Abstract: A composition for lost circulation material (LCM) usable in subsurface well intervention includes particles of a hydrated superabsorbent polymer (SAP) mixed with an aqueous solution of a salt tolerant osmotic barrier polymer. A method for stopping fluid loss from a well into a formation penetrated by the well includes pumping a selected volume of the composition into the well until the selected volume is adjacent to the formation.

Abstract: An apparatus for continuously generating and controlling the density of foam has a fluid in-flow manifold in communication with a source of liquid and comprising a pressure sensor. A plurality of branch lines are in fluid communication with the in-flow manifold a foam out-flow manifold. Each branch line has a flow control valve, a Venturi tube and in fluid communication with a throat of each Venturi tube an air induction control valve. The foam out-flow manifold has a pressure sensor. At least one in-flow control valve is disposed between the source and the in-flow manifold and at least one out-flow control valve is in communication with the out-flow manifold. The branch valves, air valves, the in-flow control valve and the out-flow control valve are operable to provide a chosen flow rate of the liquid and a selected foam product flow rate at a selected density of the foam product.

Abstract: A method for pumping a liquid-gas mixture into a subsurface well includes introducing gas into a liquid at a first pressure to generate a mixture. The mixture is pumped through a first positive displacement pump to a second pressure greater than the first pressure. The mixture at the second pressure is pumped through at least a second positive displacement pump to a third pressure greater than the second pressure. The mixture is moved into the subsurface well at at least the third pressure.

Abstract: An apparatus for continuously generating and controlling the density of foam has a fluid in-flow manifold in communication with a source of liquid and comprising a pressure sensor. A plurality of branch lines are in fluid communication with the in-flow manifold a foam out-flow manifold. Each branch line has a flow control valve, a Venturi tube and in fluid communication with a throat of each Venturi tube an air induction control valve. The foam out-flow manifold has a pressure sensor. At least one in-flow control valve is disposed between the source and the in-flow manifold and at least one out-flow control valve is in communication with the out-flow manifold. The branch valves, air valves, the in-flow control valve and the out-flow control valve are operable to provide a chosen flow rate of the liquid and a selected foam product flow rate at a selected density of the foam product.

Abstract: An apparatus for continuously generating and controlling the density of foam has a fluid in-flow manifold in communication with a source of liquid and comprising a pressure sensor. A plurality of branch lines are in fluid communication with the in-flow manifold a foam out-flow manifold. Each branch line has a flow control valve, a Venturi tube and in fluid communication with a throat of each Venturi tube an air induction control valve. The foam out-flow manifold has a pressure sensor. At least one in-flow control valve is disposed between the source and the in-flow manifold and at least one out-flow control valve is in communication with the out-flow manifold. The branch valves, air valves, the in-flow control valve and the out-flow control valve are operable to provide a chosen flow rate of the liquid and a selected foam product flow rate at a selected density of the foam product.

Abstract: A method for pumping a liquid-gas mixture into a subsurface well includes introducing gas into a liquid at a first pressure to generate a mixture. The mixture is pumped through a first positive displacement pump to a second pressure greater than the first pressure. The mixture at the second pressure is pumped through at least a second positive displacement pump to a third pressure greater than the second pressure. The mixture is moved into the subsurface well at at least the third pressure.

Abstract: A method for pumping a liquid-gas mixture into a subsurface well includes introducing gas into a liquid at a first pressure to generate a mixture. The mixture is pumped through a first positive displacement pump to a second pressure greater than the first pressure. The mixture at the second pressure is pumped through at least a second positive displacement pump to a third pressure greater than the second pressure. The mixture is moved into the subsurface well at at least the third pressure.

Abstract: A method for pumping a liquid-gas mixture into a subsurface well includes introducing gas into a liquid at a first pressure to generate a mixture. The mixture is pumped through a first positive displacement pump to a second pressure greater than the first pressure. The mixture at the second pressure is pumped through at least a second positive displacement pump to a third pressure greater than the second pressure. The mixture is moved into the subsurface well at at least the third pressure.

Abstract: An apparatus for continuously generating and controlling the density of foam has a fluid in-flow manifold in communication with a source of liquid and comprising a pressure sensor. A plurality of branch lines are in fluid communication with the in-flow manifold a foam out-flow manifold. Each branch line has a flow control valve, a Venturi tube and in fluid communication with a throat of each Venturi tube an air induction control valve. The foam out-flow manifold has a pressure sensor. At least one in-flow control valve is disposed between the source and the in-flow manifold and at least one out-flow control valve is in communication with the out-flow manifold. The branch valves, air valves, the in-flow control valve and the out-flow control valve are operable to provide a chosen flow rate of the liquid and a selected foam product flow rate at a selected density of the foam product.

