The present invention relates an Integral analysis method of inter-well tracer tests, which integrates and performs continuous feedback to each of the major stage (design, operation and interpretation) allowing quantitative interpretation of these tests. It is presented as a tool to investigate the behavior of injection fluids for recovery of hydrocarbons, as well as for the dynamic characterization of reservoirs. The main advantage of this invention is that it allows a greater certainty in the tracer response and a marked improvement in the sensitivity and quantitative analysis of the test results, since the curves fit both with mathematical models and numerical models. Another outstanding attraction of this invention is the reduction in the costs of testing such applications.

The present disclosure relates to methods and apparatus for determining a viscosity-pressure profile of downhole fluid by measuring the viscosity at several different pressures during a sampling operation. According to certain embodiments, the viscosity may be measured at different times during a sampling operation and used to generate the viscosity-pressure profile. For example, the viscosity may be measured at the beginning of pumping, during filling of a sample chamber, during a pressure-build up period, and while retracting the probe. The measured viscosities may then be employed to determine a profile that represents the change in viscosity that occurs with pressure.

A full petrophysical rock characterization of a rock sample in a single workflow uses a separator containing two immiscible fluids. The fluids form a fluid interface. A video camera monitors the height of the fluid interface. Current electrodes and potential electrodes are electrically connected to the rock sample. An impedance meter makes measurements across the current electrodes and the potential electrodes. A tubing is attached to one end of the rock sample and to one end of the separator and transports one of the immiscible fluids therebetween. Another tubing is attached to the other end of the rock sample and to the separator and transports the other immiscible fluid therebetween. Yet another tubing transports an immiscible mixture of the immiscible fluids from the rock sample to the separator. Pressure gauges measures the pressures in the tubings. Pumps are disposed inline with the certain tubings.

A full petrophysical rock characterization of a rock sample in a single workflow uses a separator containing two immiscible fluids. The fluids form a fluid interface. A video camera monitors the height of the fluid interface. Current electrodes and potential electrodes are electrically connected to the rock sample. An impedance meter makes measurements across the current electrodes and the potential electrodes. A tubing is attached to one end of the rock sample and to one end of the separator and transports one of the immiscible fluids therebetween. Another tubing is attached to the other end of the rock sample and to the separator and transports the other immiscible fluid therebetween. Yet another tubing transports an immiscible mixture of the immiscible fluids from the rock sample to the separator. Pressure gauges measures the pressures in the tubings. Pumps are disposed inline with the certain tubings.

System and methods of simulating fluid production in a multi-reservoir system with a common surface network are presented. An equation of state (EOS) characterization of fluids is matched with a delumped EOS model representing different components of the fluids for each reservoir within the multi-reservoir system. Fluid production in the multi-reservoir system is simulated for at least one simulation point in the common surface network, based in part on the delumped EOS model for each reservoir. If the fluids produced during the simulation at the simulation point are mixed fluids from different reservoirs, one or more interpolation tables representing the mixed fluids are generated and properties of the mixed fluids are calculated based on the generated interpolation tables. Otherwise, the properties of the fluids are calculated using the delumped EOS model corresponding to the reservoir from which the fluids are produced.

The present invention includes systems and methods for a continuous-wave (CW) radar system for detecting, geolocating, identifying, discriminating between, and mapping ferrous and non-ferrous metals in brackish and saltwater environments. The radar system (e.g., the CW radar system) generates multiple extremely low frequency (ELF) electromagnetic waves simultaneously and uses said waves to detect, locate, and classify objects of interest. These objects include all types of ferrous and non-ferrous metals, as well as changing material boundary layers (e.g., soil to water, sand to mud, rock to organic materials, water to air, etc.). The radar system (e.g., the CW radar system) is operable to detect objects of interest in near real time.

The present invention includes systems and methods for a continuous-wave (CW) radar system for detecting, geolocating, identifying, discriminating between, and mapping ferrous and non-ferrous metals in brackish and saltwater environments. The radar system (e.g., the CW radar system) generates multiple extremely low frequency (ELF) electromagnetic waves simultaneously and uses said waves to detect, locate, and classify objects of interest. These objects include all types of ferrous and non-ferrous metals, as well as changing material boundary layers (e.g., soil to water, sand to mud, rock to organic materials, water to air, etc.). The radar system (e.g., the CW radar system) is operable to detect objects of interest in near real time.

A method of estimating an influx profile for at least one well fluid to a producing petroleum well with two or more influx zones or influx locations to a production flow, wherein the well comprises tracer sources with distinct tracer materials in known levels of the well, at least one of said tracer sources arranged downstream and exposed to the fluids in at least one of said influx zones, wherein each said tracer source has an even release rate to said well fluid, characterised in that one or more of the tracer sources is provided in one or more delay chambers for ventilating out fluid with leaked tracer material at a time constant which is significantly longer than the diffusion rate from the tracer source to the well fluid, wherein the method further comprises: providing samples, the samples collected from the production flow at a location downstream of the tracer sources during a time period in which the tracer transient is detectable at the downstream location, analysing said samples for concentration and type of tracer material from said possible tracer sources as a function of sampling time or cumulative produced volume; and based on said measured concentrations and their sampling time or cumulative produced volume, calculating said influx volumes.

A method of estimating an influx profile for at least one well fluid to a producing petroleum well with two or more influx zones or influx locations to a production flow, wherein the well comprises tracer sources with distinct tracer materials in known levels of the well, at least one of said tracer sources arranged downstream and exposed to the fluids in at least one of said influx zones, wherein each said tracer source has an even release rate to said well fluid, characterised in that one or more of the tracer sources is provided in one or more delay chambers for ventilating out fluid with leaked tracer material at a time constant which is significantly longer than the diffusion rate from the tracer source to the well fluid, wherein the method further comprises: providing samples, the samples collected from the production flow at a location downstream of the tracer sources during a time period in which the tracer transient is detectable at the downstream location, analysing said samples for concentration and type of tracer material from said possible tracer sources as a function of sampling time or cumulative produced volume; and based on said measured concentrations and their sampling time or cumulative produced volume, calculating said influx volumes.

A stud finder and template system are provided. The system has a template, and a stud finder. The template aligns with a corner of a window frame and has multiple evenly spaced holes. The stud finder has a housing, a handle, and a pin. A method of determining a location for a curtain bracket with the stud finder and template system is also provided. The template is positioned against a window frame. The stud finder is positioned against a hole in the template. The stud finder handle is depressed. A stud finder for use with a template is also provided. The stud finder has a front housing portion, a rear housing portion, an actuator handle, a pin, and a pin return spring.