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Patent US7631002 - Storage device management method, system and program - Google PatentsSearch Images Maps Play YouTube News Gmail Drive More »Sign inAdvanced Patent SearchPatentsUse situations of storage devices utilizing a storage area network (SAN) are predicted and the devices are automatically managed on the basis of the predicted results. To manage the devices utilizing the SAN, there is established the policy prescribing actions each executed when some object to be judged...http://www.google.com/patents/US7631002?utm_source=gb-gplus-sharePatent US7631002 - Storage device management method, system and programAdvanced Patent SearchPublication numberUS7631002 B2Publication typeGrantApplication numberUS 11/648,654Publication dateDec 8, 2009Filing dateJan 3, 2007Priority dateMay 23, 2002Fee statusPaidAlso published asUS7246105, US20030220899, US20070124273Publication number11648654, 648654, US 7631002 B2, US 7631002B2, US-B2-7631002, US7631002 B2, US7631002B2InventorsTadashi Numanoi, Tatsundo Aoshima, Naoki Shimada, Kei TakedaOriginal AssigneeHitachi, Ltd.Export CitationBiBTeX, EndNote, RefManPatent Citations (66), Non-Patent Citations (19), Referenced by (4), Classifications (29), Legal Events (1) External Links: USPTO, USPTO Assignment, EspacenetStorage device management method, system and program
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Chronister, "OPEN/stor 2.0", Windows IT Pro, Dec. 1997, obtained online at http://www.windowsitpro.com/Articles/Print.cfm?ArticleID=211.8B. Gavish et al., "Dynamic File Migration in Distributed Computer Systems", Communications of the ACM, vol. 33, No. 2, Feb. 1990, pp. 177-189.9H. Biggar, "Disk-Based Backup Options Multiply", Infostor, vol. 6, No. 12, Dec. 2002, pp. 1, 14, 16.10H. Schrimpf, "Migration of Processes, Files and Virtual Devices in the MDX Operating System", ACM SIGOPS Operating Systems Review, vol. 29, Issue 2, Apr. 1995, pp. 70-81.11Hewlett-Packard, "HP OpenView PolicyXpert User's Guide", Mar. 2001, pp. 17-82.12Infortrend Web Page printed on Sep. 19, 2005 from web address:http://www.infortrend.com/main/2-product/sata.s/asp.13J. Moran et al., "The Restore-o-Mounter: The File Motel Revisited", Proceedings of the Usenix Summer 1993 Technical Conference, Jun. 1993.14M. Hope, "Users Tier Storage for ILM ", INFOSTOR, Sep. 2005.15NTP Software, "NTP Software Quota & File Sentinel Quick Start and Evaluation Guide", 2002, pp. 12-18.16Tivoli, "Storage Management Solutions for the Information Grid", 2000, pp. 47-52.17TrelliSoft, "The Storage Resource Management Challenge: Taming Explosive Data Growth in a 24x7 World", 2001, pp. 2-12.18Veritas, "Veritas SANPoint Control 2.0 Managing Your SAN with SANPoint Control Solaris and Windows NT/2000", pp. 139-184.19W. Quinn, Inc., "Guidelines for Implementing a Network Storage Resource Management Policy", 2001, pp. 1-20.Referenced byCiting PatentFiling datePublication dateApplicantTitleUS8732134 *Jan 25, 2011May 20, 2014Netapp, Inc.Collection of data associated with storage systemsUS8839392 *Feb 7, 2013Sep 16, 2014International Business Machines CorporationSelecting image or video files for cloud storageUS8925060Jan 2, 2013Dec 30, 2014International Business Machines CorporationSelecting image or video files for cloud storageUS20140081906 *Jan 25, 2011Mar 20, 2014Kishore GeddamCollection of data associated with storage systems* Cited by examinerClassifications U.S. Classification1/1, 709/238, 707/999.101International ClassificationG06F12/00, G06F7/00, H04L29/08, G06F3/06, G06F17/30, H04L12/24Cooperative ClassificationY10S707/99942, Y10S707/99931, G06F3/0649, H04L41/5012, H04L41/0816, G06F3/067, H04L41/0893, G06F3/061, H04L41/147, H04L69/329, H04L67/1097European ClassificationH04L41/08F, H04L41/14C, H04L41/50A2A, H04L41/08A2A, G06F3/06A2P, G06F3/06A6D, G06F3/06A4H2L, H04L29/08N9S, H04L29/08A7Legal EventsDateCodeEventDescriptionMar 8, 2013FPAYFee paymentYear of fee payment: 4RotateOriginal 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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text: _.mj=function(){this.H=[];this.R=[]};_.g=_.mj.prototype;_.g.Cf=function(){return this.H.length+this.R.length};_.g.ke=function(){return _.zb(this.H)&&_.zb(this.R)};_.g.clear=function(){this.H=[];this.R=[]};_.g.contains=function(a){return _.yb(this.H,a)||_.yb(this.R,a)};_.g.remove=function(a){var b=this.H;var c=(0,_.oba)(b,a);0<=c?(_.Bb(b,c),b=!0):b=!1;return b||_.Cb(this.R,a)}; _.g.Fe=function(){for(var a=[],b=this.H.length-1;0<=b;--b)a.push(this.H[b]);var c=this.R.length;for(b=0;bОльга Романова - Google+Press question mark to see available shortcut keysHomeCollectionsJoin Google+Send FeedbackHelpRegionPrivacy Policy - Terms of Service - Maps Terms©2017 GoogleSearchSign inAboutSearchSign inОльга РомановаAboutОльга Романова's postsLooks like you've reached the endLooks like you've reached the endUnable to load more. RetryWait while more posts are being loaded

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Durango RD3553 Women Pointed Toe Leather Brown Western Boot - Free Shipping Today - Overstock.com - 21158290
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Patent US6121889 - In-wall electronic timer - Google PatentsSearch Images Maps Play YouTube News Gmail Drive More »Sign in<nobr>Advanced Patent Search</nobr>PatentsAn in-wall mounted electric timer comprising a housing for mounting in an electric box in a wall. The electric timer comprises a user interface on the housing. The user-interface comprises an input panel and a display. The electric timer further includes a movable cover panel covering the user interface....http://www.google.com/patents/US6121889?utm_source=gb-gplus-sharePatent US6121889 - In-wall electronic timerAdvanced Patent SearchPublication numberUS6121889 APublication typeGrantApplication numberUS 08/840,609Publication dateSep 19, 2000Filing dateApr 24, 1997Priority dateApr 24, 1997Fee statusLapsedAlso published asCA2235221CPublication number08840609, 840609, US 6121889 A, US 6121889A, US-A-6121889, US6121889 A, US6121889AInventorsRudolph W. Janda, Kenneth W. MichaelsOriginal AssigneeIntermatic IncorporatedExport CitationBiBTeX, EndNote, RefManPatent Citations (3), Referenced by (31), Classifications (15), Legal Events (11) External Links: USPTO, USPTO Assignment, EspacenetIn-wall electronic timerUS 6121889 AAbstract An in-wall mounted electric timer comprising a housing for mounting in an electric box in a wall. The electric timer comprises a user interface on the housing. The user-interface comprises an input panel and a display. The electric timer further includes a movable cover panel covering the user interface. The cover panel has a rearward extending post aligned with the input panel to operate the input panel by moving action of the cover panel, wherein at least a portion of the cover panel is transparent enabling observation of the display through the cover panel.
