| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 41 | Wellbore servicing compositions and methods of making and using same | US14329404 | 2014-07-11 | US08985212B1 | 2015-03-24 | Freddy Molina Crespo; B. Raghava Reddy; Natalie Pascarella |
| A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a water-soluble crosslinkable composition, a particulate water-swellable superabsorber, and an aqueous base fluid, placing the fluid in a treated portion of the formation, wherein the treated portion comprises a first region having a first region permeability and a second region having a second region permeability, wherein a permeability contrast is a ratio between first region permeability and second region permeability, and wherein the permeability contrast is equal to or greater than 10 prior to placement of the fluid, allowing the superabsorber to occupy at least a portion of the first region, thereby reducing the first region permeability, and allowing the crosslinkable composition to penetrate at least a portion of the second region, thereby reducing the second region permeability, wherein the permeability contrast is reduced to less than 10 after placement of the fluid. | ||||||
| 42 | Method and system using zeta potential altering compositions as aggregating reagents for sand control | US12690292 | 2010-01-20 | US08950493B2 | 2015-02-10 | Ronald van Petegem; Sarkis R. Kakadjian; Frank Zamora |
| Methods and systems are disclosed for well completion and/or production, where an aggregating, agglomerating or conglomerating composition is injected into a producible formation, zone or interval thereof to alter an aggregation or zeta potential of formation surfaces and particulate to increase a maximum sand free production rate. | ||||||
| 43 | Methods and compositions for sand control in injection wells | US13282765 | 2011-10-27 | US08936087B2 | 2015-01-20 | Philip D. Nguyen; Richard D. Rickman; Ronald G. Dusterhoft; Jimmie D. Weaver; Dave Tiffin; Gary Hurst |
| Methods including the steps of providing an injection well having unconsolidated particulates in one or more formation intervals along the wellbore that accept injection fluid; providing a consolidating treatment fluid comprising a base fluid and a consolidating agent; introducing the consolidating treatment fluid through the injection well, while the well is under injection, such that the consolidating treatment fluid enters into a portion of a formation interval along the wellbore that accepts injection fluid; and, allowing the consolidating fluid to consolidate formation particulates therein. The methods may be performed such that the percentage of consolidating agent varies over the course of the treatment or the rate of injection varies over the course of the treatment. | ||||||
| 44 | COMPOSITIONS AND METHODS FOR CONTROLLING PARTICULATE MIGRATION IN A SUBTERRANEAN FORMATION | US13766892 | 2013-02-14 | US20140190700A1 | 2014-07-10 | Tingji Tang; Feng Liang; Loan Vo; Philip D. Nguyen |
| Stabilizers that include hydrophobically modified amine-containing polymers may be utilized as compositions or in methods for controlling particulate migration in a subterranean formation. For example, a method may include providing a treatment fluid that comprises a base fluid and a hydrophobically modified amine-containing polymer (HMAP), the HMAP comprising a plurality of hydrophobic modifications on an amine-containing polymer; introducing the treatment fluid into a wellbore penetrating a subterranean formation, the subterranean formation comprising a plurality of particulates; and allowing the HMAP to coat at least some of the particulates. | ||||||
| 45 | Wellbore Servicing Fluid System and Methods of Use | US13442610 | 2012-04-09 | US20130264057A1 | 2013-10-10 | Carl Joseph THAEMLITZ |
| A wellbore servicing method comprising circulating an invert emulsion fluid through a wellbore to form a filter cake within the wellbore, wherein the invert emulsion fluid comprises an oleaginous fluid, a non-oleaginous fluid, and an acid-sensitive surfactant, contacting at least a portion of the filter cake with an emulsion reversing fluid, wherein the emulsion reversing fluid comprises an acid precursor, wherein the acid precursor is not an acid, and wherein the acid precursor is configured to generate a quantity of acid after a predetermined delay period beginning at placement within a wellbore, allowing the emulsion reversing fluid to remain in contact with the filter cake for a soak period, and removing the filter cake from the wellbore. | ||||||
| 46 | Downhole apparatus | US12666981 | 2008-06-25 | US08479810B2 | 2013-07-09 | Paul David Metcalfe |
| Downhole apparatus comprises a base pipe and a plurality of non-concentric pressure deformable chambers mounted externally on the pipe. The chambers may be inflated to increase the diameter of the apparatus and engage and support a surrounding bore wall. | ||||||
| 47 | AGGREGATING REAGENTS AND METHODS FOR MAKING AND USING SAME | US13247985 | 2011-09-28 | US20130075100A1 | 2013-03-28 | Raynard Veldman; Sarkis R. Kakadjian; Frank Zamora |
