Abstract: A method for continuous pressure swing adsorption separation of a pressurized feed gas stream, including separating hydrocarbons heavier than methane from the pressurized feed gas stream by applying an adsorbent porous material to produce at least two product streams, a first product stream being substantially pure methane suitable for transport by natural gas pipeline, and a second product stream being substantially comprised of components with a greater molecular weight than methane.

Abstract: A method for continuous pressure swing adsorption separation of a pressurized feed gas stream, including separating hydrocarbons heavier than methane from the pressurized feed gas stream by applying an adsorbent porous material to produce at least two product streams, a first product stream being substantially pure methane suitable for transport by natural gas pipeline, and a second product stream being substantially comprised of components with a greater molecular weight than methane.

Abstract: A method for continuous pressure swing adsorption separation of a pressurized feed gas stream, including separating hydrocarbons heavier than methane from the pressurized feed gas stream by applying an adsorbent porous material to produce at least two product streams, a first product stream being substantially pure methane suitable for transport by natural gas pipeline, and a second product stream being substantially comprised of components with a greater molecular weight than methane.

Abstract: A method for continuous pressure swing adsorption separation of a pressurized feed gas stream, including separating hydrocarbons heavier than methane from the pressurized feed gas stream by applying an adsorbent porous material to produce at least two product streams, a first product stream being substantially pure methane suitable for transport by natural gas pipeline, and a second product stream being substantially comprised of components with a greater molecular weight than methane.

Abstract: A method for optimizing a well production forecast includes inputting into a computer: initial production rate measurements and probability distributions to estimate production forecast model parameters. The computer generates an initial forecast of fluid production rates and total produced fluid volumes using a selected production forecast model. After a selected time, the initial forecast is compared with actual production rate and total produced fluid volume measurements to generate an error measurement. Parameters of the selected production forecast model are adjusted to minimize the error measurement, thereby generating an adjusted production forecast model. The parameter adjustment and error measurement are repeated for a plurality of iterations to generate a plurality of production forecast models each having a determined likelihood of an error measurement. The plurality of production forecast models are displayed with respect to likelihood of error.

Abstract: Methods and systems for continuous pressure swing adsorption separation of a pressurized feed gas stream, the method including separating hydrocarbons heavier than methane from the pressurized feed gas stream to produce at least two product streams, a first product stream being substantially pure methane, and a second product stream being substantially comprised of components with a greater molecular weight than methane.

Abstract: The present disclosure pertains to methods of capturing CO2 from an environment at pressures above 1 bar by associating the environment with a porous material that has a surface area of at least 2,800 m2/g, and a total pore volume of at least 1.35 cm3/g, where a majority of pores of the porous material have diameters of less than 2 nm. The present disclosure also pertains to methods for the separation of CO2 from natural gas in an environment at partial pressures of either component above 1 bar by associating the environment with a porous material that has a surface area of at least 2,200 m2/g, and a total pore volume of at least 1.00 cm3/g, where a majority of pores of the porous material have diameters of greater than 1 nm and less than 2 nm.

Abstract: Methods and systems for continuous pressure swing adsorption separation of a pressurized feed gas stream, the method including separating hydrocarbons heavier than methane from the pressurized feed gas stream to produce at least two product streams, a first product stream being substantially pure methane, and a second product stream being substantially comprised of components with a greater molecular weight than methane.

Abstract: The present disclosure pertains to materials for CO2 adsorption at pressures above 1 bar, where the materials include a porous material with a surface area of at least 2,800 m2/g, and a total pore volume of at least 1.35 cm3/g, where a majority of pores of the porous material have diameters of less than 2 nm as measured from N2 sorption isotherms using the BET (Brunauer-Emmett-Teller) method. The present disclosure also pertains to materials for separation of CO2 from natural gas at partial pressures of either component above 1 bar, where the materials include a porous material with a surface area of at least 2,200 m2/g, and a total pore volume of at least 1.00 cm3/g, where a majority of pores of the porous material have diameters of greater than 1 nm and less than 2 nm as measured from N2 sorption isotherms using the BET method.

Abstract: A method for determining an optimum spacing of seismic energy sources based on mutual admittance includes deploying a plurality of seismic energy sources along a source line, separated by a selected spacing. Seismic receivers are deployed along a receiver line orthogonal to the source line. Seismic energy is simultaneously transmitted from each of the plurality of seismic energy sources while recording signals from the seismic receivers. The transmitting and recording of signals is repeated for a plurality of different spacings between the energy sources. Seismic energy in the recorded signals is determined in separate time windows selected to represent reflected body wave signal, and source generated ground roll noise, respectively. A signal-to-noise ratio with respect to the spacing of the seismic energy sources is calculated and the optimum spacing between energy sources is selected based on the signal-to-noise ratio.

Abstract: A method for seismic surveying includes deploying a group of vertically sensitive seismic particle motion responsive sensors at each of a plurality of geodetic survey positions. The groups each include at least two sensors spaced apart by a first selected horizontal distance. The groups are separated from each other by a second selected distance larger than the first distance. Signals detected by each of the sensors resulting from actuation of a seismic energy source are recorded. At least one of an in-line and a cross-line component of a gradient of the vertical component of the seismic wavefield is determined at each group location by determining a difference between the signals detected by each sensor in a respective group.