Patent CitationsCited PatentFiling datePublication dateApplicantTitleUS5160853 *Aug 8, 1988Nov 3, 1992Honeywell Inc.Electronic timer switch with time trackerUS5309032 *Jan 22, 1990May 3, 1994Nilssen Ole KWall switch timerUS5802171 *Dec 15, 1995Sep 1, 1998Apc/FoursumKeypad enlarger kit* Cited by examinerReferenced byCiting PatentFiling datePublication dateApplicantTitleUS6661669 *Jun 27, 2002Dec 9, 2003Albert ChoUninterrupted power supplyUS6748542Mar 12, 2001Jun 8, 2004Pathlock CorporationTimed disconnect switch for data and telephone circuitsUS6798631May 3, 2002Sep 28, 2004Roberta Maria FarsettaConvenience safety timerUS6825441 *Nov 6, 2002Nov 30, 2004Sansha Electric Manufacturing Company, LimitedPower supply apparatusUS6836402 *Jul 2, 2003Dec 28, 2004Pei-Chin HuangTransparent window structure for multiple socketUS7173516 *Feb 6, 2004Feb 6, 2007Wayne-Dalton Corp.Operating system for a motorized barrier operatorUS7244900 *Feb 1, 2007Jul 17, 2007Des Autochron, LlcControl device for wall-mounted rocker switchUS7388171Sep 16, 2005Jun 17, 2008Sansha Electric Manufacturing Company, LimitedPower supply apparatus for welderUS7394367Nov 15, 2005Jul 1, 2008Colorado Vnet, LlcKeypad for building automationUS7525058 *Apr 18, 2008Apr 28, 2009Charles Ernest Daffin, IIILight switch with automatic turn offUS7579717Sep 13, 2006Aug 25, 2009Lutron Electronics Co., Inc.Wall-mountable timer for an electrical loadUS7652888Feb 21, 2006Jan 26, 2010Watlow Electric Manufacturing CompanyController housing with connector retention assembly and methodUS7683504Nov 21, 2007Mar 23, 2010Lutron Electronics Co., Inc.Multiple location electronic timer systemUS7859136Jul 14, 2009Dec 28, 2010Lutron Electronics Co., Inc.Wall-mountable timer for an electrical loadUS7930958Jul 13, 2006Apr 26, 2011Provo Craft And Novelty, Inc.Blade housing for electronic cutting apparatusUS8044329Feb 21, 2006Oct 25, 2011Watlow Electric Manufacturing CompanyCompact limiter and controller assembly and methodUS8050145 *Feb 26, 2008Nov 1, 2011Leviton Manufacturing Co., Inc.Wall mounted programmable timer systemUS8110945Jul 29, 2008Feb 7, 2012Honeywell International Inc.Power stealing circuitry for a control deviceUS8314517Jul 29, 2008Nov 20, 2012Honeywell International Inc.Electric timer for controlling power to a loadUS8344666Jul 30, 2010Jan 1, 2013John Joseph KingCircuit for and method of implementing a configurable light timerUS8344667Jul 30, 2010Jan 1, 2013John Joseph KingCircuit for and method of enabling the use of timing characterization data in a configurable light timerUS8441155Oct 29, 2009May 14, 2013Honeywell International Inc.Electric timer for controlling power to a fanUS8446263Jul 30, 2010May 21, 2013John J. KingUser interface for and method of implementing a user interface in a configurable light timerUS8508135Feb 1, 2011Aug 13, 2013John Joseph KingUser interface for an indoor light switchUS8558464Feb 1, 2011Oct 15, 2013John Joseph KingArrangement of an outdoor light enabling ambient light detectionUS8646366Sep 1, 2011Feb 11, 2014Provo Craft And Novelty, Inc.Electronic cutting apparatus and methods for cuttingCN101641190BJan 27, 2008Jul 10, 2013博莱沃创新工艺公司Cutting apparatusEP1564609A2 *Feb 8, 2005Aug 17, 2005Diehl AKO Stiftung & Co. KGTime switch for household appliancesWO2004095151A2 *Apr 5, 2004Nov 4, 2004Gustafson ReneeTimerWO2008092139A2 *Jan 27, 2008Jul 31, 2008Gerardo AyalaCutting apparatusWO2008092140A2 *Jan 27, 2008Jul 31, 2008Gerardo AyalaCutting apparatus* Cited by examinerClassifications U.S. Classification340/815.47, 340/525, 340/815.48, 361/195, 307/141, 200/293, 200/38.00B, 340/815.49, 340/656, 340/309.8, 340/815.73, 361/616International ClassificationG04G15/00Cooperative ClassificationG04G15/00European ClassificationG04G15/00Legal EventsDateCodeEventDescriptionMar 10, 2014ASAssignmentOwner name: DMK LLC, AS COLLATERAL AGENT, FLORIDAEffective date: 20140228Free format text: SECURITY INTEREST;ASSIGNOR:INTERMATIC INCORPORATED;REEL/FRAME:032391/0423Owner name: INTERMATIC INCORPORATED, ILLINOISFree format text: RELEASE BY SECURED PARTY;ASSIGNOR:BANK OF AMERICA, N.A.;REEL/FRAME:032422/0879Effective date: 20140310Mar 3, 2014ASAssignmentFree format text: RELEASE BY SECURED PARTY;ASSIGNOR:THE PRIVATEBANK AND TRUST COMPANY;REEL/FRAME:032335/0310Effective date: 20140227Owner name: INTERMATIC INCORPORATED, ILLINOISFeb 28, 2014ASAssignmentFree format text: SECURITY AGREEMENT;ASSIGNOR:INTERMATIC INCORPORATED;REEL/FRAME:032368/0734Effective date: 20140228Owner name: BMO HARRIS BANK N.A., ILLINOISMar 1, 2011ASAssignmentFree format text: SECURITY AGREEMENT;ASSIGNOR:INTERMATIC INCORPORATED;REEL/FRAME:025880/0527Effective date: 20110301Owner name: THE PRIVATEBANK AND TRUST COMPANY, ILLINOISNov 11, 2008FPExpired due to failure to pay maintenance feeEffective date: 20080919Sep 19, 2008LAPSLapse for failure to pay maintenance feesJun 20, 2008ASAssignmentOwner name: BANK OF AMERICA, N.A., AS AGENT, ILLINOISFree format text: NOTICE OF GRANT OF SECURITY INTEREST IN PATENTS;ASSIGNOR:INTERMATIC INCORPORATED;REEL/FRAME:021118/0815Effective date: 20080327Owner name: BANK OF AMERICA, N.A., AS AGENT,ILLINOISMar 31, 2008REMIMaintenance fee reminder mailedMar 5, 2004FPAYFee paymentYear of fee payment: 4Apr 9, 2002CCCertificate of correctionNov 7, 1997ASAssignmentOwner name: INTERMATIC INCORPORATED, ILLINOISFree format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:JANDA, RUDOLPH W.;MICHAELS, KENNETH W.;REEL/FRAME:008880/0297Effective date: 19971021RotateOriginal ImageGoogle Home - Sitemap - USPTO Bulk Downloads - Privacy Policy - Terms of Service - About Google Patents - Send FeedbackData provided by IFI CLAIMS Patent Services©2012 Google


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The Latest: Giants' Harris returns following back injury | Fox News
Print The Latest on the seventh week of the NFL season (all times Eastern):	1:13 p.m.	New York Giants kick returner Dwayne Harris suffered what looked like a serious injury when returning the final punt of the first half, but he returned to field the first punt of the fourth quarter.	More from FoxSports
Harris lay still on the ground for several minutes after the injury, was immobilized and carted off the field as his teammates prayed in the game against the Los Angeles Rams.	Neither team reported any other serious injuries.	---	11:35 a.m.	New York Giants wide receiver Dwayne Harris is considered questionable to return against the Los Angeles Rams after injuring his lower back during a 2-yard punt return shortly before the end of the second quarter.	Harris returned a punt on a bounce from his own 15-yard line with 7 seconds remaining, then gained only 2 yards before being tackled low by Los Angeles Rams safety Cory Littleton.	Middle linebacker Bryce Hager and running back Chase Reynolds also landed on top of Harris, who remained on the turf for several minutes before being taken off the field with the assistance of a cart.	Harris, in his second season with the Giants, entered the game having returned eight punts for 57 yards and had returned two punts for 10 yards at the time of his injury.	- Zac Boyer reporting from London.	---	11:15 a.m.	Lawrence Brownlee was chosen by the New York Jets to sing the national anthem before their game against the Baltimore Ravens, but the operatic tenor faced a difficult decision.	In a statement Sunday morning, he said he found himself ''being torn in two different directions.'' As the son of a veteran, Brownlee wrote, he was honored to be given the opportunity to sing the anthem - as he has before.	