Abstract: A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant and a channelant through a wellbore into the fracture, heterogeneously placing the proppant in the fracture in a plurality of proppant clusters or islands spaced apart by the channelant, and removing the channelant filler material to form open channels around the pillars for fluid flow from the formation through the fracture toward the wellbore. The proppant and channelant can be segregated within the well treatment fluid, or segregated during placement in the fracture. The channelant can be dissolvable particles, initially acting as a filler material during placement of the proppant, and later dissolving to leave the flow channels between the proppant pillars. The well treatment fluid can include fibers to provide reinforcement and consolidation of the proppant and/or to inhibit settling of the proppant in the treatment fluid.

Abstract: An approach that provides reference level generation with offset compensation for a sense amplifier is described. In one embodiment, an arbitrary reference level is generated to provide an offset that compensates for device mismatch and voltage threshold of a sense amplifier.

Abstract: A method for purifying a crude acetone raw material containing low molecular weight impurities using three columns in sequence is disclosed.

Abstract: A method of preventing or treating lost circulation during the drilling of a well comprises the addition, at concentration ranging between about 0.5 and 6 pounds per barrel, of water-dispersible fibers having a length between about 10 and 25 mm, for instance glass or polymer fibers, to a pumped aqueous base-fluid including solid particles having an equivalent diameter of less than 300 ?m. The base-fluid with the solid particles can be the drilling fluid or a small-volume pill specially pumped for curing lost circulation.

Abstract: A sand consolidation system and a method for use of the system is provided. The consolidation system includes an emulsion having an oil phase and an aqueous phase, wherein the emulsion contains a source of insoluble silica particles and a source of calcium hydroxide, wherein the calcium hydroxide particles are present in the oil phase, and the insoluble silica particles are contained in the aqueous phase. Both types of particles must have average particle sizes which will fit into the pores of the formations.

Abstract: A self-adaptive cement system includes cement, water and at least one additive that reacts or/and expands in contact with oil and gas. Several chemical products have been identified including rubber alkylstyrene, polynorbornene, resins such precrosslinked substituted vinyl acrylate copolymers and diatomaceous earth. These additives have the effect of making the cement self-healing in the event of physical failure or damage such as micro-annuli. The self healing property is produced by the contact with subterranean hydrocarbon fluids, the potential repair mechanism is thus activated if and when needed in case of start of loss of zonal isolation. In another embodiment, the expansion is deliberately induced by pumping a hydrocarbon fluid in the vicinity of the set cement.

Abstract: A self-healing cement system includes cement, water and at least one additive that swells in contact with water from reservoir or from formation in the case of a structural failure in the set cement to provide a physical barrier in the zone of failure. Examples of such material include particles of super-absorbent polymer. These additives have the effect of making the cement self-healing in the event of physical failure or damage such as micro-annuli. The self healing property is produced by the contact of the water itself, the potential repair mechanism is thus activated if and when needed in case of start of loss of zonal isolation. Several super-absorbent polymers have been identified such as polyacrylamide, modified crosslinked poly(meth)acrylate and non-soluble acrylic polymers.

Abstract: An approach that provides reference level generation with offset compensation for a sense amplifier is described. In one embodiment, an arbitrary reference level is generated to provide an offset that compensates for device mismatch and voltage threshold of a sense amplifier.

Abstract: A composition and method for improving the fluid efficiency of many oilfield treatments is given. The composition is a solid additive, in a viscosified fluid, in a size range small enough that it enters formation pores; it optionally bridges there to form an internal filter cake, and then decomposes to provide a breaker for the viscosifying system for the fluid. Examples of suitable additives include waxes, polyesters, polycarbonates, polyacetals, polymelamines, polyvinyl chlorides, and polyvinyl acetates. Degradation of the additive may be accelerated or delayed.

Abstract: A system for communicating to a motor vehicle operator the maximum safe speed at which the vehicle can be operated. The system includes receiver(s), sensor(s), processor(s) and dashboard display(s). The receiver(s) detects a legal speed limit. Sensor(s) detects environmental conditions surrounding the motor vehicle. The processor(s): receive data from the receiver(s) and sensor(s); calculates a maximum safe speed; and calculates a safe speed range based on the maximum safe speed and the legal speed limit. The dashboard display alerts the driver if the maximum safe speed is less than the legal speed limit, and displays the safe speed range if the maximum safe speed is less than the legal speed limit.

Abstract: An adaptive cementitious composite composition, comprising: a coarse particulate material such as sand or proppant; a series of other particulate or fibrous materials; and a carrier fluid; the sand and other particulate materials being present as a series of coarse, medium and fine particle sizes in ratios selected to provide an optimized packing volume fraction; wherein the sand or proppant is coated with a resin and at least one of the other particulate or fibrous materials is a material that can be modified when placed at a downhole location.

