子分类：
| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 201 | Flow system for a hydraulic choke solids strainer | US11805328 | 2007-05-23 | US07360611B2 | 2008-04-22 | Donald Glynn Sims; Michael James Taylor; Robert Frank Schmidt; David Anthony Schmidt; John Walton McCaskill |
| A strainer system having two separate strainers positioned in parallel, where one strainer can be cleaned while still permitting normal flow through the other strainer. The system flow circuit is arranged so that a high pressure backwashing flow can be applied to one strainer while the other strainer is providing its normal straining function. The backwashed strainer is then isolated by valves so that its access flange can be removed and the particulate buildup within the valve plug cleaned out. The strainer is then returned to service following the replacement of the access flange. In this manner, it is possible to alternate between the two strainers so that continuous flow can be maintained to the hydraulic choke located downstream of the strainer system. | ||||||
| 202 | Irradiation system and methods of treating fluids in hydrocarbon industry applications | US11295382 | 2005-12-06 | US07332094B2 | 2008-02-19 | Larry Lance Abney; Graeme W. Pirie; Tim Hunter; Billy Slabaugh; Leonard Case |
| A method comprises rendering a hydrocarbon industry servicing fluid biologically inert without using chemical biocides. One method of rendering a hydrocarbon industry servicing fluid biologically inert comprises irradiating at least one constituent of the servicing fluid to produce an irradiated fluid. Another method comprises irradiating a used hydrocarbon industry servicing fluid to produce a remediated fluid that is biologically inert.A fluid treatment system comprises an irradiation apparatus, inlet piping directing an untreated fluid into the irradiation apparatus, outlet piping directing an irradiated fluid out of the irradiation apparatus, and a connection to a hydrocarbon industry application. | ||||||
| 203 | Pressure Safety System for Use With a Dynamic Annular Pressure Control System | US11737163 | 2007-04-19 | US20070246263A1 | 2007-10-25 | Donald G. Reitsma |
| A method for controlling formation pressure during the drilling of a borehole through a subterranean formation includes selectively pumping a drilling fluid through a drill string extended into a borehole, out a drill bit at the bottom end of the drill string, and into an annular space between drill string and the borehole. The drilling fluid is discharged to a reservoir to clean the drilling fluid for reuse. Annular space fluid pressure is selectively increased to maintain a selected fluid pressure proximate the bottom of the borehole by applying fluid pressure to the annular space. The selective increasing includes controlling an aperture of an orifice operatively coupled between the annular space and the reservoir. Fluid from the annular space is discharged other than through the orifice when the annular space fluid pressure exceeds a selected value, or drops below a selected value. | ||||||
| 204 | Flow system for a hydraulic choke solids Strainer | US11805328 | 2007-05-23 | US20070221413A1 | 2007-09-27 | Donald Sims; Michael Taylor; Robert Schmidt; David Schmidt; John McCaskill |
| A strainer system having two separate strainers positioned in parallel, where one strainer can be cleaned while still permitting normal flow through the other strainer. The system flow circuit is arranged so that a high pressure backwashing flow can be applied to one strainer while the other strainer is providing its normal straining function. The backwashed strainer is then isolated by valves so that its access flange can be removed and the particulate buildup within the valve plug cleaned out. The strainer is then returned to service following the replacement of the access flange. In this manner, it is possible to alternate between the two strainers so that continuous flow can be maintained to the hydraulic choke located downstream of the strainer system. | ||||||
| 205 | Solids strainer system for a hydraulic choke | US11799846 | 2007-05-04 | US20070215387A1 | 2007-09-20 | Donald Sims; Michael Sims; Robert Schmidt; David Schmidt; John McCaskill |
| The invention contemplates a strainer based upon a four-way, two-position rotary cylindrical plug valve having a hollow plug. The normal entry port for the sealing plug of the plug valve is a circular radial hole passing from the exterior of the plug into the interior cavity of the plug. The normal exit port for the sealing plug is a regular array of small holes across from and coaxial with the normal entry hole. The ports for the valve body are in two pairs positioned at 90° from each other, with the axes of the ports lying in the same transverse plane as the ports of the valve plug. | ||||||
| 206 | Portable degasser, flare tank and fluid storage system | US11342614 | 2006-01-31 | US20070175331A1 | 2007-08-02 | Deren Tomshak; Michael Lehmann; Dean Falkenberg |
| A portable degasser, flare tank and fluid storage system for use during oil well exploratory drilling which when connected to the fluid blow-out prevention hardware of an active drilling operation prevents the accidental spillage of liquid ejected under pressure from the drill bore hole. | ||||||
| 207 | Method and system for hydraulic friction controlled drilling and completing geopressured wells utilizing concentric drill strings | US10754022 | 2004-01-08 | US07185718B2 | 2007-03-06 | Robert Gardes |
