For a side pocket mandrel that has a primary flow bore and an offset side pocket, a method for installing a guide sleeve begins with the step of compressing the guide sleeve to reduce an outer diameter of the guide sleeve. The method continues with the step of inserting the guide sleeve into a section of the primary flow bore that has a first inner diameter (D1). The method continues with the steps of allowing the guide sleeve to radially expand such that the outer diameter of the guide sleeve matches the first diameter, pushing the guide sleeve further into the primary flow bore to a guide sleeve section that has a second inner diameter (D2) that is larger than the first inner diameter (D1), and allowing the guide sleeve to radially expand to capture the guide sleeve within the guide sleeve section of the primary flow bore.

A method for recording data relating to the performance of an oil and gas flow network uses statistical data to represent raw data in a compact form. Categories are assigned to time intervals in the data. The method comprises: (1) gathering data covering a period of time, wherein the data relates to the status of one or more control point(s) within the flow network and to one or more flow parameter(s) of interest in one or more flow path(s) of the flow network; (2) identifying multiple time intervals in the data during which the control points and the flow parameter(s) can be designated as being in a category selected from multiple categories; (3) assigning a selected category of the multiple categories to each one of the multiple datasets that are framed by the multiple time intervals; and (4) extracting statistical data representative of some or all of the datasets identified in step (2) to thereby represent the original data from step (1) in a compact form including details of the category assigned to each time interval in step (3).

A method for producing a well includes receiving production information associated with wells within a field; deriving a field specific model from the production information; receiving production information associated with the well; projecting production changes associated with installing artificial lift at the well at a projected date, the projecting using a production analysis engine applied to the field specific model, the projecting including determining a set of artificial lift parameters; and installing the artificial lift at the well in accordance with the artificial lift parameters.

A method is provided. Sensor data regarding a wellbore is received from at least one of a distributed fiber optic sensing line positioned along the wellbore and a plurality of subsurface and surface sensors. Flow models are generated based on the sensor data to optimize production flow. Flow profiles are generated based on the flow models and the sensor data to adjust at least one gas lift valve.

A system can include a completion string with a tubing and a dip tube secured in the tubing. A gas is injected into an annulus between the tubing and the dip tube, and the gas and well liquids flow into the dip tube. A method can include installing a completion string including a tubing, a dip tube in the tubing, and a packer downhole of a gas lift valve, and flowing a gas into the tubing via the gas lift valve, into an annulus between the tubing and the dip tube, and then into the dip tube. Another system can include a tubular connector connected between adjacent sections of the tubing, with the dip tube secured in the tubing and connected to the tubular connector. A gas flows from the gas lift valve to the annulus via a gas flow path formed in the tubular connector.

Gas and liquid velocities of fluid in a lift gas assisted well system are estimated by adding liquid and gas tracers downhole and monitoring their travel time over a known distance. Based on estimated velocities, a slip factor is obtained that represents relative velocities of the gas and liquid in the fluid. A flow regime of the fluid is identified based on the slip factor. The flow regime is optionally altered by adjusting one or more operational parameters of the well.

Apparatuses and methods for extracting gas from a reservoir including a well bore having a large cross sectional area which may be determined by dividing a target flow rate of the reservoir by an actual sustained flow rate and multiplying a result by a flow path area for the actual sustained flow rate. A method of converting a well of a low pressure gas reservoir is further provided.

Double barrier gas lift flow control devices that utilize first and second check valve assemblies disposed in series. A check valve assembly configured for disposition within an interior of a gas lift flow control device, the check valve assembly having flow channels disposed radially outward from a valve head of the check valve assembly. A check valve assembly configured to engage a nose end of gas lift flow control device.

A method for producing fluid from a well includes inserting a pump into a well tubing having at least one gas lift valve disposed at a selected depth. The pump arranged to lift fluid below the pump into the well tubing. A gas pressure in an annular space between the well tubing and a well casing is increased until the gas reaches a flow port in the tubing proximate the pump. The pump is operated by continuing pumping gas so as to lift fluid from a subsurface reservoir to the selected depth of the at least one gas lift valve.

A variety of systems, methods and compositions are disclosed, including, in one method, a method for producing a subterranean formation, the method comprising: introducing a reactive material into a wellbore penetrating the subterranean formation; hydrolyzing the reactive material with an aqueous-based wellbore fluid to produce hydrogen gas; reducing a bulk density of the aqueous based wellbore fluid; producing the wellbore. A system for producing a wellbore, the system comprising: an oilfield tubular disposed in a producing wellbore; a fluid column comprising an aqueous based wellbore fluid within the oilfield tubular, wherein the fluid column comprises a hydrostatic head greater than a pore pressure of the wellbore; and a solid reactive material capable of chemically reacting with the aqueous-based wellbore fluid thereby reducing the hydrostatic head.