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Patent US6376315 - Method of forming a trench DMOS having reduced threshold voltage - Google PatentsSearch Images Maps Play YouTube News Gmail Drive More »Sign inAdvanced Patent SearchPatentsA method of manufacturing one or more trench DMOS transistors is provided. In this method, one or more or more body regions adjacent one or more trenches are provided. The one or more trenches are lined with a first insulating layer. A portion of the first insulating layer is removed along at least the...http://www.google.com/patents/US6376315?utm_source=gb-gplus-sharePatent US6376315 - Method of forming a trench DMOS having reduced threshold voltageAdvanced Patent SearchPublication numberUS6376315 B1Publication typeGrantApplication numberUS 09/540,856Publication dateApr 23, 2002Filing dateMar 31, 2000Priority dateMar 31, 2000Fee statusPaidAlso published asCN1227722C, CN1426598A, DE60116612D1, DE60116612T2, EP1269530A2, EP1269530B1, WO2001075960A2, WO2001075960A3Publication number09540856, 540856, US 6376315 B1, US 6376315B1, US-B1-6376315, US6376315 B1, US6376315B1InventorsFwu-Iuan Hshieh, Koon Chong SoOriginal AssigneeGeneral Semiconductor, Inc.Export CitationBiBTeX, EndNote, RefManPatent Citations (11), Non-Patent Citations (1), Referenced by (15), Classifications (10), Legal Events (5) External Links: USPTO, USPTO Assignment, EspacenetMethod of forming a trench DMOS having reduced threshold voltage
US 6376315 B1Abstract
What is claimed is: 1. A method of manufacturing one or more trench DMOS transistors comprising:
providing a substrate of a first conductivity type, forming an epitaxial layer of said first conductivity type over said substrate, said epitaxial layer having a lower majority carrier concentration than said substrate; forming a region of a second conductivity type within an upper portion of said epitaxial layer; forming A plurality of trenches within said epitaxial layer, said trenches defining one or more body regions within said region of second conductivity type, forming a first insulating layer that lines said trenches; providing a conductive region within said trenches adjacent to the first insulating layer lining said trenches; removing a portion of said first insulating layer along at least upper sidewalls of said trenches such that portions of said body regions are exposed along said upper sidewalls; oxidizing at least said exposed portions of said body regions to form an oxide layer, said oxidizing step resulting in regions of reduced majority carrier concentration within said body regions adjacent said oxide layer; and forming a plurality of source regions of said first conductivity type within upper portions of said body regions adjacent said trenches, said source regions being adjacent said regions of reduced majority carrier concentration within said body regions. 2. The method of claim 1, wherein said substrate is a silicon substrate and said epitaxial layer is a silicon layer.
10. The method of claim 1, wherein the step of oxidizing at least the exposed upper sidewall portions of the body regions comprises dry oxidation at a temperature ranging frorn 900 to 1100� C.
11. The method of claim 10, wherein the temperature ranges from 900 to 950� C.
12. The method of claim 1, wherein the step of oxidizing at least the exposed upper sidewall portions of the body regions comprises oxidation in steam at a temperature ranging from 900 to 1100� C.
13. The method of claim 12, wherein the temperature ranges from 900 to 950� C.
providing an N-type silicon substrate forming an N-type silicon epitaxial layer over said substrate, said epitaxial layer having a tower doping concentration than said substrate; forming a P-type region within an upper portion of said epitaxal layer, fording a plurality of trenches within said epitaxial layer, said trenches defining one or more P-body regions within said P-type region; foxing a first oxide layer that lines said trenches; providing a conductive region within said trenches adjacent the first oxide layer lining said trenches; removing a portion of said first oxide layer along at least upper sidewalls of said trenches such that portions of said P-body regions are exposed along said upper sidewalls; oxidizing at least said exposed portions of said P-body regions to form a second oxide layer, said oxidizing step resulting in regions of reduced P-type carrier concentration within said P-body regions adjacent said second oxide layer; and forming a plurality of N-type source regions within upper portions of said P-body regions adjacent said trenches, said N-type source regions being adjacent said regions of reduced P-type carrier concentration within said P-body regions. 18. The method of claim 17, wherein the conductive region is a polycrystalline silicon region.
19. The method of claim 17, wherein the step of oxidizing at least the exposed upper sidewall portions of the P-body regions comprises dry oxidation at a temperature ranging from 900 to 1100� C.
20. The method of claim 19, wherein the temperature ranges from 900 to 950� C.
21. The method of claim 17, wherein the step of oxidizing at least the exposed upper sidewall portions of the P-body regions comprises wet oxidation in steam at a temperature ranging from 900 to 1100� C.
22. The method of claim 21, wherein the temperature ranges from 900 to 950� C.
providing one or mote or more body regions adjacent one or more trenches, said one or more trenches being lined with a first insulating layer; removing a portion of said first insulating layer along at least upper sidewalls of said trenches such that portions of said body regions are exposed along said upper sidewalls; and oxidizing at least said exposed portions of said body regions, said oxidizing step resulting in regions of reduced majority carrier concentration within said body regions adjacent said oxide layer.
Metal oxide semiconductor field effect transistor (MOSFET) devices using trench gates provide low turn-on resistance and are often used for low power applications. In a trench MOSFET device, the channels are arranged in a vertical manner, instead of horizontally as in most planar configurations. FIG. 1 shows a cross-sectional view of a conventional trenched gate MOSFET device having a unit cell designated by reference numeral 2. The MOSFET cell 2 includes a trench 4 filled with conductive material 6 separated from the silicon regions 8 by a thin layer of insulating material 10. A body region 12 is diffused in an epitaxial layer 18, and a source region 14 is in turn diffused in the body region 12. Due to the use of these two diffusion steps, a transistor of this type is frequently referred to as a double-diffused metal oxide semiconductor field effect transistor with trench gating or, in brief, a �trench DMOS�.
During normal operation, the drain region 20 and the body region 12 are reverse biased. Consequently, a depletion layer is formed, characterized by a depletion region 24 with a depletion width W as shown in FIG. 1. As is well known in the art, the lighter the impurity concentration of a region, the wider the depletion width W extending into that region. Referring back to FIG. 1, if the body region 12 is too lightly doped, the depletion layer 24 may reach the source region 14 during operation, resulting in an undesirable effect called �punch-through�. During punch-through, current flows directly from the source 14 to the drain 20 without passing through the channel 21, and breakdown ensues.
The majority carrier concentration within the one or more body regions is modified by removing a portion of the first insulating layer along at least upper sidewalls of the trenches, preferably by wet etch, such that portions of the body regions are exposed along the upper sidewalls. An oxide layer is then formed over at least the exposed portions of the body regions, resulting in regions of reduced majority carrier concentration within the body regions adjacent the oxide layer. This oxide-forming step can be, for example, dry oxidation at a temperature ranging from 900 to 1100� C., more preferably 900 to 950� C. Alternatively, the oxide layer can be formed in steam at a temperature ranging from 900 to 1100� C., more preferably 900 to 950� C.
FIG. 5 illustrates approximate doping profiles in a boron-doped silicon material after formation of a surface oxide in dry oxygen at 900� C.
Referring now to FIG. 4A, an N-doped epitaxial layer 202 is grown on an N+doped substrate 200. For example, epitaxial layer 202 can be 5.5 microns thick and have a doping concentration of 3.4�1016 cm−3 for a 30 V trench DMOS device. Next, P-body regions 204 are formed in the epitaxial layer 202 by implantation, diffusion and trench-forming processes. For example the epitaxial layer 202 may be implanted with boron at 50 keV with a dosage of 6�1013 cm−3, followed by diffusion at 1100� C. A patterned masking layer (not shown) is then provided and trenches 207 are formed through apertures in the patterned masking layer. Trenches 207 are preferably dry etched through the apertures in the masking layer via reactive ion etching, for example, to a depth that ranges from 1.0 to 2.0 microns, forming discrete P-body regions 204. The patterned masking layer is then removed and an oxide layer 206 is formed over the surface of the entire structure, typically by dry oxidation. Oxide thickness in the range of 300 to 700 Angstroms is typical for layer 206. The resulting structure is shown in FIG. 4A.
The surface of the structure is then covered (and the trenches are filled) with a polysilicon (i.e., polycrystalline silicon) layer using techniques known in the art, such as CVD. The polysilicon is doped, for example, N-type to reduce its resistivity, typically on order of 20 Ω/sq. N-type doping can be carried out, for example, during CVD with phosphorous chloride or by implantation with arsenic or phosphorous. The polysilicon layer is then etched, for example, by reactive ion etching, to optimize its thickness within the trenches and to expose portions of oxide layer 206 as shown in FIG. 4B. Due to etching uniformity concerns, the polysilicon layer is slightly over-etched, and the thus-formed polysilicon gate regions 210 typically have top surfaces that are 0.1 to 0.2 microns below the adjacent top surfaces of the P-body region 204 (shown as distance �d� in FIG. 4B).