''I am grateful for the fact I have far more opportunities to succeed today as a man of color than my ancestors who were alive when the anthem was written,'' he said.	He added, however, that he ''cannot ignore how protests around the national anthem have escalated as of late. My fellow Kappa Alpha Psi fraternity brother Colin Kaepernick began the movement by silently protesting the anthem in hopes that the public discourse regarding race relations, police brutality and misconduct toward people of color would change.''	Brownlee said the San Francisco quarterback's decision is ''an act of protest which I agree with and support wholeheartedly.'' The opera star said he's hopeful ''people are gradually moving toward equality in all areas,'' and asked himself whether he would sing the anthem before the game or ''stand in silent solidarity.''	''In the end, I decided to use the voice that God has given me to sing,'' Brownlee wrote, ''to sing with the conflicting emotions that pull at my heart ... the honor, the pride, the frustration, the sadness ... Colin Kaepernick's message, the hope of my ancestors, and the sacrifice of those who gave their lives protecting our flag.	''And I will keep on singing until I can no longer do so.''	- Dennis Waszak Jr. reporting from East Rutherford, New Jersey.	---	9:50 a.m.	The pregame protests were muted, with only one player, the Los Angeles Rams' Robert Quinn, raising a clenched fist during the national anthem before the start of the game against the New York Giants.	But the start of the game itself proved dramatic. On the second play from scrimmage, Giants tight end Larry Donnell took an 8-yard reception for an apparent first down - only to have the ball forced loose by Lamarcus Joyner and recovered by Rams cornerback E.J. Gaines on the Giants 35.	On the ensuing Rams' possession, Tavon Austin lost a fumble that went out of bounds and Case Keenum nearly threw a pick from a tipped ball, then hit Austin up the middle for a 10-yard strike and the game's opening TD.	- Shawn Pogatchnik reporting from London.	---	9:15 a.m.	The NFL's latest experiment in internationalizing the sport - taking the game to the English home of rugby, Twickenham, for the first time - got off to a stylish start with fireworks, flames and live music from English R&B star Craig David performing from his new album, ''Following My Intuition.''	Teams of camouflaged British soldiers unfurled field-covering banners honoring the Giants and Rams as the teams' cheerleaders surrounded David's stage on the 50-yard line.	Twickenham is filled to capacity in a special 75,000-seat layout. Ticket scalpers outside the stadium could be heard appealing to buy tickets from passers-by, complaining that the original allotment had sold out online within 20 minutes.	Newly signed Giants kicker Robbie Gould took the field on his own an hour before kickoff to take some practice swings. He wore No. 5, not his usual 9 during his 11 seasons with the Chicago Bears. On the Giants roster, 9 is already taken by punter Brad Wing.	- Shawn Pogatchnik reporting from London.	---	8:30 a.m.	It's another early start for NFL fans as the league starts 3+ hours early from London.	The New York Giants play the Los Angeles Rams in Twickenham Stadium, the home of England's rugby team in southwest London, to begin a slate of 13 games Sunday. It's the first London NFL game not being played at the national soccer stadium, Wembley, since the league started staging regular-season contests in the British capital in 2007.	The buildup has been overshadowed by the NFL's response to new domestic-abuse allegations against Giants kicker Josh Brown, who has been placed on NFL-ordered paid leave while the league mulls whether his original one-game suspension should be toughened. Former Bears kicker Robbie Gould, signed barely 24 hours earlier, will make his Giants debut in front of a sellout 75,000-strong crowd.	Later, the league's only undefeated team, the 5-0 Minnesota Vikings, face the Eagles in Philadelphia, while the Patriots travel to Pittsburgh to face a Steelers team without the injured Ben Roethlisberger. On Sunday night, the NFC West-leading Seahawks face an improving Cardinals squad in Arizona.	Also playing Sunday: Cleveland at Cincinnati, Washington at Detroit, Oakland at Jacksonville, New Orleans at Kansas City, Buffalo at Miami, Baltimore at the New York Jets, Indianapolis at Tennessee, San Diego at Atlanta, and Tampa Bay at San Francisco.	Advertisement

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thanks for the info guys!i asked the question not because i wanted to upgrade but because my current unit's AF motor is sputtering already. sent it to canon and they told me the cost of repairing it.The price is a bit high for me to consider getting a new unit, primarily because someone is offering me a good amount for this unit even though he knows that the motor is failing at times, (i have no idea if he knows how to fix it, told him the cost, or maybe he uses MF most of the time... i don't know)don't get me wrong, i am very satisfied with this unit, it has been my most used lens for the past 3 years. i just asked to know if it is worth it to move to the IS II or stick with this model.The posts have been very informative and very helpful Reply
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Patent US6702042 - Method and device for rotary well drilling - Google PatentsSearch Images Maps Play YouTube News Gmail Drive More »Sign in<nobr>Advanced Patent Search</nobr>PatentsThe invention concerns a method which includes the steps of: introducing into a pre-drilled portion of a well (16) a drilling system containing a drilling bit (11) assembled with tubular lining elements (15), an element for measuring the inclination and azimuth direction of the pre-drilled part of the...http://www.google.com/patents/US6702042?utm_source=gb-gplus-sharePatent US6702042 - Method and device for rotary well drillingAdvanced Patent SearchPublication numberUS6702042 B2Publication typeGrantApplication numberUS 10/088,931PCT numberPCT/FR2001/002427Publication dateMar 9, 2004Filing dateJul 25, 2001Priority dateJul 25, 2000Fee statusPaidAlso published asCA2384281A1, CA2384281C, US20020170750, WO2002008563A1Publication number088931, 10088931, PCT/2001/2427, PCT/FR/1/002427, PCT/FR/1/02427, PCT/FR/2001/002427, PCT/FR/2001/02427, PCT/FR1/002427, PCT/FR1/02427, PCT/FR1002427, PCT/FR102427, PCT/FR2001/002427, PCT/FR2001/02427, PCT/FR2001002427, PCT/FR200102427, US 6702042 B2, US 6702042B2, US-B2-6702042, US6702042 B2, US6702042B2InventorsJean-Michel Genevois, H�di Sellami, Christophe SimonOriginal AssigneeTotal Fina Elf S.A., Association Pour La Recherche Et Le Developpement Des Methodes Et Processus IndustrielsExport CitationBiBTeX, EndNote, RefManPatent Citations (12), Referenced by (1), Classifications (10), Legal Events (3) External Links: USPTO, USPTO Assignment, EspacenetMethod and device for rotary well drillingUS 6702042 B2Abstract The invention concerns a method which includes the steps of: introducing into a pre-drilled portion of a well (16) a drilling system containing a drilling bit (11) assembled with tubular lining elements (15), an element for measuring the inclination and azimuth direction of the pre-drilled part of the well, an element for rotary friction (26, 27) against the wall of the pre-drilled part and an element capable of modifying the friction coefficient of the friction element against the wall; measuring the azimuth direction of the pre-drilled part of the well (16); and varying the friction coefficient of the friction element (26, 27) sufficiently to influence the azimuth direction of the next well portion to be drilled.