| Composition and methods using the compositions are disclosed, where the compositions include heterocyclic aromatic amines, substituted heterocyclic aromatic amines, poly vinyl heterocyclic aromatic amines, co-polymers of vinyl heterocyclic aromatic amine and non amine polymerizable monomers (ethylenically unsaturated mononers and diene monomers), or mixtures or combinations thereof in the absence of phosphate esters, optionally ethoxylated alcohols, and optionally, which form alter self-aggregating properties and/or aggregation propensities of the particles, surfaces, and/or materials. | ||||||
| 48 | APPARATUS AND METHOD FOR SAND CONSOLIDATION | US13006456 | 2011-01-14 | US20120181023A1 | 2012-07-19 | Julio C. Guerrero; Adam Paxson; Folkers Eduardo Rojas |
| An apparatus and method for preventing the migration of unconsolidated and/or loosely consolidated material into the wellbore. Such prevention is accomplished by introducing a well treatment comprising an expandable deployable structure into an uncosolidated zone proximate the wellbore. These deployable structures are inserted into the voids of the geological formation and using stored mechanical energy convert from an unexpanded or undeployed state to an expanded or deployed state. These deployable structures can exert forces, pressure or a combination of both in multiple directions on the surrounding media. | ||||||
| 49 | Method for treating well bore within a subterranean formation | US12574390 | 2009-10-06 | US08215393B2 | 2012-07-10 | Bruce A. MacKay; Philip F. Sullivan; Nicolas Droger; Ralph M. D'Angelo; Douglas E. Miller |
| The invention discloses a method of creating a polymerized composition in a well bore: providing a polymerizable composition made of a polymerization initiator and a monomer polymerizable by frontal polymerization; introducing the polymerizable composition into the wellbore; exposing the polymerizable composition to a trigger to activate the frontal polymerization; and creating the polymerized composition. | ||||||
| 50 | WELL SCREENS HAVING ENHANCED WELL TREATMENT CAPABILITIES | US12966162 | 2010-12-13 | US20120145389A1 | 2012-06-14 | Harvey J. Fitzpatrick, JR. |
| A well screen assembly with enhanced well treatment capabilities. A well screen assembly can include a well treatment substance secured to the well screen assembly, and at least one reactive component of a well treatment stimulant. The reactive component can also be secured to the well screen assembly. A method of treating a well can include expanding a well screen assembly outward in a wellbore of the well, thereby decreasing a distance between a well treatment substance and a wall of the wellbore. Another method of treating a well can include contacting multiple reactive components of a well treatment stimulant with each other in the well, thereby dispersing a well treatment substance about a well screen assembly. | ||||||
| 51 | Process and system for creating enhanced cavitation | US12357556 | 2009-01-22 | US08011431B2 | 2011-09-06 | Ronald van Petegem; Barry Ekstrand |
| A system and method for cavitating a producible formation is disclosed to improve hydrocarbon production and to increase a production rate without an concurrent co-production of formation particulate. The method and system include conglomerating the producible formation using a conglomerating composition. Once the producible formation is conglomerated, the conglomerated, producible formation is produced above its critical draw down pressure to form a cavity surrounding the wellborn in the conglomerated, producible formation and placing the cavitated, conglomerated, producible formation on production below a higher maximum sand free rate (MSFR). | ||||||
| 52 | Emulsion system for sand consolidation | US11861894 | 2007-09-26 | US07975764B2 | 2011-07-12 | Philip F. Sullivan; Erik Nelson; Juan-Carlos Gonzalez; Samuel Danican; Gary Tustin |
| 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. | ||||||
| 53 | METHOD FOR TREATING FRACTURING WATER | US12643239 | 2009-12-21 | US20100190666A1 | 2010-07-29 | Syed Ali; Shawn McCleskey Rimassa; Francois M. Auzerais; Curtis L. Boney; Leiming Li |
| A method of treating a medium for water fracturing is disclosed, the method comprises: introducing at least one biocide and at least one metabolic inhibitor in the medium, using the medium for water fracturing. In another aspect a method of controlling the post-fracture reservoir souring by the metabolic activities of sulfate reducing bacteria of a well is described: at least one biocide and at least one metabolic inhibitor are introduced in a medium made of water, the medium is used for fracturing the well, and the medium remains in the reservoir to kill and/or inhibit growth of sulfate reducing bacteria. | ||||||
| 54 | Permeability Modification | US12666942 | 2008-06-25 | US20100175895A1 | 2010-07-15 | Paul David Metcalfe |
| Downhole apparatus for location in a bore which intersects a fluid-producing formation comprises a bore wall-supporting member configurable to provide and maintain a bore wall supporting force for a fluid-producing formation of at least 2 MPa, whereby fluid may flow from the formation into the bore. The bore wall supporting force may be utilised to modify or maintain the permeability of the rock adjacent the bore wall. | ||||||
| 55 | Calorimetric distributed temperature system and methods | US12290999 | 2008-11-05 | US20100108311A1 | 2010-05-06 | Rory D. Daussin; Ron G. Dusterhoft; Mary S. Van Domelen; Gerard Glasbergen |
