| 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 | Method for making a well for removing fluid from a desired subterranean formation | US10438720 | 2003-05-15 | US06932168B2 | 2005-08-23 | Claude Morgan; Geoff W. Fanning; Joseph P. Aman; Brian Varcoe; Robert Kolkmeier; Robert Stayton; Richard L. Toothman |
| An improved method for making a well for removing fluid from a desired subterranean formation. This invention provides for a method for making a well for removing fluid from a desired subterranean formation having an interface zone. The interface zone is coupled to a main directional well bore that extends from a top surface at ground level into the desired subterranean formation. A lateral well bore is also coupled to the interface zone. A directional sump bore is also coupled to the interface zone and the directional sump bore extends from the interface zone to a point below the interface zone. There is also a means for moving fluid from the directional sump bore through the main directional well bore to the top surface. | ||||||
| 202 | Multi seam coal bed/methane dewatering and depressurizing production system | US10372522 | 2003-02-21 | US06923275B2 | 2005-08-02 | Robert Gardes |
| A process for underbalanced drilling into multiple coal and shale formations, and dewatering the drilled formations, which includes drilling a first borehole through several coal seams to a certain depth, defined as a cased borehole; lowering an upstock on the end of a carrier string to the depth of the upper coal seam; lowering a drill string in the carrier string, and angling off of the upstock, to drill a lateral or horizontal borehole within the coal seam; repeating the process for the second coal seam; setting a packer in place above the first coal seam in the annulus between the cased borehole and the carrier string; forming perforations in the wall of the carrier string below the packer; retrieving the upstock from the carrier string; lowering an electrical submersible pump to the bottom of the principal borehole, defined as a sump portion of the borehole; collecting methane gas from the two coal seams through the annulus between the second drill string and the carrier string to the surface; pumping water from the sump portion to the surface within the annulus of the second drill string, while gas within the annulus between the carrier string and the outer casing enters the plurality of perforations in the carrier string to be carried up to the surface. | ||||||
| 203 | Segregated deployment of downhole valves for monitoring and control of multilateral wells | US10730470 | 2003-12-08 | US20050121190A1 | 2005-06-09 | James Oberkircher; Terry Schroter |
| Segregated deployment of downhole valves for monitoring and control of multilateral wells. In a described embodiment, a well completion system includes at least two tubular strings. One tubular string includes a flow control device and sensor controlling and monitoring fluid flow into the tubular string from a zone intersected by a wellbore. Another tubular string with another flow control device and sensor controls and monitors fluid flow into that tubular string from another zone intersected by another wellbore. The two wellbores intersect. Each of the flow control devices is positioned in a respective one of the wellbores and has at least one line connected to the flow control device. The lines are installed in the wellbores without interruptions in the lines and without requiring connections to be made in the lines downhole. | ||||||
| 204 | Apparatus and method of drilling with casing | US10319792 | 2002-12-13 | US06899186B2 | 2005-05-31 | Gregory G. Galloway; David J. Brunnert |
| The present invention generally relates to methods for drilling a subsea wellbore and landing a casing mandrel in a subsea wellhead. In one aspect, a method of drilling a subsea wellbore with casing is provided. The method includes placing a string of casing with a drill bit at the lower end thereof in a riser system and urging the string of casing axially downward. The method further includes reducing the axial length of the string of casing to land a wellbore component in a subsea wellhead. In this manner, the wellbore is formed and lined with the string of casing in a single run. In another aspect, a method of forming and lining a subsea wellbore is provided. In yet another aspect, a method of landing a casing mandrel in a casing hanger disposed in a subsea wellhead is provided. | ||||||
| 205 | Apparatus and method for downhole fluid separation | US10332193 | 2001-07-06 | US06845821B2 | 2005-01-25 | Jelle Sipke Bouma; Eric Johannes Puik; Paulus-Henricus Joannes Verbeek |
| This disclosure concerns a static oil/water separation chamber that is installed in a well extending to an underaround production formation containing hydrocarbon oil and water. The separation chamber has an inlet for receiving well fluid from a section below the separation chamber and two outlets. One outlet discharges a water-enriched component into a discharge well section, and the other outlet produces an oil-enriched component. The height of the separation chamber is larger than the thickness of the dispersion band that is formed under normal operating conditions. | ||||||
