Formation tester flowline decompression to test carbon dioxide content in water

Abstract

Embodiments of the disclosure provide for methods and apparatus related to fluid testing for geological analysis. Aspects disclose methods and apparatus related to fluid testing for carbon dioxide content in water. Embodiments enable precise detection and quantification of fluid properties in geological samples, supporting enhanced characterization of subsurface formations. The approaches further facilitate accurate measurement of carbon dioxide levels dissolved in water, allowing for environmental assessment and monitoring of geochemical processes. Such methods and apparatus are adaptable to a variety of geological settings, ensuring reliable results across diverse sample types and field conditions.

Description

ATTORNEY DOCKET IS24.1184FORMATION TESTER FLOWLINE DECOMPRESSION TO TEST CARBON DIOXIDE CONTENT IN WATERCROSS-REFERENCE TO RELATED APPLICATIONS

[0001] The present application claims priority to United States Provisional Application 63 / 688,508 dated August 29, 2024, the entirety of which is incorporated by reference.FIELD OF THE DISCLOSURE

[0002] Aspects of the disclosure relate to the development and testing of hydrocarbon fields. More specifically, aspects of the disclosure relate to providing a more economical way to develop hydrocarbon fields and enhancing worker safety compared to conventional technologies by using downhole apparatus to test carbon dioxide content through decompression technology.BACKGROUND

[0003] Hydrocarbons are deeply woven into the fabric of modern society, providing energy that powers vehicles, heats homes, fuels industry, and serves as raw material for countless chemicals and plastics. From gasoline and diesel to jet fuel and lubricants, hydrocarbons are present in daily life in many forms. However, the era of readily accessible, large, hydrocarbon fields is coming to a close. Fields like those discovered in the early twentieth century have largely been depleted or are in steady decline. The easy- to-find, easy-to-produce reservoirs are becoming increasingly rare, and new exploration often yields smaller, more technically complex accumulations.

[0004] The remaining hydrocarbon fields present a host of new challenges for exploration and production. Many are located at great depths beneath the earth’s surface or reside offshore, sometimes under thick layers of salt or in remote, environmentally sensitive areas. Such reservoirs are not only physically harder to reach but also come with their own suite of technical hurdles, including extreme formation pressures, very high or low temperatures, and difficult rock properties. The harshness of these environments demands advanced drilling technologies, specialized equipment, and highly skilled personnel. In addition, logistical issues, such as transporting equipment to remoteATTORNEY DOCKET IS24.1184 regions or setting up platforms in ultra-deep water, further complicate the development of these fields.

[0005] Field development costs remain a primary factor in the decision making process for oil and gas companies. Projects with lower anticipated costs are routinely prioritized over those with higher expenses, as companies seek to maximize return on investment and minimize financial risk. Estimating the full scope of development costs involves a thorough analysis of the geological, technical, and logistical aspects of the field. Factors such as drilling complexity, the need for enhanced recovery technologies, and infrastructure requirements can rapidly escalate project costs. As a result, only the most favorable fields, those with the best combination of reservoir quality, size, and accessibility, find themselves at the top of the development queue.

[0006] Another critical variable in the development of hydrocarbon fields is the fluctuating price of oil and gas. The laws of supply and demand exert a profound influence on commodity prices, which can swing widely due to geopolitical events, changing consumption patterns, or new discoveries. The general trend has been toward increasing hydrocarbon costs in which easily developed resources are exploited first, leaving behind those that are smaller, deeper, or harder to produce. This economic reality places a greater emphasis on the development of technically challenging and economically borderline fields. Companies are forced to innovate and find ways to develop these assets efficiently or risk leaving them untapped as global demand continues to rise.

