text:
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Matthew J. Fogelman
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Leonard M. Fogelman
Jillian Dahrooge
Settlements & Verdicts
Worcester diocese requests priest defrocking
The Diocese of Worcester has asked the Vatican to defrock the Rev. Lowe B. Dongor, the Roman Catholic priest charged in September with possessing child pornography and stealing from his parish in Fitchburg, reports the Telegram and Gazette.
Church and law enforcement officials believe Rev. Dongor has fled the country and may have returned to his native homeland of the Philippines. A default warrant was issued for Rev. Dongor after the clergyman failed to show up for an Oct. 25, 2011 court hearing.
Chancery officials said they are seeking to oust Rev. Dongor in the wake of a "clarification" last spring by church officials in Rome that possession of child pornography is grounds for removal from the priesthood.
In May, the Vatican's Congregation of the Doctrine of the Faith declared that "the acquisition, possession, and distribution of child pornography is a canonical delict that pertains to the sexual abuse of a minor."
State police have charged that one of Rev. Dongor's laptops contained images of girls around the ages of 10 and 11 in various states of undress. The priest also allegedly admitted to investigators that, on a number of occasions, he stole "$40 or $50" from St. Joseph Parish to send to his family in the Philippines, reports the Telegram and Gazette
Rev. Dongor is on administrative leave of absence and was relieved, in July, of his duties as associate pastor at St. Joseph's by Bishop Robert J. McManus.
Raymond L. Delisle, a spokesman for the diocese, said that Bishop McManus has asked Pope Benedict XVI to defrock Rev. Dongor in light of the pornography allegations.
Bishop McManus had written the Catholic Bishops' Conference of the Philippines warning that the priest may have returned home to the Southeast Asian islands nation.
In a letter to the Filipino prelates, the bishop said that Rev. Dongor left a note saying that he would be returning "home."
In November, the Philippine-based abs-cbnNEWS.com reported that the priest returned to his hometown of Barotac Nuevo, Iloilo, in October.
The website said that relatives, including Rev. Dongor's brother, Joey, were surprised by the visit.
Family members said they hadn't seen the priest in years and said they were shocked by the charges.
Timothy Connolly, a spokesman for District Attorney Joseph D. Early Jr., said local authorities would move to extradite Rev. Dongor back to Massachusetts, if he is located, reports the Telegram and Gazette.
At this point, he said the DA's office has no solid information on Rev. Dongor's whereabouts.
"Once he's found, the wheels will be put in motion to bring him back," Mr. Connolly said.
Rev. Dongor, 35, was summoned to Fitchburg District Court on Sept. 9 on charges of larceny of property worth more than $250, larceny from a building and possession of child pornography.
He was released on personal recognizance.
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Pocono Raceway is located in the beautiful Pocono Mountains of Pennsylvania, within a 2 hour drive from Philadelphia and New York City. We do not suggest waiting until you leave and using a GPS. We do not have a GPS address to get you to Gate #1 at Pocono Raceway. Please click on the map below and get directions you can print, using google maps.
Please arrive at the racetrack 30 minutes prior to your scheduled time. 15 minutes prior to your scheduled time please proceed to the second floor of the Pocono Penthouse (located directly in front of the parking area) with your driver's license for registration. PLEASE DO NOT BE LATE, the safety briefing will start with out you and your time at the race track will be prolonged. Guests will not be permitted in the drivers classroom area (Pocono Penthouse), there is a guest area on pit lane where they can wait for you to complete your safety briefing (Approximately 1 hour). If you have a Personal Instruction 3-Lap Ride you will be registered in the drivers classroom, NOT at the Ride Registration area.
Please arrive at the racetrack 15 minutes prior to your scheduled time. After parking, follow the signs for ride registration on pit lane.
The luxury of a timeless retreat.
Call to schedule your free track tour.
Open April thru October or shop online at the link below.
2 miles north on route 115 heading towards interstate 80.


text:
Illinois State Parks
Woodford State Fish Wildlife Area
Cardinal © stateparks.com
Campfire and Hotdogs © stateparks.com
Roasting hot dogs over an open fire.
R.R. 1
Low Point, Illinois 61545
Woodford State Fish and Wildlife Area is a picturesque area along the east side of the Illinois River. Among its features are many artesian wells, which make the manmade channels an excellent winter fishing area. The 2,900-acre site, of which 2,462-acres are water, is a favorite stopping point for waterfowl during migration.
Nature of the Area
The area comprises bottomland forest and backwater lakes of the Illinois River and features a wide variety of fauna and flora. Cottonwood, silver maple and willow cover much of the low-lying land. Deer, raccoon, muskrat, mink and beaver find this habitat to their liking and sometimes can be observed at dawn and dusk. Tall and stately great blue herons also are found in large numbers on the backwaters, and during winter it is not unusual to see a bald eagle soring above the frozen lakes or perched atop a snag.
A major waterfowl refuge of 1,400 acres exists on the area. While less attractive to wildlife due to heavy siltation in recent years, backwater lakes still attract large flights of waterfowl during migration. However, only wood ducks and Canada geese commonly nest and raise their young here. Hawks and owls, especially barred owls, are common to the area, as are an assortment of songbirds and woodpeckers.
Sites for tents and trailers are provided. Water pit privies and a sanitary dump station are available. Due to periodic flooding of the Illinois River, it is advisable to call ahead and check on conditions before you visit.
The site provides boat docks and a public boat ramp. There is no horsepower limit. Large boats are unable to navigate the shallow backwater lakes.
Woodford State Fish Wildlife Area is located near Chillicothe, East Peoria and Metamora
Marshall State Fish & Wildlife Area
Cameron National Wildlife Refuge
Henderson County State Fish & Wildlife Area
Lowden-Miller State Forest
Fort Creve Coeur State Park
The area provides a day-use area with picnic tables, stoves and a shelter.
More than 3 miles of marked trails are available for hiking, cross-country skiing and hunter access from Dec. 15-Oct. 1. Because the trail area is composed of levees used as a waterfowl management area, trails are closed during fall migration. No bicycles or other vehicles are allowed on the trails.
Chillicothe Recreational Area Ltd
20205 N. Rt. 29
Chillicothe, IL
Area Accommodations (over 20 miles away)
Carroll County Tourism - SAVANNA, IL
You will feel right at home when you reach Carroll County, our corner of beautiful Northwest Illinois. The magnificent Mississippi River and outdoor spaces will refresh your spirit and touch our soul.
WEBSITE | DIRECTIONS
97.9 miles from park*
Starved Rock Lodge Conference Center - Oglesby, IL
Relax in the rustic beauty and comfort of Starved Rock Lodge, Cabins and Starved Rock Inn. The historic Lodge has 69 guest rooms, which include three bay-window rooms, plus cabins nestled in the woods. Fireplaces can be found in four of the eight sunset cabins near the pool area...
35 miles from park*
Kishauwau Country Cabins - Tonica, IL
Within a 10 minute drive from Starved Rock and even closer to Matthiessen State Parks you will find a gorgeous, tranquil property with spacious cabins on 50 wooded acres. All with full kitchens and outdoor fire pits. 3 dog friendly.
Share Your Woodford State Fish Wildlife Area Photos (click here)
Woodford State Fish & Wildlife Area is located on State Rt 26 and can be reached from either I-80 from the north or I-74 from the south. From I-80, take I-39 south for approximately 25 miles to State Rt 17 west for 20 miles to Lacon. Than take State Rt 26 south for 10 miles. The entrance is on the right and is well signed. From I-74 at East Peoria, take State Rt 116 north for 5 miles to State Rt 26 north for 15 miles. The entrance is on the left and is well signed.

redpajama_set_name: RedPajamaCommonCrawl


Both Coca-Cola (NYSE: KO) and PepsiCo (NYSE: PEP) are down today due to disappointing earnings from Coca-Cola. This is what is known as an opportunity to buy at a discount. Long term investors should accumulate positions in PepsiCo and Coca-Cola due to potential long term total returns each offers.
Interestingly enough, both Coca-Cola and PepsiCo are up for the last quarter, six months, and year of market action.
For 2014, PepsiCo has risen by 9.98 percent. Over the same period, Coca-Cola has jumped by 4.23 percent. Each had a very strong performance over the last year of market action: Coca-Cola was up by 6.29 percent and PepsiCo shares gained just over 7 percent (chart below). Both have solid growth ahead due to opportunities in global markets in China, India, and other countries.
The dividend yield of each adds even more to the long term appeal of Coca-Cola and PepsiCo.
Both are Dividend Aristocrats. Those are stocks that have increased the dividend amount annually for at least the past 25 years. At present, the dividend yield for PepsiCo is 2.91 percent. For Coca-Cola, the dividend yield is 2.88%. Those are far above the average dividend yield of around 1.8 percent for a member of the Standard & Poor's 500 Index (NYSE: SPY). With the history of each in increasing the dividend, shareholders can look forward to more raises ahead.
That obviously adds to the total return of a stock as dividends account for more than 40 percent of the long term return for an equity according to John Bogle, founder of the Vanguard family of mutual funds.
That puts Coca-Cola and PepsiCo right around double digits for the last year. That is what the Wall Street analyst community is looking for in the future. It should also be what individual investors are looking for in the long term too from these two Dividend Aristocrats!
Since the Republicans did Well, Buy Dividend Stocks!