(3) ratio of the parabolic oxidation rate constant B and the root of the diffusion coefficient of the dopant in silicon or B D dopant , Si . FIG. 5 illustrates approximate doping profiles in a boron-doped silicon material after formation of a surface oxide in dry oxygen at 900� C. In FIG. 5, the oxide region corresponds to the left-hand side of the plot between x=0 (the oxide surface) and xi (the oxide/silicon interface). The silicon region corresponds to the right-hand side of FIG. 5 in the region beyond xi. Prior to oxidation, the silicon was uniformly doped at a bulk concentration Cb. After oxidation the bulk silicon region at the right-hand side of FIG. 5 remains at this level. However, as the interface is approached, the dopant concentration in the silicon decreases. In this case, the concentration of boron at the silicon interface is about 20% of the concentration of boron in the bulk, Cb. (By way of comparison, the concentration of the boron in the oxide layer at the interface is about 60% of Cb.)
The table to follow contains the ratio of boron concentration in silicon at the interface (Ci) to boron concentration in the silicon bulk (Cb) after oxidation of a silicon layer with initial concentration Cb. As noted above in connection with FIG. 5, this ratio is about 0.2 (20%) where silicon is oxidized in dry oxygen at 900� C. This ratio and several others are presented in the following table. Note from this table that a greater redistribution occurs at the interface at lower temperatures and for steam oxidation.
Oxidation at 640 torr
0.2 0.14
Subsequently, as seen from FIG. 4D, a patterned masking layer 211 is provided which defines source regions 212. Source regions 212 are typically formed within upper portions of the P-body regions 204 via an implantation and diffusion process. For example, the source regions 212 may be implanted with arsenic at 120 keV to a concentration in the range of 5�1015 to 1�1016 cm−3. The resulting structure is shown in FIG. 4D. As seen from FIG. 4D, after implantation of the source regions 212, a portion of the P-body region 204 remains that is adjacent to the pad oxide layer 209 that was formed (and is hence depleted in boron concentration at the oxide interface).
This dopant redistribution can be seen by examining the doping concentration profile along line x′�x′ in FIG. 4E, which approximates that shown in FIG. 3 without resorting to high implantation energies or a P-N-P structure. Specifically, the N+source region 212 has a doping profile like that of the region between x=0 and x=xjs in FIG. 3; the P-body region 204 has a doping profile like that of the region between x=xjs and x=xjb in FIG. 3; and the N-doped epitaxial layer 202 has a doping profile like that of the region beyond x=xjb in FIG. 3. Hence the doping concentration in the N+source region 212 is approximated by curve 64, the doping concentration in the P-body region 204 is approximated by curve 66, and the doping concentration in the N-doped epitaxial layer 202 is approximated by curve 68 of FIG. 3. As discussed above, by forming a pad oxide layer 209 adjacent the upper portion of the P-body region 204, the concentration of boron is reduced in the P-body region 204 at the oxide interface. This region of reduced boron concentration corresponds to the left-hand side of curve 66. Curve 30, shown as a dashed line, represents the approximate doping profile that would have existed in the absence of an etch-back step for the gate oxide 206 g and in the absence of the formation of pad oxide layer 209.
Again, by the process of the present invention, a desirable doping profile like that discussed in U.S. Pat. No. 5,907,776 can be established in the P-body region, without having to resort to high implantation energies or a P-N-P structure. As previously noted, such a doping profile is beneficial in that a low threshold voltage can be established without resorting to a thinner gate oxide (which would reduce yield and switching speed) and without substantially increasing the likelihood of punch-through. Specifically, the present inventors have found that by growing the pad oxide layer 209 to a thickness of about 200 Angstroms at 900� C. in dry oxygen, a 0.4 V reduction in threshold voltage can be achieved for a 30 V device, without a substantial sacrifice in switching speed or punch-through resistance.
Patent CitationsCited PatentFiling datePublication dateApplicantTitleUS5072266 *Dec 27, 1988Dec 10, 1991Siliconix IncorporatedTrench DMOS power transistor with field-shaping body profile and three-dimensional geometryUS5468982 *Jun 3, 1994Nov 21, 1995Siliconix IncorporatedTrenched DMOS transistor with channel block at cell trench cornersUS5597765 *Apr 17, 1995Jan 28, 1997Siliconix IncorporatedMethod for making termination structure for power MOSFETUS5907776Jul 11, 1997May 25, 1999Magepower Semiconductor Corp.Method of forming a semiconductor structure having reduced threshold voltage and high punch-through toleranceUS5970344 *Aug 24, 1998Oct 19, 1999Sanyo Electric Co., Ltd.Method of manufacturing semiconductor device having gate electrodes formed in trench structure before formation of source layersUS5981344 *Jun 4, 1996Nov 9, 1999Siliconix IncorporatedTrench field effect transistor with reduced punch-through susceptibility and low RDSonUS6096608 *Nov 3, 1998Aug 1, 2000Siliconix IncorporatedBidirectional trench gated power mosfet with submerged body bus extending underneath gate trenchUS6211018 *Dec 30, 1999Apr 3, 2001Electronics And Telecommunications Research InstituteMethod for fabricating high density trench gate type power deviceUS6218217 *Jul 18, 2000Apr 17, 2001Mitsubishi Denki Kabushiki KaishaSemiconductor device having high breakdown voltage and method of manufacturing the sameUS20010008291 *Jan 12, 2001Jul 19, 2001Takaaki AokiSemiconductor device and method for manufacturing the sameUS20010008788 *Mar 2, 2001Jul 19, 2001Fwu-Iuan HshiehDouble diffused Metal on Semiconductor (DMOS); steps of trench formation completed prior to removal of the patterned trench mask so dopant does not leach out of the p-body since the mask serves as barrier, preventing leakage current* Cited by examinerNon-Patent CitationsReference1Semiconductor Technology Handbook, Technology Associates, pp. 4.4, 4.15-4.16, Jan. 15, 1985.Referenced byCiting PatentFiling datePublication dateApplicantTitleUS6548861 *Jul 6, 2001Apr 15, 2003Infineon Technologies AgMemory cell, memory cell arrangement and fabrication methodUS6576954 *Feb 6, 2002Jun 10, 2003Fairchild Semiconductor CorporationTrench MOSFET formed using selective epitaxial growthUS6794249 *Feb 28, 2003Sep 21, 2004Infineon Technologies AgMethod for fabricating a memory cellUS6802719 *Sep 6, 2001Oct 12, 2004Zetex PlcImplantation methodUS7488647 *Aug 11, 2005Feb 10, 2009National Semiconductor CorporationSystem and method for providing a poly cap and a no field oxide area to prevent formation of a vertical bird's beak structure in the manufacture of a semiconductor deviceUS7504303May 24, 2006Mar 17, 2009Fairchild Semiconductor CorporationTrench-gate field effect transistors and methods of forming the sameUS7923776Feb 2, 2010Apr 12, 2011Fairchild Semiconductor CorporationTrench-gate field effect transistor with channel enhancement region and methods of forming the sameUS7989883Jan 16, 2009Aug 2, 2011National Semiconductor CorporationSystem and method for providing a poly cap and a no field oxide area to prevent formation of a vertical bird's beak structure in the manufacture of a semiconductor deviceUS8043913Mar 29, 2011Oct 25, 2011Fairchild Semiconductor CorporationMethod of forming trench-gate field effect transistorsUS8441069Oct 21, 2011May 14, 2013Fairchild Semiconductor CorporationStructure and method for forming trench-gate field effect transistor with source plugUS8592895Oct 1, 2012Nov 26, 2013Fairchild Semiconductor CorporationField effect transistor with source, heavy body region and shielded gateUS8872278Oct 25, 2011Oct 28, 2014Fairchild Semiconductor CorporationIntegrated gate runner and field implant termination for trench devicesUS8884365May 10, 2013Nov 11, 2014Fairchild Semiconductor CorporationTrench-gate field effect transistorUS8889539Dec 11, 2008Nov 18, 2014Samsung Electronics Co., Ltd.Recess gate transistorCN101459135BDec 14, 2007May 26, 2010上海华虹Nec电子有限公司Implementing method for slot type dual layer grid power MOS device construction* Cited by examinerClassifications U.S. Classification438/270, 438/272, 257/E29.066, 257/330, 438/271International ClassificationH01L21/336, H01L29/10, H01L29/78Cooperative ClassificationH01L29/1095European ClassificationH01L29/10GLegal EventsDateCodeEventDescriptionOct 18, 2013FPAYFee paymentYear of fee payment: 12Oct 14, 2009FPAYFee paymentYear of fee payment: 8May 20, 2005FPAYFee paymentYear of fee payment: 4Dec 31, 2002CCCertificate of correctionSep 5, 2000ASAssignmentOwner name: GENERAL SEMICONDUCTOR, INC., NEW YORKFree format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:HSHIEH, FWU-IUAN;SO, KOON CHONG;REEL/FRAME:011224/0661Effective date: 20000807Owner name: GENERAL SEMICONDUCTOR, INC. 10 MELVILLE PARK RD. MRotateOriginal ImageGoogle Home - Sitemap - USPTO Bulk Downloads - Privacy Policy - Terms of Service - About Google Patents - Send FeedbackData provided by IFI CLAIMS Patent Services


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April Lady by Georgette Heyer Book Paperback 2005 0099476347 | eBay Skip to main contenteBayShop bycategoryEnter your search keywordAll CategoriesAdvancedDaily DealsCollectionsHi, (Sign in to bid or buy)My eBayExpand My eBaySellExpand SellCommunityExpand CommunityHelp & ContactExpand Help & ContactBasket
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DescriptionDespite the scandalous blemish on his bride's family name, Lord Giles Cardross is convinced that Nell cares for him. But as the bills and debts mount, Giles begins to suspect that his wife isn't as innocent as she looks. Reissue.Key FeaturesAuthor(s)Georgette HeyerPublisherCornerstoneDate of Publication02/06/2005Language(s)EnglishFormatPaperbackISBN-100099476347ISBN-139780099476344GenreHistorical & Mythological FictionPublication DataPlace of PublicationLondonCountry of PublicationUnited KingdomImprintArrow Books LtdDimensionsWeight187 gWidth129 mmHeight198 mmSpine16 mmPagination256Editorial DetailsFormat DetailsB-format paperbackDescriptionAuthor BiographyAuthor of over fifty books, Georgette Heyer is the best-known and best-loved of all historical novelists, who made the Regency period her own. Her first novel, The Black Moth, published in 1921, was written at the age of fifteen to amuse her convalescent brother; her last was My Lord John. Although most famous for her historical novels, she also wrote eleven detective stories. Georgette Heyer died in 1974 at the age of seventy-one. Georgette Heyer was to many minds the finest historical and romantic novelist of her age, and April Lady shows how she has won a new audience with her dashing heroes and sparkly heroines.	Copyright in bibliographic data and cover images is held by Nielsen Book Services Limited or by the publishers or by their respective licensors: all rights reserved.