[0007] Within this landscape, the field of fluid testing for geological analysis has become an indispensable tool. By carefully analyzing performance from exploratory wells or producing reservoirs, geoscientists and engineers are able to assess reservoir potential, predict production performance and optimize development strategies. Fluid testing provides vital information on hydrocarbon composition, pressure, temperature, and saturation, all of which form the backbone of economic and technical evaluations. However, while fluid testing for geological analysis is undeniably beneficial, it is not without significant drawbacks that can affect decision making and project outcomes.ATTORNEY DOCKET IS24.1184

[0008] One major issue lies in the reliability of certain fluid tests, especially those pertaining to carbon dioxide (CO2) content. Conventional carbon dioxide testing often yields incorrect results, which may stem from the inherent difficulties in collecting representative samples or from limitations in laboratory techniques. In some geological formations, fluid testing for CO2content becomes exceptionally challenging due to the nature of the reservoir rock or the presence of impurities that interfere with measurements. Conventional bubble point testing, used to determine the pressure at which gas begins to come out of solution, can also return inaccurate economic analyses for certain fields, resulting in flawed investment decisions or suboptimal development plans. Such errors in fluid analysis can ripple through every subsequent stage of field development, from reserve estimation to facilities design and financial modeling.

[0009] An additional drawback in developing marginal fields is worker safety. In environments where the composition of the reservoir fluids is inaccurately assessed, workers may be exposed to hazardous conditions they were not prepared for, such as unexpected concentrations of toxic gases. Failure to correctly analyze a hydrocarbon field may compromise the effectiveness of safety protocols, leading to increased risk of accidents, injuries, or even fatalities. The importance of accurate, reliable fluid testing cannot be overstated when it comes to safeguarding the workforce.

[0010] There is a need to provide a more economical way to develop hydrocarbon fields compared to conventional technologies related to testing for various gases, such as carbon dioxide.

[0011] There is a need to provide additional worker safety compared to conventional technologies.

[0012] There is a need to provide solutions to the drawbacks of the fluid testing for geological analysis and to provide quick results in the field as opposed to expensive laboratory analysis.ATTORNEY DOCKET IS24.1184

[0013] There is a need to provide an apparatus and methods that are easier to operate than conventional apparatus and methods and that provide higher quality results compared to conventional gaseous testing.

[0014] There is a further need to provide apparatus and methods that do not have the drawbacks discussed above, such as time delays for analysis of fluid samples and expensive test equipment used in determining gaseous content in various fluids.

[0015] There is a still further need to reduce economic costs associated with operations and apparatus described above with conventional tools.SUMMARY

[0016] 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 drawings. It is to be noted that the 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. Accordingly, the following summary provides just a few aspects of the description and should not be used to limit the described embodiments to a single concept.

[0017] In one example embodiment, a method is disclosed. The method may comprise conducting a flowline decompression to a volume of water. The method may further comprise isolating the volume of water in a fluid analyzer module of a formation tester. The method may further comprise using a downhole pump to reduce flowline pressure at a flowrate. The method may further comprise detecting a phase change using optical spectroscopy to measure light scattering caused by released gas bubbles.

[0018] In another example embodiment, a method for performing an analysis of a fluid in a downhole formation tester is disclosed. The method may comprise selecting aATTORNEY DOCKET IS24.1184 volume of the fluid and placing the volume in through a volume chamber and into a sample bottle. The method may further comprise decompressing the volume of fluid within the volume chamber. The method may further comprise continually decompressing the volume of fluid until a threshold pressure is reached. The method may further comprise, after reaching the threshold pressure, stopping the decompression of the volume of fluid. The method may further comprise identifying the presence of gases generated in the volume chamber through the decompression. The method may further comprise pumping the presence of the gases generated in the volume chamber to a system for compositional analysis. The method may further comprise performing a compositional analysis of the gases generated in the volume chamber.

[0019] In another example embodiment, a method for performing an analysis of a fluid in a downhole formation tester is disclosed. The method may comprise selecting a volume of the fluid and placing the volume in a volume chamber. The method may further comprise decompressing the volume of fluid within the volume chamber until a bubble point is reached for the volume of fluid. The method may further comprise identifying the presence of gases generated in the volume chamber through the decompression. The method may further comprise pumping the presence of the gases generated in the volume chamber to a system for compositional analysis. The method may further comprise performing a compositional analysis of the gases generated in the volume chamber. The method may further comprise determining a volume of gases generated in the volume chamber.BRIEF DESCRIPTION OF THE DRAWINGS

[0020] 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 drawings. It is to be noted; however, that the appended drawings illustrate only typical embodiments of this disclosure and are; therefore, not be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments.ATTORNEY DOCKET IS24.1184

[0021] FIG. 1 illustrates an embodiment of a flowline decompression system according to one example embodiment of the disclosure.