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So it looks like some Democrats are recognizing that they better get their butts in gear after the Sherley v. Sebelius fiasco. According to Talking Points Memo, Congresswoman Diana Degette (D-CO) – whose pro-stem cell advocacy bona fides seem well-established and who co-authored the twice-vetoed (in '05 and '07) Stem Cell Research Enhancement Act – is trying to rally her colleagues in the House to pass a bill that would reinforce the standards first established by Obama's now-overridden executive order. She claims that "she believes legislation could be passed as early as next month," which sounds just lovely but completely unrealistic given the breed of conservatives that have emerged in this election season. In parallel, TPM also reports that Sen. Tom Harkin (D-IA) aims to kick off hearings on 16 September.


Search for more informations about 6321471610. Use Google Search Engine.
Who called me from Metro Manila ??? Add your opinion about this phone number, maybe you know who called from number 6321 471 610? Maybe it's yours phone number and you can comment on it. Please rate if this phone number is secure and you can pick up this phone. If someone called you from this phone number, someone called or sent you some paid SMS, please add your opinion on our website. Do not keep the information who called only for myself. Share the description and your opinion on the description of your experience with this number phone, use our form and help other our users. Please rate this phone number (+44 063 21 47 161) is it a secure number and you can answer the call. Thank you for yours reviews.
Your information about who called from number 06321471610 to you will be stored in our database of landline and mobile numbers. Sharing message with other users can prevent many threats or form positive feedback on subject of a given telephone or company number. Warning of others about the risks of receiving dangerous and paid phone calls is now an important piece of information that you can use protect against fraud or extortion resulting from high telecommunications fees among others for calling back, writing an SMS, answering a telephone. Maybe somebody called on a loan or a loan, payday or on third party insurance or flat insurance. Someone could also call from a bank or debt collection. Someone could have contacted the hotel regarding a vacation or holiday, from a service company regarding the service ordered, or called a courier with a parcel to be delivered purchased on the allegro or online store. From what network he called to me?
Harringtons Advisory ....PPI claims, using my local area dialling code!
Called and hung up upon answering. Area code should be Devon, but I don't have anything to do with Devon, so I don't have a clue what it could be.
Pest road accident claim number.
I signed up to a strange website named Telegram10.net. I filled in my phone number and thought nothing of it, but 5 minutes later, this number kept on calling me.
This number called me but I didn't pick up. Anyone knows who they are?


text:
ComputerLanguage.com
Longest-Running Tech Encyclopedia
Term of the Moment
Look Up Another Term
Definition: microwave
Meaning "small wave," a microwave is a radio signal in the frequency range from 300 MHz to 300 GHz or from 1 to 300 GHz, depending on the rating system. Except for AM and FM radio, shortwave radio and over-the-air TV, almost all other communications systems transmit microwaves, including satellites, cellular systems, wireless LANs and line-of-sight between buildings and across vast distances.
Confusing Terminology
The microwave bands include the millimeter wave bands, which range from 30 to 300 GHz. See spectrum and millimeter wave.
Early Microwave Tower
Line-of-sight microwaves were first used to transmit across long distances where the terrain was too difficult to lay cable. This tower was installed in 1969 in Boulder Junction, Colorado. (Image courtesy of AT&T.)
THIS DEFINITION IS FOR PERSONAL USE ONLY
All other reproduction requires permission
The Computer Language Company Inc.


text:
The Flies and the Honey-Pot
A NUMBER of Flies were attracted to a jar of honey which had been overturned in a housekeeper's room, and placing their feet in it, ate greedily. Their feet, however, became so smeared with the honey that they could not use their wings, nor release themselves, and were suffocated. Just as they were expiring, they exclaimed, "Buzzzzz, BuzzzBuzzzzzzz Bzzzzzzzzzz Bzzz Bzz Bz... Bz."
Poo, though not as delicious, is far less treacherous than honey.
The Flies and the Honey-Pot (original fable)
A NUMBER of Flies were attracted to a jar of honey which had been overturned in a housekeeper's room, and placing their feet in it, ate greedily. Their feet, however, became so smeared with the honey that they could not use their wings, nor release themselves, and were suffocated. Just as they were expiring, they exclaimed, "O foolish creatures that we are, for the sake of a little pleasure we have destroyed ourselves."
Pleasure bought with pains, hurts.
View the orginal fable View the jacked fable Perry #80


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Q: How to have JavaScript generate n number of var buttons for modals Please forgive me if I misuse some terms here; JavaScript is outside of my regular work domain.
I have a Flask app where the route generates the proper database query, passing n number of entries to the page. In Jinja code, I have turned the device.DTxProgramName field for each entry into a button, which opens up a Modal box. However, the issue that I'm running into is that only the first instance of the device.DTxProgramName button opens up a modal box. All of the other buttons do nothing.
During some testing, where I explicitly defined two buttons and explicitly defined two var btn and var modal, I was able to get the effect that I was looking for. However, this requires hard coding this information, which is not the route I can take.
Can someone with more experience in JavaScript suggest what steps I can take to create the vars I need for each device.DTxProgramName button to function properly?
{% extends "layout.html"%}
{% block content %}
    {% for device in devices %}

              <button id="DeviceButton" class="btn">{{ device.DTxProgramName }}</button>

{{device.DTxProgramName}}

    {% endfor %}

{% endblock content %}

A: I used a referencing method to make the active modal selection dynamic. What's happening here is the JS assigns a function on all the button clicks and individually selects the modal based on data-modal value. All you have to ensure is data-modal is same as the id of child modal element and they are unique for each device.
Also changed your hiding modal function. Using == will trigger the closing only if the click in on modal. Changed it to !==.
{% extends "layout.html"%}
{% block content %}
{% for device in devices %}

          <button data-modal="deviceModal1" class="deviceModals btn">{{ device.DTxProgramName }}</button>

{{device.DTxProgramName}}

{% endfor %}

{% endblock content %}

redpajama_set_name: RedPajamaStackExchange


text:
Ellen Pompeo Clarifies Grey's Anatomy Diss, Says She Never Shaded Patrick Dempsey
by Hilton Hater at June 10, 2019 11:35 am .
Ellen Pompeo would like to make something very clear.
Yes, as she stated last week, Grey's Anatomy was not always a pleasant place to work.
By no means does she take back the remark that the set was "toxic" for about the first decade of the show's existence.
However, Pompeo is apparently aware of the Internet's reaction to this comment, which basically boils down to the following:
Whoa! She totally hurled some shade at former co-star Patrick Dempsey.
Because Dempsey left the show after Season 11, because the stars weren't especially close, and because Pompeo said things have been a lot better over the past several years... many observers assumed Pompeo was impyling that Dempsey was to blame for the aforementioned toxicity.
Heck, that's what we straight-up wrote at the time.
But she swears in some follow-up Tweets this was not her intention. At all.
"Hey! Anyone having feelings over Variety piece. It's not worth getting yourself upset over not singling anyone out," Pompeo wrote over the weekend, adding:
"As a show we all had a part to play in the environment me included..as many workplaces do..We changed that story. That's the story we all have the power to change!"
In a pair of further messages, Pompeo added:
None of my comments in print are ever meant to shade anyone. That's so not productive. My words about my journey are always meant to inspire and reflect.
My shade is very obvious when I'm not subtle about it you all should know that!!
I'm aware how much love there is for this show and these characters...no one has more love than me..I've dedicated half my life to it. The show has been a blessing for us all in different ways.
The negative vibes...not healthy....and ummmm a doctah.
Anyone who has chronicled Grey's Anatomy over the years is likely aware that Pompeo could easily have been talking in general when she said last week that she nearly left the show at one point because it wasn't a fun place to work.
Yes, Dempsey is a notoriously prickly person with whom to interact on set.
But Katherine Heigl walked away from the series unceremoniously after saying writers did not give her quality material.
And remember Isaiah Washington? He got fired after uttering a gay slur and then later claiming he did no such thing.
For a very long-running hit program, Grey's Anatomy had quite a lot of cast turmoil over the first 10 years of its existence, which is what Pompeo told Taraji P. Henson.
For Variety's latest Actors on Actors chat, Pompeo told her fellow star it was a "really toxic work environment" during her first decade on the show.
During her sit-down with Henson, she explained that it became her "mission" to change the environment because she didn't want the show to be so "fantastic to the public" but a "disaster behind the scenes."
Since then?
Pompeo has succeeded in this mission -- and also managed to deservedly pad her bank account in the process.
Tags: Grey's Anatomy, Ellen Pompeo
13 Shows That Need to End... Right Now!
13 TV Characters Who Were Royally Screwed
13 TV Characters Who Are a Waste of Air
Grey's Anatomy Photos
Grey's Anatomy Videos
Grey's Anatomy Season 15 Trailer: Meredith is Getting it in and We Are Living For it
Grey's Anatomy Deaths: Which Hit the Hardest?
Ellen Pompeo on Grey's Anatomy: Who Needs Penises?!?
Ellen Pompeo: Easy There! I Never Shaded Patrick Dempsey!