| 206 | Self orienting lateral junction system | US10878795 | 2004-06-28 | US20050006100A1 | 2005-01-13 | Douglas Murray; David Westgard; Aubrey Mills |
| A self orienting liner hanger system including a bent sub, an indexing sub in operable communication with the bent sub, a hanger assembly in operable communication with the indexing sub, and a profile connected with the hanger assembly. Yet further disclosed herein is a method for constructing a junction between a primary borehole and a lateral borehole. The method includes installing a window sleeve at the junction, running a liner hanger into the sleeve, cycling an indexing sub of the hanger until a bent sub of the hanger exits the window, and running the hanger into engagement with the sleeve. | ||||||
| 207 | Method and apparatus of providing an optical fiber along a power supply line | US10884057 | 2004-07-02 | US20040256100A1 | 2004-12-23 | Paulo S. Tubel; Glynn Williams; Kurt A. Hickey; Nigel Leggett |
| This invention provides a method for controlling production operations using fiber optic devices. An optical fiber carrying fiber-optic sensors is deployed downhole to provide information about downhole conditions. Parameters related to the chemicals being used for surface treatments are measured in real time and on-line, and these measured parameters are used to control the dosage of chemicals into the surface treatment system. The information is also used to control downhole devices that may be a packer, choke, sliding sleeve, perforation, device, flow control valve, completion device, an anchor or any other device. Provision is also made for control of secondary recovery operations online using the downhole sensors to monitor the reservoir conditions. The present invention also provides a method of generating motive power in a wellbore utilizing optical energy. This can be done directly or indirectly, e.g., by first producing electrical energy that is then converted to another form of energy. | ||||||
| 208 | Process for pressure stimulating a well bore through a template | US10626298 | 2003-07-24 | US20040238172A1 | 2004-12-02 | Gary J. Collins; John Lindley Baugh; Doug J. Murray; Aubrey Clifton Mills |
| One or more templates are provided for circulating fluids in a main well bore and for drilling and completing at least one offset well bore from the main well bore. Each template has a body, an inlet leg, a main outlet leg, and an offset outlet leg. A straddle assembly is mounted in the template to configure the template for fluid circulation. The straddle assembly, in cooperation with the inlet and main outlet legs, effects a downhole flow path which directs fluids from the inlet leg through body of the template and out the main outlet leg, bypassing the offset outlet leg. The straddle assembly is distally displaced from the template to reconfigure the template for drilling. A diverter is placed in the body of the template upon displacement of the straddle assembly to define a drill string path from the inlet leg to the offset outlet leg. The offset well bore is drilled by conveying a drill string through the drill string path. The diverter may then be used to direct additional fluids or tools from the inlet leg to the offset outlet leg for completion of the offset well bore. | ||||||
| 209 | Downhole equipment, tools and assembly procedures for the drilling, tie-in and completion of vertical cased oil wells connected to liner-equipped multiple drainholes | US09944115 | 2001-09-04 | USRE38616E1 | 2004-10-12 | Michael Gondouin |
| Single horizontal wells drilled through heterogeneous reservoirs are capable of greater oil productivity than vertical wells, often with lower produced GOR and WOR. Multiple drainholes tied-in to a vertical cased well are even more beneficial. Completion of such drainholes in many sandy reservoirs must use cemented liners. Well configurations comprising multiple drainholes liners, each of them tied-in to a vertical casing by pressure-tight connections require novel technologies making use of some novel downhole equipment, tools and procedures for drilling, tie-in and completion of such wells. These may be for newly-drilled wells or may be obtained by re-entry into an existing vertical cased well. Specific equipment, including novel casing joints, whipstocks, intermediate liners and tubing completion assembly components applicable to new wells are described herein. Equipment comprising novel casing inserts and patches applicable to re-entry wells, and the corresponding tubing completion assembly components for a variety of well exploitation modes are also described, together with the required tools and procedures. The liners of the drainholes are such that known well logging and cleaning tools may be used throughout the well's life. The various tubing completion assemblies can all be run-in and installed in a single trip. They allow either commingled flow from all drainholes or selective injection into some drainholes while others are under production. They are adapted to a variety of reservoir pressure conditions and of oil types, including heavy oil produced by sequential “huff and puff” steam injection. | ||||||