What is claimed is: 1. A rotary well drilling method, comprising the following successive phases:
introducing into a pre-drilled part of a well (16) a drilling system comprised of a drill bit (11) assembled with tubular string elements (15), means for measuring the inclination and azimuth direction of the pre-drilled part of the well, means for rotary friction (26, 27) against the wall of said pre-drilled part and controlled means capable of modifying the friction coefficient of said means for friction against the wall; measuring the azimuth direction of the pre-drilled part of the well (16); and varying sufficiently the friction coefficient of said means for friction (26, 27) to influence the azimuth direction of the next part of the well to be drilled, wherein the means for rotary friction comprise a stabilizing element with a variable geometry (26, 27), free-mounted in rotation in relation to the string (15), and controlled connection means in rotation of said stabilizing element with the string (15). 2. Method as set forth in claim 1, further comprising measuring the inclination direction of the pre-drilled part of the well, wherein the stabilizing element with a variable geometry (26, 27) is a stabilizing element with a variable diameter, making it possible to modify the inclination of the next part of the well to be drilled.
3. Method as set forth in claim 1, wherein the means for rotary friction comprise a stabilizing element with a variable geometry (26, 27) capable of functioning according to two different modes, namely a first mode, in which the friction coefficient against the wall of the pre-drilled part of the well (16) is nil or reduced, and a second mode, in which the friction coefficient is increased in relation to that of the previously stated mode.
4. A rotary drill stringy for implementing the method as set forth in claim 1, comprising (i) a drill bit (11) assembled with tubular string elements (15), means for measuring the inclination and the azimuth direction of a pre-drilled part of the well (16) in which it is meant to be engaged, and means for rotary friction (26, 27) against the wall of said pre-drilled part, and (ii) controlled means capable of modifying the friction coefficient of the means for friction against said wall, in order to modify a lateral force transmitted by the rotary drill string, wherein the means for rotary friction comprise at least one stabilizing element with a variable geometry (26, 27), free-mounted in rotation in relation to string elements (15) and controlled connection means in rotation of said stabilizing element with string elements (15).
5. String as set forth in claim 4, wherein the stabilizing element with a variable geometry (26, 27) is a stabilizing element with a variable diameter.
6. String as set forth in claim 5, wherein the controlled connection means in rotation of the stabilizing element with the string and the means that control a change of diameter of the stabilizing element act in a coordinated manner.
7. String as set forth in claim 4, wherein the connection means are such that the stabilizing element (26, 27) can occupy two different modes, namely a first mode, in which the friction coefficient is cancelled or reduced, and a second mode in which said coefficient is increased compared to that of the first mode.
This invention relates to a method for rotary well drilling that makes it possible to actively control both the inclination and the azimuth path of the well when drilling. The invention also relates to a device for implementing said method.
The techniques that aim at controlling the direction of the drilled well's path, when drilling a well, have known spectacular progress with the advent of measurements at the bottom of the hole during the drilling (techniques called MWD, from �Measurement While Drilling�). The inclination and azimuth orientation of the drilling can thus easily be followed and controlled, using both traditional deflection systems, such as the downhole motor hooked up to a bent sub (called �motor and bent-sub�) or, more recently, the downhole motor with built-in sub (called �bent-housing�).
Said downhole motor drilling systems, and mainly the last one mentioned above, which is widely used today, have taken on a more and more important role among the array of directional tools being used in modem directional drilling operations. Over the last few years, they even had a tendency to supersede the directional tools that use the traditional rotary drilling principle.
However, downhole motor drilling does have a certain number of disadvantages.
The principle is linked to the fact that, in order to make corrections to the path, it is necessary to keep rotating the stopped string, so as to be able to point the downhole motor bend in a defined direction in a fixed plane. Stopping the rotation of the string leads to a significant increase in the friction of the drill string inside the well which has a negative effect on, among other things, the correct transmission of the weight over the drill bit needed for the drilling to progress properly. Therefore, the speed of penetration is reduced, as is the possible length of the drilling passes, whether it be in traditional deviated wells, highly deviated wells or horizontal drains. In some cases, stopping the rotation can also make the rods stick against the wall of the hole, through a differential pressure effect, which hinders the continuation of the drilling.
Other techniques, currently developed, aim at implementing systems that make it possible to control the inclination and azimuth orientation of the drilling, while maintaining the rotation of the drill string from the surface, which is the underlying principle of the traditional rotary drilling. The most evolved (and the most complex) systems called RSS, �Rotary Stecrable System�, make it possible to generate a substantially lateral force against the drill bit, using pistons that rest on the wall of the well (technique called �Push The Bit�) or to slightly pivot the drill bit in any direction, by bending the drill shaft upstream from the drill bit. The complexity of said systems is linked to the activation mechanism, as well as to the device that controls and commands the orientation of the action.
At the same time, the development of the directional behavior codes of the string in traditional rotary drilling, using stabilized rotary strings, has made it possible to highlight the influence of a certain number of parameters linked to the geometry and the mechanical characteristics of the string, that have a significant influence on the directional answer of the drilling system.
Indeed, if the well has a significant inclination, the string, under the effect of gravity, rests on the lower part of the hole. It takes on a deformed profile (abbreviated as �distortion�), that can be controlled by varying the resting points, meaning by acting on the position and the diameter of the stabilizers, whose role is to more or less center the drill collars in the hole. For a specific distortion of the string, we know the orientation of the lateral force the drill bit, which is, to simplify matters, either pointed upward, or pointed downward, from the direction of gravity. Experience has shown that any traditional rotary string that transmits a lateral force with a large enough module and directed upward to the drill bit will develop, in a consolidated formation, a tendency called �upward� (also called �build-up tendency�), whose final effect will be an increase in the inclination of the well as the drilling is carried out. Conversely, any traditional rotary string that transmits a lateral force directed downward and with a rather large module to the drill bit will develop, in a consolidated formation, a tendency called �falling� (also called �drop-off tendency), whose final effect will be a reduction of the inclination of the well as the drilling is carried out.
A third behavior can be added to these two and relates to the use of rotary drilling strings in straight sections (called �slant sections), that still today make up a large portion of the drilled lengths in modem deviated wells. Indeed, experience has also shown that any traditional rotary string subjected to a force that is lateral to the drill bit, directed either upward or downward, and with a low module (or even a non existent module) develops, in a consolidated formation, a tendency called �neutral� (also called �lock-up tendency�), whose final effect is to maintain the inclination of the well as the drilling is carried out.
This is illustrated in FIGS. 1a, 1 b, 2 a and 2 b from the set of attached schematic drawings, of which the other figures will be explained in further detail later, while referring to the description of this invention. To make things easier, in said figures the drill strings are represented horizontally, which is only one specific configuration of the inclination.