text:
Notre Dame, Iowa, Stanford or Miami: Which school is the true 'Tight End U.'?
By The Athletic College Football Staff May 27, 2021 102
Notre Dame has developed 12 tight ends into NFL draft picks over the last 20 years, the most of any school over that span. In 2019, Iowa had two tight ends selected in the same first round for the first time in NFL draft history. Four Miami (Fla.) tight ends have compiled at least 5,000 receiving yards in the NFL over the last 20 years. Stanford's tight-end profile resembles all of them in some way.
But which school actually is "Tight End U.?" That's a debate of which three of the schools legitimately have an argument. Stanford has produced several quality NFL tight ends, including two Pro Bowl-caliber players in Zach Ertz and Austin Hooper, but perhaps lacks the high-end NFL superstars who represent the other three schools. Florida recently called itself "Tight End U." after Kyle Pitts' incredible 2020 season, but only one selection in the last eight drafts doesn't get it done. Michigan offensive coordinator Josh Gattis tried to affix the label to his program when he joined the Wolverines but the Twitter swarm instantly ratioed his assertion.
To break it down, The Athletic college football reporters Manny Navarro, Pete Sampson and Scott Dochterman, who cover Miami, Notre Dame and Iowa, respectively, examine what basis each school has to make the claim of "Tight End U.


