) through the unfinished well (116); and a fluid analysis system (142, 242) for analyzing fluid returned from the unfinished well (116), wherein the fluid analysis system (142, 242) comprises: a sensor system (202) operable for measuring one or more properties of the returned fluid; a recirculation system (212) comprising a pump (214) and controllable valves (216, 218), the recirculation system (212) operable for controlling the flow of the returned fluid through the fluid analysis system (142, 242);and a control system (210) in electronic communication with the drilling fluid pump (120) and the recirculation system (212), the control system (210) programmed to: operate the fluid analysis system (142, 242) in a normal mode to take fluid samples (200) from the returned fluid and analyze the fluid samples (200); monitor a property of the drilling fluid pump (120); determine if the property of the drilling fluid pump (120) falls below a predetermined threshold, wherein the property of the drilling fluid pump (120) being above the predetermined threshold is indicative of sufficient fluid flow so that fluid samples (200) can be taken from the returned fluid;and to transition the fluid analysis system (142, 242) from Petition 870260030053, dated 31 / 03 / 2026, page 33 / 80 2 / 4 normal mode to a recirculation mode based on the determination that the drilling fluid pump property (120) falls below the predetermined threshold so that the fluid sample (200) cannot be withdrawn due to a reduction in the flow of the returned fluid, wherein, in recirculation mode, the fluid is recirculated within the fluid analysis system (142, 242).; 2. Drilling system (100) according to claim 1, characterized in that the control system (210) is further programmed to generate an indication based on the determination.

3. Drilling system (100) according to claim 1, characterized in that the control system (210) is further programmed to: determine whether the property of the drilling fluid pump (120) rises above the predetermined threshold; and transition the fluid analysis system (142, 242) from recirculation mode to normal mode based on the determination of the property rising above the predetermined threshold.

4. Drilling system (100) according to claim 3, characterized in that the control system (210) is further programmed to generate an indication based on the determination of the property that rises above the predetermined threshold.

5. Drilling system (100) according to claim 1, characterized in that the fluid analysis system (142, 242) further comprises an operable degassing system (206) for extracting gases from the returned fluid.

6. Drilling system (100) according to claim 1, characterized in that the fluid analysis system (142, 242) further comprises a thermal energy device (204) operable for heating or cooling the returned fluid. Petition 870260030053, dated 31 / 03 / 2026, page 34 / 80 3 / 4 7. Drilling system (100) according to claim 1, characterized in that the property of the drilling fluid pump (120) comprises at least one of a flow rate produced by the drilling fluid pump (120) or an RPM of the drilling fluid pump (120).

8. Method for drilling an unfinished well (116), the method characterized in that it comprises: circulating fluid (122) through an unfinished well (116) by means of a drilling fluid pump (120); operating a fluid analysis system (142, 242) in a normal mode to take fluid samples (200) from fluid returned from the unfinished well (116) and analyzing the fluid samples (200); monitoring a property of the drilling fluid pump (120); determining whether the property of the drilling fluid pump (120) falls below a predetermined threshold, wherein the property of the drilling fluid pump (120) being above the predetermined threshold is indicative of sufficient fluid flow so that fluid samples (200) can be taken from the returned fluid;and the transition of the fluid analysis system (142, 242) from normal mode to a recirculation mode based on the determination that the drilling fluid pump property (120) falls below the predetermined threshold so that the fluid sample (200) cannot be withdrawn due to a reduction in the flow of the returned fluid, wherein, in recirculation mode, the fluid is recirculated within the fluid analysis system (142, 242).

9. Method according to claim 8, characterized in that it further comprises generating an indication based on the determination. Petition 870260030053, dated 31 / 03 / 2026, page 35 / 80 4 / 4 10. Method according to claim 8, characterized in that it further comprises: determining whether the property of the drilling fluid pump (120) rises above the predetermined threshold; and transitioning the fluid analysis system (142, 242) from recirculation mode to normal mode based on the determination of the property rising above the predetermined threshold.

11. Method according to claim 10, characterized in that it further comprises generating an indication based on the determination of the property that rises above the predetermined threshold.

12. Method according to claim 8, characterized in that it further comprises: operating a thermal energy device (204) to heat or cool the returned fluid; and operating a degassing system (206) to extract gases from the returned fluid.

13. Method according to claim 8, characterized in that the property of the drilling fluid pump (120) comprises at least one of a flow rate produced by the drilling fluid pump (120) or an RPM of the drilling fluid pump (120). Petition 870260030053, dated 31 / 03 / 2026, page 36 / 80

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