Item No: 9780099476344
Despite the scandalous blemish on his bride's family name, Lord Giles Cardross is convinced that Nell cares for him. But as the bills and debts mount, Giles begins to suspect that his wife isn't as innocent as she looks. Reissue.
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Patent US6700129 - Electronic board system and coordinates-inputting pen - Google PatentsSearch Images Maps Play YouTube News Gmail Drive More »Sign inPatentsThe present invention transmits, to an electronic board controller 14, click signals generated upon manipulating multiple switches provided on a coordinates-inputting pen 13, timing signals upon detecting infrared scanning beams 18 a and 18 b, and the like without using a connecting wire. Specifically,...http://www.google.com/patents/US6700129?utm_source=gb-gplus-sharePatent US6700129 - Electronic board system and coordinates-inputting penAdvanced Patent SearchTry the new Google Patents, with machine-classified Google Scholar results, and Japanese and South Korean patents.Publication numberUS6700129 B1Publication typeGrantApplication numberUS 10/048,557PCT numberPCT/JP2000/005266Publication dateMar 2, 2004Filing dateAug 4, 2000Priority dateAug 6, 1999Fee statusLapsedAlso published asDE60001671D1, DE60001671T2, EP1208529A1, EP1208529B1, WO2001011554A1Publication number048557, 10048557, PCT/2000/5266, PCT/JP/0/005266, PCT/JP/0/05266, PCT/JP/2000/005266, PCT/JP/2000/05266, PCT/JP0/005266, PCT/JP0/05266, PCT/JP0005266, PCT/JP005266, PCT/JP2000/005266, PCT/JP2000/05266, PCT/JP2000005266, PCT/JP200005266, US 6700129 B1, US 6700129B1, US-B1-6700129, US6700129 B1, US6700129B1InventorsYutaka Usuda, Yoshikazu Shinkai, Ichirou Takeuchi, Yuji Tsukamoto, Jun NamikiOriginal AssigneeHitachi Software Engineering Co., Ltd.Export CitationBiBTeX, EndNote, RefManPatent Citations (10), Referenced by (30), Classifications (12), Legal Events (6) External Links: USPTO, USPTO Assignment, EspacenetElectronic board system and coordinates-inputting pen
Based on the information of angles α and β, the operation circuit 100 calculates x-y coordinates of the coordinates-inputting pen 13 where, for example, the upper left corner of the board 11 being the origin, the x-axis being positive towards right and the y-axis being positive downward. The x-y coordinates of the coordinates-inputting pen 13 may be calculated by the following expressions where a is the distance between the left and right infrared scanning beam generators 12 a and 12 b. x=a·tan β/(tan α+tan β)
Patent CitationsCited PatentFiling datePublication dateApplicantTitleUS4217649Oct 11, 1978Aug 12, 1980Doundoulakis George JDigitizer for locating the position of a stylus point on a writing surfaceUS4294543Nov 13, 1979Oct 13, 1981Command Control & Communications CorporationOptical system for developing point coordinate informationUS4677428 *Jun 7, 1985Jun 30, 1987Hei, Inc.Cordless light penUS5900943 *Aug 29, 1997May 4, 1999Hewlett-Packard CompanyPage identification by detection of optical characteristicsUS6100538 *Feb 13, 1998Aug 8, 2000Kabushikikaisha WacomOptical digitizer and display means for providing display of indicated positionUS6437314 *May 26, 1999Aug 20, 2002Hitachi Software Engineering Co., Ltd.Coordinate input pen, and electronic board, coordinate input system and electronic board system using the coordinate input penUS6441362 *Oct 28, 1999Aug 27, 2002Kabushikikaisha WacomStylus for optical digitizerDE19810452A1Mar 11, 1998Dec 17, 1998Wacom Co LtdOptical coordinate digitiserGB2263546A Title not availableGB2306669A Title not available* Cited by examinerReferenced byCiting PatentFiling datePublication dateApplicantTitleUS7158117 *Jul 30, 2003Jan 2, 2007Canon Kabushiki KaishaCoordinate input apparatus and control method thereof, coordinate input pointing tool, and programUS7298367 *Nov 25, 2003Nov 20, 20073M Innovative Properties CompanyLight emitting stylus and user input device using sameUS7710504 *Feb 21, 2006May 4, 2010Mitsubishi Digital Electronics America, Inc.Remote control system and method for controlling a televisionUS8144271Aug 4, 2008Mar 27, 2012Perceptive Pixel Inc.Multi-touch sensing through frustrated total internal reflectionUS8259240Mar 26, 2012Sep 4, 2012Perceptive Pixel Inc.Multi-touch sensing through frustrated total internal reflectionUS8264619May 4, 2010Sep 11, 2012Mitsubishi Electric Visual Solutions America, Inc.Remote control system and method for controlling televisionUS8441467Aug 3, 2007May 14, 2013Perceptive Pixel Inc.Multi-touch sensing display through frustrated total internal reflectionUS9035914Jan 9, 2013May 19, 2015Samsung Display Co., Ltd.Touch system including optical touch panel and touch pen, and method of controlling interference optical signal in touch systemUS9196068 *Jun 13, 2013Nov 24, 2015Ricoh Company, LimitedProjector system, and method for drawingsUS20050091297 *Jul 30, 2003Apr 28, 2005Canon Kabushiki KaishaCoordinate input apparatus and control method thereof, coordinate input pointing tool, and programUS20050110777 *Nov 25, 2003May 26, 2005Geaghan Bernard O.Light-emitting stylus and user input device using sameUS20050110781 *Nov 25, 2003May 26, 2005Geaghan Bernard O.Light emitting stylus and user input device using sameUS20070195205 *Feb 21, 2006Aug 23, 2007Lowe Jerry BRemote control system and methodUS20080029691 *Aug 3, 2007Feb 7, 2008Han Jefferson YMulti-touch sensing display through frustrated total internal reflectionUS20080179507 *Aug 3, 2007Jul 31, 2008Han JeffersonMulti-touch sensing through frustrated total internal reflectionUS20080284925 *Aug 4, 2008Nov 20, 2008Han Jefferson YMulti-touch sensing through frustrated total internal reflectionUS20080291179 *Nov 21, 2006Nov 27, 2008Koninklijke Philips Electronics, N.V.Light Pen Input System and Method, Particularly for Use with Large Area Non-Crt DisplaysUS20090167728 *Mar 13, 2009Jul 2, 20093M Innovative Properties CompanyLight-emitting stylus and user input device using sameUS20100214495 *May 4, 2010Aug 26, 2010Mitsubishi Digital Electronics America, Inc.Remote Control System and Method for Controlling TelevisionUS20110279248 *Apr 26, 2011Nov 17, 2011Panasonic CorporationRemote instruction transmission/reception systemUS20130113758 *Jul 3, 2012May 9, 2013Samsung Electronics Co., Ltd.Method and system for recognizing touch point, and display apparatusUS20140015861 *Jun 13, 2013Jan 16, 2014Ryo TAKEMOTOProjection apparatus, projection system, and projection methodUS20150204658 *Jan 16, 2015Jul 23, 2015Seiko Epson CorporationPosition detecting device, position detecting system, and controlling method of position detecting deviceUS20160034106 *Dec 26, 2014Feb 4, 2016Coretronic CorporationTouch apparatus and touch sensing method thereofEP2188701A2 *Aug 4, 2008May 26, 2010Perceptive Pixel, Inc.Multi-touch sensing through frustrated total internal reflectionEP2188701A4 *Aug 4, 2008Nov 9, 2011Perceptive Pixel IncMulti-touch sensing through frustrated total internal reflectionEP2590059A3 *Mar 29, 2012Feb 24, 2016Samsung Electronics Co., Ltd.Method and system for recognizing touch point, and display apparatusWO2007102857A2 *Nov 14, 2006Sep 13, 2007Electronic Scripting Products, Inc.Optical navigation apparatus using fixed beacons and a centroid sensing deviceWO2007102857A3 *Nov 14, 2006Apr 17, 2008Marek AlbosztaOptical navigation apparatus using fixed beacons and a centroid sensing deviceWO2009020940A2Aug 4, 2008Feb 12, 2009Perceptive Pixel, Inc.Multi-touch sensing through frustrated total internal reflection* Cited by examinerClassifications U.S. Classification250/559.29, 250/221International ClassificationG06F3/042, G06F3/033, G06F3/041, G06F3/038Cooperative ClassificationG06F3/0423, G06F3/0383, G06F3/03545European ClassificationG06F3/0354N, G06F3/038E, G06F3/042B4Legal EventsDateCodeEventDescriptionMay 7, 2002ASAssignmentOwner name: HITACHI SOFTWARE ENGINEERING CO., LTD., JAPANFree format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:USUDA, YUTAKA;SHINKAI, YOSHIKAZU;TAKEUCHI, ICHIROU;AND OTHERS;REEL/FRAME:012870/0209Effective date: 20020301Aug 30, 2007FPAYFee paymentYear of fee payment: 4Aug 25, 2011FPAYFee paymentYear of fee payment: 8Oct 9, 2015REMIMaintenance fee reminder mailedMar 2, 2016LAPSLapse for failure to pay maintenance feesApr 19, 2016FPExpired due to failure to pay maintenance feeEffective date: 20160302RotateOriginal ImageGoogle Home - Sitemap - USPTO Bulk Downloads - Privacy Policy - Terms of Service - About Google Patents - Send 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How to type faster while coding? : learnprogramming
u/Punetic
How to type faster while coding?