2013-07-29 Assigned to BAKER HUGHES INCORPORATED reassignment BAKER HUGHES INCORPORATED ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: SCHULTE, PHILIP CHRISTOF, BILEN, JUAN MIGUEL, DO, ERIC, HOINES, JASON E.
Earth-boring tools may have a body, a cutting element attached to the body at a first location, and a formation-engaging structure attached to the body at a second location. The formation-engaging structure may be movable during a drilling operation between a first position and a second position. In the first position, the formation-engaging structure may be located rotationally behind the cutting element at a first radial distance from a longitudinal axis of the body at which the cutting element will at least initially shield the formation-engaging structure from engaging a formation. In the second position, the formation-engaging structure may be located at a different second radial distance from the longitudinal axis of the body at which the formation-engaging structure will engage a formation.
The subject matter of this application is related to the subject matter of U.S. Patent application Ser. No. 13/892,745, filed on May 13, 2013, for "EARTH-BORING TOOLS INCLUDING MOVABLE FORMATION-ENGAGING STRUCTURES AND RELATED METHODS," the disclosure of which is incorporated herein in its entirety by this reference.
Embodiments of the disclosure relate to earth-boring tools having movable formation-engaging structures, and to methods of making and using such earth-boring tools.
Earth-boring tools are used to form boreholes (e.g., wellbores) in subterranean formations. Such earth-boring tools include, for example, drill bits, reamers, mills, etc. For example, a fixed-cutter earth-boring rotary drill bit (often referred to as a "drag" bit) generally includes a plurality of cutting elements secured to a face of a bit body of the drill bit. The cutters are fixed in place when used to cut formation materials. A conventional fixed-cutter earth-boring rotary drill bit includes a bit body having generally radially projecting and longitudinally extending blades.
A plurality of cutting elements is positioned on each of the blades. Generally, the cutting elements have either a disk shape or, in some instances, a more elongated, substantially cylindrical shape. The cutting elements commonly comprise a "table" of superabrasive material, such as mutually bound particles of polycrystalline diamond, formed on a supporting substrate of a hard material, such as cemented tungsten carbide. Such cutting elements are often referred to as "polycrystalline diamond compact" (PDC) cutting elements or cutters. The plurality of PDC cutting elements may be fixed within cutting element pockets formed in rotationally leading surfaces of each of the blades. Conventionally, a bonding material such as an adhesive or, more typically, a braze alloy may be used to secure the cutting elements to the bit body.
Some earth-boring tools may also include backup cutting elements, bearing elements, or both. Backup cutting elements are conventionally fixed to blades rotationally following leading cutting elements. The backup cutting elements may be located entirely behind associated leading cutting elements or may be laterally exposed beyond a side of a leading cutting element, longitudinally exposed above a leading cutting element, or both. As the leading cutting elements are worn away, the backup cutting elements may be exposed to a greater extent and engage with (e.g., remove by shearing cutting action) an earth formation. Similarly, some bearing elements have been fixed to blades rotationally following leading cutting elements. The bearing elements conventionally are located entirely behind associated leading cutting elements to limit depth-of-cut (DOC) as the bearing elements contact and ride on an underlying earth formation.
During drilling operations, the drill bit is positioned at the bottom of a well borehole and rotated.
In some embodiments, the present disclosure includes an earth-boring tool having a body, a cutting element attached to the body at a first location, and a formation-engaging structure attached to the body at a second location. The formation-engaging structure is movable during a drilling operation between a first position and a second position. In the first position, the formation-engaging structure is located rotationally behind the cutting element at a first radial distance from a longitudinal axis of the body at which the cutting element will at least initially shield the formation-engaging structure from engaging a formation. In the second position, the formation-engaging structure is located at a different second radial distance from the longitudinal axis of the body at which the formation-engaging structure will engage a formation.
Additional embodiments of the present disclosure include methods of manufacturing earth-boring tools as described herein. For example, in some embodiments, the present disclosure includes a method of forming an earth-boring tool in which a cutting element is attached to a body at a first location, and a movable formation-engaging structure is attached to the body at a second location. The movable formation-engaging structure is movable during a drilling operation between a first position and a second position. In the first position, the formation-engaging structure is located rotationally behind the cutting element at a first radial distance from a longitudinal axis of the body at which the cutting element will at least initially shield the formation-engaging structure from engaging a formation. In the second position, the formation-engaging structure is located at a different second radial distance from the longitudinal axis of the body at which the formation-engaging structure will engage a formation.
In yet further embodiments, the present disclosure includes methods of using earth-boring tools as described herein. For example, in some embodiments, the present disclosure includes a method of drilling a wellbore using an earth-boring tool. A first section of a wellbore may be drilled in a formation using an earth-boring tool that includes a cutting element attached to a body of the earth-boring tool at a first location, and a movable formation-engaging structure attached to the body at a second location, while the movable formation-engaging structure is in a first position. In the first position, the formation-engaging structure is located rotationally behind the cutting element at a first radial distance from a longitudinal axis of the body, and the cutting element at least initially shields the formation-engaging structure from engagement with the formation. The formation-engaging structure may be moved from the first position to a second position. In the second position, the formation-engaging structure is located at a different second radial distance from the longitudinal axis of the body and engages the formation. A second section of the wellbore then may be drilled in the formation using the earth-boring tool while the formation-engaging structure is in the second position and engages the formation.
FIG. 15 is a perspective view of another embodiment of an earth-boring tool including another embodiment of a movable replacement cutting element.
The illustrations presented herein are not actual views of any particular earth-boring tool or component thereof, but are merely idealized representations that are employed to describe embodiments of the present disclosure. Additionally, elements common between figures may retain the same numerical designation.
FIG. 1 is a perspective view of an embodiment of an earth-boring tool 100 of the present disclosure. The earth-boring tool 100 of FIG. 1 is configured as an earth-boring rotary drill bit. The earth-boring tool 100 more specifically comprises a drag bit having a plurality of cutting elements 102 mounted at fixed locations on a body 104 of the earth-boring tool 100. The earth-boring tool 100 also includes one or more movable formation-engaging structures 106 that are also attached to the body 104. The movable formation-engaging structures 106 may comprise, for example, cutting elements or bearing elements and may be moved from one position to another position during a drilling operation, as discussed in further detail below.
The body 104 of the earth-boring tool 100 may be secured to a shank 108 having a threaded connection portion 110, which may conform to industry standards, such as those promulgated by the American Petroleum Institute (API), for attaching the earth-boring tool 100 to a drill string.
The body 104 may include internal fluid passageways that extend between fluid ports 112 at the face of the body 104 and a longitudinal bore that extends through the shank 108 and partially through the body 104. Nozzle inserts 114 may be secured within the fluid ports 112 of the internal fluid passageways. The body 104 may further include a plurality of blades 116 that are separated by what are referred to in the art as "junk slots" 118. In some embodiments, the body 104 may include gage wear plugs 120, wear knots 122, or both.
Referring to FIG. 2, a plan view of a face 124 of the earth-boring tool 100 of FIG. 1 is shown. The cutting elements 102 (which may include, for example, PDC cutting elements) may be positioned along the face 124 at a leading end of the body 104. The cutting elements 102 may be positioned at fixed, immovable locations across the face 124. For example, the cutting elements 102 may be rendered immobile by securing them in cutting element pockets 126 formed in each of the blades 116, such as, for example, by brazing. The cutting elements 102 may be located at a rotationally leading edge 128 of each blade 116.
Each movable formation-engaging structure 106 may be attached to a blade 116. In some embodiments, the movable formation-engaging structures 106 may be attached to each primary blade 116 of the earth-boring tool 100. Each formation-engaging structure 106 may rotationally trail at least one cutting element 102 secured to the same blade 116. The formation-engaging structures 106 may be mounted to support members 130, which may be at least partially located within recesses 132 formed in the body 104 of the earth-boring tool 100. The support members 130 may secure the formation-engaging structures 106 to the blades 116 and enable the formation-engaging structures 106 to move relative to the blades 116.
Referring to FIG. 3, an enlarged view of a portion of the earth-boring tool 100 of FIGS. 1 and 2 illustrating a movable formation-engaging structure 106 of the earth-boring tool 100 in a first position is shown. In some embodiments, such as that shown in FIGS. 3 and 4, the formation-engaging structure 106 may comprise a bearing element (e.g., a bump, knot, post, or other protrusion configured to bear against and ride on an underlying earth formation). When the formation-engaging structure 106 is in the first position, it may be located at a first radial distance D1 from a longitudinal axis A (e.g., an axis of rotation) of the body 104. For example, the formation-engaging structure 106 may be at least partially shielded from directly engaging with an underlying earth formation. As used herein, being shielded or obstructed from directly engaging with an underlying earth formation means that a structure does not remove, or removes to a lesser extent, material from an earth formation by cutting action (e.g., shearing). More specifically, the formation-engaging structure 106 may be at least partially located behind and not exposed above a rotationally leading cutting element 102 secured to the same blade 116 as the formation-engaging structure 106. As a specific, nonlimiting example, the formation-engaging structure 106 may be completely within a helical path (e.g., a kerf) traversed by a rotationally leading cutting element 102 in the first position. The movable formation-engaging structure 106 may be located in the first position, for example, during a first stage of drilling during which the formation-engaging structure 106 is at least partially obstructed from direct engagement with an earth formation.
Referring to FIG. 4, a view similar to FIG. 3 illustrating the movable formation-engaging structure 106 in a second position is shown. When the formation-engaging structure 106 is in the second position, it may be located at a second, different radial distance D2 from the longitudinal axis A of the body 104. For example, the formation-engaging structure 106 may move closer to or farther away from the longitudinal axis A of the body 104 when moving from the first position to the second position. In some embodiments, the formation-engaging structure 106 may rotate (e.g., clockwise or counterclockwise) as it moves from the first position to the second position. For example, in the embodiment shown in FIG. 4, the formation-engaging structure 106 and the support member 130 to which it is mounted may rotate in a clockwise direction, as indicated by arrow 134, relative to the body 104 to move the formation-engaging structure 106 from the first position to the second position. Because of the rotational movement, forces that act on the formation-engaging structure 106 may be more effectively transferred to the blade 116, as compared to formation-engaging structures that may move longitudinally (e.g., may pop up). The formation-engaging structure 106 may be exposed to a greater extent to directly engage with an underlying earth formation when the formation-engaging structure 106 is in the second position. More specifically, a greater proportion of the formation-engaging structure 106 may be exposed at a side of a rotationally leading cutting element 102 secured to the same blade 116 as the formation-engaging structure 106. As a specific, nonlimiting example, the formation-engaging structure 106 may completely occupy a space between helical paths (e.g., kerfs) traversed by adjacent rotationally leading cutting elements 102 in the second position. The movable formation-engaging structure 106 may be located in the second position, for example, during a second stage of drilling, subsequent the first stage of drilling, during which the formation-engaging structure 106 directly engages with an earth formation to a greater extent than it did during the first stage.
In some embodiments, the movable formation-engaging structure 106 may only be movable between the two extreme end positions. In other embodiments, the movable formation-engaging structure 106 may be further movable to, and at least temporarily maintained in, additional, intermediate positions. For example, the movable formation-engaging structure 106 may temporarily stop at a third position (and any additional intermediate positions, such as, for example, fourth, fifth, etc.) between the first and second positions before the movable formation-engaging structure 106 moves to the second position or the movable formation-engaging structure 106 may be temporarily maintained at the second position and then move to a third position between the first and second positions. More specifically, the movable formation-engaging structure 106 may be movable to, and temporarily or permanently maintainable at, a slightly exposed third position before or after it has moved to the second, more exposed position.