[0022] FIG. 2 is a workflow for obtaining a bubble point of carbon dioxide and other gases, in water, according to one or more examples of the disclosure.

[0023] FIGS. 3A, 3B and 3C illustrate another embodiment of a decompression system, according to one or more examples of the disclosure.

[0024] To facilitate understanding, identical reference numerals have been used, where possible, to designate identical elements that are common to the figures (“FIGS”). It is contemplated that elements disclosed in one embodiment may be beneficially utilized on other embodiments without specific recitation.DETAILED DESCRIPTION

[0025] In the following, reference is made to embodiments of the disclosure. It should be understood; however, that the disclosure is not limited to specific described embodiments. Instead, any combination of the following features and elements, whether related to different embodiments or not, is contemplated to implement and practice the disclosure. Furthermore, 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, reference to “the disclosure” shall not be construed as a generalization of 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.

[0026] 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. TheseATTORNEY DOCKET IS24.1184 terms may be only used to distinguish one element, components, region, layer, or section from another region, layer, or section. Terms such as “first”, “second”, and other numerical terms, when 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.

[0027] When an element or layer is referred to as being “on”, “engaged to”, “connected to”, or “coupled to” another element or layer, it may be directly on, engaged, connected, coupled to the other element or layer, or interleaving 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 interleaving elements or layers present. Other words used to describe the relationship between elements should be interpreted in a like fashion. As used herein, the term “and / or” includes any and all combinations of one or more of the associated listed terms.

[0028] Some embodiments will now be described with reference to the figures. Like elements in the various figures will be referenced with like numbers for consistency. In the following description, numerous details are set forth to provide an understanding of various embodiments and / or features. It will be understood; however, 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”, “up” and “down”, “upper” and “lower”, “upwardly” and “downwardly”, and other like terms indicating relative positions above or below a given point are used in this description to more clearly describe certain embodiments.

[0029] In some embodiments, methods described may be stored in a non-volatile memory. In some embodiments, the non-volatile memory may be defined as an article of manufacture. In embodiments, the non-volatile memory is configured such that the methods may contain a list of instructions that may be read by a computing device andATTORNEY DOCKET IS24.1184 the list of instructions performed. The list of instructions may perform calculations, illustrate graphic results on a visual device, such as a monitor, print results, or store data for further use, as non-limiting embodiments. The list of instructions may be executable in their own programming or may be executed using other programming. The list of instructions may be stored in various configurations, such as a compact disk, a floppy disk, a solid-state drive, a computer hard drive, a server, a web-oriented storage device, and a cloud-computing device or system. Embodiments of methods described may control other systems, such as machines, to perform specified functions. Operational control may be performed through additional programming and / or operation of other computing or control devices. Embodiments described may be implemented using wireless technologies to allow for computing and execution of the list of instructions from various locations. Computing may occur, for example, in various platforms, including a personal computer, a laptop computer, a computer server, a cloud-based computer, a mainframe computer, a cellular telephone, and a cellular connected device.

[0030] Embodiments of the methods described may use other programming technologies to help implement the methods described. In some embodiments, machine learning programming may be used to evaluate data and provide results. In some embodiments, training datasets may be used to allow for convergence of needed results and thus using pretrained machine learning programming is considered within the scope of the disclosure. In other instances, artificial intelligence programming systems may be implemented as part of the disclosure or may be incorporated within the methods described. Such artificial intelligence systems may be used in various capacities, including results generation, error detection, problem definition and problem convergence methods. Graphical representation of results obtained by artificial intelligence systems is also considered within the scope of the disclosure.

[0031] In embodiments using machine learning and / or artificial intelligence, programming may be altered by the programming based upon instructions provided. As such, in one non-limiting embodiment, different nodal layers of evaluation may be provided for analysis. The different nodal layers provided may incorporate modificationATTORNEY DOCKET IS24.1184 techniques to allow for accurate reading and evaluation of large datasets. The large datasets may be designated training datasets or may be actual data that is desired to be evaluated. Coefficients used for corresponding different nodal layers may be developed within the methods described or may be pre-set according to training. Such coefficients may be altered by the computer programming itself or may be designated by a computer user. As a non-limiting embodiment, if possible results from analysis disclose too many potential outcomes or results, a computer operator may be asked or may alter the analysis protocol to achieve more focused results.

