Methods and systems for processing financial market data using reconfigurable logic are disclosed. Various functional operations to be performed on the financial market data can be implemented in firmware pipelines to accelerate the speed of processing. Also, a combination of software logic and firmware logic can be used to efficiently control and manage the high speed flow of financial market data to and from the reconfigurable logic.

High Speed Processing of Financial Information Using FPGA Devices

An under-balanced drilling fluid additive is disclosed which reduces reactive shale and/or clay swelling during under-balanced drilling operations, where the additive includes an effective amount of a choline salt. A method for under-balanced drilling is also disclosed including the step of circulating a drilling fluid including an effective amount of a choline salt to reduce reactive shale and/or clay swelling during under-balanced drilling operations.

Shale Inhibition additive for oil/gas down hole fluids and methods for making and using same

Provided are methods of using fluid loss control additives that comprise a water-soluble polymer with hydrophobic or hydrophilic modification. In one embodiment, a method of providing at least some degree of fluid loss control during a subterranean treatment is provided. In an example of such a method, the method may comprise providing a treatment fluid comprising an aqueous liquid and a fluid loss control additive, the fluid loss control additive comprising a water-soluble polymer with hydrophobic or hydrophilic modification; and introducing the treatment fluid into a well bore that penetrates a subterranean formation, wherein there is at least a partial reduction in fluid loss into at least a portion of the subterranean formation from the treatment fluid and/or another aqueous fluid introduced into well bore subsequent to the treatment fluid.

Methods useful for controlling fluid loss in subterranean formations

Parameters Affecting the Interaction Among Closely Spaced Hydraulic Fractures

A well treatment fluid composition comprises a solvent (such as water), a polymer soluble or hydratable in the solvent, a crosslinking agent, an inorganic breaking agent, and an ester compound. Preferably, the hydratable polymer is a polysaccharide, such as galactomannan, cellulose, or derivatives thereof. The crosslinking agent is preferably a borate, titanate, or zirconium-containing compound. The inorganic breaking agent is preferably a metal-based oxidizing agent, such as an alkaline earth metal or transition metal-based oxidizing agent. The ester compound is preferably an ester of polycarboxylic acid, such as an ester of oxalate, citrate, or ethylenediamine tetraacetate. One example of a suitable ester compound is acetyl triethyl citrate.

Well treatment fluid compositions and methods for their use

Method of hydraulic fracturing of a subterranean formation comprising drilling a deviated wellbore in a direction parallel to a desired fracture direction, and supplying fracturing fluid through the wellbore to the formation. The average net pressure on the fluid is maximized in a fracture formed in the formation by pumping the fracturing fluid at a maximum rate, and by using a high viscosity fracturing fluid. Maximization of the average net pressure acts to extend the fracture in a direction parallel to the direction of the wellbore. The amount of the extension of the fracture is a function of the ratio of the average net pressure to the horizontal stress difference, whereby the higher the ratio, the greater the amount of the extension.

Wellbore guided hydraulic fracturing

Fracturing from horizontal and highly deviated wells can often result in complex, non-planar fracture geometry. A two-dimensional model was developed to analyze the effects of non-planar fracture propagation for different in situ boundary conditions and hydraulic fracturing parameters. Numerical simulations show that curving fracture geometry reduces created fracture length compared to a planar fracture and causes a fracture width restriction at the wellbore. Reduction in fracture length can reduce expected well stimulation effects and jeopardize well economics. Near-wellbore width restrictions increase fracture treating pressure and may cause wellbore screen-out during the proppant stages of a fracturing treatment. The negative impact of non-planar geometry can be mitigated with short perforated intervals, high viscosity fracturing fluids, proper wellbore alignment and pre-pad proppant slugs for near-wellbore erosion.

Jon E. Olson

Papers

Wellbore guided hydraulic fracturing

Fracturing from Highly Deviated and Horizontal Wells: Numerical Analysis of Non-planar Fracture Propagation