FIG. 1a illustrates an example of the configuration of the traditional rotary string called �build-up tendency�;
FIG. 1b illustrates an example of the configuration of the traditional rotary string called �drop-off tendency�;
FIGS. 2a and 2 b illustrate the control of the inclination of a drill hole using a stabilizer with a variable diameter;
FIG. 3a is a cut away perspective view that illustrates the incidence of friction of a stabilizer whose diameter is less than that of a well against the wall of the latter and the role of the bit on the orientation of the drilling direction outside the vertical plane;
FIG. 3b is a cut according to the transversal plane 22 of FIG. 3a; FIG. 4a is a view similar to that of figure 3a of the drilling device as set forth in the invention, with the stabilizer in the engaged mode, meaning with the blade block linked in rotation to the string;
FIG. 4b is a cut according to the transversal plane 22 of FIG. 4a; FIGS. 5a and 5 b are views that are respectively similar to FIGS. 4a and 4 b with the stabilizer in the disengaged mode, meaning with the blade block in free rotation in relation to the drill lining;
FIGS. 6 and 7 are graphs that offer the azimuth and inclination gradient for the two modes, engaged and disengaged, based on the friction coefficient between the stabilizer as set forth in the invention and the formation in which the well is drilled;
FIG. 8 is a view that illustrates the traditional measurements in the example of a string as set forth in the invention;
FIGS. 9a and 9 b are two schematic perspective views of the stabilizer, respectively in the engaged state and in the disengaged state;
FIG. 10 represents two partial longitudinal half sections of the stabilizer, showing the blade block mechanism and the engagement/disengagement system, respectively in the engaged position (upper half section) and in the disengaged position (lower half section);
FIG. 11 is a cross-sectional cut along line XI�XI of FIG. 10;
FIG. 12 is a schematic diagram of the indexing mechanism of the stabilizer's state (diameter and engagement/disengagement).
We see that, under the effect of gravity, the section of the string 1 between the stabilizers 2 and 3 bends downward, which produces a lever effect on the first stabilizer 2 and makes it possible to generate an upward directed force F1 on the drill bit 4.
FIG. 1b, in which the elements already described are designated by the same reference numbers, illustrates a traditional configuration of a downward string. By eliminating the stabilizer 2 of FIG. 1a located close to the drill bit 4, the string unit 1 between the stabilizer 3 and the drill bit 4 produces, through a pendular effect, a force F2 that is lateral to the drill bit and directed downward.
To make the most of the physical principle illustrated in said figures, to control the inclination, we have conceived stabilizers with variable diameters, that can usually accept various blade diameters (at least two extreme diameters, or three blade diameters, or more), their activation and their deactivation being carried out namely by acting of the weight exerted on the drill bit, or even on the injection pressure and the drilling fluid delivery.
By carefully choosing the two extreme diameters of a stabilizer with a variable diameter and playing with the configuration of the string (spacing and diameter of the stabilizers), we can obtain an upward string, for one of the stabilizer's extreme diameters and a downward string for the other extreme diameter.
This is illustrated in FIGS. 2a and 2 b, where the stabilizer 5, in the second position from the drill bit 4, has two different diameters, where one is reduced (under-sized, called �undergauge�, meaning with a diameter that is less that that of the drilled hole)�see FIG. 2a�corresponding to an upward string, and the other is larger (maximum, full hole, called �full-gauge�, meaning with a diameter that is very close to that of the drilled hole)�see FIG. 2b�corresponding to a downward string. Between these two extremes, it is of course possible to chose an appropriate diameter that makes it possible to practically cancel the lateral force on the drill bit, thus making the drill string neutral in its inclination directional behavior, as was brought up earlier.
However, in the prior technique, the use of a stabilizer, with or without a variable geometry, was not taken into consideration to control of the azimuth direction of a rotary drilling system, meaning of the unit comprised of the string and the drill bit, where the term �variable geometry� can be taken in the strict sense of variable diameter or may include changes in shape, in contact surfaces, in the status of said contact surfaces or in distance between contact points.
This invention aims at providing the means for carrying out such a control, meaning exerting an action on the rotary drilling system that can generate a modification of the system's azimuth direction, for example a slow down of the system's tendency to drill to the right or to the left, or even a reversal of the drilling direction from the right to the left or vice versa.
With this end in view, the first object of the invention is a method for rotary well drilling, where said method is characterized by the following successive phases:
a drilling system comprised of an assembled drill bit with tubular string elements, means for measuring the inclination and azimuth direction of the pre drilled part of the well, means for friction against the wall of said pre-drilled part and controlled means capable of modifying the friction coefficient of said friction means against the wall are introduced into a pre drilled portion of the well;
the azimuth direction of the pre-drilled part of the well is measured;
and the friction coefficient of said friction means is varied sufficiently to influence the inclination and azimuth direction of the next well portion to be drilled.
Another object of the invention is a controlled rotary drilling string used to implement the above-mentioned method, where said string is comprised of a drill bit assembled with tubular string elements, means for measuring the inclination and azimuth direction of a pre-drilled part of the well in which it is meant to be engaged, and means of friction against the wall of said pre-drilled part, where this string is characterized in that it includes controlled means capable of modifying the friction coefficient of the friction means against the wall, in order to modify the lateral force transmitted by the string on the drill bit.
Advantageously, the means for friction include at least one stabilizing element with a variable geometry, in particular with a variable diameter, that guarantees the active control of inclination variations and whose blade block is free mounted in rotation in relation to the string and linked controlled means in rotation of the blade block of said stabilizer with the string, thus creating two possible modes of use: the disengaged mode (free blade block in rotation in relation to the string) and the engaged mode (linked blade block in rotation in relation to the string).
Said means of linking are preferably such that the stabilizing element can occupy two distinctive states, namely a first state, in which the friction coefficient is cancelled or reduced, that corresponds to the disengaged mode, and a second state, in which said coefficient is increased in relation to the previous state and that corresponds to the engaged mode.
Passing from one state to the next can be done by remote control from the ground surface, based on the measured position of the drill bit and the information concerning this position that is transmitted to the surface.
In the solution proposed herein, the variation of the friction coefficient of the means of friction is obtained by modifying the slide area: either located between the blade block and the wall of the well in the engaged mode, (strong friction coefficient), or located between the string and the blade block in the disengaged mode (low friction coefficient, if not non existent). We must point out that said modification of the friction coefficient can be obtained by other means without changing of the slide area. We can, for example, modify the state of the blade surface (removal of small bumps, modification of the direction of the grooves . . . ) of a traditional stabilizer, which results in modifying the friction coefficient at the interface between the blades and the formation.
Note that in the technique we already know of stabilizers that are capable of turning freely in relation to the drill string (see U.S. Pat. No. 5,810,100 A; see also the stabilizer proposed under the name SR 2 S (�Stationary Rubber Sleeve�) by the French company SMFI (Soci�t� de materiel de Forage International). We also know of rotating stabilizers that can be engaged and disengaged automatically (see U.S. Pat. No. 4,989,679 A), and stabilizers with a variable diameter (see U.S. Pat. No. 4,848,490 A) but to date there has been no suggestion of creating stabilizers that can be engaged and disengaged in a controlled manner and whose external diameter can be modified simultaneously, also in a controlled manner. Nor has anyone suggested the use of such stabilizers in a method for rotary well drilling, in order to adjust the inclination and the azimuth of said well.
The invention will be described here after in more detail in reference to FIGS. 3a through 12 in the attached drawings.
As outlined above, the work carried out by the applicants concerning the directional behavior of drilling systems has made it possible to point out the impact of a certain number of parameters on the azimuth response of the drilling system. Said parameters are mainly:
the friction coefficient between the stabilizer blades and the wall of the well,
FIG. 3a shows a drill string that consists of assembled drill collars 15 and comprises a drill bit 11, two full hole stabilizers, one 12, known as the �near bit�, meaning close to the bit, and the other 14, known as the �string stabilizer�, meaning stabilizer fitted into the string, where this term designates any stabilizer except the one that is close to the bit, and lastly an under-sized stabilizer 13, meaning whose diameter is less than that of the hole. Once introduced into an inclined well 16 and under the effect of gravity 17, the drill collars between the stabilizers 12 and 14 bend and the stabilizer 13 comes in contact with the lower part of the hole.