Abstract: The present disclosure pertains to methods of capturing CO2 from an environment at pressures above 1 bar by associating the environment with a porous material that has a surface area of at least 2,800 m2/g, and a total pore volume of at least 1.35 cm3/g, where a majority of pores of the porous material have diameters of less than 2 nm. The present disclosure also pertains to methods for the separation of CO2 from natural gas in an environment at partial pressures of either component above 1 bar by associating the environment with a porous material that has a surface area of at least 2,200 m2/g, and a total pore volume of at least 1.00 cm3/g, where a majority of pores of the porous material have diameters of greater than 1 nm and less than 2 nm.

Abstract: A method for selecting core points in subsurface formations includes selecting a zone from at least one subsurface formation. At least one statistical measure of at least one petrophysical measurement with respect to position along the selected zone is calculated. A predetermined number of core points at randomly selected positions along the selected zone is selected The at least one statistical measure is calculated for the randomly selected positions. Using a Monte Carlo iteration, the positions along the selected zone are randomly reselected and the at least one statistical measure is recalculated for the randomly reselected points until the at least one statistical measure for the randomly selected points is a maximum for a user selected statistical criterion applied to the at least one statistical measure of at least one petrophysical measurement with respect to position along the selected zone.

Abstract: Methods and systems of enhanced carbon dioxide recovery from an inlet gas stream are provided, by introducing the gas stream to one or more membrane-based separation units to produce a permeate byproduct gas stream having increased concentration of carbon dioxide compared to the inlet gas stream and then introducing the permeate byproduct gas stream to one or more pressure swing adsorption units or trains to enhance recovery of hydrocarbons, such as methane, lost in the byproduct stream and to produce a substantially pure carbon dioxide stream, while minimizing process compression and eliminating process heat for process regeneration. The methods introduced herein are for enhancing product recovery by enhancing carbon dioxide recovery from gas streams with pressures greater than atmospheric conditions. Further refinement to the methods would be the introduction of hydrogen sulfide polishing units within the process to produce product that meets or exceeds sales quality specifications.

Abstract: The present disclosure pertains to materials for CO2 adsorption at pressures above 1 bar, where the materials include a porous material with a surface area of at least 2,800 m2/g, and a total pore volume of at least 1.35 cm3/g, where a majority of pores of the porous material have diameters of less than 2 nm as measured from N2 sorption isotherms using the BET (Brunauer-Emmett-Teller) method. The present disclosure also pertains to materials for separation of CO2 from natural gas at partial pressures of either component above 1 bar, where the materials include a porous material with a surface area of at least 2,200 m2/g, and a total pore volume of at least 1.00 cm3/g, where a majority of pores of the porous material have diameters of greater than 1 nm and less than 2 nm as measured from N2 sorption isotherms using the BET method.

Abstract: A method for analyzing total oil in place and fraction that is movable oil in a fine gain rock formation includes monitoring thermal extraction of hydrocarbon and non-hydrocarbon compounds from a sample of a subsurface formation by heating the sample. The heating has a selected initial temperature, and a temperature increase at a selected rate to a final temperature. The extracted hydrocarbon and non-hydrocarbon compounds are passed through a capillary column to a flame ionization detector. Types of hydrocarbon and non-hydrocarbon compounds and relative fractional amounts of each type thereof are determined from the sample by analyzing a chemical thermogram generated by the flame ionization detector.

Abstract: A method for characterizing subsurface formations penetrated by a wellbore includes accepting as input to a computer measurements of a physical parameter of the formations made over a selected axial interval of the wellbore. At least one attribute of the measurements is determined from a change in the measurements over the selected axial interval. At least one characteristic of the formations in the selected axial interval using the at least one attribute.

Abstract: A method for optimizing a well production forecast includes a) inputting initial production rate measurements made at selected times, b) inputting probability distributions to estimate production forecast model parameters, c) generating an initial forecast of fluid production rates and total produced fluid volumes using a selected production forecast model, d) at a time after a last one of the selected times, comparing the initial forecast with actual production rate and total produced fluid volume measurements to generate an error measurement, e) adjusting parameters of the selected production forecast model to minimize the error measurement, thereby generating an adjusted production forecast model, f) repeating (d) and (e) for a plurality of iterations to generate a plurality of production forecast models each having a determined likelihood of an error measurement and displaying the plurality of production forecast models with respect to likelihood of error.

Abstract: A method for seismic surveying includes deploying a group of vertically sensitive seismic particle motion responsive sensors at each of a plurality of geodetic survey positions. The groups each include at least two sensors spaced apart by a first selected horizontal distance. The groups are separated from each other by a second selected distance larger than the first distance. Signals detected by each of the sensors resulting from actuation of a seismic energy source are recorded. At least one of an in-line and a cross-line component of a gradient of the vertical component of the seismic wavefield is determined at each group location by determining a difference between the signals detected by each sensor in a respective group.

Abstract: A system for cementing a wellbore penetrating an earth formation into which a pipe extends. A cement material is positioned in the space between the wellbore and the pipe by circulated capsules containing the cement material through the pipe into the space between the wellbore and the pipe. The capsules contain the cementing material encapsulated in a shell. The capsules are added to a fluid and the fluid with capsules is circulated through the pipe into the space between the wellbore and the pipe. The shell is breached once the capsules contain the cementing material are in position in the space between the wellbore and the pipe.