Abstract: A method for determining hydration of a polymer includes mixing a water-soluble, powdered dye with a powdered polymer and introducing the mixed water-soluble, powdered dye and powdered polymer into a water-based fluid. Full hydration of the powdered polymer is determined when the mixed water-soluble, powdered dye, powdered polymer and water-based fluid comprises substantially no internal optical contrast.

Abstract: A well fluid composition includes powdered polylactic acid having a selected melting temperature below a lowest expected temperature of a subsurface formation into which the composition is to be introduced. The composition includes powdered polymer suspension aide and/or viscosifier in an amount which when hydrated enables suspension of the powdered polylactic acid in liquid for at least 2 hours and up to 24 hours. The powdered polylactic acid and the powdered polymer solids suspension aide and/or viscosifier are mixed with a liquid capable of hydrating the powdered polymer solids suspension aide and/or viscosifier.

Abstract: A method for determining hydration of a polymer includes mixing a water-soluble, powdered dye with a powdered polymer and introducing the mixed water-soluble, powdered dye and powdered polymer into a water-based fluid. Full hydration of the powdered polymer is determined when the mixed water-soluble, powdered dye, powdered polymer and water-based fluid comprises substantially no internal optical contrast.

Abstract: A composition for a chemical coating includes either (a) a low volatile organic compound (VOC), high flash point, BTEX-free, and at least partially hydrophobic liquid and/or (b) a concentrated solution of polyethylene glycol and/or (c) melted polyethylene glycol; wherein any or all of (a), (b), (c) is mechanically applied as a coating to a hydrophilic polymer powder to reduce clumping of the partially hydrated polymer upon introduction to a water-based fluid, and therefore promote dispersion and ultimately improve hydration. The coating is naturally removed when introduced into the water-based fluid by either hydrophilic-hydrophobic repulsion, emulsification, dissolution, or a combination thereof; and while higher shear rates increase the removal rate of the coating, high shear mixing is not required to remove the coating.

Abstract: A composition for fluid additives that includes at least one water soluble polymer having a predetermined melting temperature. The polymer has mixed therein a selected amount of at least one powdered fluid additive when at least one soluble polymer is held at or above the predetermined melting temperature and is subsequently cooled to solidify. The predetermined temperature is greater than a maximum expected temperature to which the composition will be exposed prior to use of the composition.

Abstract: A drilling fluid composition comprises a concentrated mixture of mud additives. The concentrate comprises a water-based suspension medium comprising a colloidal solid and an effective amount of a water-sequestering polymer and an effective amount of at least one drilling mud additive mixed into the water-based suspension medium.

Abstract: A fluid composition for cleanout of wellbores and pipe systems includes an effective amount of an amphiphilic chemical combined with an effective amount of a friction reducer in an aqueous solution of a base liquid. A remainder of the composition includes the base liquid.

Abstract: A fluid composition for cleanout of wellbores and pipe systems includes an effective amount of an amphiphilic chemical combined with an effective amount of a friction reducer in an aqueous solution of a base liquid. A remainder of the composition includes the base liquid.

Abstract: A fluid composition for cleanout of wellbores and pipe systems includes an effective amount of an amphiphilic chemical combined with an effective amount of a friction reducer in an aqueous solution of a base liquid. A remainder of the composition includes the base liquid.

Abstract: By including a chemical additive in the well treatment fluid system design the cost and environmental impact of hydraulic fracturing may be substantially reduced. By adding a weak base to the well treatment fluid, water having a high, heterogeneous concentration of dissolved solids, such as water produced by oil and gas wells, may be utilized as the base fluid for hydraulic fracturing or other stimulation processes without adversely affecting the various components of the well treatment fluid. The well treatment fluid typically includes a base fluid, in this case produced water, a gelling agent, a weak base, and other additives useful for treating a well such as friction reducers, buffering agents, clay control agents, biocides, scale inhibitors, chelating agents, gel-breakers, oxygen scavengers, antifoamers, crosslinkers, wax inhibitors, corrosion inhibitors, de-emulsifiers, foaming agents, or tracers.

Abstract: A fluid composition for cleanout of wellbores and pipe systems includes an effective amount of an amphiphilic chemical combined with an effective amount of a friction reducer in an aqueous solution of a base liquid. A remainder of the composition includes the base liquid.