Referring to FIG. 5, an enlarged view of a portion of an earth-boring tool 100 illustrating another embodiment of a formation-engaging structure 106′ in a first position is shown. In some embodiments, such as that shown in FIGS. 5 and 6, the formation-engaging structure 106′ may comprise an additional cutting element (e.g., a backup cutting element or an additional primary cutting element). When the formation-engaging structure 106′ is in the first position, it may be located at a first radial distance D1′ from a longitudinal axis A (e.g., an axis of rotation) of the body 104. For example, the formation-engaging structure 106′ may be at least partially shielded (e.g., completely shielded) from directly engaging with an underlying earth formation in the first position. More specifically, the formation-engaging structure 106′ may be at least partially located behind and not exposed above a rotationally leading cutting element 102 secured to the same blade 116 as the formation-engaging structure 106′. As a specific, nonlimiting example, the formation-engaging structure 106′ may be completely within a helical path (e.g., a kerf) traversed by a rotationally leading cutting element 102 in the first position.
Referring to FIG. 6, a view similar to FIG. 5 illustrating the formation-engaging structure 106′ in a second position is shown. When the formation-engaging structure 106′ is in the second position, it may be located at a second, different radial distance D2′ from the longitudinal axis A of the body 104. For example, the formation-engaging structure 106′ may move closer to or farther away from the longitudinal axis A of the body 104 when moving from the first position to the second position. In some embodiments, the formation-engaging structure 106′ may translate linearly as it moves from the first position to the second position. For example, in the embodiment shown in FIG. 6, the formation-engaging structure 106′ and the support member 130′ to which it is mounted may move linearly on tracks 136 within the recess 132′, as indicated by arrow 134′, relative to the body 104 to move the formation-engaging structure 106′ from the first position to the second position.
In some embodiments, the formation-engaging structure 106′ may be exposed to a greater extent to directly engage with an underlying earth formation when the formation-engaging structure 106′ is in the second position. For example, a greater proportion of the formation-engaging structure 106′ may be exposed at a side of a rotationally leading cutting element 102 secured to the same blade 116 as the formation-engaging structure 106′. As a specific, nonlimiting example, the formation-engaging structure 106′ may become an additional primary cutting element by moving to occupy a space (e.g., some of the space, a majority of the space, or all of the space) between helical paths (e.g., kerfs) traversed by adjacent rotationally leading cutting elements 102 in the second position. In some embodiments, the formation-engaging structure 106′ may render a rotationally following cutting element 102 on another blade 116 a backup cutting element to the formation-engaging structure 106′ when the formation-engaging structure 106′ moves to the second position and becomes an additional primary cutting element. As another specific, nonlimiting example, the formation-engaging structure 106′ may become a backup cutting element with respect to a rotationally leading cutting element 102 on the same blade 116 or on another blade 116 by moving into (e.g., exactly aligned with or underexposed with respect to) a helical path (e.g., a kerf) traversed by the rotationally leading cutting element 102.
Although FIGS. 5 and 6 depict the formation-engaging structure 106′ as moving a distance approximately equal to a diameter of the formation-engaging structure 106′, the formation-engaging structure 106′ may move smaller distances when transitioning from the first position to the second position. For example, a difference between the first radial distance D1′ and the second radial distance D2′ may be between about 0.1% and about 100%, between about 1% and about 25%, or between about 2% and about 5% of the diameter of the formation-engaging structure 106′. As specific, nonlimiting examples, the difference between the first radial distance D1′ and the second radial distance D2′ may be about 0.1 in (2.54 mm) or less, about 0.05 in (1.27 mm) or less, or even about 0.01 in (0.254 mm) or less.
Referring to FIG. 7, a partial cutaway side view of a blade 116 of an earth-boring tool 100 (see FIG. 1) illustrating another embodiment of a formation-engaging structure 106′ in a first position. The formation-engaging structure 106′ may comprise, for example, an additional cutting element (e.g., a backup cutting element or an additional primary cutting element). When the formation-engaging structure 106′ is in the first position, may be located at a first axial distance AD1 from an exposure E (e.g., a line extending from a most exposed point, sometime referred to as a "cutting point") of a rotationally leading cutting element 102 secured to the same blade 116. For example, the formation-engaging structure 106′ may be at least partially below (e.g., completely below) an upper surface of the blade 116 in the first position. More specifically, the formation-engaging structure 106′ may be at least partially located behind a rotationally leading cutting element 102 secured to the same blade 116 as the formation-engaging structure 106′ and at least partially within a recess 132 formed in the blade 116. As a specific, nonlimiting example, the formation-engaging structure 106′ may be completely within a helical path (e.g., a kerf) traversed by a rotationally leading cutting element 102 and completely within the recess 132 in the first position.
Referring to FIG. 8, a view similar to FIG. 7 illustrating the formation-engaging structure 106′ in a second position is shown. When the formation-engaging structure 106′ is in the second position, it may be located at a second, different axial distance AD2 from the exposure E of the rotationally leading cutting element 102. More specifically, the formation-engaging structure 106′ may move closer to the exposure E of the rotationally leading cutting element 102 when moving from the first position to the second position. In some embodiments, the formation-engaging structure 106′ may translate linearly as it moves from the first position to the second position. For example, in the embodiment shown in FIG. 8, the formation-engaging structure 106′ and the support member 130″ to which it is mounted may move axially within the recess 132, as indicated by arrow 134″, relative to the rotationally leading cutting element 102 to move the formation-engaging structure 106′ from the first position to the second position.
In some embodiments, the formation-engaging structure 106′ may be exposed to a greater extent, but may not directly engage with an underlying earth formation when the formation-engaging structure 106′ is in the second position. For example, a greater proportion of the formation-engaging structure 106′ may be exposed above the upper surface of the blade 116, but the formation-engaging structure 106′ may remain underexposed with respect to a rotationally leading cutting element 102 secured to the same blade 116 as the formation-engaging structure 106′. As a specific, nonlimiting example, the formation-engaging structure 106′ may become a backup cutting element by moving to occupy a portion of a helical path (e.g., kerf) traversed by a rotationally leading cutting element 102 without extending beyond the rotationally leading cutting element 102 in the second position.
In other embodiments, the formation-engaging structure 106′ may directly engage with an underlying earth formation when the formation engaging structure 106′ is in the second position. For example, the formation-engaging structure 106′ may be laterally offset from the cutting element 102 such that raising the formation-engaging structure 106′ exposes the formation-engaging structure 106′ at a side of the cutting element 102. As another example, the formation-engaging structure 106′ may directly rotationally follow the cutting element 102 such that raising the formation-engaging structure 106′ causes the formation-engaging structure 106′ to replace the cutting element 102 as a primary cutting element (e.g., at the same original exposure E of the cutting element 102 or at a greater exposure E than the original exposure E of the cutting element 102). The formation-engaging structure 106′ may be moved from the first position to the second position in such an example embodiment when the cutting element 102 has become dull, for example.
Although FIGS. 7 and 8 depict the formation-engaging structure 106′ as moving a distance approximately equal to one-half of a diameter of the formation-engaging structure 106′, the formation-engaging structure 106′ may move smaller distances when transitioning from the first position to the second position. For example, a difference between the first axial distance AD1 and the second axial distance AD2 may be between about 0.1% and about 100%, between about 1% and about 25%, or between about 2% and about 5% of the diameter of the formation-engaging structure 106′. As specific, nonlimiting examples, the difference between the first axial distance AD1 and the second axial distance AD2 may be about 0.1 in (2.54 mm) or less, about 0.05 in (1.27 mm) or less, or even about 0.01 in (0.254 mm) or less.
Referring to FIG. 9, a side view of a support member 130 to which a movable formation-engaging structure 106′ is mounted and which may be used to connect the formation-engaging structure 106′ to an earth-boring tool 100 (see FIGS. 1, 2) is shown. In embodiments where the formation-engaging structure 106′ comprises an additional cutting element (e.g., a backup cutting element), the formation-engaging structure 106′ may be configured to rotate to move from the first position (see FIG. 3) to the second position (see FIG. 4). The support member 130 may be generally cylindrical in shape and may rotate about its longitudinal axis (e.g., central axis) relative to the body 104 (see FIGS. 1, 2) to move the formation-engaging structure 106 from the first position to the second position.
The support member 130 may be a component of an actuation device 138 configured to be secured within a recess 132 (see FIG. 2) extending into a body 104 (see FIG. 2) of an earth-boring tool 100 (see FIG. 2). For example, the support member 130 may be located within a housing 140 configured to be secured to walls defining the recess 132 (see FIG. 2), such as, for example, by brazing. The support member 130 may rotate within the housing 140 to move the formation-engaging structure 106′ from the first position to the second position. The housing 140 may include, for example, a guide slot 142 within which a guidepost 144 extending from the support member 130 may be located. As the support member 130 rotates, mechanical interference between the guidepost 144 and the walls defining the guide slot 142 may maintain the support member 130 within the housing 140 and may define the location of the first and second positions. For example, the guidepost 144 may be located at a first radial extent of the guide slot 142, as shown in FIG. 9, when the formation-engaging structure 106′ is in the first position.
The actuation device 138 may be configured to automatically move the formation-engaging structure 106′ in response to a predetermined event (e.g., a signal, a change in drilling conditions, etc.). For example, the actuation device 138 may include an actuation module 146, which may be, for example, an electro-mechanical or an electro-hydraulic device. More specifically, the actuation module 146 may include a battery 148 configured to power the actuation module 146. The actuation module 146 may further include a receiver 150 configured to detect the predetermined event. For example, the receiver 150 may comprise a mud-pulse telemetry receiver configured to detect pulse patterns in drilling fluid flow, an accelerometer configured to detect changes in rotational speed or patterns of changes in rotational speed of the earth-boring tool 100 (see FIG. 1), or a flow meter configured to detect changes in flow rate of drilling fluid. The receiver 150 may be configured to send power from the battery 148 to a motor 152 (e.g., an electric motor or a hydraulic motor), which may be connected to the support member 130 to rotate the support member 130. As another example, the actuation module 146 may include a flywheel configured to rotate in response to drilling fluid flow and a brake configured to prevent the flywheel from rotating when the pressure of the drilling fluid is below a threshold amount. When the pressure exceeds the threshold amount, the flywheel may rotate, causing the support member 130 to rotate. When the predetermined event occurs, the actuation module 146 may cause the formation-engaging structure 106′ to move from the first position to the second position (see FIGS. 10, 11).
Referring to FIG. 10, an enlarged side view of the support member 130 and movable formation-engaging structure 106′ of FIG. 9 illustrating the movable-formation engaging structure 106′ in a second position is shown. When the support member 130 rotates to move the formation-engaging structure 106′ to the second position, the guidepost 144 may move to a second, opposing radial extent of the guide slot 142. In some embodiments, such as those shown in FIGS. 9 through 11, the support member 130 may rotate in a counterclockwise direction to move the formation-engaging structure 106′ from the first position (see FIG. 9) to the second position. The formation-engaging structure 106′ may be mounted on a longitudinal end of the support member 130 at a location offset from a longitudinal axis L of the support member 130, which may enable the radial distance D1 and D2 of the formation-engaging structure 106′ from the longitudinal axis A (see FIGS. 3 through 5) to change in response to rotation of the support member 130. A central axis C of the formation-engaging structure 106′ may be oriented at an oblique angle θ (e.g., an acute angle) relative to a plane of rotation P of the formation-engaging structure 106′. In other words, the formation-engaging structure 106′ may be oriented at a negative back rake in some embodiments.
Referring to FIG. 11, an enlarged side view of another embodiment of a movable formation-engaging structure 106′ in a second position and mounted to the support member 130 of FIG. 9 is shown. The central axis C of the formation-engaging structure 106′ may be in a common plane with the plane of rotation P of the formation-engaging structure 106′. In other words, the formation-engaging structure 106′ may be oriented at a neutral back rake (i.e., zero back rake) in some embodiments.