Abstract: Methods for treating a formation penetrated by a wellbore which improves fluid loss control during treatment. In some aspects, the treatments include preparing an aqueous fluid including one or more water inert polymers and an optional viscosifier, injecting the aqueous fluid into the wellbore at a pressure equal to or greater than the formation's fracture initiation pressure, and thereafter injecting into the wellbore a proppant laden fluid at a pressure equal to or greater than the formation's fracture initiation pressure. The water inert polymer may be a polymer such as an emulsion polymer or a latex polymer. Some methods of the invention use a fluid which may have a normalized leak off coefficient (Cw/sqrt(K)) equal to or less than about 0.0022, 0.0014, or 0.0010. A conventional fluid loss additive may or may not be used in conjunction with the treatment fluid and/or the proppant laden fluid. The water inert polymer may or may not substantially enter formation pores.

Abstract: A composition and method for improving the fluid efficiency of many oilfield treatments is given. The composition is a solid additive, in a viscosified fluid, in a size range small enough that it enters formation pores; it optionally bridges there to form an internal filter cake, and then decomposes to provide a breaker for the viscosifying system for the fluid. Examples of suitable additives include waxes, polyesters, polycarbonates, polyacetals, polymelamines, polyvinyl chlorides, and polyvinyl acetates. Degradation of the additive may be accelerated or delayed.

Abstract: A method for purifying a crude acetone raw material containing low molecular weight impurities using three columns in sequence is disclosed.

Abstract: A method for purifying a crude acetone raw material containing low molecular weight impurities using two columns is disclosed. The method comprises the steps of feeding the crude acetone raw material into a first column; adding an alkaline reagent and an oxidative agent into the first column to form high molecular weight impurities; removing a top fraction from the first column by distillation to form bottom fraction comprising an acetone mixture comprising high molecular weight impurities; feeding the bottom fraction comprising the acetone mixture obtained to a second rectification column at a charge point on the column; adding an alkaline reagent to the second column above the charge point of the bottom fraction fed; and separating a purified acetone from the high molecular weight impurities and removing the purified acetone as a top fraction by distillation in the second column, wherein the second rectification column is operated at atmospheric pressure.

Abstract: A composition and method for improving the fluid efficiency of many oilfield treatments is given. The composition is a solid additive, in a viscosified fluid, in a size range small enough that it enters formation pores; it optionally bridges there to form an internal filter cake, and then decomposes to provide a breaker for the viscosifying system for the fluid. Examples of suitable additives include waxes, polyesters, polycarbonates, polyacetals, polymelamines, polyvinyl chlorides, and polyvinyl acetates. Degradation of the additive may be accelerated or delayed.

Abstract: Methods for treating a formation penetrated by a wellbore which improves fluid loss control during treatment. In some aspects, the treatments include preparing an aqueous fluid including one or more water inert polymers and an optional viscosifier, injecting the aqueous fluid into the wellbore at a pressure equal to or greater than the formation's fracture initiation pressure, and thereafter injecting into the wellbore a proppant laden fluid at a pressure equal to or greater than the formation's fracture initiation pressure. The water inert polymer may be a polymer such as an emulsion polymer or a latex polymer. Some methods of the invention use a fluid which may have a normalized leak off coefficient (Cw/sqrt(K)) equal to or less than about 0.0022, 0.0014, or 0.0010. A conventional fluid loss additive may or may not be used in conjunction with the treatment fluid and/or the proppant laden fluid. The water inert polymer may or may not substantially enter formation pores.

Abstract: A sand consolidation system and a method for use of the system is provided. The consolidation system includes an emulsion having an oil phase and an aqueous phase, wherein the emulsion contains a source of insoluble silica particles and a source of calcium hydroxide, wherein the calcium hydroxide particles are present in the oil phase, and the insoluble silica particles are contained in the aqueous phase. Both types of particles must have average particle sizes which will fit into the pores of the formations.

Abstract: In a process to design high temperature cement sluries, the temperature stable phases (anorthite, wairakite) are selected; aluminum modifiers and silica oxides are added to the dry cement so that the elemental composition of the blend corresponds to the phases selected; the control of the particle size distribution and the relative amount of those minerals allow their addition at high concentration while leaving the slurry easily mixable and pumpable; and the kinetics of the targeted phases formation is then controlled by adjusting the crystallinity and the particles sizes of the different solids.

Abstract: Methods for treating a formation penetrated by a wellbore which improves fluid loss control during treatment. In some aspects, the treatments include preparing an aqueous fluid including one or more water inert polymers and an optional viscosifier, injecting the aqueous fluid into the wellbore at a pressure equal to or greater than the formation's fracture initiation pressure, and thereafter injecting into the wellbore a proppant laden fluid at a pressure equal to or greater than the formation's fracture initiation pressure. The water inert polymer may be a polymer such as an emulsion polymer or a latex polymer. Some methods of the invention use a fluid which may have a normalized leak off coefficient (Cw/sqrt(K)) equal to or less than about 0.0022, 0.0014, or 0.0010. A conventional fluid loss additive may or may not be used in conjunction with the treatment fluid and/or the proppant laden fluid. The water inert polymer may or may not substantially enter formation pores.