Just starting to learn how to code with html dog and was wondering if there is any tips on how to type faster. I'm ok at typing regularly but with coding the keys used seem out of the way. Any help would be appreciated
How did you learn normal typing? By hitting the same keys over and over, right? Well, programming requires keys you may not use in "normal" typing as much. So how do you learn? Just keeping using them over and over, it just takes time.
Great observation. The short answer is, speed will come with practice.
The typical QWERTY keyboard layout isn't ideal for programming. We use a lot of special symbols that most people don't use on a regular basis and they often require slow and awkward hand positions. There are other layouts that can be easier to work with, but one can still become a fast typist on the standard QWERTY layout.
With time, typing a { will be just as natural as typing an 'x'. Some languages are also more verbose than others, so your choice of language can have an affect, but you can become fast at typing in any language.
Often the best thing you can do is not type as much. Shorter code is often easier to read, because it takes less time to read and requires us to remember less. Less is often more. The principal Don't Repeat Yourself can help to save time typing as well as avoid more opportunities for making mistakes.
Your choice of editor can also help. Many editors will auto-complete, which can save typing, including filling in parentheses and brackets automatically. Copy and paste can also be quite beneficial. Keyboard shortcuts for things like search and replace help too. Macros, templates, boilerplate code -- all of these can save time typing. Even just the key combinations involved can make a big difference. Emacs and Vim are both popular editors, each with different but effective ways of minimizing keystrokes for common actions.
As a professional with 6 years experience, I find typing isn't the problem. Reading, navigating, searching, testing, and thinking make up a large portion of my time while coding. Clean code practices can help to make reading and navigating faster. A good editor can make navigating and searching faster. Unit tests and scripts can make testing faster. And that leaves you more time for the most important part: thinking.
Long story short, you'll get faster with practice, but good coding habits and a good editor can help too.
Does VIM have comprehensive code complete? I was thinking of learning VIM or EMACS but without code complete I can't see any advantage.

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Garnet Ring 9K Yellow Gold 925 Silver filigree Garnet Ring
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MIRA POWER Limited: Board of Directors - Bloomberg
Company Overview of MIRA POWER Limited
MIRA POWER Limited INSIDERS ON Board Members
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To contact MIRA POWER Limited, please visit . Company data is provided by S&P Global Market Intelligence. Please use this form to report any data issues.

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Time-frequency dynamics of resting-state brain connectivity measured with fMRI. - PubMed - NCBI
1 selected item: 20006716
Neuroimage. 2010 Mar;50(1):81-98. doi: 10.1016/j.neuroimage.2009.12.011. Epub 2009 Dec 16.
Department of Electrical Engineering, Stanford University, Stanford, CA 94305, USA. catie@stanford.edu
Most studies of resting-state functional connectivity using fMRI employ methods that assume temporal stationarity, such as correlation and data-driven decompositions computed across the duration of the scan. However, evidence from both task-based fMRI studies and animal electrophysiology suggests that functional connectivity may exhibit dynamic changes within time scales of seconds to minutes. In the present study, we investigated the dynamic behavior of resting-state connectivity across the course of a single scan, performing a time-frequency coherence analysis based on the wavelet transform. We focused on the connectivity of the posterior cingulate cortex (PCC), a primary node of the default-mode network, examining its relationship with both the "anticorrelated" ("task-positive") network as well as other nodes of the default-mode network. It was observed that coherence and phase between the PCC and the anticorrelated network was variable in time and frequency, and statistical testing based on Monte Carlo simulations revealed the presence of significant scale-dependent temporal variability. In addition, a sliding-window correlation procedure identified other regions across the brain that exhibited variable connectivity with the PCC across the scan, which included areas previously implicated in attention and salience processing. Although it is unclear whether the observed coherence and phase variability can be attributed to residual noise or modulation of cognitive state, the present results illustrate that resting-state functional connectivity is not static, and it may therefore prove valuable to consider measures of variability, in addition to average quantities, when characterizing resting-state networks.
PMC2827259
10.1016/j.neuroimage.2009.12.011
Group-level thresholded t-maps for positive (red) and negative (blue) correlations with the PCC. Clusters are labeled according to .
Neuroimage. ;50(1):81-98.
Example of the cross-wavelet power (above left) and wavelet transform coherence (above right) for simulated data (bottom). The simulated data consist of negatively-correlated sinusoids with piecewise frequency content (f = 1/16 Hz for 0<t<200 sec, f = 1/32 Hz for 200<t<400 sec, and f = 1/96 Hz for 400<t<720 sec; thick lines in figure), embedded in Gaussian white noise (SNR=1.25; thin lines in figure). For the WTC, the phase angle between the 2 time series at particular locations in the time-frequency plane is indicated by an arrow (see text for further detail). Regions inside the cone of influence appear in faded color.
Wavelet transform coherence between the PCC and 3 of its anticorrelated ROIs, shown for 6 subjects: (top row) right SMG, (middle row) right insula, and (bottom row) right DLPFC. For each WTC map, time is on the x-axis and scale (Fourier period) is on the y-axis. Maps have been thresholded to include only regions that were significant at 95% confidence based on Monte Carlo tests. Colors indicate ranges of the wavelet coherence phase. A phase difference of 0 indicates positive correlation; π indicates negative correlation; π/2 indicates that the PCC ROI leads the anticorrelated ROI; −π/2 indicates that the anticorrelated ROI leads the PCC ROI. Regions of insignificant coherence appear in dark blue, and areas inside the cone of influence are in purple.
Wavelet transform coherence between the PCC and default-mode ROIs, shown for 6 subjects: (top row) MPFC, (middle row) right angular gyrus, (bottom row) left angular gyrus. For further detail, please refer to the caption of .
Significance of temporal variability in the wavelet transform coherence. Each plot shows the number of subjects for which the variance in the WTC between the PCC and the indicated ROI exceeded the 90% (blue) and 95% (red) confidence levels, for each wavelet scale (Fourier period).
Time-averaged coherence (see ), shown for default-mode (top row) and anticorrelated (middle and bottom rows) ROIs. Thick lines represent the mean across subjects (N=12), and error bars represent standard error.
Percentage of the total significant coherence occurring within each phase range (φ±π/4), within each of 5 different frequency bands. Lines and error bars represent the mean±SD, respectively, across the 3 DMN ROIs (left) and 6 anticorrelated ROIs (right).
(A) WTC analysis and (B) time-averaged coherence between the PCC ROI and voxels in the MPFC having an overall correlation coefficient with the same approximate SNR as the anticorrelated ROIs in the actual data (for the instance shown here, r = 0.35±0.03 (mean±SD across subjects)). For the time-averaged coherence, error bars indicate the standard error of the mean over 50 iterations.
(A) Variability (standard deviation) over the sequence of 2-min sliding-window correlation coefficients, averaged across all 12 subjects. Five ROIs chosen for further analysis are labeled. (B) t-maps of positive and negative correlations with the PCC (red and blue, respectively, and thresholded identically to ), superimposed for anatomical comparison with regions of high variability (SD>0.18; magenta). (C) The intersection of group-level seeded correlation maps (computed across all time points in the scan) using ROIs 1, 2, and 3 as seed regions (green overlay), and using ROIs 4 and 5 as seed regions (cyan overlay). The slice location (z, mm) appears in white numerals and also applies to parts (A) and (B).