Referring to FIG. 12, an enlarged plan view of a support member 130 to which a movable formation-engaging structure 106′ is mounted illustrating the formation-engaging structure 106′ in a first position is shown. When an earth-boring tool 100 (see FIG. 1) to which the formation-engaging structure 106′ is secured rotates within a wellbore, the formation engaging structure 106′ may move. A direction of movement of the formation-engaging structure 106′ is indicated by arrow 154. When the formation-engaging structure 106′ is in the first position, the central axis C of the formation-engaging structure 106′ may be oriented at an angle α with respect to the direction of movement 154 of the formation-engaging structure 106′. The angle α may be, for example, a right angle, an oblique angle, or an acute angle. More specifically, the central axis C of the formation-engaging structure 106′ may be located in a plane oriented at an acute angle α to the direction of movement 154 of the formation-engaging structure 106′ relative to a formation when the formation-engaging structure 106′ is in the first position and the earth-boring tool 100 (see FIG. 1) is used to cut a bore in the formation.
Referring to FIG. 13, a view similar to FIG. 12 illustrating the formation-engaging structure 106′ in a second position is shown. When the formation-engaging structure is in the second position, the central axis C of the formation-engaging structure 106′ may be oriented at a different angle β with respect to the direction of movement 154 of the formation-engaging structure 106′. The angle β may be, for example, a smaller acute angle or 0°. More specifically, the central axis C of the formation-engaging structure 106′ and the direction of movement 154 of the formation-engaging structure 106′ relative to a formation may lie in a common plane (e.g., may be parallel to one another) when the formation-engaging structure 106′ is in the second position and the earth-boring tool 100 (see FIG. 1) is used to cut a bore in the formation.
Referring to FIG. 14, a perspective view of another embodiment of an earth-boring tool 100′ including a movable replacement cutting element 156 is shown. The earth-boring tool 100′ may include a support member 130 attached to the body 104 of the earth-boring tool 100′. More specifically, the earth-boring tool 100′ may include support members 130 attached to blades 116 extending radially over and longitudinally outward from a remainder of the body 104 within recesses 132 proximate rotationally leading surfaces of the blades 116. In some embodiments, the support members 130 may be attached to each primary blade 116 of the earth-boring tool 100′. Movable cutting elements 158 and movable replacement cutting elements 156 may be attached respective support members 130. For example, a movable cutting element 158 may be attached to each support member 130 at a first location, and a movable replacement cutting element 156 may be attached to each support member 130 at a second, different location.
Each support member 130 may be configured to move from a first orientation to a second orientation. For example, each support member 130 may be configured to rotate about an axis of rotation R to move from a first orientation, in which the lower left two support members 130 are shown, to a second orientation, in which the upper right support member 130 is shown. As a specific, nonlimiting example, each support member 130 may rotate about 180° to move from the first orientation to the second orientation. The axis of rotation R of a support member 130 may be at least substantially perpendicular to a tangent line T of a rotational path traversed by the movable cutting element 158 attached to the support member 130 when the support member 130 is in the first orientation in some embodiments, as shown in FIG. 14.
When the support member 130 is in the first orientation, the movable cutting element 158 attached to the support member 130 may be located to engage with a formation. For example, the movable cutting element 158 may be located at a rotationally leading edge 128 of the blade 116 when the support member 130 is in the first orientation. The axis of rotation R of the support member 130 may be at least substantially perpendicular to a central axis C of the movable cutting element 158 when the support member 130 is in the first orientation in some embodiments, such as that shown on the leftmost blade 116 of FIG. 14. The axis of rotation R of the support member 130 may be oriented at an oblique angle θ to the central axis C of the movable cutting element 158 when the support member 130 is in the first orientation in other embodiments, such as that shown on the lowermost blade 116 of FIG. 14, because of the rake angle (e.g., back rake) of the movable cutting element 158. The movable replacement cutting element 156 attached to the support member 130 may be located not to engage with the formation when the support member 130 is in the first orientation. For example, the movable replacement cutting element 156 may be located rotationally following the movable cutting element 158 when the support member 130 is in the first orientation. More specifically, the movable replacement cutting element 156 may be located, for example, within a helical rotational path (e.g., kerf) traversed by the movable cutting element 158 such that the movable replacement cutting element 156 does not actively remove formation material when the support member 130 is in the first orientation.
When the support member 130 is in the second orientation, the movable replacement cutting element 156 attached to the support member 130 may be located to engage with the formation. For example, the movable replacement cutting element 156 may be located at the rotationally leading edge 128 of the blade 116 when the support member 130 is in the second orientation. More specifically, the movable replacement cutting element 156 may be located, when the support member 130 is in the second orientation, in the same position (e.g., same exposure, back rake, side rake, etc.) originally occupied by the movable cutting element 158 when the support member 130 was in the first orientation. The movable cutting element 158 attached to the support member 130 may be located not to engage with the formation when the support member 130 is in the second orientation. More specifically, the movable cutting element 158 may be located, for example, within a helical rotational path (e.g., kerf) traversed by the movable replacement cutting element 156 such that the movable cutting element 158 does not actively remove formation material when the support member 130 is in the second orientation. As a specific, nonlimiting example, the movable cutting element 158 may be located, when the support member 130 is in the second orientation, in the same position originally occupied by the movable replacement cutting element 156 when the support member 130 was in the first orientation. Each of the movable cutting element 158 and the movable replacement cutting element 156 may be mounted on an end of the support member 130 at a location offset from the axis of rotation R of the support member 130 to enable the movable cutting element 158 and the movable replacement cutting element 156 to change positions in response to rotation of the support member 130.
In use, the earth-boring tool 100′ may be used to drill a first section of a wellbore in a formation with the support members 130 in the first orientation. The movable cutting elements 158 may engage and remove the formation, and the movable replacement cutting elements 156 may not engage or remove the formation because they may be shielded rotationally behind the movable cutting elements 158. The support member 130 may be moved from the first orientation to the second orientation. For example, the support member 130 may be moved from the first orientation to the second orientation after the passage of a fixed amount of time, when instrumentation detects that the movable cutting elements 158 have become dull (e.g., have developed a wear flat), or when the rate or penetration (ROP) of the earth-boring tool 100′ falls below a threshold rate. The support member 130 may be moved using any of the actuation devices 138 (see FIGS. 9 through 11) described previously in connection with the formation-engaging structures 106 and 106′. A second section of the wellbore may then be drilled using the earth-boring tool 100′ with the support member 130 in the second orientation. The movable replacement cutting elements 156 may engage and remove the formation, and the movable cutting elements 158 may not engage or remove the formation because they may be shielded rotationally behind the movable replacement cutting elements 156.
Additional non-limiting example embodiments of the disclosure are set forth below.
Embodiment 1: An earth-boring tool, comprising: a body; a cutting element attached to the body at a first location; and a formation-engaging structure attached to the body at a second location, the formation-engaging structure being movable during a drilling operation between a first position and a second position, the formation-engaging structure located rotationally behind the cutting element at a first radial distance from a longitudinal axis of the body at which the cutting element will at least initially shield the formation-engaging structure from engaging a formation when the formation-engaging structure is in the first position, the formation-engaging structure located at a different second radial distance from the longitudinal axis of the body at which the formation-engaging structure will engage a formation when the formation-engaging structure is in the second position.
Embodiment 2:The earth-boring tool of Embodiment 1, wherein the cutting element is attached to the body at an immovable fixed location.
Embodiment 3: The earth-boring tool of Embodiment 2, wherein the body comprises a plurality of blades, and wherein the immovable fixed location is at a rotationally leading edge of a blade of the plurality of blades.
Embodiment 4: The earth-boring tool of any one of Embodiments 1 through 3, wherein the formation-engaging structure rotates as the formation-engaging structure moves from the first position to the second position.
Embodiment 5: The earth-boring tool of any one of Embodiments 1 through 4, wherein the formation-engaging structure comprises an additional cutting element.
Embodiment 6: The earth-boring tool of Embodiment 5, wherein a central axis of the additional cutting element is located in a plane oriented at an acute angle to the direction of movement of the additional cutting element relative to a formation when the additional cutting element is in the first position and the earth-boring tool is used to cut a bore in the formation.
Embodiment 7:The earth-boring tool of Embodiment 5 or Embodiment 6, wherein the central axis of the additional cutting element and the direction of movement of the additional cutting element relative to a formation lie in a common plane when the additional cutting element is in the second position and the earth-boring tool is used to cut a bore in the formation.
Embodiment 8: The earth-boring tool of any one of Embodiments 1 through 7, wherein the formation-engaging structure is mounted to a support member, the support member disposed at least partially within a recess in the body.
Embodiment 9: The earth-boring tool of Embodiment 8, wherein the support member is configured to rotate relative to the body to move the formation-engaging structure from the first position to the second position.
Embodiment 10: The earth-boring tool of Embodiment 9, wherein the support member is generally cylindrical, at least a portion of the support member configured to rotate relative to the body about a longitudinal axis of the support member to move the formation-engaging structure from the first position to the second position.
Embodiment 11: The earth-boring tool of Embodiment 10, wherein the formation-engaging structure is mounted on a longitudinal end of the generally cylindrical support member at a location offset from the longitudinal axis of the support member.
Embodiment 12: The earth-boring tool of any one of Embodiments 1 through 11, further comprising an actuation device configured to move the formation-engaging structure from the first position to the second position.
Embodiment 13: The earth-boring tool of Embodiment 12, wherein the actuation device comprises at least one of an electro-mechanical device and an electro-hydraulic device.
Embodiment 14: The earth-boring tool of Embodiment 12 or Embodiment 13, wherein the actuation device is configured to allow a pressure of drilling fluid flowing through the earth-boring tool to move the formation-engaging structure from the first position to the second position.
Embodiment 15: A method comprising manufacturing an earth-boring tool as recited in any one of Embodiments 1 through 14.
Embodiment 16: A method of forming an earth-boring tool, comprising: attaching a cutting element to a body at a first location; and attaching a movable formation-engaging structure to the body at a second location, the movable formation-engaging structure being movable during a drilling operation between a first position and a second position, the formation-engaging structure located rotationally behind the cutting element at a first radial distance from a longitudinal axis of the body at which the cutting element will at least initially shield the formation-engaging structure from engaging a formation, the formation-engaging structure located at a different second radial distance from the longitudinal axis of the body at which the formation-engaging structure will engage a formation.
Embodiment 17: The method of Embodiment 16, further comprising configuring the formation-engaging structure to rotate as the formation-engaging structure moves from the first position to the second position.
Embodiment 18: The method of Embodiment 16 or Embodiment 17, further comprising selecting the formation-engaging structure to comprise an additional cutting element.
Embodiment 19: A method of drilling a wellbore using an earth-boring tool, comprising: drilling a first section of a wellbore in a formation using an earth-boring tool including a cutting element attached to a body of the earth-boring tool at a first location and a movable formation-engaging structure attached to the body at a second location while the movable formation-engaging structure is in a first position in which the formation-engaging structure is located rotationally behind the cutting element at a first radial distance from a longitudinal axis of the body and the cutting element at least initially shields the formation-engaging structure from engagement with the formation; moving the formation-engaging structure from the first position to a second position at which the formation-engaging structure is located at a different second radial distance from the longitudinal axis of the body and engages the formation; and drilling a second section of the wellbore in the formation using the earth-boring tool while the formation-engaging structure is in the second position and engages the formation.
Embodiment 20: The method of Embodiment 19, further comprising selecting the formation-engaging structure to comprise an additional cutting element.
Embodiment 21: An earth-boring tool, comprising: a body; a cutting element attached to the body at a first location; and a formation-engaging structure attached to the body at a second location, the formation-engaging structure being movable during a drilling operation between a first position and a second position, the formation-engaging structure located rotationally behind the cutting element at a first axial distance from an exposure of the rotationally leading cutting element at which the formation-engaging structure is at least partially located within a recess extending into the body when the formation-engaging structure is in the first position, the formation-engaging structure located at a smaller second axial distance from the exposure of the cutting element at which the formation-engaging structure is underexposed with respect to the rotationally leading cutting element when the formation-engaging structure is in the second position.