FIG. 3b is a sectional view of the transversal plane 22, at the level of the stabilizer 13. Under the combined effect of the rotation 18 and the friction coefficient between the blades of the stabilizer 13 and the wall of the well 16, the stabilizer 13 is subjected to a shear force 19, that tends to move the point of contact 25 on the wall of the well upward and thus makes it possible to make the lateral force 20 applied by the string 15 on the drill bit turn to the left in relation to the vertical plane 24. Therefore, the string 15 has a tendency to slightly push the drill bit to the left.
By playing with its geometry, it is possible to create a drill bit whose lateral movement 21 will be to the left (the case in FIG. 3a), parallel, or to the right, in relation to the direction of the lateral force 20 applied by the string.
In summary, the azimuth directional behavior of a drilling system or its capability to drill in a direction outside the vertical plane thus depends on:
the friction coefficient between the under-sized stabilizer's blades and the wall of the hole, which influences the direction of the lateral force that is transmitted by the string to the drill bit.
the directional behavior of the drill bit that defines the orientation of the drilling direction from the direction of the force applied.
An example of implementation of this invention is shown in FIG. 4a. The configuration of the string is that of FIG. 3a, and the elements already described in reference to said FIG. 3a are designated by the same reference numbers, but the stabilizer 13 has been replaced, in accordance with this invention, by a variable geometry stabilizer, comprising a blade block 26 and a stabilizer body 27. As indicated above, the term �variable geometry� can be taken in the strict sense of variable diameter or include changes in shape, in contact surfaces, in the state of said contact surfaces or in the distance between the contact points. In this FIG. 4a the blade block 26 is represented in the engaged mode, meaning integral with the body of the stabilizer 27.
FIG. 4b is a sectional view of the transversal plane 22, where it is shown that the friction occurs at the interface between the blade block 26 and the rock 16, where the unit behaves like a traditional stabilizer.
In the disengaged mode of FIG. 5a, the blade block 26 is no longer integral with the body of the stabilizer 27 and the lateral force 20 transmitted by the string 15 to the stabilizer then finds itself in the vertical plane 24.
FIG. 5b is a sectional view of the plane 22 where it is shown that the friction occurs at the interface between the blade block 6 and the body of the stabilizer 27: as the friction coefficient is very low, the shear force 19 is almost non existent and the contact point 25 is located in the vertical plane.
We will note that, in order to have a positive azimuth gradient in one of the stabilizer's modes of use, and a negative gradient in the other mode, we can intervene on the following parameters:
the number, the diameter and the position of the stabilizers,
the position, the diameter and the friction coefficient of the blade block on the drilled formation, in the engaged mode,
the directional characteristics of the drill bit.
FIG. 6 shows the evolution of the azimuth gradient (in degrees/30 meters) based on the blade block/formation friction coefficient for an upward string comprised of four stabilizers.
Note that in passing for example from a friction coefficient of 0.4, which corresponds to the engaged mode of the stabilizer, to an artificially nil friction coefficient, which corresponds to the disengaged mode, the azimuth gradient the goes from 0.1 degree/30 m (to the left) to +0.02 degree/30 m (to the right). These values can be increased by adjusting the configuration and the type of drill bit.
FIG. 7 illustrates the evolution of the inclination gradient based on the blade block/formation friction coefficient for the same upward string comprised of four stabilizers.
We note that the inclination gradient is more or less independent from the friction coefficient, which demonstrates that the control of the azimuth directional system, using the invention, remains almost independent of the inclination behavior.
The dimensional characteristics in an example of upward string as set forth in the invention appear in FIG. 8, where the elements already described in reference to FIGS. 4a, 4 b, 5 a and 5 b are designated by the same reference numbers.
The diameters of the various elements are not only expressed in centimeters but, as is customary in the oil industry, also in inches (one inch is equal to 2.54 cm).
One method of execution of a stabilizer with a controlled engagement and disengagement is with a variable diameter that is also controlled, capable of being used in the context of the invention, will now be described in reference to FIGS. 9a-9 b through 12 of the attached drawings.
The unit schematically represented in FIGS. 9a and 9 b is essentially composed of two parts, one high part 30, for which we will simply mention the functions, and one low part 31 that will be described here after in more detail and is connected to part 30 by an intermediary joint 32.
Part 30 comprises:
a part 33, whose function is to guarantee a hydraulic visualization system that makes it possible to confirm the state of the bit (diameter and engagement);
a part 34, that comprises one or several return elements meant to apply a distinctive prestressing on the described system to guarantee cohesion between its mobile parts in any position;
a part 35, that guarantees the controlled transmission of the drilling torque between the string linked to the surface and the string arranged below the system to the drill bit. Furthermore, this part 35 guarantees the transmission of the weight on the drill bit through straight and variable stops.
The intermediary joint 32 guarantees cohesion between the high part 30 and the low part 31.
According to one main characteristic of the invention, the bit is telescopic. It is represented in FIG. 9a with the male engagement connection 36 engaged and, in FIG. 9b, with said male connection 36 disengaged.
The rotating blade block 37 comprises blades 45, here in the number of three, whose variable diameter is adjustable in a way that will be described in further detail here after. The lower part of the blade block 37 comprises a female part that cooperates in a controlled way with the male connection 36, through a system of grooves.
In the example shown, the engagement system bathes in the drilling fluid, which simplifies its execution, but it could just as well be equipped with sealing systems and then be positioned in a hydraulic fluid.
The bit is meant to occupy a position within the bottom assembly of the string (called Bottom Hole Assembly or BHA) that allows it to ensure inclination and azimuth control under the best possible conditions of efficiency.
In FIGS. 10 and 11, where only part 31 of the bit is represented, the stabilizing function with variable geometry and the engagement-disengagement function that are at the heart of the invention are brought together. This example of execution comprises a main multifunction shaft 41, a sleeve 42 that is concentric to it and carries the blade block 37, and an intermediary connection 44.
The rotating blade block 37 occupies a central part of part 31 and is comprised of three blades 45, held by their extremities in a blade carrying sleeve 6 by return springs 47. The blades 45 act as shoes and are in controlled contact with the wall of the well, to ensure the centering or decentering of the unit and the string elements above and below that are integral with it. It is thus possible, as stated above, to act on the deflection of the solid elements of the string under the influence of gravity, in order to apply a desired module and direction force to the drill bit.
The blades 45 rest on actuators 48 that slide in recesses 49 and are meant to pick up a significant fraction of the forces exerted on the blades. The latter are held in permanent contact with the actuators 48 by end return springs 47.
The actuators 48, in this case cylindrical, are comprised at their lower part of a ball system 50, aimed namely at ensuring that the rotary blade block rolls on tracks when the bit is in the disengaged position. Said tracks are arranged at the external surface of a part 51, creating a back and forth liner that makes it possible to index the external diameter of the blades.
This part 51, concentric to the sleeve 42, is connected in its longitudinal movements to the shaft 41. It is mounted in a sliding manner on the sleeve 42 and comprises at its external surface degrees in steps, allowing it, when solicited by the shaft 41, to control the position of the blades 45 through actuators and make their external diameter vary.
Part 51 also comprises depressions 52, that constitute, in certain positions of the shaft 41, tracks for the balls 50 of the actuators 48.
The blade block 37 is guided along the sleeve 42 by ball bearings 53 meant to allow it to rotate as freely as possible.
In the type of execution represented in the drawings, the function of variation of the diameter of the blades and the engagement-disengagement function of the blade block 37 that will be described here after are controlled simultaneously by the multi-function shaft 41 according to a predetermined automatic sequence but theses two functions could be dissociated without leaving the realm of the invention.
As stated previously, the unit described is telescopic in itself. In a stable state, it can therefore either be popped-in, meaning occupy a shortened position, in particular when the drill bit rests on the bottom of the well, or occupy an extended position, when the drill bit is no longer resting on the bottom of the well. The invention takes advantage from the passing from a first stable state to a second stable state to ensure, in a way that is automatic and in this case simultaneous, the function of diameter change and the engagement-disengagement function.