Range of sliding-window correlation values for ROIs 1–5 (), for window sizes of 2 min (top row) and 4 min (bottom row). Vertical lines indicate the minimum and maximum values of the windowed correlation coefficient across the scan, and the dot on each bar indicates the mean.
Group average (N=12) of Fisher z-transformed correlation coefficients between 5 ROIs () whose correlation with the PCC was highly variable over time. High mutual correlation was observed between ROIs 1–3, and between ROIs 4–5.
(Top row) Time-averaged coherence for for the 5 ROIs indicated in . Thick lines represent the mean across subjects (N=12), and error bars represent standard error. (Bottom row) Histograms of the number of subjects for which the variance in the WTC between the PCC and the indicated ROI exceeded the 90% (blue) and 95% (red) confidence levels, for each wavelet scale (Fourier period).
Raw time series and sliding-window correlation coefficients between the PCC and (A) ROI5 and (B) ROI2, shown for one subject (Subject 1). Sliding-window correlation coefficients are plotted at the time point corresponding to the center of its associated window.
Negative correlations with the PCC across two successive 7-min segments of resting-state data, shown for one subject. (A) First 7 min, (B) second 7 min. Intensity values represent correlation coefficient (color scale is 0.08<r<0.4), and map is superimposed on the subject s T2-weighted anatomic image. Substantial differences between the two segments are apparent.
F31 AG032168-02/AG/NIA NIH HHS/United States

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149th Regiment, Pennsylvania Infantry | Learn | FamilySearch.org
149th Regiment, Pennsylvania Infantry	From FamilySearch Wiki	(Difference between revisions)	Jump to:	navigation	, search	Revision as of 23:31, 25 September 2013 (view source)Pparadise (Talk | contribs)← Older edit
Revision as of 23:34, 25 September 2013 (view source)Pparadise (Talk | contribs) (added links to sources)Newer edit →
*Pennsylvania-German Society.''Der Reggeboge.  The Rainbow''. (Birdsboro, Pa. [etc.]: Pennsylvania German Society, 1967). v. 27 no. 2 1993. Weidle, Benjamin Franklin and Edward E. Quinter. "Letters home to Myerstaun (1863-1864)". {{FHL|1033974|item|disp=FHL 974.8 B2r v. 26-27}}. [https://www.worldcat.org/title/reggeboge-the-rainbow/oclc/1855408&referer=brief_results WorldCat].
 *Pennsylvania-German Society.''Der Reggeboge.  The Rainbow''. (Birdsboro, Pa. [etc.]: Pennsylvania German Society, 1967). v. 27 no. 2 1993. Weidle, Benjamin Franklin and Edward E. Quinter. "Letters home to Myerstaun (1863-1864)". {{FHL|1033974|item|disp=FHL 974.8 B2r v. 26-27}}. [https://www.worldcat.org/title/reggeboge-the-rainbow/oclc/1855408&referer=brief_results WorldCat].

−*Bassler, J. H. Reminiscences of the First Day's Fight at Gettysburg. Myerstown, Pa: Myerstown Enterprise, 1896. {{FHL|664942|item|disp=FHL Fiche 6084105}}. WorldCat.+*Bassler, J. H. Reminiscences of the First Day's Fight at Gettysburg. Myerstown, Pa: Myerstown Enterprise, 1896. {{FHL|664942|item|disp=FHL Fiche 6084105}}. [https://www.worldcat.org/title/reminiscences-of-the-first-days-fight-at-gettysburg/oclc/34090414&referer=brief_results WorldCat.]
−*Pa-roots gives a history of this regiment and includes rosters for each company. It also lists additional references.
+*[http://www.pa-roots.com/pacw/infantry/149th/149thorg.html Pa-roots ]gives a history of this regiment and includes[http://www.pa-roots.com/pacw/infantry/paregimentsnew3.html rosters] for each company. [http://www.pa-roots.com/pacw/infantry/149th/149thpvi.htm Additional history] for Companies B, E, and F.  It also lists additional[http://www.pa-roots.com/pacw/infantry/paregimentsnew3.html references.]

−*Ranger95 describes the history of this regiment. It lists rosters for each company. It includes an image of the monument for this regiment.
+*[http://ranger95.com/civil_war_us/penna/infantry/149pav/149th_rgt_inf.html Ranger95] describes the history of this regiment. It lists rosters for each company. It includes an image of the monument for this regiment.

−*PaArchives lists the men in each company with the place each was enrolled.+*[http://www.phmc.state.pa.us/bah/dam/rg/di/r19-65RegisterPaVolunteers/r19-65%20Reg147-159Interface.htm PaArchives ]lists the men in each company with the place each was enrolled.
Revision as of 23:34, 25 September 2013
United States U.S. Military Pennsylvania Pennsylvania Military Pennsylvania in the Civil War 149th Regiment, Pennsylvania Infantry Contents
Brief History This regiment was organized at Harrisburg August, 1862.It mustered out June 24, 1865.[1] This regiment was also known as the 2nd Bucktails. For more information on the history of this unit, see: The Civil War Archive section, 149th Regiment Infantry (2nd Bucktails), (accessed 26 October 2012).
Company A - Many men were recruited in Tioga County - See Roster
Company B - Many men were recruited in Clearfield County - See Roster
Company C - Many men were recruited in Dauphin County and Lebanon County - See Roster
Company D - Many men were recruited in Allegheny County and Huntingdon County - See Roster
Company E - Many men were recruited in Clearfield County, Lackawana County and Westmoreland County - See Roster
Company F - Many men were recruited inLuzerne County and Union County - See Roster
Company G - Many men were recruited in Huntingdon County, Tioga County, and Potter County - See Roster
Company H - Many men were recruited in Clarion County and Mifflin County - See Roster
Company K - Many men were recruited in Potter County - See Roster
Unassigned Men - See Roster The Civil War Soldiers and Sailors database lists 2,799 men on its roster for this unit. Roster.
National Park Service, The Civil War Soldiers and Sailors System, is searchable by soldier's name and state. It contains basic facts about soldiers on both sides of the Civil War, a list of regiments, descriptions of significant battles, sources of the information, and suggestions for where to find additional information. Pennsylvania in the Civil War describes many sources, specifically for Pennsylvania, and how to find them. These include compiled service records, pension records, rosters, cemetery records, Internet databases, published books, etc. United States Civil War, 1861 to 1865 describes and explains United States and Confederate States records, rather than state records, and how to find them. These include veterans’ censuses, compiled service records, pension records, rosters, cemetery records, Internet databases, published books, etc. Matthews, Richard E. The 149th Pennsylvania Volunteer Infantry Unit in the Civil War. (Jefferson, N.C.: McFarland & Co, 1994). FHL Book 974.8 M2mr. GoogleBooks. WorldCat.
Nesbit, John W. General History of Company D, 149th Pennsylvania Volunteers and Personal Sketches of the Members. ([S.l.]: Oakdale Print. and Pub. Co, 1908). FHL Fiche 6084106.GoogleBooks. Pittedu. PennState. WorldCat
Pennsylvania-German Society.Der Reggeboge. The Rainbow. (Birdsboro, Pa. [etc.]: Pennsylvania German Society, 1967). v. 27 no. 2 1993. Weidle, Benjamin Franklin and Edward E. Quinter. "Letters home to Myerstaun (1863-1864)". FHL 974.8 B2r v. 26-27. WorldCat.
Bassler, J. H. Reminiscences of the First Day's Fight at Gettysburg. Myerstown, Pa: Myerstown Enterprise, 1896. FHL Fiche 6084105. WorldCat.
Pa-roots gives a history of this regiment and includesrosters for each company. Additional history for Companies B, E, and F. It also lists additionalreferences.
PaArchives lists the men in each company with the place each was enrolled.
Retrieved from "https://familysearch.org/learn/wiki/en/149th_Regiment,_Pennsylvania_Infantry"

value: This website is a nonprofit organization and website offering genealogical records, education, and software. It is operated by The Church of Jesus Christ of Latter-day Saints , and is closely connected with the church's Family History Department.


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New Courtyard format & level of service = below average - Review of Courtyard by Marriott Denver Tech Center, Greenwood Village, CO - TripAdvisor
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This courtyard will lose my business together with my 10-15 other business colleagues as we head to another hotel property that will give us some good customer service and courtesy... :(More

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Home > Business Directory > Building Contractors > Excel Group
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Patent US4003434 - Method and apparatus for running, operating, and retrieving subsea well ... - Google PatentsSearch Images Maps Play YouTube News Gmail Drive More »Sign in<nobr>Advanced Patent Search</nobr>PatentsA method and apparatus for running, operating, and retrieving packoffs, bowl protectors, casing heads, casing hangers, and other well tools employed in drilling and completing subsea wells. Broadly considered, the method involves running the well tool and a special running and retrieving tool to which...http://www.google.com/patents/US4003434?utm_source=gb-gplus-sharePatent US4003434 - Method and apparatus for running, operating, and retrieving subsea well equipmentAdvanced Patent SearchPublication numberUS4003434 APublication typeGrantApplication numberUS 05/599,141Publication dateJan 18, 1977Filing dateJul 25, 1975Priority dateJul 25, 1975Also published asCA1041008A1Publication number05599141, 599141, US 4003434 A, US 4003434A, US-A-4003434, US4003434 A, US4003434AInventorsMichael R. Garrett, Michael J. KrenekOriginal AssigneeFmc CorporationExport CitationBiBTeX, EndNote, RefManPatent Citations (9), Referenced by (10), Classifications (7) External Links: USPTO, USPTO Assignment, EspacenetMethod and apparatus for running, operating, and retrieving subsea well equipmentUS 4003434 AAbstract A method and apparatus for running, operating, and retrieving packoffs, bowl protectors, casing heads, casing hangers, and other well tools employed in drilling and completing subsea wells. Broadly considered, the method involves running the well tool and a special running and retrieving tool to which it is releasably connected into the well by means of a drill or other pipe string and then pressurizing the wellhead through the choke and kill lines to actuate the running and retrieving tool and release it from the well tool for subsequent retrieval and re-use. Various embodiments of the running and retrieving tool are described.