| 210 | Wellbores utilizing fiber optic-based sensors and operating devices | US10121375 | 2002-04-12 | US06787758B2 | 2004-09-07 | Paulo S. Tubel; Glynn Williams; Michael H. Johnson; John W. Harrell; Jeffrey J. Lembcke; Kurt A. Hickey; Nigel Leggett |
| This invention provides a method for controlling production operations using fiber optic devices. An optical fiber carrying fiber-optic sensors is deployed downhole to provide information about downhole conditions. Parameters related to the chemicals being used for surface treatments are measured in real time and on-line, and these measured parameters are used to control the dosage of chemicals into the surface treatment system. The information is also used to control downhole devices that may be a packer, choke, sliding sleeve, perforating device, flow control valve, completion device, an anchor or any other device. Provision is also made for control of secondary recovery operations online using the downhole sensors to monitor the reservoir conditions. The present invention also provides a method of generating motive power in a wellbore utilizing optical energy. This can be done directly or indirectly, e.g., by first producing electrical energy that is then converted to another form of energy. | ||||||
| 211 | Subsea controlled milling | US10377138 | 2003-02-28 | US20040168829A1 | 2004-09-02 | Joseph E. Hess; Neil Hepburn; Benji Smith; John J. Guerrero; Ian W. Thackwray |
| Subsea controlled milling apparatus and methods. In a described embodiment, a method of controlling displacement of a cutting device conveyed on a tubular string in a subterranean well includes the steps of: interconnecting an apparatus in the tubular string, the apparatus including an axial advancement device and an anchoring device; actuating the anchoring device to anchor the apparatus in the well; applying a pressure differential to the advancement device, thereby displacing the cutting device relative to the apparatus; and operating the cutting device to cut a structure in the well. | ||||||
| 212 | Multi-layer deformable composite construction for use in a subterranean well | US10348212 | 2003-01-21 | US20040140103A1 | 2004-07-22 | David J. Steele; John C. Gano |
| A multi-layer deformable composite construction. In a described embodiment, a method of expanding a structure in a wellbore includes the steps of: positioning the structure in an unexpanded configuration in the wellbore, the structure including a wall made up of multiple layers; expanding the structure to an expanded configuration while permitting relative displacement between the layers; and then preventing relative displacement between the layers. | ||||||
| 213 | Method and system for hydraulic friction controlled drilling and completing geopressured wells utilizing concentric drill strings | US10262557 | 2002-09-30 | US06745855B2 | 2004-06-08 | 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. | ||||||
| 214 | Apparatus and method for spacing out of offshore wells | US10044397 | 2002-01-09 | US06712149B2 | 2004-03-30 | Dwayne D. Leismer; Rodney J. Wetzel |
| An apparatus and technique for use in spacing out tubular strings within a well includes a casing that has an inner wall and at least one profile that is disposed within the inner wall. A tubing hanger is attached to the well tubing and if capable of landing within a target location, such as a wellhead. When the landing tool is seated within the profile, the length of well tubing needed to land the tubing hanger within the target location can be determined. A landing tool is linked to well tubing and is sized so as to seat within the profile. | ||||||
| 215 | Inductively coupled method and apparatus of communicating with wellbore equipment | US09859944 | 2001-05-17 | US06684952B2 | 2004-02-03 | Mark W. Brockman; Herve Ohmer; David L. Malone |
| A method and apparatus that allows communications of electrical power and signaling from downhole component to another downhole component employs an inductive coupler assembly. In one arrangement, one portion of the inductive coupler assembly is attached to a production tubing section and the other portion of the inductive coupler assembly is attached to a casing or other liner section. The production tubing inductive coupler portion is electrically connected to a cable over which electrical power and signals may be transmitted. Such power and signals are magnetically coupled to the inductive coupler portion in the casing or liner section and communicated to various electrical devices mounted outside the casing or liner section. In other arrangements, inductive coupler assemblies may be used to couple electrical power and signals from the main bore to components in lateral branches of a multilateral well. | ||||||