| A method and system of drilling straight directional and multilateral wells utilizing hydraulic frictional controlled drilling, by providing concentric casing strings to define a plurality of annuli therebetween; injecting fluid down some of the annuli; returning the fluid up at least one annulus so that the return flow creates adequate hydraulic friction within the return annulus to control the return flow within the well. The hydraulic friction should be minimized on the injection side to require less hydraulic horsepower and be maximized on the return side to create the desired subsurface friction to control the well. | ||||||
| 208 | Degradable particulate generation and associated methods | US11049483 | 2005-02-02 | US20060172894A1 | 2006-08-03 | Michael Mang; Trinidad Munoz; Rajesh Saini |
| Herein provided are methods for producing degradable particulates at a drill site, and methods related to the use of such degradable particulates in subterranean applications. In one embodiment, the present invention provides a method comprising: providing a treatment fluid, the treatment fluid comprising degradable particulates, at least a portion of the degradable particulates having been made by a supercritical fluid assisted method at a drill site; and introducing the treatment fluid into a well bore penetrating a subterranean formation at the drill site. | ||||||
| 209 | System and method for developing and recycling drilling fluids | US10201419 | 2002-07-23 | US06932169B2 | 2005-08-23 | Glenda Wylie; Frank Zamora; Donald L. Whitfill |
| A system and method for developing and recycling drilling fluids at the site of a subterranean well is described, thus eliminating the need for transporting the fluids to the site. | ||||||
| 210 | System and method for treating drilling mud in oil and gas well drilling applications | US10390528 | 2003-03-17 | US06926101B2 | 2005-08-09 | Luc deBoer |
| A system and method for controlling drilling mud density at a location either at the seabed (or just above the seabed) or alternatively below the seabed of wells in deep water and ultra deep water applications. A base fluid of lesser density than the drilling mud required at the wellhead is used to produce a diluted mud in the riser. By combining the appropriate quantities of drilling mud with base fluid, a diluted riser mud density at or near the density of seawater may be achieved. The present invention also includes a wellhead injection device for injecting the base fluid into the rising drilling mud. The riser charging lines are used to carry the low density base fluid to the injection device for injection into the return mud. At the surface, the diluted return mud is passed through a treatment system to cleanse the mud of drill cuttings and to separate the heavier drilling mud from the lighter base fluid. The present invention further includes a control unit for manipulating drilling fluid systems and displaying drilling and drilling fluid data. | ||||||
| 211 | Solids strainer system for a hydraulic choke | US10880640 | 2004-06-30 | US20050006150A1 | 2005-01-13 | Donald Sims; Michael Taylor; Robert Schmidt; David Schmidt; Joh McCaskill |
| The invention contemplates a strainer based upon a four-way, two-position rotary cylindrical plug valve having a hollow plug. The normal entry port for the sealing plug of the plug valve is a circular radial hole passing from the exterior of the plug into the interior cavity of the plug. The normal exit port for the sealing plug is a regular array of small holes across from and coaxial with the normal entry hole. The ports for the valve body are in two pairs positioned at 90° from each other, with the axes of the ports lying in the same transverse plane as the ports of the valve plug. | ||||||
| 212 | Screen assembly for vibratory separators | US10453471 | 2003-06-03 | US20040099578A1 | 2004-05-27 | Joseph C. Winkler; Thomas C. Adams; Kenneth W. Seyffert; David Wayne Largent; David L. Schulte JR.; Charles N. Grichar; Guy L. McClung III |
| Screen assemblies for a vibratory separator and methods of using them, the screen assemblies in one aspect including a first screen portion having a first end and a second end spaced apart from the first end, a second screen portion adjacent the second end of the first screen portion, the second screen portion projecting down from the second end of the first screen portion. | ||||||
| 213 | Vibratory separators and screens | US09971070 | 2001-10-04 | US06722504B2 | 2004-04-20 | David L. Schulte; Thomas C. Adams; Kenneth W. Seyffert; David W. Largent; Guy L. McClung, III; Jeffrey E. Walker; Hector M. Murray |
| A vibratory separator with a base, vibrating apparatus, a screen container on the base, the screen container having a plurality of spaced-apart drain holes, a plurality of spaced-apart screens in the screen-container, said screens oriented vertically within the screen container, and the screens positioned so that screened fluid passes through the screens and flows from the container through the plurality of spaced-apart drain holes. | ||||||
| 214 | Screen with ramps for vibratory separator system | US09696662 | 2000-10-25 | US06629610B1 | 2003-10-07 | Thomas C. Adams; David L. Schulte, Jr.; David W. Largent; Kenneth W. Seyffert; Guy L. McClung, III |