What is claimed is: 1. A method of releasing a running and retrieving tool connected to a pipe string from a well tool located in a well below a blowout preventer system, said well having a wellhead and at least one choke and kill line extending from said wellhead to a control station, comprisinga. closing the blowout preventer system around the pipe string, b. conducting hydraulic pressure through the choke and kill line into the well to pressurize the well annulus below the blowout preventer system, and c. exerting the choke and kill line hydraulic pressure in the well annulus against pressure-responsive means on the running and retrieving tool to disengage said means from said well tool, thereby releasing said running and retrieving tool from said well tool for withdrawal by said pipe string from said well. 2. A method according to claim 1, wherein the running and retrieving tool is located in the wellhead.
3. A method according to claim 1, wherein the pressure-responsive means includes hydraulic piston means responsive to externally applied pressure for actuation.
4. A hydraulically actuated running and retrieving tool for use in running and retrieving well tools into and from a remotely located wellhead, said running and retrieving tool comprisinga. a body, b. means on the body for attaching the tool to a drill pipe string, and c. means on the body for releasably connecting the running and retrieving tool to a well tool, said connecting means comprising external piston means mounted on the exterior of said body and linearly movable with respect thereto in response to external exertion of hydraulic pressure thereon, whereby exertion of said external hydraulic pressure actuates said external piston means and releases said running and retrieving tool from said well tool. 5. A running and retrieving tool according to claim 4, wherein the releasably connecting means comprises a split contractible lock ring.
6. A running and retrieving tool according to claim 4, wherein the releasably connecting means comprises at least one lock piston.
7. A running and retrieving tool according to claim 7, wherein the piston means comprises an annular external hydraulic piston sealed in fluid-tight manner to the body, and wherein the releasably connecting means comprises a split contractible lock ring, said lock ring contracting in response to application of said external hydraulic pressure to said external hydraulic piston.
8. A running and retrieving tool according to claim 4, wherein the releasably connecting means facilitates interconnecting said running and retrieving tool with a well tool in the absence of hydraulic pressure.
BACKGROUND OF THE INVENTION This invention relates to methods and apparatus for running, operating, and retrieving devices used in drilling and completing wells at an underwater location. More particularly, the invention relates to hydraulically actuated tools for running, operating, and retrieving various subsea well completion equipment such as packoffs, bowl protectors, casing heads, and casing hangers, and to methods for actuating these tools. United States patents on these subjects can be found in class 166 of the United States Patent Classification System.
Prior to the present invention, in the process of drilling and completing subsea oil and gas wells it has been conventional practice to employ external hydraulic lines or the inner bore of the drill pipe string to conduct hydraulic control fluid from the drilling vessel or platform to the subsea wellhead for actuating various well tools at that remote location. Although external hydraulic lines are generally successful these lines are cumbersome, they are easily damaged, their cost is significant, and their use usually requires a separate source of power and controls therefor. Using the bore of the drill string also is not considered desirable, especially because of the time involved in installing the kelly assembly. Furthermore, when the drill string is employed for this purpose it must be plugged at the bottom, and this prevents the hydraulic fluid from draining as the string is broken apat during retrieval from the well, with the result that the hydraulic fluid spills onto the work area. Although retrievable plugs can be used in the drill string, such use requires an extra, and of course costly, trip into and out of the well to retrieve the plug.
SUMMARY OF THE INVENTION Broadly considered, the present invention involves the use of the choke and kill lines to conduct hydraulic pressure from the surface to a subsea or other remotely located wellhead for actuating a special hydraulically operated running and retrieving tool that is employed to releasably interconnect a well tool such as for example, a packoff, a bowl protector, a casing head, and a casing hanger, to a drill string or other pipe string on which this equipment is run into the well. In carrying out the method of this invention, after the well tool has been run into the wellhead the blowout preventer stack is closed around the running string, and the wellhead is then pressurized through the choke and kill lines. This pressure actuates a hydraulic piston or other hydraulically responsive element on the running and retrieving tool to release it from the well tool, whereupon the running and retrieving tool can be retrieved by lifting straight up on the running string and withdrawing it from the well.
One embodiment of running and retrieving tool according to the present invention has a split contractible lock ring that functions to releasably secure this tool to the well tool that is being run into or retrieved from the well. Application of hydraulic pressure against an annular piston on the running and retrieving tool causes the piston to contract the lock ring inwardly into an annular recess in the tool body, thereby releasing the running and retrieving tool from the well tool, and facilitating its withdrawal from the well tool and the well by simply lifting on the running string.
Another embodiment of running and retrieving tool according to this invention employs a plurality of lock pistons in lieu of the lock ring to interconnect the tool with a well tool, these lock pistons preferably being spaced circumferentially about the running and retrieving tool body and being spring-biased in an outward or locking direction. The lock pistons are disengaged from the well tool, thereby unlocking or releasing the running and retrieving tool from said well tool, also by pressurizing the wellhead through the choke and kill lines.
The various embodiments of the running and retrieving tool of the present invention can be employed not only to run and/or retrieve well tools into and from a subsea wellhead, they also can be employed to operate the well tools, such as setting a compression-type packoff in the wellhead, if desired.
Accordingly, one object of the present invention is to provide a new method and apparatus for running, operating, and retrieving subsea well tools.
Another object of the present invention is to provide an improved method and apparatus for hydraulically operating subsea well tools without the need for auxiliary hydraulic lines.
Another object of the present invention is to provide an improved method and apparatus for hydraulic operation of remote well tools without employing a drill string, or other pipe string, as a conduit for the hydraulic pressure.
Still another object of the present invention is to provide a new type of hydraulically operated running and retrieving tool for use in drilling and completion activities in subsea wells.
Still another object of the present invention is to provide a more efficient method and apparatus for running and retrieving well tools from a remotely located wellhead.
BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is an elevation, partially in section, diagrammatically illustrating a subsea wellhead, a blowout preventer mounted on the wellhead, and one embodiment of running and retrieving tool according to the present invention attached to a drill string and releasably connected to a packoff between the wellhead and the casing hanger of the innermost casing string.
FIG. 2 is a fragmentary view of the wellhead of FIG. 1 showing a modification of the running and retrieving tool.
FIG. 3 is a view like FIG. 1, illustrating another embodiment of running and retrieving tool according to the present invention.
FIG. 4 is a view like FIG. 2, showing a modification of the running and retrieving tool illustrated in FIG. 3.
FIG. 5 is a view like FIG. 1, illustrating yet another embodiment of running and retrieving tool according to the present invention.
FIG. 6 is a view like FIG. 2, showing a modified version of the running and retrieving tool of FIG. 5.
FIG. 7 is a fragmentary view similar to FIG. 1, illustrating still another embodiment of running and retrieving tool according to the present invention.
FIG. 8 is a view like FIG. 2, illustrating a modification of the running and retrieving tool of FIG. 7.
FIG. 9 is an elevation in central section, and on an enlarged scale, of another embodiment of running and retrieving tool according to the present invention.
DESCRIPTION OF THE PREFERRED EMBODIMENT Referring first to FIG. 1, a hydraulically actuated running and retrieving tool according to the present invention is diagrammatically illustrated at 10, and comprises a generally annular body 12, an axially-split, contractible lock ring 14 carried by the body 12 in an external annular groove 16, and an annular piston 18 surrounding the portion of the body 12 above the lock ring 14. The body 12 has an upwardly extending central tubular portion 12a that is threaded at its upper end for attaching the tool 10 to a drill string or other pipe string 20 that is employed to run and retrieve the tool into and from a subsea wellhead 22. The tool body 12 also has a downwardly extending central tubular portion 12b for supporting an annular flexible seal element 24 that provides a fluid-tight barrier in the annulus between the tubular portion 12b and a casing string 26 when the tool 10 is properly positioned in the wellhead 22, as shown in FIG. 1.
The lock ring 14 is somewhat L-shaped in cross-section, having a radially outwardly projecting portion 14a, an outwardly and upwardly sloping lower cam surface 28, and an inwardly and upwardly sloping upper cam surface 30. In the lock ring's expanded condition as illustrated in FIG. 1, the portion 14a projects a significant distance beyond the outer annular surface 12c of the tool body 12. When, as shown in FIG. 1, the running and retrieving tool 10 is properly connected to a well tool such as a compression-type packoff diagrammatically illustrated at 32, the lock ring 14 protrudes into an inner annular groove in the well tool, such as the groove 34 near the upper end of the packoff 32, thereby releasably securing the packoff 32 or other well tool to the running and retrieving tool 10 so that they can be run into and/or retrieved from the wellhead 22 as an assembly.
