Abstract: Methods, systems, and apparatuses for determining the location or depth in a wellbore of a tubular string or downhole component is provided. One method may include placing a tubular string having a depth measurement module into a wellbore, the wellbore emanating radiation at at least one location along the wellbore and determining the location of the depth measurement module in the wellbore based on a correlation between a wellbore property that is a function of depth and a radiation intensity at at least one location within the wellbore.

Abstract: A sensor package may include a sensor housing unit and a first sensor that may acquire a first set of measurements within a first measurement range. The sensor package may also include a second sensor configured to acquire a second set of measurements within a second measurement range. The first measurement range and the second measurement range may include an overlapping range used to calibrate the first set of measurements, the second set of measurements, or both.

Abstract: The service life of a packer element, an annular BOP, is estimated using one pressure sensor below the elastomer seal or two pressure sensors positioned above and below the elastomer seal. The pressure variations below the elastomer are monitored versus piston position and used to detect elastomer wear with time/pressure cycles. The pressure variations above the elastomer can be used to detect potential leakage, as well as leak characteristics such as leaking rate or leak geometry.

Abstract: Methods, systems, and apparatuses for determining the location or depth in a wellbore of a tubular string or downhole component is provided. One method may include placing a tubular string having a depth measurement module into a wellbore, the wellbore emanating radiation at at least one location along the wellbore and determining the location of the depth measurement module in the wellbore based on a correlation between a wellbore property that is a function of depth and a radiation intensity at at least one location within the wellbore.

Abstract: The service life of a packer element, an annular BOP, is estimated using one pressure sensor below the elastomer seal or two pressure sensors positioned above and below the elastomer seal. The pressure variations below the elastomer are monitored versus piston position and used to detect elastomer wear with time/pressure cycles. The pressure variations above the elastomer can be used to detect potential leakage, as well as leak characteristics such as leaking rate or leak geometry.

Abstract: Systems and methods are described for monitoring displacement on structural elements of subsea systems such as on components of a subsea pipeline network used to transport production fluid from a subsurface wellhead to surface facilities. The described techniques sense changes in displacement using a sensing blade, for example made of crystalline material such as sapphire, that is anchored to the structural element such that it is approximately perpendicular to the direction of sensed displacement. Displacement is sensed as bending of the sensing blade using one or more instruments fabricated on the blade. Robustness of design is in part provided by additional flexible non-sensing blades mounted in parallel to the sensing blade.

Abstract: Methods, systems, and apparatuses for determining the location or depth in a wellbore of a tubular string (15) or downhole component is provided. One method may include placing a tubular string (15) having a depth measurement module (102) into a wellbore, the wellbore emanating radiation at at least one location along the wellbore and determining the location of the depth measurement module (102) in the wellbore based on a correlation between a wellbore property that is a function of depth and a radiation intensity at at least one location within the wellbore.

Abstract: Systems and methods are described for non-invasively acoustically monitoring containers to distinguish gas contents from liquid contents. In some embodiments the container is part of a buoyancy tank (132) in a subsea pipeline network (102) used to transport production fluid from a subsurface wellhead (112) to surface facilities, and the systems and methods are used to detect water ingression into the buoyancy tank (132) and to transmit alert signals to the surface relating thereto.

Abstract: Systems and methods are described for monitoring displacement on structural elements of subsea systems such as on components of a subsea pipeline network used to transport production fluid from a subsurface wellhead to surface facilities. The described techniques sense changes in displacement using a sensing blade, for example made of crystalline material such as sapphire, that is anchored to the structural element such that it is approximately perpendicular to the direction of sensed displacement. Displacement is sensed as bending of the sensing blade using one or more instruments fabricated on the blade. Robustness of design is in part provided by additional flexible non-sensing blades mounted in parallel to the sensing blade.

Abstract: A system and method for determining pressure differences of a fluid flowing through a differential pressure conduit positioned in a wellbore. The system comprises a first pressure measurement circuit positioned at a first pressure measuring station and including a first pressure sensor to generate a first pressure measurement signal indicative of the pressure measured by the first pressure sensor at a first signal point, and a second pressure measurement circuit positioned at a second pressure measuring station and including a second pressure sensor to generate a second pressure measurement signal indicative of the pressure measured by the second pressure sensor at a second signal point. The calculation of the pressure differential between the first and second pressure measuring stations is based on the first and second pressure measurement signals taken or read from the first and second signal points, wherein the first and third second points are symmetrical.

Abstract: A system and method for determining pressure differences of a fluid flowing through a differential pressure conduit positioned in a wellbore. The system comprises a first pressure measurement circuit positioned at a first pressure measuring station and including a first pressure sensor to generate a first pressure measurement signal indicative of the pressure measured by the first pressure sensor at a first signal point, and a second pressure measurement circuit positioned at a second pressure measuring station and including a second pressure sensor to generate a second pressure measurement signal indicative of the pressure measured by the second pressure sensor at a second signal point. The calculation of the pressure differential between the first and second pressure measuring stations is based on the first and second pressure measurement signals taken or read from the first and second signal points, wherein the first and third second points are symmetrical.