| A screen which in at least certain aspects has at least one layer of screening material, at least one ramp formed on the at least one layer of screening material, and the at least one ramp having an upwardly projecting portion and also a lower portion or piece connected to the at least one layer of screening material, the at least one ramp positioned on the at least one layer of screening material normal to transverse to or at an angle to a direction of fluid to be flowed over the screen so that at least a portion of the fluid will pass up and over the upwardly projecting portion, the fluid, in one aspect, having solids entrained therein to be separated from the fluid by the screen. | ||||||
| 215 | Screen assembly for vibratory separators | US09820179 | 2001-03-28 | US06607080B2 | 2003-08-19 | Joseph Charles Winkler; Thomas C. Adams; David L. Schulte; Kenneth W. Seyffert; David W. Largent; Charles N. Grichar; Guy L. McClung, III |
| A screen assembly for a vibratory separator, the screen assembly having a first screen portion having a first end and a second end spaced apart from the first end, and a second screen portion formed integrally of or connected to the second end of the second screen portion. A screen assembly with a first portion of screening material and a second raised portion of screening material, the second raised portion extending from a material introduction end of the screen assembly to a material exit end thereof, the raised portion, in one aspect, culminating in an apex above the first portion of screening material. | ||||||
| 216 | Treatments for drill cuttings | US09836699 | 2001-04-16 | US06602181B2 | 2003-08-05 | Lirio Quintero; Jose Limia |
| The invention provides a method for treating drill cuttings, preferably marine cuttings, preferably in situ, so that the cuttings can be discharged into the environment, preferably back into marine waters without causing oxygen depletion of marine sediment. In a preferred embodiment, the treatment emulsifies and then encapsulates free hydrocarbons in the marine cuttings. | ||||||
| 217 | Method and system for hydraulic friction controlled drilling and completing geopressured wells utilizing concentric drill strings | US10262557 | 2002-09-30 | US20030062198A1 | 2003-04-03 | Robert Gardes |
| A method and system of drilling straight directional and multilateral wells utilizing hydraulic frictional controlled drilling, by providing concentric casing strings to define a plurality of annuli therebetween; injecting fluid down some of the annuli; returning the fluid up at least one annulus so that the return flow creates adequate hydraulic friction within the return annulus to control the return flow within the well. The hydraulic friction should be minimized on the injection side to require less hydraulic horsepower and be maximized on the return side to create the desired subsurface friction to control the well. | ||||||
| 218 | Removal of oil and chloride from oil contaminated material | US09459760 | 1999-12-13 | US06503337B1 | 2003-01-07 | Brian G. Roberts |
| A method for chemically removing hydrocarbons from oil contaminated material is described. The method comprises contacting the material containing the oil with a combinations of surfactants in an oil carrier similar to or identical to the oil to be removed. This process avoids the use of water. Therefore the process does not compromise the quality of the oil by having water as a contaminant and thus eliminating the possibility of oil contaminated water getting into the environment. In certain examples, when the process is used to remove oil from land based well bore cuttings, the processed well bore cuttings contain high levels of chlorides, which is an environmental problem. In such examples the method also includes contacting the well bore cuttings with a solution of dioctyl sodium sulfosuccinate in water to reduce the chloride concentration. An apparatus designed for this purpose is also described. | ||||||
| 219 | Methods and machines for making glued shale shaker screens | US10037474 | 2001-10-19 | US20020168469A1 | 2002-11-14 | Thomas C. Adams; Kerry Ward; Kenneth W. Seyffert; David W. Largent; David L. Schulte JR.; Charles N. Grichar; Vincent D. Leone; Jeffrey E. Walker; Guy L. McClung III |
| Methods for making screen assemblies and screens for a vibratory separator or shale shaker, such methods including applying glue in a glue pattern to at least one layer of screening material, said applying done by powered moving mechanical glue application apparatus; in one aspect moving with powered mechanical screen movement apparatus the at least one layer of screening material beneath the powered moving mechanical glue application apparatus; in one aspect, using hot melt moisture-curing glue, and in one aspect facilitating the cure of moisture-curing glue by applying moisture to it. | ||||||
| 220 | Method and system for hydraulic friction controlled drilling and completing geopressured wells utilizing concentric drill strings | US09771746 | 2001-01-29 | US06457540B2 | 2002-10-01 | Robert Gardes |
| A method and system of drilling straight directional and multilateral wells utilizing hydraulic frictional controlled drilling, by providing concentric casing strings to define a plurality of annuli therebetween; injecting fluid down some of the annuli; returning the fluid up at least one annulus so that the return flow creates adequate hydraulic friction within the return annulus to control the return flow within the well. The hydraulic friction should be minimized on the injection side to require less hydraulic horsepower and be maximized on the return side to create the desired subsurface friction to control the well. | ||||||
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