Abstract: A method may include drilling a wellbore, the wellbore intersecting a shale formation at an interval of the shale formation and casing at least a portion of the wellbore. The method may also include perforating the casing at the interval to fluidly couple the interval and the wellbore, and liberating free and absorbed gas entrapped within the interval. In addition, the method may include solubilizing in the wellbore fluid the free and absorbed gas, forming a plume comprising solubilized gas, and determining an identity and amount of solubilized gas in the plume.

Abstract: A coal seam producibility determination system may include a fiber optic cable, the fiber optic extending from a DAS interrogation unit into a wellbore. The DAS interrogation unit may be located at a surface. The wellbore may intersect a plurality of coal seams to be measured, the coal seams comprising fluid and solubilized gas. The wellbore contains wellbore fluid and the wellbore has a wall. The fiber optic cable extends along the plurality of coal seams. The coal seam producibility determination system may further include a spectrometer, the spectrometer located at the surface or within the wellbore. The coal seam producibility determination system may also include an optical window, the optical window in optical communication with the spectrometer, the optical window in fluid communication with the wellbore fluid.

Abstract: A method may include drilling a wellbore, the wellbore intersecting a shale formation at an interval of the shale formation and casing at least a portion of the wellbore. The method may also include perforating the casing at the interval to fluidly couple the interval and the wellbore, and liberating free and absorbed gas entrapped within the interval. In addition, the method may include solubilizing in the wellbore fluid the free and absorbed gas, forming a plume comprising solubilized gas, and determining an identity and amount of solubilized gas in the plume.

Abstract: A coal seam producibility determination system is disclosed. The coal seam producibility determination system may include a fiber optic cable, the fiber optic extending from a DAS interrogation unit into a wellbore. The DAS interrogation unit may be located at a surface. The wellbore may intersect a plurality of coal seams to be measured, the coal seams comprising fluid and solubilized gas. The wellbore contains wellbore fluid and the wellbore has a wall. The fiber optic cable extends along the plurality of coal seams. The coal seam producibility determination system may further include a spectrometer, the spectrometer located at the surface or within the wellbore. The coal seam producibility determination system may also include an optical window, the optical window in optical communication with the spectrometer, the optical window in fluid communication with the wellbore fluid.

Abstract: An analytical method that establishes a thermodynamic equilibrium or known dynamic relationship between the concentrations of gases, natural gas liquids and oils or pressures of gasses in an isolated zone of a shale, or group of distinct shale gas intervals, with the concentrations of fluids or pressures of gasses in a wellbore penetrating the shale interval or intervals. An analytical method for identifying the chemical composition of gas, natural gas liquids and oils and determining their origin in an isolated zone of a shale, or group of distinct shale gas intervals with the identification of chemical composition of gas, natural gas liquids and oils in a wellbore penetrating the shale interval or intervals. A surface measurement apparatus capable of performing the measurement ex-situ. A downhole measurement apparatus capable of reliably performing the measurement in-situ and a downhole straddle-packer assembly capable of isolating part of, or an entire shale interval.

Abstract: The invention subject of this disclosure teaches a method of determining a production factor for a carbonaceous material reservoir, the method comprising: providing a well in a carbonaceous material reservoir; providing unsampled fluid at a depth in the well; placing a sensor adjacent to the unsampled fluid and performing a measurement on the unsampled fluid; using data from the measurement to determine a partial pressure of a solution gas in the carbonaceous material reservoir; and determining a production factor for the carbonaceous material reservoir from the partial pressure of the solution gas.

Abstract: The invention subject of this disclosure teaches a method of determining a production factor for a carbonaceous material reservoir, the method comprising: providing a well in a carbonaceous material reservoir; providing unsampled fluid at a depth in the well; placing a sensor adjacent to the unsampled fluid and performing a measurement on the unsampled fluid; using data from the measurement to determine a partial pressure of a solution gas in the carbonaceous material reservoir; and determining a production factor for the carbonaceous material reservoir from the partial pressure of the solution gas.

Abstract: An analytical method that establishes a thermodynamic equilibrium or known dynamic relationship between the concentrations of gases, natural gas liquids and oils or pressures of gasses in an isolated zone of a shale, or group of distinct shale gas intervals, with the concentrations of fluids or pressures of gasses in a wellbore penetrating the shale interval or intervals. An analytical method for identifying the chemical composition of gas, natural gas liquids and oils and determining their origin in an isolated zone of a shale, or group of distinct shale gas intervals with the identification of chemical composition of gas, natural gas liquids and oils in a wellbore penetrating the shale interval or intervals. A surface measurement apparatus capable of performing the measurement ex-situ. A downhole measurement apparatus capable of reliably performing the measurement in-situ and a downhole straddle-packer assembly capable of isolating part of, or an entire shale interval.

Abstract: The invention subject of this disclosure teaches a method of determining a production factor for a carbonaceous material reservoir, the method comprising: providing a well in a carbonaceous material reservoir; providing unsampled fluid at a depth in the well; placing a sensor adjacent to the unsampled fluid and performing a measurement on the unsampled fluid; using data from the measurement to determine a partial pressure of a solution gas in the carbonaceous material reservoir; and determining a production factor for the carbonaceous material reservoir from the partial pressure of the solution gas.

Abstract: The invention subject of this disclosure teaches a method of determining a production factor for a carbonaceous material reservoir, the method comprising: providing a well in a carbonaceous material reservoir; providing unsampled fluid at a depth in the well; placing a sensor adjacent to the unsampled fluid and performing a measurement on the unsampled fluid; using data from the measurement to determine a partial pressure of a solution gas in the carbonaceous material reservoir; and determining a production factor for the carbonaceous material reservoir from the partial pressure of the solution gas.

Abstract: The invention subject of this disclosure teaches a method of determining a production factor for a carbonaceous material reservoir, the method comprising: providing a well in a carbonaceous material reservoir; providing unsampled fluid at a depth in the well; placing a sensor adjacent to the unsampled fluid and performing a measurement on the unsampled fluid; using data from the measurement to determine a partial pressure of a solution gas in the carbonaceous material reservoir; and determining a production factor for the carbonaceous material reservoir from the partial pressure of the solution gas.

Abstract: A flow control device comprises a housing, a flow restriction member, and a flow control ring defining a flow control port which is configured to receive the flow restriction member. The flow control ring is configured so as to be sealingly mounted onto a base pipe. The flow restriction member is at least partially inserted into the flow control port so as to at least partially define a predetermined flow restriction through the flow control ring. The housing is sealingly mounted on the flow control ring. The flow control device may be mounted on a base pipe. The flow control device may be used for controlling fluid flow, in particular, though not exclusively in oil and/or gas wells.

Abstract: A network control unit for monitoring and controlling all of the operational components of a facility management system, the unit including a modular base frame having a wiring board assembly mounted on the back, a number of termination board assemblies mounted on the front of the frame and being operably connected to the wiring board assembly, one or more function modules, digital control modules, expansion modules, and a network control module are mounted on the front of the frame and operably connected to the wiring board assembly.