The annular piston 18 of the running and retrieving tool 10 includes a body 18a that surrounds the tool's upper tubular portion 12a, and a skirt 18b that extends downwardly from the outer edge of the body 18a to surround the upper area of the tool body 12. The piston 18 is slidable axially with respect to the tool body 12, and is dynamically sealed thereto by annular seal elements 36,38. As the piston 18 moves downwardly with respect to the tool body 12, the lower inner edge of the skirt 18b bears against the lock ring cam surface 30, thereby camming the ring inwardly into the groove 16 and withdrawing the ring from engagement with the packoff 32.
A central longitudinal bore 40 extends through the tool 10 and is continuous with a bore 42 in the running string 20. The piston 18 and the body 12 of the tool 10 form an annular chamber 44, and this chamber is vented to the bore 40 by a passage 46 to relieve pressure in the chamber as the piston moves downwardly, and also of course to facilitate returning the piston to its uppermost postion as shown in FIG. 1.
When employing the running and retrieving tool 10 to run the packoff 32 or other well tool into the wellhead 22, which wellhead is surmounted by a blowout preventer system diagrammatically illustrated at 48, the packoff is releasably connected to the tool 10 at the drilling platform or vessel by means of the lock ring 14. The tool 10 and the packoff 32 are then run as an assembly into the wellhead 22, the packoff is landed as on a fluted casing hanger 50, locked to the wellhead by expanding the packoff's split lock ring 52 into a wellhead groove 54, and the packoff's annular resilient seal element 56 compressed axially until it establishes the desired fluid-tight barrier between the wellhead and the casing hanger 50. The blowout preventer rams 58 are then closed around the running string 20, and hydraulic pressure is applied to the wellhead interior 60 through the choke and kill lines diagrammatically represented at 62. Since the wellhead interior 60 is sealed off by the running and retrieving tool seal element 24, the packoff seal element 56, and the blowout preventer rams 58, the differential pressure between the wellhead interior and the bore 42 of the running string 20 forces the running and retrieving tool piston 18 downwardly, thereby contracting the tool lock ring 14 and releasing the tool from the packoff 32. The wellhead interior 60 then can be depressurized, as by releasing the hydraulic pressure in the choke and kill lines 62, the blowout preventer rams 58 opened, and the tool 10 retrieved from the wellhead by withdrawal of the running string 20.
When the running and retrieving tool 10 is used to retrieve the packoff 32 or other well tool from a wellhead such as 22, the tool 10 with the piston 18 in its upper position, i.e., as in FIG. 1 wherein the lock ring 14 is in its expanded condition, is run on the running string 20 into the wellhead and the packoff until the lock ring 14 is opposite the packoff groove 34. As the lock ring 14 moves downwardly through the top of the packoff, the lower cam surface 28 of the lock ring engages the packoff whereby the ring is caused to contract into the tool groove 16. When the lock ring 14 reaches the packoff groove 34 it expands into this groove, thereby interconnecting the packoff and the tool 10 for subsequent retrieval as an assembly simply by withdrawing the running string 20 from the well.
When the present invention is to be employed for running, operating, and/or retrieving a packoff or other well tool having well-known "J" slot connecting means, a modified version of running and retrieving tool 100, illustrated diagrammatically in FIG. 2, can be used. This tool 100 comprises a body 102 with upper and lower central tubular portions 102a,102b, an annular seal element 104 on the lower tubular portion 102b, and a central bore 106, all functionally equivalent to their counterparts 12a, 12b, 24, and 40, respectively, in the tool 10 of FIG. 1. However, instead of a split lock ring, the tool 100 has a plurality of circumferentially spaced lock pistons 108 disposed in individual lateral chambers 110 (only one shown) in the body 102, and each lock piston is biased outwardly into the packoff groove 34 by a coil spring 112 (only one shown). Each lock piston 108 is dynamically sealed to its chamber 110 by an annular seal element 114 (only one shown), and each chamber is vented to the tool bore 106 by a passage 116 (only one shown).
Accordingly, when the wellhead 22 is pressurized through the choke and kill lines 62 (FIG. 1), the lock pistons 108 are forced inwardly towards the tool bore 106 and out of the packoff groove 34, thereby releasing the tool 100 from the packoff for subsequent retrieval from the well.
The coil springs 112 of the running and retrieving tool 100 (FIG. 2) that bias the lock pistons 108 outwardly also permit the lock pistons to move inwardly as the tool is being inserted into the packoff 32, that is in response to the camming action of the packoff's upper inner annular cam surface 32a. Accordingly, this tool 100 eliminates the need to rotate the running string in order to locate the entrance to the "J" slot in the packoff or other well tool when connecting the tool 100 to these well tools.
Because of their through bores 40 and 106, both the running and retrieving tool 10 and its modified version 100 are completely pressure balanced while being run into or retrieved from a well. Thus they do not have a tendency to be pumped out of the well, and of course they do not pressure up the entire casing string, during their operation.
The running and retrieving tool diagrammatically illustrated at 120 in FIG. 3 is identical in most respects to the tool 10 of FIG. 1, the difference being that the tool body 122 is closed at its lower end so that its bore 124 terminates within the body 122 instead of extending entirely through it. Otherwise the tool 120 has a piston 126, a lock ring 128, and an upper central tubular portion 122a that are functional equivalent to their counterparts 18,14, and 12a, respectively, of the tool 10. The chamber 130 is vented to the tool bore 124 by one or more passages 132, and pressure balancing is accomplished by perforations or ports 136 in the drill string 134 above the blowout preventer 48. Thus, it should be evident that the tools 10 and 120 function generally in the same manner with respect to their operation during running and retrieving well tools into and from a remotely located wellhead.
The running and retrieving tool 140 shown in FIG. 4 is a modified version of the tool 120 of FIG. 3, having a body 142 with sprinng-biased lock pistons 144 that are employed in lieu of the lock ring 128 to interconnect the tool 140 with a packoff 32 or other well tool. Thus, this tool 140 functions in the same way as the tool 100 of FIG. 2, yet is pressure balanced in the manner of tool 120 of FIG. 3.
As should be readily apparent, both running and retrieving tools 120,140 may be modified by the provision of a seal or packing element, such as 24 of FIG. 1, to seal them to the casing 26 where pressuring up the entire casing string is not desirable. Such a seal could be mounted, for example, on a cylindrical downward extension of the tool bodies 122,142, much like the lower central tubular portion 12b of FIG. 1, but without, of course, a bore.
The running and retrieving tool 160 shown in FIG. 5 is a variation of the tool 10 of FIG. 1, the difference being in the arrangement for pressure-balancing. Like the tool 10, the tool 160 has a body 162 with an upper central tubular portion 162a and a lower central tubular portion 162b, a split contractible lock ring 164, and an annular piston 166 for retracting the lock ring into its groove 168. In addition, the tool body 162 has a second upper tubular portion 162c concentrically disposed around and spaced from the extension 162a, thereby defining an annulus 170 that is in communication with the chamber 172 between the piston 166 and the tool body 162 by means of one or more ports 174 (only one shown). The annulus 170 extends above the blowout preventer system 48 to vent the chamber 172 at a location above the preventer. Otherwise, the tool 160 functions in identical manner with the tool 10 of FIG. 1.
FIG. 6 illustrates how the tool 160 of FIG. 5 can be modified by employing lock pistons instead of a lock ring. In FIG. 6, the tool 180 has a body 182, upper and lower central tubular portions 182a, 182b, an outer upper tubular portion 182c concentric with and spaced from the tubular portion 182a, and a pressure balancing annulus 184 communicating with lock piston chambers 186 (only one shown) by means of passages 188 (only one shown). A plurality of lock pistons 190 function like their counterparts in tools 100 (FIG. 2) and 140 (FIG. 4) to releasably interconnect the tool 180 with a packoff 32 or other well tool. If desired, the through bores 176,192 of the tools 160,180 can be closed in the respective tool bodies to provide yet another version of this apparatus similar to that illustrated in FIGS. 3 and 4.
The running and retrieving tool 200 illustrated in FIG. 7 is similar to the tool 10 of FIG. 1, in that it has a body 202 with a single upper central tubular portion 202a, a through-bore 204, a split contractible lock ring 206, and an annular piston 208. However, in lieu of a lower central tubular body portion and a seal element corresponding to 12b and 24 of the tool 10, the piston 208 is provided with an annular dynamic seal 210 that functions as a pressure barrier between the piston and the wellhead 22. Furthermore, the annular chamber 212 between the piston 208 and the tool body 202 is vented to the wellhead below the seal 210 by one or more passages 214 (only one shown), thereby achieving pressure balancing to the tool bore 204 in slightly different manner than that employed in the tool 10. In other respects, the tools 200 and 10 function identically in response to being pressurized through the choke and kill lines 62 (FIG. 1) according to the present invention.
