Esteramine compositions and their derivatives are disclosed. The esteramines comprise a reaction product of a metathesis-derived C.sub.10-C.sub.17 monounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives with a tertiary alkanolamine. Derivatives made by quaternizing, sulfonating, alkoxylating, sulfating, and/or sulfitating the esteramines are also disclosed. In one aspect, the ester derivative of the C.sub.10-C.sub.17 monounsaturated acid or octadecene-1,18-dioic acid is a lower alkyl ester. In other aspects, the ester derivative is a modified triglyceride made by self-metathesis of a natural oil or an unsaturated triglyceride made by cross-metathesis of a natural oil with an olefin. The esteramines and derivatives are valuable for a wide variety of end uses, including cleaners, fabric treatment, hair conditioning, personal care (liquid cleansing products, conditioning bars, oral care products), antimicrobial compositions, agricultural uses, and oil field applications.

A method of selecting an injectate for recovering liquid hydrocarbons from a reservoir includes designing a plurality of injectates, calculating a net present value of each injectate, and selecting a candidate injectate based on the net present value. For example, the candidate injectate may be selected to maximize the net present value of a waterflooding operation.

A method of selecting an injectate for recovering liquid hydrocarbons from a reservoir includes designing a plurality of injectates, calculating a net present value of each injectate, and selecting a candidate injectate based on the net present value. For example, the candidate injectate may be selected to maximize the net present value of a waterflooding operation.

The present invention relates to a method of storing CO.sub.2 in a geological formation, said method comprising (i) injecting a first composition comprising CO.sub.2 into said formation; and (ii) injecting a second composition comprising CO.sub.2 and at least one CO.sub.2 soluble polymer into said formation, wherein steps (i) and (ii) are performed separately and in any order and wherein said first and second compositions are different.

The present invention relates to a method of storing CO.sub.2 in a geological formation, said method comprising (i) injecting a first composition comprising CO.sub.2 into said formation; and (ii) injecting a second composition comprising CO.sub.2 and at least one CO.sub.2 soluble polymer into said formation, wherein steps (i) and (ii) are performed separately and in any order and wherein said first and second compositions are different.

Quaternary ammonium, betaine, or sulfobetaine compositions derived from fatty amines, wherein the fatty amine is made by reducing the amide reaction product of a metathesis-derived C.sub.10-C.sub.17 monounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives and a secondary amine, are disclosed. Quaternary ammonium, betaine, or sulfobetaine compositions derived from fatty amidoamines, wherein the amidoamine is made by reacting of a metathesis-derived C.sub.10-C.sub.17 monounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives and an aminoalkyl-substituted tertiary amine, are also disclosed. The quaternized compositions are advantageously sulfonated or sulfitated. In one aspect, the ester derivative of the C.sub.10-C.sub.17 monounsaturated acid or octadecene-1,18-dioic acid is a lower alkyl ester. In other aspects, the ester derivative is a modified triglyceride made by self-metathesis of a natural oil or an unsaturated triglyceride made by cross-metathesis of a natural oil with an olefin. The quaternary ammonium, betaine, and sulfobetaine compositions and their sulfonated or sulfitated derivatives are valuable for a wide variety of end uses, including cleaners, fabric treatment, hair conditioning, personal care (liquid cleansing products, conditioning bars, oral care products), antimicrobial compositions, agricultural uses, and oil field applications.

Methods of wellbore cementing are provided. A method of generating a wellbore treatment fluid may include: classifying a plurality of solid particulates using correlations; calculating a reactive index and/or a water requirement for at least one of the solid particulates; and selecting two or more solid particulates from the plurality of solid particulates to create a wellbore treatment fluid.

Production chemicals and methods of selecting the production chemicals based on Hansen Solubility Parameters (HSP) are disclosed. The production chemicals selected by the methods mitigate or reduce one or more issues or problems associated with oil and gas productions and transportations. The methods measure HSP values for the production chemicals and/or crude oil and select at least one production chemical for at least one application on the crude oil based on the HSP values of the production chemicals and the crude oil.

An apparatus and methods for characterizing and communicating chemical tracer presence in a subterranean formation traversed by a wellbore including collecting fluid from the wellbore at a wellhead, analyzing the fluid for the presence or concentration or both of the tracer using a gas chromatograph connected to a line collecting the fluid from the wellhead, and communicating the gas chromatograph analysis information within 24 hours of analyzing the fluid. In some embodiments, the tracing chemical is a perfluorocarbon. In some embodiments, the collecting fluid is continuous. Some embodiments condition a flow of fluid. Some embodiments control the collecting, analyzing, and communicating using a controller that may include an autonomous system that includes a multiplex valve that controls for multiple inputs. The multiple inputs may include time, wellhead identity, calibration, signals from the gas chromatograph or the controller, or a combination thereof. Some embodiments may also analyze for the concentration of the tracing chemicals. In some embodiments, the gas chromatograph measures the fluid from the wellbore after a conditioning activity. The conditioning activity may include adjusting the fluid composition, fluid gas to liquid ratio, time between analyzing, phase separation, temperature control, pressure control, or a combination thereof. In some embodiments, the gas chromatograph has a line in direct communication with the wellbore. In some embodiments, communicating includes a transmitter to transmit a signal to a remote device.

An apparatus and method for monitoring the presence of a chemical tracer in a fluid produced from a wellbore including continuously collecting and conditioning a sample line from a wellbore, analyzing the sample line with a gas chromatograph at the wellsite, recording information from the analyzing continuously over time; and controlling the collecting, conditioning, analyzing, and recording with a process control device. In some embodiments, the process control device is a microprocessor. Some embodiments communicate information to a remote location. In some embodiments, the collecting, conditioning, analyzing, recording, and communicating occur within 10 minutes or are repeated continuously over 24 hours. Some embodiments may adjust a heater or air conditioner.

An apparatus and methods for characterizing and communicating chemical tracer presence in a subterranean formation traversed by a wellbore including collecting fluid from the wellbore at a wellhead, analyzing the fluid for the presence or concentration or both of the tracer using a gas chromatograph connected to a line collecting the fluid from the wellhead, and communicating the gas chromatograph analysis information within 24 hours of analyzing the fluid. In some embodiments, the tracing chemical is a perfluorocarbon. In some embodiments, the collecting fluid is continuous. Some embodiments condition a flow of fluid. Some embodiments control the collecting, analyzing, and communicating using a controller that may include an autonomous system that includes a multiplex valve that controls for multiple inputs. The multiple inputs may include time, wellhead identity, calibration, signals from the gas chromatograph or the controller, or a combination thereof. Some embodiments may also analyze for the concentration of the tracing chemicals. In some embodiments, the gas chromatograph measures the fluid from the wellbore after a conditioning activity. The conditioning activity may include adjusting the fluid composition, fluid gas to liquid ratio, time between analyzing, phase separation, temperature control, pressure control, or a combination thereof. In some embodiments, the gas chromatograph has a line in direct communication with the wellbore. In some embodiments, communicating includes a transmitter to transmit a signal to a remote device.

An apparatus and method for monitoring the presence of a chemical tracer in a fluid produced from a wellbore including continuously collecting and conditioning a sample line from a wellbore, analyzing the sample line with a gas chromatograph at the wellsite, recording information from the analyzing continuously over time; and controlling the collecting, conditioning, analyzing, and recording with a process control device. In some embodiments, the process control device is a microprocessor. Some embodiments communicate information to a remote location. In some embodiments, the collecting, conditioning, analyzing, recording, and communicating occur within 10 minutes or are repeated continuously over 24 hours. Some embodiments may adjust a heater or air conditioner.