Saudi Arabian Oil Company

Pan Luo

Peng Lu

Khaled Arouri

Moemen A Abdelrahman

Abdulbari N Alhayaf

Harald Karg

Rabah Mesdour

Ibrahim Alfraih

Methods and systems for determining an estimated reservoir property using a determined desorption stage are disclosed. The method includes determining a fluid property and composition of a first fluid sample obtained from a reservoir, determining a measured relative volume of gas components and isotope ratios of gas components of the sample, and determining an equation of state. The method also includes obtaining a second and third sample at two later times, determining a composition, a measured relative volume of gas components, and isotope ratios of gas components of the later samples, and calibrating the equation of state utilizing the fluid composition and measured relative volume of gas components. The method further includes predicting a relative volume of gas components from the equation of state, determining a desorption stage, determining a critical pressure, an extent of desorption and a quantity of produced desorbed gas and determining the estimated reservoir property.

Integrated time-lapse gas geochemistry and equation of state modeling for evaluating desorbed gas in production

Systems and methods for identifying natural hydrogen sweet spots in a subsurface formation include obtaining rock samples from the subsurface formation; performing pyrolysis of the rock samples to determine an amount of hydrogen generated in the rock samples; determining kinetic parameters based on the performed pyrolysis and a thermal history of the subsurface formation; simulating hydrogen generation in the subsurface formation based on the determined kinetic parameters and the thermal history to predict target maturity data for hydrogen richness in the subsurface formation; measuring total organic content and rock sample maturity data for the rock samples; and identifying hydrogen sweet spots in the subsurface formation based on the target maturity data, the total organic content, and the measured rock sample maturity data.

Identifying hydrogen sweet spots in subsurface formations

Methods of the present disclosure may include obtaining an origin fluid having a calcium concentration of about 1.5 M or greater. A treatment fluid may be created by introducing an amount of slaked lime to the origin fluid to change a pH of the resulting treatment fluid to about 11 or greater. The treatment fluid may be introduced into a subterranean formation containing a formation gas comprising natural gas and carbon dioxide. The calcium in the treatment fluid may be allowed to react with the carbon dioxide within the subterranean formation to form calcite. The treated formation gas may be removed from the subterranean formation after the formation of calcite, wherein the concentration of carbon dioxide in the treated formation gas is lower than the formation gas before it was contacted with the treatment fluid.

Methods for removing carbon dioxide from natural gas

A method for evaluating thermal reactivity in source rock evaluation may include obtaining information relating to various source rock samples. The method may include determining reactivities of source rocks corresponding to the various source rock samples. The source rocks may be at a same level of thermal maturity in an area of interest. The method may include interpreting kinetic parameters derived from the plurality of source rock samples. The method includes comparing published, archived and measured kinetic parameters of source rocks in the area of interest. The method may include converting complex format of kinetic parameters into a single variable for reactivity for evaluation and characterization of source rock in the area of interest.

Method and system for evaluating reactivity in source rock evaluation

A method for ranking thermal reactivities for kinetics assignment in basin modeling may include obtaining information relating to various source rock samples. The method may include determining thermal reactivities of source rocks corresponding to the various source rock samples. The source rocks are at a same level of thermal maturity in an area of interest. The method may include ranking the thermal reactivities at different thermal maturities. The method includes comparing published, archived and measured kinetic parameters of source rocks in the area of interest. The method may include sorting kinetic parameters in organofacies of a source rock formation in terms of reactivity and maturity. The method may include assigning kinetic parameters derived from an immature source rock unit to mature source rock units in a source rock formation in a sedimentary basin. The method may include evaluating the reactivities to improve selection and assignment of the kinetic parameters in the basin modeling.

Method and system for ranking reactivities for kinetics assignment in basin modeling

Embodiments provide a method for evaluating a hydrocarbon-bearing formation. The method includes the step of identifying a hydrocarbon sweet spot. The identifying step includes determining a carbon dioxide content of a gas sample retrieved from the hydrocarbon-bearing formation. The identifying step includes determining an isotopic signature of carbon dioxide of the gas sample. The carbon dioxide content of the gas sample retrieved from the hydrocarbon sweet spot can have a mole percentage ranging from 9 percent to 20 percent. The isotopic signature of carbon dioxide of the gas sample retrieved from the hydrocarbon sweet spot can have a &#x3b4;C value greater than &#x2212;10 per mil. The identifying step can further include determining a cutoff range of the carbon dioxide content corresponding to the hydrocarbon sweet spot. The cutoff range can have a mole percentage ranging from 9 percent to 20 percent. The identifying step can further include obtaining a gas flow rate of the hydrocarbon-bearing formation. The gas flow rate can be greater than 10 million standard cubic feet per day.

Growing community of inventors

Dhahran, Saudi Arabia

Pan Luo