Tools, processes, and systems for in-situ fluid characterization based on a thermal response of a fluid are provided. The thermal response of a downhole fluid may be measured using a downhole thermal response tool and compared with thermal responses associated with known fluids. The properties of the downhole fluid, such as heat capacity, diffusivity, and thermal conductivity, may be determined by matching the thermal response of the downhole fluid with a thermal response of a known fluid and using the properties associated with the known fluid. The composition of the downhole fluid may be determined by matching the viscosity of the downhole fluid to the viscosity of known fluid. A downhole thermal response tool for cased wellbores or wellbore sections and a downhole thermal response tool for openhole wellbores or wellbore sections are provided.

The invention relates to a fluid sampling device comprising a sample chamber (01) including a lower piston (05), an upper piston (02) and an intermediate piston (28). Intermediate piston (28) is moved so as to guarantee a substantially constant volume for chamber (01) when closing the chamber.

This disclosure presents systems and processes to collect elemental composition of target fluid and solid material located downhole of a borehole. Waveguides can be utilized that include capillary optics to deliver emitted high energy into a container or a conduit and then to detect the high energy. A source waveguide can be used to emit the high energy into the target fluid and a detector waveguide can collect resulting measurements. Each waveguide can include a protective sheath and a pressure cap on the end of the capillary optics that are proximate the target fluid, to protect against abrasion and target fluid pressure. In other aspects, a pulsed neutron tool can be utilized in place of the waveguides to collect measurements. The collected measurements can be utilized to generate chemical signature results that can be utilized to determine the elemental composition of the target fluid or of the solid material.

A method of conditioning a well bore featuring an annulus (50) between a bore-lining tubing (20) and a surrounding bore wall (110) comprises pumping conditioning fluid through an inner tubing (10) located within the bore-lining tubing (20) and into a portion of the well bore containing the bore-lining tubing to affect the temperature of the portion of the well bore containing the bore-lining tubing. The annulus (50) between the bore-lining tubing (20) and the surrounding bore wall (110) is at least partially filled with settable material (54). The affected temperature of the portion of the well bore containing the bore-lining tubing influences the setting of the settable material. For example, heating the bore may accelerate setting of the material, while cooling the bore may retard setting of the material.

Methods of actuating a well tool can include releasing chemical energy from at least one portion of a reactive material, thermally expanding a substance in response to the released chemical energy, and applying pressure to a piston as a result of thermally expanding the substance, thereby actuating the well tool, with these steps being repeated for each of multiple actuations of the well tool. A well tool actuator can include a substance contained in a chamber, one or more portions of a reactive material from which chemical energy is released, and a piston to which pressure is applied due to thermal expansion of the substance in response to each release of chemical energy. A well tool actuator which can be actuated multiple times may include multiple portions of a gas generating reactive material, and a piston to which pressure is applied due to generation of the gas.

Systems, tools, and methods are disclosed that utilize at least one integrated computational element to measure a property of a substance in close proximity to the substance's source. More specifically, systems, tools, and methods are presented that allow the interaction of electromagnetic radiation and the optically-processing of interacted electromagnetic radiation in proximity to an emergence of a fluid from the fluid's source. The integrated computational elements optically-process the interacted electromagnetic radiation into a weighted optical spectrum. The weighted optical spectrum enables the determination of various chemical or physical characteristics of the fluid.

A method of mud logging is disclosed which the chemical constituents and concentrations of formation fluid are calculated based on pulse power plasma parameters and the constituent species and concentrations of drilling mud, including reaction products, upon which the pulse power plasma has acted. Based on correlation between pulse power plasma parameters, including drilling parameters, drilling can be optimized for identified formation and formation fluid species. An offset between the chemical makeup of the drilling mud exposed to pules power plasma and the chemical makeup of formation fluid is calculated. Based on the calculated offset, pulse power plasma drilling can be controlled as a function of drilling mud concentration including in other wellbores in the formation or field.

Methods and systems including a photodetector of a downhole tool for performing downhole operations are provided herein. The photodetector includes a housing configured along a carrier disposed downhole within a borehole and a graphene tunneling photodetector located within the housing configured to perform a downhole operation.

Systems, devices, and techniques for determining downhole fluid contamination are disclosed. In one or more embodiments, phase-related properties are measured for a reservoir fluid having a determined composition. An equation-of-state (EOS) is selected and/or tuned based, at least in part, on the measured phase-related properties and the tuned EOS is applied to estimate fluid property values for a reference fluid over specified ranges of at least two thermodynamic properties. Contaminant reference data are generated that correlate the estimated fluid property values for the reference fluid with respective contaminant levels. Within a wellbore, a fluid sample is analyzed to determining a fluid property values. A contaminant level is identified that corresponds within the contaminant reference data to the determined fluid property value of the fluid sample.

A method for sampling a downhole formation fluid includes pumping formation fluid into the flowline of a downhole sampling tool While pumping, a saturation pressure of the formation fluid is measured. The pumping rate is adjusted such that the fluid pressure in the flowline remains above a threshold saturation pressure.