With this end in view, an indexing element 54 is comprised of fingers 55 attached to the extremity of the upper part of the sleeve 42 and mounted on springs. Said fingers cooperate with ramps, machined into the shaft 41, where said unit, when passing from one stable state to another, ensures controlled and predetermined movements of the shaft and therefore of to the back and forth sleeve connected to it.
In the example illustrated in FIG. 12, the ramps are composed of straight parts 56 a, 56 b, 56 c, etc., parallel to the axis of the shaft 41 and whose high and low parts correspond to the above-mentioned stable states (meaning to the positions of the drill bit at the bottom of the well and above the bottom of the well respectively) and parts such as 57 a arranged sideways in relation to the previous parts, which they bring together and that ensure a cycle change under the effect of a rotation of the shaft 41 controlled by the indexing fingers 55.
We will note that the shape of the ramps is such that it prohibits the fingers 55 from coming back to a previous position between two stable states, thus ensuring a continuous and cyclical series of rotations of the shaft 41 in a same direction.
In FIG. 12, in the case of the straight part 56 b, one indexing finger is represented by an interrupted line in two stable states, referenced as 55 a and 55 b, where the 55 a state corresponds to the system's extended position, with the drill bit above the bottom of the well, whereas the 55 b state corresponds to the system's popped-in position, with the drill bit resting on the bottom of the well. In the stable state 55 a, the system is in the extended position, systematically disengaged, where the bit is in what could be considered to be in a resting state, whereas, in the stable state 55 b the system is in the popped-in position, which can be considered to be a working state and does not in any way anticipate the state of the diameter of the blades and the state of the engagement-disengagement function that will be set by design. In the case of the straight part 56 c contiguous to part 56 b, the stable state of the indexing finger symbolized in 55 c corresponds, as does the stable state 55 b, to an engaged state as it corresponds to the maximum range of telescoping.
Between the positions of the drill bit corresponding to the stable states 55 a and 55 b, the indexing finger 55 that remains in contact with the bottom of the ramp under the solicitation of its return spring, must pass a difference in level that appears clearly on the slanting part 57 a and acts as a anti-return.
The indexing finger 55 passing from one straight part of a ramp to the straight part of the contiguous ramp causes, in addition to the straight movement of this shaft, a rotation of the latter. The straight parts have different lengths, which allows for relative positions of the shaft that correspond to any desired combination of shaft diameter and engagement and disengagement.
In the configuration represented on the upper half section of FIG. 10, the stabilizer is in the engaged position in its maximum popped-in state, which corresponds to the straight part 56 c of a ramp and the position 55 c of the indexing finger, allowing for maximum interpenetration of the engagement male connection and female connection. This position also corresponds to a determined diameter of the bit.
We will note that, for some bottom assembly configurations, the smaller the diameter of the blades of a traditional stabilizer (engaged), the greater the capacity to induce an azimuth gradient. With the stabilizer as set forth in the invention we will thus seek, through design, to associate the smallest diameter of the blades to the system's engaged position.
It is known, where the control of the inclination of a well is concerned, that for a specific configuration of the bottom assembly (bottom assembly with four stabilizers for drilling of straight parts of wells, meaning parts with a constant inclination), in which the stabilizer as set forth in the invention occupies the position of �active� stabilizer (second stabilizer from the drill bit), the bottom assembly takes on a directional behavior called �falling�, meaning inducing a negative inclination gradient, for the maximum diameter of the blades (diameter called �full hole� in the technique). Conversely, for the minimum diameter of the blades, the bottom assembly takes on a directional behavior called �rising�, meaning inducing a positive inclination gradient. Therefore, it is possible, to determine an intermediary diameter for which the bottom assembly induces a neutral behavior, meaning with a more or less non existent inclination gradient.
By combining these different parameters in an appropriate fashion, it is therefore possible to adapt the stabilizer as set forth in the invention to all practical conditions encountered in directional drilling.
Patent CitationsCited PatentFiling datePublication dateApplicantTitleUS4319649 *Jun 18, 1973Mar 16, 1982Jeter John DStabilizerUS4606417 *Apr 8, 1985Aug 19, 1986Webb Derrel DPressure equalized stabilizer apparatus for drill stringUS4807708 *Nov 28, 1986Feb 28, 1989Drilex Uk Limited And Eastman Christensen CompanyDirectional drilling of a drill stringUS4989679 *Dec 22, 1988Feb 5, 1991Institut Francais Du PetrolCentering device that can be engaged or disengaged, specifically for a drilling assemblyUS5168941 *May 22, 1991Dec 8, 1992Baker Hughes IncorporatedDrilling tool for sinking wells in underground rock formationsUS5213168 *Nov 1, 1991May 25, 1993Amoco CorporationApparatus for drilling a curved subterranean boreholeUS5603386 *Sep 8, 1995Feb 18, 1997Ledge 101 LimitedDownhole tool for controlling the drilling course of a boreholeUS6206108 *Oct 22, 1997Mar 27, 2001Baker Hughes IncorporatedDrilling system with integrated bottom hole assemblyUS6321857 *Jun 13, 1997Nov 27, 2001Andergauge LimitedDirectional drilling apparatus and method utilizing eccentric stabilizerEP0806542A2 *May 8, 1997Nov 12, 1997Camco International (UK) LimitedSteerable rotary drilling systemFR2780753A1 * Title not availableWO2000028188A1 *Nov 10, 1999May 18, 2000Baker Hughes IncSelf-controlled directional drilling systems and methods* Cited by examinerReferenced byCiting PatentFiling datePublication dateApplicantTitleUS6935442 *Aug 7, 2003Aug 30, 2005S.M.F. InternationalStabilizer device for rotary string of drill rods with reduced friction* Cited by examinerClassifications U.S. Classification175/45, 175/76, 175/73, 175/61International ClassificationE21B17/10, E21B7/06Cooperative ClassificationE21B17/1064, E21B7/06European ClassificationE21B17/10R3, E21B7/06Legal EventsDateCodeEventDescriptionAug 29, 2011FPAYFee paymentYear of fee payment: 8Aug 29, 2007FPAYFee paymentYear of fee payment: 4Jun 20, 2002ASAssignmentOwner name: ASSOCIATION POUR LA RECHERCHE ET LE DEVELOPMENT DEOwner name: TOTAL FINA ELF S.A., FRANCEFree format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:GENEVOIS, JEAN-MICHEL;SELLAMI, HEDI;SIMON, CHRISTOPHE;REEL/FRAME:013092/0083;SIGNING DATES FROM 20020531 TO 20020607Owner name: TOTAL FINA ELF S.A. 2, PLACE DE LA COUPOLE, LA DEFFree format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:GENEVOIS, JEAN-MICHEL /AR;REEL/FRAME:013092/0083;SIGNINGDATES FROM 20020531 TO 20020607RotateOriginal 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:
Anti-Abortion Violence Rises Slightly, Study Finds - NYTimes.com
Anti-Abortion Violence Rises Slightly, Study Finds
ATLANTA, Dec. 21— Violence at abortion clinics this year has risen only slightly from last year, according to a survey by an abortion rights group, although the group also found that clinics were experiencing a sharp increase in death threats.
The Feminist Majority Foundation, a nonprofit advocacy group that runs a clinic protection program and conducted the study, found that in the first seven months of this year violence of various kinds had occurred at 52 percent of the clinics surveyed, including death threats, bombings and blockades by protesters. This was up from the 50 percent in a similar survey covering the first seven months of 1993.