| 216 | Template and system of templates for drilling and completing offset well bores | US09528781 | 2000-03-17 | US06615920B1 | 2003-09-09 | Gary J. Collins; John Lindley Baugh; Doug J. Murray; Aubrey Clifton Mills |
| One or more templates are provided for circulating fluids in a main well bore and for drilling and completing at least one offset well bore from the main well bore. Each template has a body, an inlet leg, a main outlet leg, and an offset outlet leg. A straddle assembly is mounted in the template to configure the template for fluid circulation. The straddle assembly, in cooperation with the inlet and main outlet legs, effects a downhole flow path which directs fluids from the inlet leg through body of the template and out the main outlet leg, bypassing the offset outlet leg. The straddle assembly is distally displaced from the template to reconfigure the template for drilling. A diverter is placed in the body of the template upon displacement of the straddle assembly to define a drill string path from the inlet leg to the offset outlet leg. The offset well bore is drilled by conveying a drill string through the drill string path. The diverter may then be used to direct additional fluids or tools from the inlet leg to the offset outlet leg for completion of the offset well bore. | ||||||
| 217 | Method and system for avoiding damage to behind-casing structures | US10082469 | 2002-02-25 | US20030159826A1 | 2003-08-28 | Herve Ohmer |
| A structure is positioned on the outer surface of a casing or liner to enable cutting the casing in substantially any azimuth over a given length of casing without damaging the structure. After placing the casing in a wellbore, the position of the structure on the casing may be determined with reference to an orienting slot in an indexing coupling. Thereafter, a non-colliding region on the casing may be identified for cutting the casing. | ||||||
| 218 | Anchor apparatus and method | US09575091 | 2000-05-19 | US06554062B1 | 2003-04-29 | Charles H. Dewey; Mark J. Murray; Wei Xu |
| The well reference apparatus and method of the present invention includes an anchor member with a orientation member preferably permanently installed within the borehole at a preferred depth and orientation in one trip into the well. The orientation member provides a permanent reference for the orientation of well operations, particularly in a multi-lateral well. The assembly of the present invention includes disposing the anchor member and orientation member on the end of a pipe string. An orienting tool such as an MWD collar is disposed in the pipe string above the anchor member. This assembly is lowered into the borehole on the pipe string. Once the preferred depth is attained, the MWD is activated to determine the orientation of the orientation member. If the orientation member is not oriented in the preferred direction, the pipe string is rotated to align the orientation member in the preferred direction. This process is repeated for further corrective action and to verify the proper orientation of the orientation member. Upon achieving the proper orientation of the orientation member, the anchor member is set within the borehole and the pipe string is disconnected from the orientation member and anchor member and retrieved. | ||||||
| 219 | Method and apparatus for controlling well pressure in open-ended casing | US10294080 | 2002-11-14 | US20030066653A1 | 2003-04-10 | Herve Ohmer; Ricardo M. Carossino; Jean-Marc Follini; Mikhail V. Gotlib |
| A system and method for preventing blowouts during the deployment of a casing string into a wellbore. The system includes securing a casing coupling to a casing string and securing a retrievable check valve within the casing coupling. The retrievable check valve allows fluid from the surface to be pumped through the retrievable check valve. However, the retrievable check valve prevents upward fluid flow from the wellbore through the retrievable check valve to the surface. | ||||||
| 220 | Single well combination oil production/water dump flood apparatus and methods | US10217704 | 2002-08-13 | US20030066649A1 | 2003-04-10 | Leo W. Koot; Michael R. Konopczynski |
| A subterranean well production system utilizes a single well to perform both hydrocarbon fluid production and water dumpflooding processes. The well has a primary wellbore that is communicated with first and second subterranean zones respectively containing hydrocarbon fluid and higher pressure water. A second, lateral wellbore extends from the primary wellbore and communicates with the first zone. A remotely controllable routing system, including a valved production tubing structure extending through the primary wellbore, is operable to (1) flow hydrocarbon fluid from the first zone to the surface via the production tubing and (2) simultaneously dumpflood water from the second zone into the first zone, via the production tubing, to increase the pressure within the first zone and thereby increase the hydrocarbon fluid production rate. | ||||||
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