In FIG. 8 the running and retrieving tool 220 has a body 222 with a single upper central tubular portion 222a, a through bore 224, a plurality of hydraulically responsive lock pistons 226 biased outwardly of the tool body 222 by coil springs 228, and passages 230 (only one shown) providing communication between piston chambers 232 (only one shown) and the bore 224 for pressure balancing purposes. This tool 220 is sealed to the packoff 32, or other well tool to which it may be releasably connected by the lock pistons 226, by means of an annular seal element 234 residing in an external groove in the tool body 222 beneath the level of the lock pistons. As will be readily understood, this tool 220 operates in the same manner as the tools of FIGS. 2, 4 and 6 when subjected to pressure in the wellhead 22.
As should be evident, both tools 200 and 220 can be modified by closing their through bores 204,224, respectively, if such is desirable, without in any way changing their mode of operation.
The running and retrieving tool 240 illustrated in FIG. 9 is particularly suitable for running and/or retrieving bowl protectors in accordance with the present invention. This tool comprises a body 242 with an upper central tubular portion 242a, a lower central cylindrical portion 242b for supporting a seal element such as shown at 24 in FIG. 1, an annular piston 244, and a split contractible lock ring 246. The piston 244 is retained on the tool body 242 by one or more bolts 248 that project freely through the piston into threaded engagement with the tool body, and a retaining nut 250 that is non-rotatably secured to the bolt 248 by a set screw (not shown). The annular chamber 252 between the piston 244 and the tool body 242 is vented to the tool's central bore 254 by one or more passages 256 (only one shown) for pressure equalizing purposes, and a port 258 with a removable pipe plug 260 affords a means to flush out the chamber 252 when desired. The piston is dynamically sealed to the tool body by annular seal elements 262,264, and longitudinal passages 266 through the piston and 268 through the tool body provide a means to eliminate pressure build-up in the well as the tool 240 is being run or retrieved.
In operation, the tool 240 functions in like manner to the tool 120 of FIG. 3, the tool 240 of course being attached to a running string that is perforated or ported at a level above the blowout preventer system, as shown in FIG. 3.
One of the highly desirable advantages of this invention is that the use of choke and kill lines to conduct hydraulic pressure to the wellhead 22 for operating the running and retrieving tools described above eliminates the need for additional hydraulic lines that are cumbersome and easily damaged, that involve added equipment cost, and that usually require a separate power source. Furthermore, since choke and kill lines are normally present in a wellhead system during drilling, their use for this additional function requires no additional hook up time, thereby also achieving a significant financial saving over previous techniques that utilize a separate hydraulic system between the drilling platform or vessel and the wellhead.
Patent CitationsCited PatentFiling datePublication dateApplicantTitleUS2695064 *Aug 1, 1949Nov 23, 1954Baker Oil Tools IncWell packer apparatusUS3002561 *Dec 23, 1957Oct 3, 1961Baker Oil Tools IncSubsurface well toolUS3086590 *Jun 23, 1958Apr 23, 1963Mcevoy CompanyApparatus for drilling and completion of inaccessible wellsUS3098525 *Apr 27, 1961Jul 23, 1963Shell Oil CoApparatus for installing and retrieving equipment from underwater wellsUS3177703 *Dec 2, 1963Apr 13, 1965Cameron Iron Works IncMethod and apparatus for running and testing an assembly for sealing between wellhead conduitsUS3223169 *Aug 6, 1962Dec 14, 1965Otis Eng CoRetrievable well packerUS3321217 *Aug 2, 1965May 23, 1967Ventura Tool CompanyCoupling apparatus for well heads and the likeUS3412801 *Nov 8, 1966Nov 26, 1968Schlumberger Technology CorpRetrievable well packer apparatusUS3924678 *Jul 15, 1974Dec 9, 1975Vetco Offshore Ind IncCasing hanger and packing running apparatus* Cited by examinerReferenced byCiting PatentFiling datePublication dateApplicantTitleUS4284142 *May 7, 1979Aug 18, 1981Armco Inc.Method and apparatus for remote installation and servicing of underwater well apparatusUS4736799 *Jan 14, 1987Apr 12, 1988Cameron Iron Works Usa, Inc.Packoff assembly for sealing the walls of an annulusUS4909321 *Dec 27, 1988Mar 20, 1990Conoco Inc.Wireline releasing deviceUS4986359 *Apr 16, 1990Jan 22, 1991Vetco Gray Inc.Release apparatus and method for threaded conductor pipeUS5000266 *May 4, 1990Mar 19, 1991Cooper Industries, Inc.Hydraulic/torsion packoff installation toolUS5080174 *Jan 14, 1991Jan 14, 1992Cooper Industries, Inc.Hydraulic packoff and casing hanger installation toolUS5450905 *Aug 23, 1994Sep 19, 1995Abb Vetco Gray Inc.Pressure assist installation of production components in wellheadUS6390198Jan 19, 2001May 21, 2002Halliburton Energy Services, Inc.Method for running two tubing strings into a wellEP0495437A2 *Jan 13, 1992Jul 22, 1992Cooper Cameron CorporationHydraulic packoff and casing hanger installation toolWO1999039073A2 *Jan 29, 1999Aug 5, 1999Dresser IndMethod and apparatus for running two tubing strings into a well* Cited by examinerClassifications U.S. Classification166/377, 166/120, 166/136, 166/212International ClassificationE21B33/043Cooperative ClassificationE21B33/043European ClassificationE21B33/043RotateOriginal ImageGoogle Home - Sitemap - USPTO Bulk Downloads - Privacy Policy - Terms of Service - About Google Patents - Send FeedbackData provided by IFI CLAIMS Patent Services©2012 Google


text:
Stepping into his father’s shoes | bollywood | Hindustan Times
Stepping into his father’s shoes
Director Atul Sabharwal, whose documentary about the shoe trade in Agra is set for a release, talks about what prompted him to explore the subject.
bollywood Updated: Apr 02, 2015 17:29 IST
A-still-from-In-Their-Shoes
The phrase ‘revisiting your roots’ means different things to different people. But for Atul Sabharwal, who marked his Bollywood directorial debut with Aurangzeb (2013), going home meant looking at Agra, his hometown’s indigenous shoe industry through a different lens — for his upcoming documentary, In Their Shoes. Here, the director talks about his new work and how it altered his view about film-making.
How did the idea of the documentary strike you?
It is a documentary that I wanted to make since 2010, but it was only in 2013 that I started work on it. It is about people who are involved in the shoe trade in Agra, Uttar Pradesh. It’s relevant because of the government policies that we are facing today, especially with the ‘Make in India’ programme as a context. I am involved in it as a producer, director and a son. Primarily, it started with me wanting to ask my father why he pushed me out of the family business, which was shoe-making.
Most directors first try making a short film or documentary before working on a feature film. It was different in your case.
I did a short film first called Midnight Lost And Found (2008). Then, of course, I didn’t plan that my first directorial project on a commercial scale would be a television show (Powder), although my focus was to make a feature film. Similarly, I didn’t plan this documentary; there was an urge to do this to figure out how an industry, which I’ve seen while growing up, has changed.
Why did you not choose to go into the shoe trade?
My first love has always been movies. The most comfortable thing would have been to join the shoe trade, but I was pushed away from the easy path by my father. After I finished my schooling, I told him that I was keen on joining the business. Instead of that, he encouraged me to join his CA’s firm as I was pursuing commerce. Six months down the line, they asked me to appear for the CA foundation exam. Soon, I moved to Delhi, but eventually realised my passion for film-making.
What were the challenges of making the documentary?
They were personal in nature. Asking my father about his trade was challenging.
What are the troubles that the industry is currently facing?
The best of the leather is exported. Also, being an old industry, it is not organised well monetarily. People who are working on a small scale want to keep it that way as they don’t want to get into trouble with the excise department, plus, the corruption doesn’t help. Post liberalisation, Voluntary Disclosure of Income Scheme (VDIS) was introduced to dissuade corruption. But that just got worse as now, a larger sum is involved than before. Also, competition is harder as foreign players had entered the market.
How did people who have seen you since childhood react to you following them with a camera?
The familiarity helped them to adapt being in front of the camera. Also, through electronic news, people are now used to the idea of a camera tracking them.
How did the film enrich your style of film-making?
The film has matured me as a film-maker. I have gone and fetched the smallest of things, hunted for a poster designer, and even bargained fees as we just had a five-member crew.

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The pain in Spain: Officials propose breaking up the country | Fox News
Catalan regional acting president Artur Mas. (AP Photo/Manu Fernandez)
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Although the pro-independence camp won 72 seats, it got only 48 percent of the popular vote. This is because Spain's electoral system gives more seats to votes from rural areas, where secession sentiment is strong in Catalonia. Most of the remaining parties are strongly opposed to independence.
Spain has ruled out any possibility of Catalonia becoming independent, saying it goes against the country's constitution.
The region of 7.5 million people is responsible for nearly a fifth of Spain's economic output.

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Shop Safavieh Handmade Moroccan Cambridge Gold/ Ivory Wool Rug with .5-inch Pile - 9' x 12' - On Sale - Free Shipping Today - Overstock.com - 8531135
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Dale County, Alabama	From FamilySearch Wiki	(Difference between revisions)	Jump to:	navigation	, search	Revision as of 23:05, 7 August 2012 (view source)Evancol (Talk | contribs) (Added Military Records)← Older edit
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