| Methods for designing and performing a treatment operation on a subterranean formation penetrated by a wellbore are provided, in which the treatment operation includes the use of a treatment fluid comprising reactants for a chemical reaction. The methods generally include the step of obtaining wellbore temperature-profile information on the wellbore and obtaining kinetic or thermodynamic data for the chemical reaction, and combining the information to help design the treatment operation. Preferably, the methods include the use of a distributed temperature system (“DTS”) for gaining temperature-profile information for a wellbore. | ||||||
| 56 | Methods of Cleaning Sand Control Screens and Gravel Packs | US12683308 | 2010-01-06 | US20100101773A1 | 2010-04-29 | Philip D. Nguyen; Richard D. Rickman |
| Methods for remediating a subterranean environment. Methods comprising introducing a cleanup fluid through a well bore and into a portion of a subterranean formation penetrated by the well bore, applying a pressure pulse to the cleanup fluid, and introducing a consolidating agent through the well bore and into the portion of the subterranean formation. Methods of cleaning a sand control screen comprises introducing a cleanup fluid through a sand control screen and into a portion of a subterranean formation, the sand control screen located in a well bore that penetrates the subterranean formation; applying a pressure pulse to the cleanup fluid; and introducing a consolidating agent through the sand control screen and into the portion of the subterranean formation. | ||||||
| 57 | Sand control screen assembly and associated methods | US12082644 | 2008-04-11 | US07703520B2 | 2010-04-27 | Ronald G. Dusterhoft |
| Methods are provided including a method comprising: placing a sand control screen in the wellbore penetrating the subterranean formation, wherein the sand control screen comprises: a base pipe having at least one opening in a sidewall portion thereof; a swellable material layer disposed exteriorly of the base pipe and having at least one opening corresponding to the at least one opening of the base pipe; a telescoping perforation operably associated with the at least one opening of the base pipe and at least partially disposed within the at least one opening of the swellable material layer; and a filter medium disposed within the telescoping perforation; and introducing a consolidating agent into at least a portion of a subterranean formation. Additional methods are also provided. | ||||||
| 58 | Methods of cleaning sand control screens and gravel packs | US11354651 | 2006-02-15 | US07665517B2 | 2010-02-23 | Philip D. Nguyen; Richard D. Rickman |
| Methods for remediating a subterranean environment. Methods comprising introducing a cleanup fluid through a well bore and into a portion of a subterranean formation penetrated by the well bore, applying a pressure pulse to the cleanup fluid, and introducing a consolidating agent through the well bore and into the portion of the subterranean formation. Methods of cleaning a sand control screen comprises introducing a cleanup fluid through a sand control screen and into a portion of a subterranean formation, the sand control screen located in a well bore that penetrates the subterranean formation; applying a pressure pulse to the cleanup fluid; and introducing a consolidating agent through the sand control screen and into the portion of the subterranean formation. | ||||||
| 59 | SYSTEM AND METHOD FOR PERFORATED WELL SAND CONTROL | US12117915 | 2008-05-09 | US20090277636A1 | 2009-11-12 | Gregory Kubala; Philip F. Sullivan; Kevin W. England |
| In one embodiment, a system includes a cased wellbore disposed in a formation of interest. The system includes an emulsion positioned in the wellbore at a depth of the formation of interest. The emulsion includes an oil external phase and an aqueous internal phase. The oil external phase includes particles having calcium hydroxide. The aqueous internal phase includes insoluble silica particles. The system further includes a perforating tool that generates perforation tunnels through the cased wellbore into the formation of interest. The system further includes a well flow control device that shuts in the wellbore for a specified period of time. The emulsion breaks during contact with the formation in the perforation tunnels, and the calcium hydroxide and silica particles form a cementitious material that consolidates the perforation tunnels. | ||||||
| 60 | Control of Fines Migration In Well Treatments | US12212509 | 2008-09-17 | US20090111718A1 | 2009-04-30 | Balkrishna Gadiyar; Erik B. Nelson; Juan-Carlos Santamaria; Brent Busby; Philip F. Sullivan |
| A treatment fluid that can be used for treating a subterranean formation penetrated by a wellbore is prepared from a primary treatment fluid component and an emulsion component mixed with the primary treatment fluid component. The emulsion component has an oil phase and an aqueous phase. The emulsion component comprising a source of insoluble silica particles and a source of calcium hydroxide, wherein the source of calcium hydroxide is present in the oil phase, and the source of insoluble silica particles are contained in the aqueous phase. The method is carried out by contacting at least a portion of the formation with the treatment fluid. | ||||||
QQ群二维码
意见反馈
意见反馈