Abstract: A flow rate device for measuring the flow rate of a fluid flowing through a wellbore is disclosed. The flow rate device includes a differential pressure conduit, a flow restrictor insert and a differential pressure measurement device. The differential pressure conduit is locatable in the wellbore, defines an internal bore, and is adapted to include a restriction having a cross-sectional area to increase the velocity of fluid flowing through the differential pressure conduit to create a differential pressure. The differential pressure conduit defining first and second pressure measuring stations axially spaced along the differential pressure conduit. The flow restrictor insert is located in the restriction to reduce the cross-sectional area of the restriction. The flow restrictor insert defines an internal bore having a cross-sectional area less than the cross-sectional area of the restriction. The flow restrictor insert also has a pressure measuring port aligned with the second pressure measuring station.

Abstract: A flow rate device for measuring the flow rate of a fluid flowing through a wellbore is disclosed. The flow rate device includes a differential pressure conduit, a flow restrictor insert and a differential pressure measurement device. The differential pressure conduit is locatable in the wellbore, defines an internal bore, and is adapted to include a restriction having a cross-sectional area to increase the velocity of fluid flowing through the differential pressure conduit to create a differential pressure. The differential pressure conduit defining first and second pressure measuring stations axially spaced along the differential pressure conduit. The flow restrictor insert is located in the restriction to reduce the cross-sectional area of the restriction. The flow restrictor insert defines an internal bore having a cross-sectional area less than the cross-sectional area of the restriction. The flow restrictor insert also has a pressure measuring port aligned with the second pressure measuring station.

Abstract: An apparatus for determining the nature of the formation at the bottom of a wellbore being drilled with a tubular drill string through which drilling fluid is pumped to return the drilling fluid to the surface via the wellbore, the apparatus comprising a tool body for installation in a drill string with a bore extending there through and an ultraviolet fluorescence detector in a passageway in the tool body, the tool body being configured to receive drilling fluid from inside the drill string and to receive drilling fluid from outside the drill string, wherein the drilling fluid can be directed past the detector so as to enable measurements to be made.

Abstract: Apparatus and method for investigating underground formations surrounding a borehole, comprises: a drill bit (28); an optical probe (30) having substantially the same outer diameter as the drill bit; a drive mechanism (22), operable to cause the drill bit to drill a hole in the formation when the apparatus is in the borehole, and to advance the optical probe into the drilled hole; and an optical system (36), arranged such that when the optical probe is in the drilled hole, light from a light source (32) is directed into the optical probe, light entering the probe from the source is directed at the formation around the drilled hole, and light entering the probe from the formation around the drilled hole is directed to a detector.

Abstract: Fluid diversion measurement systems and methods are described. One system includes a section of tubular having a main flow passage and a fluid diversion port, the section of tubular adapted to be either moving or stationary during a fluid diversion operation, at least two sensors in the section of tubular, at least one sensor located upstream of the fluid diversion port and at least one sensor located downstream of the fluid diversion port, each sensor adapted to measure a parameter of a fluid diverted into a wellbore through the fluid diversion port; and means for using the measured parameters in realtime to monitor, control, or both monitor and control diversion of the fluid. This abstract allows a searcher or other reader to quickly ascertain the subject matter of the disclosure. It will not be used to interpret or limit the scope or meaning of the claims. 37 CFR 1.72(b).

Abstract: Apparatus for optically determining the presence of carbon dioxide within a fluid, said apparatus comprising:—a light emitting source, an optical sensing probe in contact with the fluid to analyze; optical light transmitting means in order to convey the light emitted from the light emitting source to the optical sensing probe and the light reflected by the optical sensing probe to means to discriminate between wavelengths of light beams reflected by the optical sensing probe;—means to convert wavelengths discriminated light beams into measurement data indicating presence of carbon dioxide within the fluid, wherein the optical sensing probe comprises a tip working as attenuated total reflection (ATR) absorber within the infrared wavelength.

Abstract: A well for producing oil from an underground formation, comprises a vertical section extending from the surface to a depth below the oil-producing formation; a sidetrack or perforated interval (production zone) extending from the vertical section into the oil-producing formation; and a valve, located in the well, and operable to prevent flow of fluid from the vertical section into the production zone and a valve to prevent flow of fluid from the portion below the production zone into the production zone or into the vertical section above the production zone.

Abstract: A ruggedized pressure sensor is described for high pressure applications having a top part of hard material with a surface adapted to deform when exposed to pressure, transducers to transform deformation of the surface into a signal proportional to the pressure, and a base part of hard material, wherein the base part has one or more openings.

Abstract: A wellbore formation sample acquisition and analysis instrument includes an annular drill bit configured to couple to one end of a drill string. The bit defines a passageway extending from a cutting face thereof to an exterior surface at a longitudinally spaced apart position from the cutting face. The instrument includes at least one sensor configured to measure a selected parameter of a sample of subsurface formation urged into the passageway by action of the cutting face against subsurface formations. Samples of the subsurface formations are ejected from the exterior surface end of the passageway by the samples entering the cutting face end thereof.