Embodiment 22: An earth-boring tool, comprising: a body; a cutting element attached to the body at a first location; and a formation-engaging structure attached to the body at a second location, the formation-engaging structure being movable during a drilling operation between a first position and a second position, the formation-engaging structure located rotationally behind the cutting element such that the cutting element will at least initially shield the formation-engaging structure from engaging a formation when the formation-engaging structure is in the first position, the formation-engaging structure located to engage a formation when the formation-engaging structure is in the second position.
Embodiment 23: The earth-boring tool of Embodiment 22, wherein the formation-engaging structure is located at a first radial distance from a longitudinal axis of the body when the formation-engaging structure is in the first position and the formation-engaging structure is located at a different second radial distance from the longitudinal axis of the body when the formation-engaging structure is in the second position.
Embodiment 24: The earth-boring tool of Embodiment 22, wherein the formation-engaging structure is located at a first axial distance from an exposure of the cutting element when the formation-engaging structure is in the first position and the formation-engaging structure is located at a different second axial distance from the exposure of the cutting element when the formation-engaging structure is in the second position.
Embodiment 25: An earth-boring tool, comprising: a body; a support member attached to the body, the support member being movable during a drilling operation between a first orientation and a second orientation; a movable cutting element attached to the support member at a first location; and a movable replacement cutting element attached to the support member at a second location, wherein the movable cutting element is located to engage with a formation and the movable replacement cutting element is located not to engage the formation when the support member is in the first orientation, and the movable replacement cutting element is located to engage with a formation and the movable cutting element is located not to engage the formation when the support member is in the second orientation.
Embodiment 26: The earth-boring tool of Embodiment 25, wherein the movable replacement cutting element is located in a same position when the support member is in the second orientation as a position occupied by the movable cutting element when the support member is in the first orientation.
Embodiment 27: The earth-boring tool of Embodiment 26, wherein the body comprises blades, and wherein the position occupied by the movable cutting element when the support member is in the first orientation is at a rotationally leading edge of one of the blades.
Embodiment 28: The earth-boring tool of any one of Embodiments 25 through 27, wherein the support member is configured to rotate as the support member moves from the first orientation to the second orientation.
Embodiment 29: The earth-boring tool of Embodiment 28, wherein the second orientation is about 180° of rotation from the first orientation.
Embodiment 30: The earth-boring tool of Embodiment 28 or Embodiment 29, wherein an axis of rotation of the support member is at least substantially parallel to a tangent line of a rotational path traversed by the movable cutting element when the support member is in the first orientation.
Embodiment 31: The earth-boring tool of Embodiment 28 or Embodiment 29, wherein an axis of rotation of the support member is at least substantially perpendicular to a tangent line of a rotational path traversed by the movable cutting element when the support member is in the first orientation.
Embodiment 32: The earth-boring tool of any one of Embodiments 28 through 30, wherein an axis of rotation of the support member is at least substantially parallel to a central axis of the movable cutting element.
Embodiment 33: The earth-boring tool of any one of Embodiments 28, 29, and 31, wherein an axis of rotation of the support member is at least substantially perpendicular to a central axis of the movable cutting element.
Embodiment 34: The earth-boring tool of any one of Embodiments 28 through 31, wherein an axis of rotation of the support member is oriented at an oblique angle to a central axis of the movable cutting element.
Embodiment 35: The earth-boring tool of any one of Embodiments 28 through 34, wherein each of the movable cutting element and the movable replacement cutting element is mounted on an end of the support member at a location offset from an axis of rotation of the support member.
Embodiment 36: The earth-boring tool of any one of Embodiments 25 through 35, further comprising an actuation device configured to move the support member from the first orientation to the second orientation.
Embodiment 37: The earth-boring tool of Embodiment 36, wherein the actuation device comprises at least one of an electro-mechanical device and an electro-hydraulic device.
Embodiment 38: The earth-boring tool of Embodiment 36, wherein the actuation device is configured to allow a pressure of drilling fluid flowing through the earth-boring tool to move the support member from the first orientation to the second orientation.
Embodiment 39: An earth-boring rotary drill bit, comprising: a body; blades extending radially outward over the body and longitudinally outward from a remainder of the body; fixed cutting elements attached to the blades at rotationally leading edges of the blades; a support member attached to at least one of the blades proximate the rotationally leading edge thereof, wherein the support member is movable between a first orientation and a second orientation; a movable cutting element attached to the support member at a first location; and a movable replacement cutting element attached to the support member at a different second location.
Embodiment 40: The earth-boring rotary drill bit of Embodiment 39, wherein the support member is rotatable between the first orientation and the second orientation and each of the first location and the second location is offset from an axis of rotation of the support member.
Embodiment 41: The earth-boring rotary drill bit of Embodiment 39 or Embodiment 40, wherein the movable replacement cutting element is located in a same position when the support member is in the second orientation as a position occupied by the movable cutting element when the support member is in the first orientation.
Embodiment 42: A method of forming an earth-boring tool, comprising: attaching a support member to a body, the support member comprising a movable cutting element attached to the support member at a first location and a movable replacement cutting element attached to the support member at a second location; and positioning a support member to be movable during a drilling operation between a first orientation and a second orientation, wherein the movable cutting element is located to engage with a formation and the movable replacement cutting element is located not to engage the formation when the support member is in the first orientation, and the movable replacement cutting element is located to engage with a formation and the movable cutting element is located not to engage the formation when the support member is in the second orientation.
Embodiment 43: The method of Embodiment 42, further comprising configuring the support member to rotate as the support member moves from the first orientation to the second orientation.
Embodiment 44: The method of Embodiment 42 or Embodiment 43, wherein positioning the support member to be movable during the drilling operation between the first orientation and the second orientation comprises positioning the support member to locate the movable replacement cutting element in a same position when the support member is in the second orientation as a position occupied by the movable cutting element when the support member is in the first orientation.
Embodiment 45: A method of drilling a wellbore using an earth-boring tool, comprising: drilling a first section of a wellbore in a formation using an earth-boring tool including a support member attached to a body of the earth-boring tool in a first orientation in which a movable cutting element attached to the support member engages the formation and a movable replacement cutting element attached to the support member does not engage the formation; moving the support member from the first orientation to a second orientation in which the movable replacement cutting element is located to engage the formation and the movable cutting element is located not to engage the formation; and drilling a second section of the wellbore in the formation using the earth-boring tool while the support member is in the second orientation and the movable replacement cutting element engages the formation.
Embodiment 46: The method of Embodiment 45, wherein moving the support member from the first orientation to the second orientation comprises rotating the support member.
Embodiment 47: The method of Embodiment 46, wherein rotating the support member comprises rotating the support member about 180°.
Although the foregoing description contains many specifics, these are not to be construed as limiting the scope of the present invention, but merely as providing certain embodiments. Similarly, other embodiments of the disclosure may be devised that do not depart from the scope of the present invention. For example, features described herein with reference to one embodiment also may be provided in others of the embodiments described herein. The scope of the invention is, therefore, indicated and limited only by the appended claims and their legal equivalents, rather than by the foregoing description. All additions, deletions, and modifications to the invention, as disclosed herein, which fall within the meaning and scope of the claims, are encompassed by the present invention.
wherein the cutting element is located to engage with a formation and the other cutting element is located not to engage the formation and is located at least partially within a cutting path traversed by the cutting element when the support member is selectively fixed in the first orientation, and the other cutting element is located to engage with a formation and the cutting element is located not to engage the formation when the support member is selectively fixed in the second orientation.
2. The earth-boring tool of claim 1, wherein the other cutting element is located in a same position when the support member is in the second orientation as a position occupied by the cutting element when the support member is in the first orientation.
3. The earth-boring tool of claim 2, wherein the body comprises blades, and wherein the position occupied by the cutting element when the support member is in the first orientation is at a rotationally leading edge of one of the blades.
4. The earth-boring tool of claim 1, wherein the support member is configured to rotate as the support member moves from the first orientation to the second orientation.
5. The earth-boring tool of claim 4, wherein the second orientation is about 180° of rotation from the first orientation.
6. The earth-boring tool of claim 4, wherein an axis of rotation of the support member is at least substantially perpendicular to a tangent line of a rotational path traversed by the cutting element when the support member is in the first orientation.
7. The earth-boring tool of claim 4, wherein an axis of rotation of the support member is at least substantially perpendicular to a central axis of the cutting element.
8. The earth-boring tool of claim 4, wherein an axis of rotation of the support member is oriented at an oblique angle to a central axis of the cutting element.
9. The earth-boring tool of claim 4, wherein each of the cutting element and the other cutting element is mounted on an end of the support member at a location offset from an axis of rotation of the support member.
10. The earth-boring tool of claim 1, further comprising an actuation device configured to move the support member from the first orientation to the second orientation.
11. The earth-boring tool of claim 10, wherein the actuation device comprises at least one of an electro-mechanical device and an electro-hydraulic device.
12. The earth-boring tool of claim 10, wherein the actuation device is configured to allow a pressure of drilling fluid flowing through the earth-boring tool to move the support member from the first orientation to the second orientation.
another cutting element attached to the support member at a different second location at least partially within a cutting path traversed by the cutting element when the support member is selectively fixed in the first orientation.
14. The earth-boring rotary drill bit of claim 13, wherein the support member is rotatable between the first orientation and the second orientation and each of the first location and the second location is offset from an axis of rotation of the support member.
15. The earth-boring rotary drill bit of claim 13, wherein the other cutting element is located in a same position when the support member is in the second orientation as a position occupied by the cutting element when the support member is in the first orientation.
positioning the support member to be selectively movable during a drilling operation between a first orientation and a second orientation, wherein the cutting element is located to engage with a formation and the other cutting element is located not to engage the formation and at least partially within a cutting path traversed by the cutting element when the support member is selectively fixed in the first orientation, and the other cutting element is located to engage with a formation and the cutting element is located not to engage the formation when the support member is selectively fixed in the second orientation.
17. The method of claim 16, further comprising configuring the support member to rotate as the support member moves from the first orientation to the second orientation.
18. The method of claim 16, wherein positioning the support member to be movable during the drilling operation between the first orientation and the second orientation comprises positioning the support member to locate the other cutting element in a same position when the support member is in the second orientation as a position occupied by the cutting element when the support member is in the first orientation.
US1029491A (en) * 1911-10-30 1912-06-11 Eugenio F Cortinas Drill.
Rasheed et al., SPE 92623, Reducing Risk and Cost in Diverse Well Construction Applications: Eccentric Device Drills Concentric Hole and Offers a Viable Alternative to Underreaamers; SPE/IADC Drilling Conference, Feb. 23-25, 2005, Amsterdam, Netherlands, 23 pages.