Death threats against doctors and staff members had been the major bane of the clinics, according to the survey, which was released on Tuesday, and had been experienced at 25 percent of the clinics. Fourteen percent of the clinics said that such threats had increased over last year and 16 percent said that they increased significantly after an abortion clinic doctor and his volunteer bodyguard were shot to death on July 29 outside a clinic in Pensacola, Fla.
But the survey found that the number of blockades of clinics by abortion opponents had dropped sharply, and many clinics reported greater cooperation and help from local law-enforcement agencies.
"It isn't a big increase in violence, but it is still at high levels," said Eleanor Smeal, president of the feminist foundation. Ms. Smeal said that the combination of the increase in death threats and the decrease in blockades of clinics suggested that opponents might have abandoned one strategy in favor of another. The threats qualified as violence because they caused disruptions and sometimes proved not to be idle.
Ms. Smeal said the decrease in blockades was also attributable to a Federal law that went into effect in May and made it a Federal offense to interfere violently and forcefully with abortion clinics and clinic personnel. Also since the killings in Pensacola, several clinics around the country have had Federal marshals assigned to protect them.
Ms. Smeal also saw the increase in cooperation from law-enforcement agencies as attributable to the new law, which signaled to local police that crimes at clinics were to be taken seriously.
Endorsing the findings of the survey, Susan Hill, president of the National Women's Health Organization, a for-profit operator of nine clinics across the nation, said: "This has been our experience precisely. But we saw the blockades decreasing before the Federal law went into effect and think that it was because of the increasing association of violence and killing with the anti-abortion movement. Many just didn't want to be associated with that, and so there were fewer people available for clinic blockades than before the killings of doctors."
The Rev. Flip Benham, national director of Operation Rescue, the anti-abortion group, agreed that the new Federal law and other factors had led to decreases in the number of blockades, but he disagreed with the survey's findings of increases in anti-abortion violence generally.
Mr. Benham said his group was conducting its own study of clinic violence and would make a report in February.

value: This website is an American daily newspaper based in New York City with a worldwide readership. Founded in 1851, the Times has since won 132 Pulitzer Prizes, the most of any newspaper, and has long been regarded within the industry as a national "newspaper of record".


text:
BSA Optics Sweet S17-618x40SP 6-18x40mm Rifle Scope for sale online | eBay
BSA S17-618X40SP 6-18X40 Sweet 17 Rifle Scope with Side Parallax Adjustment and
Dec 12, 2018, 08:45:32 AM PST
Get it by Mon, Mar 25 - Tue, Apr 2 from Northbrook, Illinois
Especially designed for the. 17HMR bullet. BSA Optics 618X40SP: Sweet 17 Side Focus 6-18x40 Riflescope, Standard Duplex Reticle, 18.8in. Specifications for BSA Optics Matte Black Sweet 17 6-18X40 w/Side Focus/Standard Duplex Reticle S17-618X40SP.
Sold byopticsplanet (185201)98.9% Positive feedbackContact seller
The BSA Optics Sweet S17-618X40SP scope is ideal for a great shooting experience. To provide the user with optimum comfort, this BSA Optics pistol scope offers an exit pupil range of 6.6-2.3mm. The eye relief of this BSA Optics rifle scope is 4 inches that gives a perfect view even for people wearing glasses. The parallax settings of the BSA Optics Sweet S17-618X40SP scope are from 10 to infinity that gives an idea of the actual distance of the object. The zoom ring in this BSA Optics pistol scope offers an inner drum with markings that lets you focus perfectly. Weighing just 17.60 ounces, this BSA Optics rifle scope does not add too much weight to your rifle.
0631618112375
Sweet S17-618x40SP 6-18x40mm
79898959
4.8ft.
6.67/2.22mm
16.6ft.
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item 1 BSA Optics Sweet 17 Side Focus 6-18x40 Riflescope, Standard Duplex: S17-618X40SP -BSA Optics Sweet 17 Side Focus 6-18x40 Riflescope, Standard Duplex: S17-618X40SP
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by mitcheln2006Jul 04, 2013
Will buy another for my 22-250. Great price for a great scope.
Great scope. crystal clear optics, everything I wanted. zeroed at 100 yds. I then shot out at 200 yds. my shots were 6 inches high and dead center don't know why, I turned the turret to 200. Might have to try 175 yds. and see what happens. Overall I love the scope, it put the smack down on several ground hogs. Hilljack
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I purchased this scope as a birthday gift for my friend. He loves it. The scope looks neat, nicely packed. I think it's a good produt.
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text:
To Amend Section 27 of the Merchant Marine Act of 1920: Hearings Before the ... by United States Congress. House (Creator) - New, Rare & Used Books Online at Alibris Marketplace
To Amend Section 27 of the Merchant Marine Act of 1920: Hearings Before the ...	by
To Amend Section 27 of the Merchant Marine Act of 1920: Hearings Before the ... – Trade paperback
by United States Congress. House (Creator)
ISBN: 1175851639
ISBN-13: 9781175851635
Title: To Amend Section 27 of the Merchant Marine Act of 1920: Hearings Before the...
9781175851635
Title: To Amend Section 27 of the Merchant Marine Act of 1920: Hearings Before the ...
Description: New. 211 pages. Reprinted from 1922 edition. New 2013 edition...
New. 211 pages. Reprinted from 1922 edition. New 2013 edition in PAPERBACK is SEWN PERFECT BOUND, much more durable than a standard paperback. This is a quality reprint of an old book of historical value. If the original book was printed in multiple volumes than this reprint is of only a single volume. This is an exact/strict reproduction of text, no changes has been made in respect to the original text. A lot of effort has been made to check and improve each page/scan manually for its quality of text and illustrations (if any, are in b/w). Folded illustrations, if any, are not included in the book. This is not a retyped or an ocr'd book. Index, contents, etc, if any in the original book, are included. This item is printed on demand using good quality natural shade paper. The title of the book, on the cover, is in gold lettering.
Description: New. 221 pages. ReInk Books reprint from the 1922 edition. This...
New. 221 pages. ReInk Books reprint from the 1922 edition. This paperback book is SEWN perfect bound, where the book block is actually sewn (smythe sewn/section sewn) with thread before binding which results in a more durable type of paperback binding. It can also be open wide. The pages will not fall out and will be around for a lot longer than normal paperbacks. NO changes have been made to the original text. Each page is checked manually before printing. Illustrations, Index, if any, are included in b/w. Fold-outs, if any, are not part of the book. If the original book was printed in multiple volumes than this reprint is of only a single volume. This book is printed on demand on acid-free paper. (Original publisher: Govt. print. off. )
New. 221pp. It It is Hard Cover reprint edition of the book published long back. (1922)with isbn and coloured dust cover. We processed it for making more readable. We understand the importance of these books to the world so we planned to bring them back to print for the readers in the best possible manner. Print on Demand.
Description: New. 211 pages. Reprinted from 1922 edition. Smyth/Section Sewn...
New. 211 pages. Reprinted from 1922 edition. Smyth/Section Sewn, Hard-Cover. Exact/Strict reproduction of text, no changes has been made in respect to the original text. If the original book was printed in multiple volumes/bindings than this reprint is of only a single volume/binding. A lot of effort has been made to check and improve each page/scan manually for its quality of text and illustrations (if any, are in b/w). Folded illustrations, if any, are not included in the book. This is not a retyped or an ocr'd book. Index, contents, etc, if any in the original book, are included. This item is printed on demand using good quality natural shade paper.
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Hotel Reviews of Grand Hotel Esplanade Berlin Berlin Germany - Page 1
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Bada i poolen. Show more customer reviews
Customer Reviews - Grand Hotel Esplanade Berlin, Berlin
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