Abstract: A surge flow mitigation tool can include a surge flow valve that permits one-way fluid flow through a flow passage, and a bypass flow path that opens when a differential pressure across the surge flow valve is greater than a predetermined level. A method of mitigating surge flow in a well can include producing fluid through a tubular string with a bottom hole assembly including a surge flow mitigation tool connected downhole of a packer, the surge flow mitigation tool including a surge flow valve that permits the fluid to flow toward surface via the tubular string, but prevents the fluid from flowing into the well via the tubular string, and increasing a differential pressure across the surge flow valve to greater than a predetermined level, thereby opening a bypass flow path that permits injection flow from the tubular string into the well downhole of the packer.

Abstract: A gas vent can include an inner production tube and at least two outer housings. One outer housing is configured to be connected above a tubing anchor, and another outer housing is configured to be connected below the tubing anchor. The inner production tube is configured to extend longitudinally through the tubing anchor. A gas vent system can include an inner production tube which extends longitudinally through a tubing anchor, and an annulus formed between the inner production tube and the tubing anchor. A gas flows through an interior of the tubing anchor via the annulus.

Abstract: A gas separator can include an intake section. Splines extend radially from an inner manifold of the intake section and engage an interior surface of an outer housing, thereby isolating openings formed in the splines from longitudinal channels extending through the outer housing. Another gas separator can include an intake section, a discharge section and multiple intermediate sections connected between the intake and discharge sections. A gas separation system can include a completion string including a packer, a downhole pump and a gas separator connected between the packer and the pump. An annulus is formed between the gas separator and a wellbore, an intake section of the gas separator receives formation fluids from below the packer, a discharge section of the gas separator discharges gas and liquids into the annulus, the intake section receives the liquids from the annulus, and the pump receives the liquids from the discharge section.

Abstract: A surge flow mitigation tool can include a surge flow valve that permits one-way fluid flow through a flow passage, and a bypass flow path that opens when a differential pressure across the surge flow valve is greater than a predetermined level. A method of mitigating surge flow in a well can include producing fluid through a tubular string with a bottom hole assembly including a surge flow mitigation tool connected downhole of a packer, the surge flow mitigation tool including a surge flow valve that permits the fluid to flow toward surface via the tubular string, but prevents the fluid from flowing into the well via the tubular string, and increasing a differential pressure across the surge flow valve to greater than a predetermined level, thereby opening a bypass flow path that permits injection flow from the tubular string into the well downhole of the packer.

Abstract: A gas separator can include an intake section. Splines extend radially from an inner manifold of the intake section and engage an interior surface of an outer housing, thereby isolating openings formed in the splines from longitudinal channels extending through the outer housing. Another gas separator can include an intake section, a discharge section and multiple intermediate sections connected between the intake and discharge sections. A gas separation system can include a completion string including a packer, a downhole pump and a gas separator connected between the packer and the pump. An annulus is formed between the gas separator and a wellbore, an intake section of the gas separator receives formation fluids from below the packer, a discharge section of the gas separator discharges gas and liquids into the annulus, the intake section receives the liquids from the annulus, and the pump receives the liquids from the discharge section.

Abstract: A downhole fluid separation apparatus can include multiple sections connected together with connectors, the connectors providing fluid communication between annuli in adjacent ones of the sections, and between inner conduits in adjacent ones of the sections. Each connector can include at least one flow passage providing communication between an inner conduit of each of the connected sections, and another flow passage providing communication between an annulus of each of the connected sections. A bypass valve can be included that opens in response to a predetermined differential pressure between an exterior of the apparatus and the inner conduits.

Abstract: A downhole fluid separation apparatus can include multiple sections connected together with connectors, the connectors providing fluid communication between annuli in adjacent ones of the sections, and between inner conduits in adjacent ones of the sections. Each connector can include at least one flow passage providing communication between an inner conduit of each of the connected sections, and another flow passage providing communication between an annulus of each of the connected sections. A bypass valve can be included that opens in response to a predetermined differential pressure between an exterior of the apparatus and the inner conduits.

Abstract: A downhole assembly for delivering chemical treatment to a wellbore at the level of a hydrocarbon-bearing formation is provided. The chemical treatment is in solid phase, and slowly dissolves when exposed to wellbore fluids.

Abstract: A method for downhole delivering of chemicals to a wellbore at the level of a hydrocarbon-bearing formation using an assembly formed form a blank tubular with first and second perforation sections, a no-flow nipple connected on one end and a bull plug connected on the other end, wherein the chemical is in solid phase, and slowly dissolves when exposed to wellbore fluids forming a method that can be repeated with the same equipment but additional charges of chemical.

Abstract: A downhole assembly for delivering chemical treatment to a wellbore at the level of a hydrocarbon-bearing formation is provided. The chemical treatment is in solid phase, and slowly dissolves when exposed to wellbore fluids. A method of treating a wellbore using a solid chemical is also provided.

Abstract: A desander system for a wellbore for separating wellbore fluid from particulate. The system having a dip tube nipple, a dip tube, base tubing connecting around the dip tube having base tubing perforations, two collars affixed to the base tubing, two weld rings affixed to the base tubing, a screen jacket mounted over the base tubing perforations, and a Venturi centrifugal helical desander having a Venturi tube with a bore connected to the base tubing. The Venturi tube having a plurality of spiral fins configured to flow particulate around the tube and a desander tube connected to the Venturi tube for flowing wellbore fluid over the outside of the Venturi tube causing a vortex while simultaneously allowing particulate to fall out while simultaneously allowing cleaned fluid to flow up the bore.

Abstract: A downhole assembly for delivering chemical treatment to a wellbore at the level of a hydrocarbon-bearing formation is provided. The chemical treatment is in solid phase, and slowly dissolves when exposed to wellbore fluids. A method of treating a wellbore using a solid chemical is also provided.