[0032] In embodiments, computer code may be any programming code that lists instructions to be followed. Programming codes may include instructions provided by a computer programmer with or without assistance by computers. Programming may occur through use of a library of programs or subroutines to section programming tasks. Programming may be accomplished to run on different operating systems or may be included with internal executable files for stand-alone computer instructions.

[0033] Referring to FIG. 1 , an embodiment of a flowline decompression system 100 is illustrated. FIG. 2 shows a workflow or method 200 for obtaining a bubble point of carbon dioxide and other gases in a fluid, such as water, using the flowline decompression system depicted in FIG. 1. In one or more embodiments, a method for obtaining the bubble point of carbon dioxide and other gases in water may comprise conducting a flowline decompression, which involves dropping pressure of a fluid, such as water, in the downhole environment, to below saturation pressure and detecting any possible phase changes.

[0034] In one or more embodiments, conducting a flowline decompression, referred to above, comprises isolating a volume of water in a fluid analyzer module of a formation tester at 202, and using a downhole pump to reduce flowline pressure at a low and precise flowrate. In embodiments, at 204, the flow rate is always closed on one side while fluid is extracted with a piston displacement pump connected to the other side of the flowline. In one or more embodiments, the pump may be either above or below the fluid analyzerATTORNEY DOCKET IS24.1184 module. As will be understood, any technology that will cause a differential pressure may be used; therefore, a piston displacement pump is one non-limiting embodiment that is possible.

[0035] During the creation of a pressure differential, different scenarios may take place according to the constituents of the fluid being tested. Once the bubble point pressure is reached inside the flowline, the gas bubble may first be formed through heterogeneous nucleation, for example, forming on a optical density detection window. Detection of the heterogeneous nucleation may be done through optical density analysis using optical spectroscopy measurements. As the pressure drops in the flowline, optical density remains stable when the flowline is filled with a single-phase liquid (water). A smooth increase in optical density indicates that light is being scattered and as bubbles grow or as more bubbles appear, the scattering increases in a smooth fashion. Once the bubbles become mobile, light scattering caused by gas bubbles moving to the spectrometer become erratic and often become visible as noise on other senses.

[0036] In one or more embodiments, the phase change occurring in the water may be detected using optical spectroscopy measurements made at a desired sampling rate, for example, in a nonlimiting embodiment, a 128ms data sampling rate. This sampling rate ensures divisibility of even very small bubbles or dewdrops and near infrared light directed through the flowline, which subsequently ensures that any occurring phase change event is detected.

[0037] Once the gas bubbles are liberated, they accumulate as gas at the top of the flowline. Once sufficient gas bubbles are liberated, the gas volume may be large enough to cover an optical density cell, which allows for the evaluation of the composition of the gas. Since the flowline volumes are known, the starting volume and volume of water may be deduced. Thus, the volume of gas may be calculated, for example the minimum value required to fill the flowline and cover the optical density sensor. In one or more embodiments, several different brackets acting as sensors may be configured below the optical density cell, such as resistivity and density cells, which are also immersed in the flowline gas. In one or more embodiments, because the flowline volume is known, at leastATTORNEY DOCKET IS24.1184 three different scenarios may be encountered. In the first scenario, at 206, no bubble point is found. In the second scenario, a bubble point is detected, but gas volumes are too small to form a measurable volume at 208. In the third scenario, a bubble point is detected in a gas that accumulates, and a gas cap is formed, at 210. The method then progresses to 212 wherein the composition of the gas is determined from optical density calculations and bracket gas volumes are determined based on the number of sensors that are emersed in the gas cap. In this third scenario, the flow line up volume and gas minimum volume are known and gas composition is identified.

