Baker Hughes Corporation

C Mitch Means

Joseph L Stark

Christopher T Gallagher

Kristopher T Kohl

David H Green

Thomas H Lopez

Vladimir Jovancicevic

Jaedong Lee

Paul Hammonds

Guy Vachon

Michael James Ponstingl

Chee M Chok

Brian L Thigpen

Garabed Yeriazarian

Clark Sann

Xin Liu

John L Przybylinski

James Kevyn Smith

J Kevyn Smith

Mingdong Yuan

A system and method for supplying an additive into a well is disclosed that includes estimating injection rates for the additives and setting of one or more fluid flow control devices in the well based on a computer model. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.

Apparatus and method for managing supply of additive at wellsites

A system is provided that monitors at the wellsite injection of additives into formation fluids recovered through wellbores and controls the supply of such additives from remote locations. The selected additive is supplied from a source at the wellsite into the wellbore via a suitable supply line. A flow meter in the supply line measures the flow rate of the additive through the supply line and generates signals representative of the flow rate. A controller at the wellsite determines the flow rate from the flow meter signals and in response thereto controls the flow rate of the additive to the well. The wellsite controller interfaces with a suitable two-way communication link and transmits signals and data representative of the flow rate and other parameters to a second remote controller. The remote controller transmits command signals to the wellsite controller representative of any change desired for the flow rate.

Closed loop additive injection and monitoring system for oilfield operations

Disclosed is a method of reducing drag in a fluid stream. The method includes admixing the components of a drag reducer to form an incipient drag reducer and injecting the incipient drag reducer into the fluid stream wherein the drag reducer components are admixed at the site of the fluid stream.

Method for introducing drag reducers into hydrocarbon transportation systems

Disclosed is a method for transporting blended crude oils comprising the steps of; (a) admixing a first crude oil with a second, different crude oil to form a crude oil admixture; (b) determining a first value representing the content of unprecipitated asphaltenes in the admixture; (c) holding the admixture for a period of time at standard conditions; (d) determining a second value representing the content of unprecipitated asphaltenes in the admixture; and (e) either: (i) transporting the admixture if the second value is the same as or within a predetermined range of the first value; or (ii) taking remedial action to prevent asphaltene precipitation prior to transporting if the second value is outside a predetermined range from the first value. Also disclosed is a method for estimating the storage stability of stored crude oils and crude oil admixtures.

Method for storing and transporting crude oil

Real time determination of the presence of emulsion in a formation fluid is accomplished using an optical probe, preferably an attenuated total reflectance probe. The determination can then be used to appropriately increase, decrease or leave unchanged the use of demulsification additives or other means to control emulsion formation. The method is particularly useful for free water knock-out separations, where a plurality of probes can be used to distinguish the location and/or volume of emulsion, or 'rag', layer and thereby to facilitate decantation of relatively pure oil and water fractions. It can also be effectively used in pipelines, and can optionally determine the degree of emulsification and trends toward emulsification or demulsification.

Real-time on-line sensing and control of emulsions in formation fluids

The present invention provides a method and system for controlling mineral scale deposition from a formation fluid. The rate at which scaling is occurring is measured in real time using an attenuated total reflectance probe and a photometer. The results are then used to determine whether to increase, decrease or leave unchanged addition of anti-scaling additives.

Real-time on-line sensing and control of mineral scale deposition from formation fluids

A system is provided that monitors at the wellsite injection of additives into formation fluids recovered through wellbores and controls the supply of such additives from remote locations. A pump supplies the selected additive from a source at the wellsite into the wellbore via a suitable supply line. A flow meter in the supply line measures the flow rate of the additive through the supply line and generates signals representative of the flow rate. A controller at the wellsite determines the flow rate from the flow meter signals and in response thereto controls the pump to control the flow rate of the additive to the well. The wellsite controller interfaces with a suitable two-way communication link and transmits signals and data representative of the flow rate, and other parameters to a second remote controller. The remote controller transmits command signals to the wellsite controller representative of any change desired for the flow rate. The wellsite controller is microprocessor based and may be programmed at the wellsite or by the remote controller to adjust the flow rate. The system of the present invention may be configured for multiple wells, with each well having a separate wellsite controller or a common wellsite controller.

A system for monitoring gas carry-under of a formation fluid exiting a gas separator by measuring a parameter of interest of the formation fluid exiting the gas separator is disclosed. The parameter of interest that can be correlated with the extent of gas entrained in the formation fluid exiting the separator can be the density of the formation fluid, or an absorbance spectrum of the formation fluid. A correlation of the measurement of the parameter of interest with a level of gas carry-under is made and a signal is transmitted to a device to control the supply of at least one additive to control the gas carry-under.

Gas carry-under monitoring and control system

The present invention provides a system that monitors and controls the precipitation of asphaltenes in a formation fluid recovered from a subsurface formation or reservoir by using a sensor to make a direct real-time on-site measurement of the relative concentration asphaltenes from at least one location at a wellsite or in a pipeline. In a system including a fiber optic attenuated total reflectance probe for sensing asphaltenes and using a processor to compare sequential measurements, the system of the present invention can trigger the addition of additives in response to a change in asphaltene concentration in the formation fluid, preventing precipitation.

Asphaltenes monitoring and control system

A system for monitoring foaming or carry over, at a well site, of a formation fluid by taking a sample of the gas exiting from a high-pressure separator and either measuring the density of the sample or measuring the amount of oil particles present. A correlation of the density or optical density with a level of foaming is made and a signal is transmitted to a device to control the supply of at least one additive to control the foaming.

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Richmond, TX, United States of America

C Mitch Means