Sandia Corporation

National Technology & Engineering Solutions of Sandia, LLC

The United States of America As Represented by the United States

Columbia University

Patrick V Brady

James L Krumhansl

David M Teter

Charles R Bryan

John R Torczynski

Michail A Gallis

Carlton F Brooks

Nadim R Khandaker

Helmuth J Heneman

Robert Charles Moore

Mark D Tucker

Scott Banta

Thomas Dewers

Ah-Hyung Alissa Park

Eric R Lindgren

Brian P Dwyer

Mark J Rigali

Edward J Swanson

Joseph Daniel Chwirka

Paul McConnell

Huangjing Zhao

Greeshma Gadikota

Tushar Patel

Placement of proppant in subterranean formations during hydraulic fracturing is assessed. A method of one aspect includes introducing a hydraulic fracturing fluid including a proppant into a subterranean formation through a well. Samples of the hydraulic fracturing fluid are recovered through the well over a period of time. A concentration of at least one tracer in each of the samples is determined. The concentrations of the at least one tracer in the samples are analyzed to assess placement of the proppant in the subterranean formation. Other methods, apparatus, and systems are also disclosed.

Injection withdrawal tracer tests to assess proppant placement

Injectates and method that use surface blocking agents for enhancing subterranean oil recovery are disclosed. The surface blocking agents reduce the adhesion of oil to rock surfaces thereby increasing oil recovery. The surface blocking agents attach to or are attracted to the oils positive nitrogen sites and have an opposing negative charge that is repulsed by the negative rock surface charge.

Surface blocking agents

Methods and systems for capturing and storing carbon dioxide are disclosed. In some embodiments, the methods include the following: mixing materials including magnesium or calcium with one or more acids and chelating agents to form a magnesium or calcium-rich solvent; using the organic acids derived from biogenic wastes as acids or chelating agents; generating carbonate ions by reacting a gas including carbon dioxide with a carbonic anhydrase biocatalyst; reacting the solvent with the carbonate ions to form magnesium or calcium carbonates; recycling a solution containing the biocatalyst after forming magnesium or calcium carbonates for re-use in the generating step; using the magnesium and calcium carbonates as carbon neutral filler materials and using the silica product as green filler materials or inexpensive absorbents.

Methods and systems for capturing and storing carbon dioxide

A method of increasing recovery of liquid hydrocarbons from subsurface reservoirs, and particularly from those located in tight formations, is disclosed. One aspect includes calculating the in situ fractured formation wettability from real-time measurement of flowback volume and composition. Another aspect includes determining the composition of the fracturing fluid, the overflush or both, that will achieve higher liquid hydrocarbon recovery by increasing the water wettability of rock surfaces within the reservoir. Monitoring of rock-surface wettability through flowback volume and composition profiles allows the above mentioned injectates to be adjusted in the field to achieve maximal recovery. Other methods, apparatuses, and systems are disclosed.

Method for enhancing hydrocarbon recovery from tight formations

A method of selecting an injectate for recovering liquid hydrocarbons from a reservoir includes designing a plurality of injectates, calculating a net present value of each injectate, and selecting a candidate injectate based on the net present value. For example, the candidate injectate may be selected to maximize the net present value of a waterflooding operation.

Financial methods for waterflooding injectate design

A method of recovering a liquid hydrocarbon using an injectate includes recovering the liquid hydrocarbon through primary extraction. Physico-chemical data representative of electrostatic interactions between the liquid hydrocarbon and the reservoir rock are measured. At least one additive of the injectate is selected based on the physico-chemical data. The method includes recovering the liquid hydrocarbon from the reservoir rock through secondary extraction using the injectate.

Waterflooding injectate design systems and methods

A method for sequestering selenium is disclosed. The method includes contacting selenium with a stannous modified apatite under conditions whereby the selenium is absorbed by the apatite.

Apatite sequestration of selenium

A system including a vessel including a heat source and a flue; a turbine; a condenser; a fluid conduit circuit disposed between the vessel, the turbine and the condenser; and a diverter coupled to the flue to direct a portion of an exhaust from the flue to contact with a cooling medium for the condenser water. A method including diverting a portion of exhaust from a flue of a vessel; modifying the pH of a cooling medium for a condenser with the portion of exhaust; and condensing heated fluid from the vessel with the pH modified cooling medium.

PH adjustment of power plant cooling water with flue gas/fly ash

A method of designing an injectate to be used in a waterflooding operation is disclosed. One aspect includes specifying data representative of chemical characteristics of a liquid hydrocarbon, a connate, and a reservoir rock, of a subterranean reservoir. Charged species at an interface of the liquid hydrocarbon are determined based on the specified data by evaluating at least one chemical reaction. Charged species at an interface of the reservoir rock are determined based on the specified data by evaluating at least one chemical reaction. An extent of surface complexation between the charged species at the interfaces of the liquid hydrocarbon and the reservoir rock is determined by evaluating at least one surface complexation reaction. The injectate is designed and is operable to decrease the extent of surface complexation between the charged species at interfaces of the liquid hydrocarbon and the reservoir rock. Other methods, apparatus, and systems are disclosed.

A process and apparatus for separating a gas mixture comprising providing a slot in a gas separation channel (conceptualized as a laterally elongated Clusius-Dickel column), having a length through which a net cross-flow of the gas mixture may be established; applying a higher temperature to one side of the channel and a lower temperature on an opposite side of the channel thereby causing thermal-diffusion and buoyant-convection flow to occur in the slot; and establishing a net cross-flow of a gas mixture comprising at least one higher density gas component and at least one lower density gas component along the length of the slot, wherein the cross-flow causes, in combination with the convection flow, a spiraling flow in the slot; and wherein the spiral flow causes an increasing amount of separation of the higher density gas from the lower density gas along the length of the channel. The process may use one or more slots and/or channels.

Process and apparatus for separation of components of a gas stream

An in situ recovery of uranium operation involves circulating reactive fluids through an underground uranium deposit. These fluids contain chemicals that dissolve the uranium ore. Uranium is recovered from the fluids after they are pumped back to the surface. Chemicals used to accomplish this include complexing agents that are organic, readily degradable, and/or have a predictable lifetime in an aquifer. Efficiency is increased through development of organic agents targeted to complexing tetravalent uranium rather than hexavalent uranium. The operation provides for in situ immobilization of some oxy-anion pollutants under oxidizing conditions as well as reducing conditions. The operation also artificially reestablishes reducing conditions on the aquifer after uranium recovery is completed. With the ability to have the impacted aquifer reliably remediated, the uranium recovery operation can be considered inherently safe.

Inherently safe in situ uranium recovery

A low-cost, water treatment system and method for reducing arsenic contamination in small community water storage tanks. Arsenic is removed by using a submersible pump, sitting at the bottom of the tank, which continuously recirculates (at a low flow rate) arsenic-contaminated water through an attached and enclosed filter bed containing arsenic-sorbing media. The pump and treatment column can be either placed inside the tank (In-Tank) by manually-lowering through an access hole, or attached to the outside of the tank (Out-of-Tank), for easy replacement of the sorption media.

In-tank recirculating arsenic treatment system

A method (and concomitant kit) for treating a surface to reduce subsequentCs nuclide desorption comprising contacting the surface with a first cation-containing solution, the cation being one or more of Cs, Rb, Ag, Tl, K, and NH, and contacting the surface with a second cation-containing solution, the cation being one or more of Cs, Rb, Ag, Tl, K, and NH, thereby reducing amounts of radioactive cesium embedded in clays found on the surface.

Growing community of inventors

Albuquerque, NM, United States of America

Patrick V Brady