[0038] FIGS. 3A, 3B, 3C shows an embodiment of a flowline decompression system for obtaining a bubble point of carbon dioxide and other gases in a fluid, such as water. In this embodiment, formation water may fill a volume chamber of the flowline decompression system for decompression. The volumes for the volume chamber used may include 5, 10, or 20 liters chambers. In this embodiment, the compressibility obtained may be correlated to the quality of gas dissolved in water.

[0039] In the example flowline decompression system depicted in FIG. 3A, 3B and 3C, a dual packer module 320 is used along with a focused radial probe. A fluid analysis module is also used similar to the depiction in FIG. 1 , with an optics module 330 at the top and sensor slots at the lower end of the module. Two pumps 340, 350 may be used in one nonlimiting example embodiment of the disclosure. A multi-sample module may also be used that allows for storage of fluid in sample bottles. In one nonlimiting embodiment, six sample bottles may be obtained within the multi-sample module.

[0040] The steps for obtaining a bubble point of carbon dioxide and other gases in water using the embodiment presented in FIG. 3 is now described. In a first step, starting from FIG. 3A, a tool string 300 illustrated, where the desired fluid has been identified by the fluid analyzer, the valve on line 1 302 is closed and the chamber valve 1 304 is opened. Fluid from line 1 302 is now being removed out of the top of the volume chamber 306 and formation fluid proceeds to enter a bottle 308 through chamber valve 1 304. This process may be stopped when the volume chamber 306 is filled or when the operator deems that the volume chamber 306 contains sufficient formation fluid.ATTORNEY DOCKET IS24.1184

[0041] In step 2, FIG. 3B, a toolstring is illustrated, the water in the volume chamber 306 is decompressed. To this end, chamber valve 1 304 is closed and chamber valve 2 308 is opened. The lower pump on line 2 then pumps in the upward direction drawing the fluid out of the chamber through chamber valve 2. The chamber piston has formation water below and “prefilled fluid” or another fluid above. Importantly, the piston is movable, so pressure is transmitted, but no fluid can pass through. A pressure gauge is present on line 1 302. Line 1 302 is closed through use of a flowline valve as well as the pump position on line 1 302. If the chamber valve is not completely filled with formation water, then some decompression may also be conducted by the line 1 until the piston reaches the end of its stroke. Fluid line 1 302 and fluid line 2 310 fluid should all be at the same pressure, with the line to pump generating the flowline decompression. Bubble point detection may be performed on line 1 302 through attached optics. In the case of operations where line 1 302 and line 2 310 fluid are potentially the same, the bubble point may be detected through both line 1 and line 2 optics.

[0042] In step 3, FIG. 3C, after the decompression is complete, the formation water and liberated gas are pumped from the volume chamber 306 on line 2. To enable this, flowline 1 302 is opened so that a chamber piston may move the formation water and liberated gas. In one example embodiment, an upper pump is put into bypass mode. In other configurations valves within the system are opened to move the fluids. Fluid is now pumped from chamber valve 2 up flowline 2 310 for compositional analysis. The flowrate is integrated to obtain water and gas volumes. Systems may be placed between the two pumps to capture the liberated gas in to a dedicated sample bottle.

[0043] Aspects of the disclosure herein provide significant advancements in reducing the number of errors commonly encountered in conventional analysis related to fluid testing for geological analysis. By refining the methodologies and integrating improved computational techniques, the likelihood of inaccuracies in geological data interpretation is notably diminished. These enhancements serve to increase the reliability of results, delivering greater confidence to operators and end users involved in complex geological assessments.ATTORNEY DOCKET IS24.1184

[0044] Worker safety is directly enhanced by this reduction in analysis errors and the subsequent decrease in potential mistakes that can occur in the field due to inaccurate engineering assessments. The possibility of harm or hazardous incidents caused by erroneous data is substantially lessened, serving as an important safeguard for personnel conducting fluid testing in challenging environments. An additional drawback of conventional analysis is the risk imposed on worker safety, which this disclosure specifically addresses by prioritizing accuracy and eliminating common sources of error.

[0045] Further, aspects of the disclosure demonstrate clear superiority over existing conventional technologies, particularly in the efficiency with which complex field configurations and situations are analyzed. The innovative methods described herein allow users to complete analyses in less time, optimizing operational workflows, and minimizing the delays often associated with intricate and variable field conditions. This time saving advantage is crucial for field operations where rapid decision making and adaptability are essential for success.

