The present disclosure relates to a crude oil parameter detection device, which includes a liquid cavity constituted by a first housing, a flow measurement cavity constituted by a second housing, a detection cavity constituted by a third housing, and a processing module; the flow measurement cavity is in-built in the liquid cavity; the first housing includes a first liquid inlet and a first liquid outlet; the second housing includes a second liquid inlet and a second liquid outlet; the second liquid outlet is in communication with the first liquid outlet through a liquid outlet pipeline; a float assembly is in-built in the flow measurement cavity, which includes a float and a float connection rod integrally connected with the float, and an end of the float connection rod is connected to a detection part; the detection cavity at least internally comprises a position detection module; the position detection module detects a position of the detection part at the end of the float connection rod to obtain a float height detection signal; and the processing module calculates a flow rate of measured crude oil according to the float height detection signal. The present disclosure can safely meter the crude oil flow rate of a crude oil transport pipeline and meet the accuracy of metering the crude oil.

A multi-pump integrated mixed fluid delivery device includes a hollow cylindrical casing, a hydraulic drive part, a power part, a sample part and a pipeline unit. The hydraulic drive part, the power part, the sample part and the pipeline unit are provided within the casing in sequence. The hydraulic drive part includes multiple hydraulic plunger pumps. The power part includes a dual-shaft motor, wherein an output shaft of the dual-shaft motor is connected with the hydraulic plunger pumps. The sample part includes a lead screw, a screw nut, a piston rod and a sample chamber, wherein one end of the lead screw is connected with another output shaft of the dual-shaft motor, the screw nut is sleeved on the lead screw, the piston rod is fixedly connected with the screw nut. The sample chamber is configured to accommodate a sample.

A shale shaker system. The system includes a fluid transport pipe configured to receive a stream of drill cuttings and fluid returns from a wellbore during a drilling operation; an analysis module configured to receive at least a portion of the stream of drill cuttings and fluid returns at an inlet; a cuttings chute configured to receive at least a portion of the stream of drill cuttings and fluid returns from an outlet of the container, and deliver them to a screen box; and one or more screens for filtering drill cuttings from the fluid returns. The analysis module comprises logging sensors configured to operate while drill cuttings are moving through the system. The logging sensors communicate with a processor to determine characteristics of the drill cuttings in real time. A method for analyzing drill cuttings at a well site is also provided.

A shale shaker system. The system includes a fluid transport pipe configured to receive a stream of drill cuttings and fluid returns from a wellbore during a drilling operation; an analysis module configured to receive at least a portion of the stream of drill cuttings and fluid returns at an inlet; a cuttings chute configured to receive at least a portion of the stream of drill cuttings and fluid returns from an outlet of the container, and deliver them to a screen box; and one or more screens for filtering drill cuttings from the fluid returns. The analysis module comprises logging sensors configured to operate while drill cuttings are moving through the system. The logging sensors communicate with a processor to determine characteristics of the drill cuttings in real time. A method for analyzing drill cuttings at a well site is also provided.

A method for analyzing a drilling fluid receiving a drilling fluid sample from a flow of the drilling fluid at a surface of a borehole being drilled in a subterranean formation and extracting, using a gas extraction and sampling system, a dissolved gas from the drilling fluid sample. The method includes determining, using a gas chromatograph, a concentration over time of at least one chemical species of a dissolved gas from the drilling fluid sample and generating an area per concentration curve based on the concentration over time. The method includes determining, using a gas extraction and sampling system, at least one concentration value of the at least one chemical species of the dissolved gas from the drilling fluid sample and correcting bias caused by the gas extraction and sampling system, wherein correcting the bias comprises modifying the at least one concentration value based on the area per concentration curve.

Embodiments include a core plug holding apparatus including a tubular member configured to be inserted into a side pocket of a mandrel, the tubular member having an uphole end, a downhole end, and a core plug section located between the uphole end and the downhole end, wherein the core plug section is used for housing of one or more core plug samples and wherein tubular member includes one or more orifices formed in the core plug section. Embodiments include a method of sampling a well including deploying one or more core plug holding apparatuses into one or more side pocket mandrels of a completion; holding the one or more core plug holding apparatuses in the one or more side pocket mandrels for an incubation period; and retrieving the one or more core plug holding apparatuses from the one or more side pocket mandrels after the passage of the incubation period.

A method for controlling corrosion is described. The method includes determining a concentration of a first gas in a first formation, determining a concentration of a second gas different than the first gas in a second formation, determining a ratio between the first gas and the second gas, comparing the determined ratio to a threshold ratio of the first gas to the second gas for the wellbore which reduces a corrosion rate within the wellbore, and based on a result of comparing the determined ratio to the threshold ratio, modifying a quantity of the first formation fluid or the second formation fluid flowed into the wellbore. The first gas and the second gas mix within the wellbore.

A mobile coiled tubing rig and method for obtaining samples from a formation. The rig having a carrier, a coiled tubing reel positioned on the carrier, a mast pivotally mounted on the carrier, a coiled tubing injector mounted on the mast, at least one wrench for connecting components to the coiled tubing and to each other to form the bottom hole assembly. The rig is operable to perform earth coring operations and/or reverse circulation drilling to obtain samples of a formation for analysis.

The apparatus may include a tool conveyed by a conveyance device. The tool has a body with a load bearing section, an outer surface defined by a diameter, a rotational axis, and a channel in the body extending from an opening at the outer surface. At least a part of the channel is inclined relative to the rotational axis of the body at the axial location of the opening in the body. The apparatus also includes at least one functional element disposed in the channel; and a conduit operatively connected to the at least one functional element transferring at least one of: (i) energy, (ii) a signal, (iii) a fluid, (iv) and formation material. Alternatively, the apparatus includes at least one self-contained functional element disposed in the channel.

A water sampling assembly for sampling water within a groundwater production well includes a primary pump and a water sampler. The primary pump is positioned within the groundwater production well. Additionally, the primary pump defines at least a portion of an annulus between the primary pump and one of the support casing and the well screen. The water sampler is configured to obtain a plurality of water samples from the groundwater production well without removal of the water sampler from the groundwater production well. Additionally, the water sampling assembly can further include a flow detection assembly that is conjoined with the water sampler within a single jacket to form a conjoined system. The flow detection assembly is configured to detect a flow, i.e. a dynamic flow and/or an ambient flow, of the water within the groundwater production well.