An apparatus for measuring a viscosity of a fluid is disclosed. The apparatus includes a Parylene coated quartz tuning fork for immersion in the fluid and an electronic circuit to excite a vibration of the Parylene coated quartz tuning fork and measure one or more vibrational parameters of the Parylene coated quartz tuning fork. A computer processor is configured to determine a non-Newtonian viscosity from the vibration of the Parylene coated quartz tuning fork based, at least in part, on a Stokes flow hydrodynamic model. The computer processor is coupled to a memory for storing a calibration curve to determine a Newtonian viscosity of the fluid from the non-Newtonian viscosity of the fluid.

The invention relates to the technical field of oilfield exploration, and discloses a 4D quantitative and intelligent diagnosis method and system for spatio-temporal evolution of oil-gas reservoir damage types and extent. The method includes: determining a characteristic parameter characterizing reservoir damage by each of a plurality of factors based on a spatio-temporal evolution simulation equation of reservoir damage by each of the plurality of factors; and determining an effective characteristic parameter characterizing the damage extent of the reservoir based on the characteristic parameter characterizing reservoir damage rby each of the plurality of factors. The invention can quantitatively simulate the characteristic parameters of reservoir damage caused by the various factors and a total characteristic parameter of the reservoir damage. Therefore for a well without reservoir damage, performing quantitative prediction of reservoir damage and spatio-temporal deduction of damage laws is of scientific guidance significance for preventing reservoir damage, and formulating development plans for oil pools and subsequent well stimulation measures, and for a well with reservoir damage, also performing quantitative diagnosis of reservoir damage and spatio-temporal deduction of damage laws achieves optimal design of a declogging measure and improvement or restoration of oil-gas well production and water well injection capacity.

The invention relates to the technical field of oilfield exploration, and discloses a 4D quantitative and intelligent diagnosis method and system for spatio-temporal evolution of oil-gas reservoir damage types and extent. The method includes: determining a characteristic parameter characterizing reservoir damage by each of a plurality of factors based on a spatio-temporal evolution simulation equation of reservoir damage by each of the plurality of factors; and determining an effective characteristic parameter characterizing the damage extent of the reservoir based on the characteristic parameter characterizing reservoir damage rby each of the plurality of factors. The invention can quantitatively simulate the characteristic parameters of reservoir damage caused by the various factors and a total characteristic parameter of the reservoir damage. Therefore for a well without reservoir damage, performing quantitative prediction of reservoir damage and spatio-temporal deduction of damage laws is of scientific guidance significance for preventing reservoir damage, and formulating development plans for oil pools and subsequent well stimulation measures, and for a well with reservoir damage, also performing quantitative diagnosis of reservoir damage and spatio-temporal deduction of damage laws achieves optimal design of a declogging measure and improvement or restoration of oil-gas well production and water well injection capacity.

Techniques for determining rheological properties of a fluid include actuating a resonator disposed in a volume that contains a fluid sample to operate the resonator in the fluid sample at a predetermined actuation scheme; measuring at least one characteristic of the resonator based on the operation of the resonator in the fluid sample; comparing the at least one measured characteristic to a rheological model that associates characteristics of the fluid sample to one or more rheological properties; and based on the comparison, determining one or more rheological properties of the fluid sample.

Apparatuses and methods designed to allow for on-site, on-demand measurement of rheological properties of a sample are disclosed. The apparatuses and methods utilize both a visual component (e.g., a camera) to obtain information about the sample for making such rheological property determinations and an integrated electrical circuit to apply a current to the sample for also making such rheological property determinations. The application of the current is done in a manner such that a thinning behavior of the sample is unaffected. Further, the apparatuses are configured in a manner that allow them to be portable so that samples can be analyzed shortly after they are received, at a point-of-use. Various configurations and methods associated with such apparatuses are also disclosed.

There is provided a method of detecting a change of a state of a liquid comprising the steps of: •providing a liquid detection medium (12) comprising a liquid and having a plurality of anisotropic magnetic particles suspended therein; •applying a modulated magnetic field across at least a portion of the liquid detection medium (12), wherein the magnetic field induces an alignment of the magnetic particles; •introducing electromagnetic radiation (22) into the liquid detection medium (12); •detecting a variable which is modulated by the applied magnetic field, wherein the variable is associated with the interaction of the electromagnetic radiation (22) with the magnetic particles and wherein the change in the state of the liquid causes a variation in the detected variable; and •correlating the variation in the detected variable with the change in the state of the liquid.

Disclosed are systems and methods for detecting the beginning of a flush volume. A blended fluid is output by a fluid blending apparatus and pumped into a wellbore. The blended fluid transitions from a first composition to a second composition. A blending signal comprising time-varying data relating to characteristics of the blending apparatus or measured from sensors associated with the blending apparatus is received. Based on a first portion of the blending signal corresponding to the first composition, a calibration profile is generated. Based on the calibration profile and a second portion of the blending signal corresponding to the second composition, a transition indicator corresponding to a change in the blended fluid from the first composition to the second composition is determined. Based on the transition indicator, a flush signal indicating the beginning of a flush volume being output by the blending apparatus and pumped into the wellbore is generated.

An automated batch sampling drilling mud management system includes a portable mud measurement system and a communications system. The portable mud measurement system has or more measurement devices arranged to measure at least one property and/or characteristic of drilling mud; and a pumping system arranged to pump a batch sample of drilling mud from a supply of drilling mud to the one or more measurement devices. The pumping system is also able to subsequently flush the batch sample of drilling mud from the one or more measurement devices. The communications system enables bidirectional communications between the mud management system and a remote location to enable transfer of data therebetween and the exertion of control from the remote location to the mud management system.

An automated batch sampling drilling mud management system includes a portable mud measurement system and a communications system. The portable mud measurement system has or more measurement devices arranged to measure at least one property and/or characteristic of drilling mud; and a pumping system arranged to pump a batch sample of drilling mud from a supply of drilling mud to the one or more measurement devices. The pumping system is also able to subsequently flush the batch sample of drilling mud from the one or more measurement devices. The communications system enables bidirectional communications between the mud management system and a remote location to enable transfer of data therebetween and the exertion of control from the remote location to the mud management system.

A method is provided to measure viscosity of an analyte using a microfluidic piezoelectric sensor including a channel on an active area of a piezoelectric resonator substrate. The microfluidic piezoelectric sensor is driven so that the active area of the piezoelectric resonator substrate generates shear motion in a direction of shear motion displacement that is parallel with respect to a first surface of the piezoelectric resonator substrate. A high shear-rate viscosity of the analyte is determined based on a shift in resonance of the microfluidic piezoelectric sensor while driving the microfluidic piezoelectric sensor with the analyte in the channel. A low shear-rate viscosity of the analyte is determined by detecting flow of the analyte through the channel based on tracking shifts in resonance of the microfluidic piezoelectric sensor. Related sensors are also discussed.