[0046] By overcoming the drawbacks of conventional analysis, the present disclosure enables efficient and economical development of results not achievable with prior technologies. The integrated approaches outlined offer streamlined processes that conserve resources and reduce operational costs, while maintaining or enhancing the quality and precision of outcomes. These solutions represent a substantial improvement, providing operators with practical and cost effective tools for fluid testing in geological applications.

[0047] Example embodiments of the claims are recited next. The embodiments disclosed should not be considered limiting of the disclosure. In one example embodiment, a method is disclosed. The method may comprise conducting a flowline decompression to a volume of water. The method may further comprise isolating the volume of water in a fluid analyzer module of a formation tester. The method may further comprise using a downhole pump to reduce flowline pressure at a flowrate. The method may further comprise detecting a phase change using optical spectroscopy to measure light scattering caused by released gas bubbles.ATTORNEY DOCKET IS24.1184

[0048] In another example embodiment, the method may further comprise measuring the composition of the released gas bubbles.

[0049] In another example embodiment, the method may further comprise determining if a gas cap is formed to the volume of water.

[0050] In another example embodiment, the method may be performed wherein when the gas cap is not formed to the volume of water, concluding that a gas volume within the volume of water is too small to determine a composition.

[0051] In another example embodiment, the method may be performed wherein the gas cap is formed, the determination of the composition of the gas is performed through optical density analysis and a volume of gas is determined through at least one sensor.

[0052] In another example embodiment, the method may be performed wherein the at least one sensor is emersed in the formed gas cap.

[0053] In another example embodiment, a method for performing an analysis of a fluid in a downhole formation tester is disclosed. The method may comprise selecting a volume of the fluid and placing the volume in through a volume chamber and into a sample bottle. The method may further comprise decompressing the volume of fluid within the volume chamber. The method may further comprise continually decompressing the volume of fluid until a threshold pressure is reached. The method may further comprise, after reaching the threshold pressure, stopping the decompression of the volume of fluid. The method may further comprise identifying the presence of gases generated in the volume chamber through the decompression. The method may further comprise pumping the presence of the gases generated in the volume chamber to a system for compositional analysis. The method may further comprise performing a compositional analysis of the gases generated in the volume chamber.ATTORNEY DOCKET IS24.1184

[0054] In another example embodiment, the method may further comprise measuring the volume placed into the sample bottle and stopping the placing of the volume in through the volume chamber when a volume threshold is reached in the sample bottle.

[0055] In another example embodiment, the method may be performed wherein the fluid is water.

[0056] In another example embodiment, the method may be performed wherein the decompression of the volume of fluid within the volume chamber is conducted through a pressure connected pump.

[0057] In another example embodiment, the method may be performed wherein the pressure connected pump is a positive displacement pump.

[0058] In another example embodiment, the method may further comprise performing a bubble point detection after the decompressing of the volume of fluid.

[0059] In another example embodiment, the method may be performed wherein the bubble point detection is performed using optical analysis of fluid from the volume of fluid.

[0060] In another example embodiment, the method may further comprise measuring at least one of a gas volume and the determining the volume of fluid tested.

[0061] In another example embodiment, a method for performing an analysis of a fluid in a downhole formation tester is disclosed. The method may comprise selecting a volume of the fluid and placing the volume in a volume chamber. The method may further comprise decompressing the volume of fluid within the volume chamber until a bubble point is reached for the volume of fluid. The method may further comprise identifying the presence of gases generated in the volume chamber through the decompression. The method may further comprise pumping the presence of the gases generated in the volume chamber to a system for compositional analysis. The method may furtherATTORNEY DOCKET IS24.1184 comprise performing a compositional analysis of the gases generated in the volume chamber. The method may further comprise determining a volume of gases generated in the volume chamber.

[0062] In another example embodiment, the method may be performed wherein the decompression of the volume of fluid within the volume chamber is conducted through a pressure connected pump.

[0063] In another example embodiment, the method may be performed wherein the pressure connected pump is a positive displacement pump.

[0064] In another example embodiment, the method may be performed wherein the bubble point is determined through optically observing the fluid during decompression.

