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: 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: Disclosed is a system for measuring a chemical in a subsurface formation comprising housing component traversable within the well, a guide extending down the well from a fixed location being operatively connected to the housing, a radiation source, and an optical pathway between a sample and detector wherein the detector is located at the ground surface. Also disclosed is a method for reducing long distance transmission of radiation comprising placing a radiation source in a housing, placing a housing down in a well bore, lowering a spectrometer down the well bore, and controlling movement of a spectrometer by a guide wire controller at the ground surface. Further disclosed is a method of radiating a sample comprising, transmitting the radiation through at least one optical pathway, interacting a sample with the radiation, producing characteristic radiation from the sample, and transmitting by an optical pathway to a detector located in a spectrometer.

Abstract: Well fluids in coalbed natural gas reservoirs and other carbonaceous reservoirs are analyzed to determine production factors such as gas content, critical desorption pressure, and/or other reservoir and operational variables. In particular, the partial pressure of methane or a predictor substance, or a methane concentration, are measured and/or determined for the wells and production factors are determined therefrom.

Abstract: A measuring system for in-situ measurements down a well (1) by a spectrometer (4) is provided. The spectrometer (4) includes a radiation source (5) and a detector (6). A probe (15) optically connected to the spectrometer (4) and includes an optical pathway (7) for transmission of a radiation from the radiation source (5) and at least a second optical pathway for transmission of a characteristic radiation from a sample to the detector (6). A positioner is provided to position the probe (15) near a side surface (11) of the borehole (3) and to optically couple the optical pathways (7) to the side surface (11), wherein the probe (15) is traversable up and down the well (1) by way of a guide operatively connected to the probe (15) and to a fixed location at the wellhead. By use of the apparatus and method a concentration of methane or other substance of interest is obtained, and thereby, a potential production of a coal bed methane formation is obtained.