[0065] In another example embodiment, the method may be performed wherein the fluid comprises, at least in part, water.

[0066] In another example embodiment, the method may be performed wherein the method is performed in a downhole location.

[0067] The foregoing description of the embodiments has been provided for purposes of illustration and description. It is not intended to be exhaustive or to limit the disclosure. Individual elements or features of a particular embodiment are generally not limited to that particular embodiment, but, where applicable, are interchangeable and can be used in a selected embodiment, even if not specifically shown or described. The same may be varied in many ways. Such variations are not to be regarded as a departure from the disclosure, and all such modifications are intended to be included within the scope of the disclosure.ATTORNEY DOCKET IS24.1184

[0068] While embodiments have been described herein, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments are possible that do not depart from the inventive scope. Accordingly, the scope of the present claims or any subsequent claims shall not be unduly limited by the description of the embodiments described herein.

Claims

ATTORNEY DOCKET IS24.1184CLAIMSWhat is claimed is:

1. A method, comprising: conducting flowline decompression to a volume of water; isolating the volume of water in a fluid analyzer module of a formation tester; using a downhole pump to reduce flowline pressure at a flowrate; and detecting a phase change using optical spectroscopy to measure light scattering caused by released gas bubbles.

2. The method according to claim 1 , further comprising measuring the composition of the released gas bubbles.

3. The method according to claim 2, further comprising determining if a gas cap is formed to the volume of water.

4. The method according to claim 3, wherein when the gas cap is not formed to the volume of water, concluding that a gas volume within the volume of water is too small to determine a composition.

5. The method according to claim 4, wherein the gas cap is formed, the determination of the composition of the gas is performed through optical density analysis and a volume of gas is determined through at least one sensor.

6. The method according to claim 5, wherein the at least one sensor is emersed in the formed gas cap.

7. A method for performing an analysis of a fluid in a downhole formation tester, comprising:ATTORNEY DOCKET IS24.1184 selecting a volume of the fluid and placing the volume in through a volume chamber and into a sample bottle; decompressing the volume of fluid within the volume chamber; continually decompressing the volume of fluid until a threshold pressure is reached; after reaching the threshold pressure, stopping the decompression of the volume of fluid; identifying the presence of gases generated in the volume chamber through the decompression; pumping the presence of the gases generated in the volume chamber to a system for compositional analysis; and performing a compositional analysis of the gases generated in the volume chamber.

8. The method according to claim 7, further comprising measuring the volume placed into the sample bottle and stopping the placing of the volume in through the volume chamber when a volume threshold is reached in the sample bottle.

9. The method according to claim 7, wherein the fluid is water.

10. The method according to claim 7, wherein the decompression of the volume of fluid within the volume chamber is conducted through a pressure connected pump.11 . The method according to claim 10, wherein the pressure connected pump is a positive displacement pump.

12. The method according to claim 7, further comprising performing a bubble point detection after the decompressing of the volume of fluid.ATTORNEY DOCKET IS24.118413. The method according to claim 12, wherein the bubble point detection is performed using optical analysis of fluid from the volume of fluid.

14. The method according to claim 12, further comprising measuring at least one of a gas volume and the determining the volume of fluid tested.

15. A method for performing an analysis of a fluid in a downhole formation tester, comprising: selecting a volume of the fluid and placing the volume in a volume chamber; decompressing the volume of fluid within the volume chamber until a bubble point is reached for the volume of fluid; identifying the presence of gases generated in the volume chamber through the decompression; pumping the presence of the gases generated in the volume chamber to a system for compositional analysis; performing a compositional analysis of the gases generated in the volume chamber; and determining a volume of gases generated in the volume chamber.

16. The method according to claim 15, wherein the decompression of the volume of fluid within the volume chamber is conducted through a pressure connected pump.

17. The method according to claim 16, wherein the pressure connected pump is a positive displacement pump.

18. The method according to claim 15, wherein the bubble point is determined through optically observing the fluid during decompression.ATTORNEY DOCKET IS24.118419. The method according to claim 15, wherein the fluid comprises, at least in part, water.

20. The method according to claim 15, wherein the method is performed in a downhole location.

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