text:
Q: Robust ANCOVA literature? I am looking for some source of information, some articles about Robust ANCOVA. Can you suggest me something? And do you know any source that directly gives information about how to perform various robust ANCOVA with R?
I have seen a citation about Maxwell et al. 1993, an article called Analysis of Covariance but I do not find it!
I know Quinn and Keough, Experimental Design and Data Analysis for Biologists but they do not give much information about Robust ANCOVA.

A: Look for material on robust regression. There is lots of it.
ANCOVA, ANOVA and regression are all the same model, really.  In matrix algebra terms they are all
$Y = X\beta + \epsilon$

A: A general approach is to use cumulative probability ordinal models, the most popular being the proportional odds ordinal logistic model.  See a case study in R in Chapter 15 of my Handouts.

A: I suggest you  read Discovering Statistics Using R by Andy Field. He explains  gives information about how to perform various robust ANCOVA in R step by step and it is really easy to follow.


Tired of only being able to race on video games or think you have what it takes to transfer your skills to a real race track? A raffle hosted by Lemons of Love, a racer-owned non-profit that supports chemo patients, may give you the chance to do just that come March 16, when it announces the winner of a brand-spanking-new 2019 Mazda MX-5 Cup race car.
This sweet little racer is based on the newest version of the Mazda MX-5, the ND2, which means it rocks the enhanced 2.0-liter SKYACTIV-G engine that pumps out 181 horsepower. Combine that with a serious diet, the removal of electronic nannies, the addition of a roll-cage, and basically stiffer or stronger everything else, and the result is a big-boy race car capable of tackling the country's most famed racing circuits in the Global MX-5 Cup. But what about race entry fees? Don't worry, those are covered for the whole season, too.
If you want to get a piece of this awesomeness pie, all you have to do is visit Lemons of Love and drop $100 on a raffle ticket. Now, I know that a hondo isn't exactly pocket change, but let me remind you that an MX-5 Cup race car costs $68,000 brand new and that doesn't even include all the other goodies Lemons of Love and its sponsors are throwing in for the raffle winner. The best part? The more tickets you buy the more chances you have of Mazda Motorsports boss John Doonan drawing your name the morning of the 12 Hours of Sebring on March 16.
Ashton Harrison is one of the rising MX-5 Cup stars we interviewed last year.
Lemons of Love is a non-profit, 501(c)(3) organization that creates, fills, and delivers chemo care packages. We know about the little, day-to-day challenges that chemotherapy patients are faced with, and the racer-owned charity hopes to provide some insight about the effects of chemotherapy and make those short-term side effects, like dry skin and cold toes, a little more manageable through the gift of a care package.
The 2018 Lemons of Love raffle was won by Daniel Miller, a member of the United States Air Force who was deployed in the Middle East when Doonan drew his winning ticket the morning of the 2018 12 Hours of Sebring. Once he found out, Miller told Lemons of Love founder Jill Swanson Peltier that he donated to the charity because his mother is also a cancer survivor.


text:
Q: Patterns in local winding number sequences This is something of a followup to an earlier question
Can any sequence of consecutive integers be realized as winding numbers?, whose answer is Yes.
Now I would like to define a local winding number for a
plane curve as follows. For any region $R$ delimited by arcs of a plane curve $C$, define the local winding number as the number of counterclockwise arcs bounding $R$ minus the number of clockwise arcs bounding $R$.
It might be easiest to assume that two arcs that meet cross there, so tangencies
are excluded.

As @ZachTeitler observed in a preliminary (now deleted) version of the question,
"the sum of all the local winding numbers [must be] $0$, because each arc counts $+1$ on one side and $-1$ on the other." Indeed in the example above, the sum
is zero.

My question is:

Q. Are there any other constraints to the sequence of local winding numbers
  defined by a plane curve?

I've explored a bit without seeing clear patterns, except
for classes of regimented curves, e.g.:


text:
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Review No. 7 – Talisker 10 Year Old
Whisky, Aye?	Distillery, Islands, scotch, scotland, single malt, whisky	 May 30, 2019 May 30, 2019 3 Minutes
An all-time classic. There, I've said it, and I steadfastly refuse to back down. I'm putting my head on the block, and my non-existent reputation on the line. Granted, what I write is all subjective and is only my own experiences, but if you can bear with me and the following woeful analogies, then I will do my utmost to do Talisker's 10 Year Old offering a wee bit of justice.
For many whisky enthusiasts, the overwhelming aromas of smoke and peat can be, well, overwhelming. A wee search of the internet will bring up a few reviews describing Laphroaig as having a medicinal, even iodine-like, smoky odour and taste, or those who are taken aback by the meaty, peaty Caol Ila 12 Years Old, for instance.
Talisker 10 acts as a kind of 'whisky bridge' between the mellow peat, smoke, and spice of the West Highlands region, and the full-on, blow-your-socks-off smoke bombs and peat monsters that often define Islay's whisky industry.
However, I don't want to paint a poorly-worded picture of the Talisker 10 as being a stepping stone to bigger and better things, but more that it's a wonderful whisky! A stature well-earned due to its own delicious merits, which allow it to act as a bridge to enjoying some of the more powerful whiskies that dominate the whisky region to the south of Skye.
The largest of the Inner Hebrides islands, Skye currently has 2 distilleries, Talisker and Torabhaig, but it's the former's single malts which are the most well-known. Founded in 1830, Talisker has had a relatively straightforward existence when compared to the market fluctuations the industry has suffered over the past 150 years. Aside, of course, from a destructive fire in 1960 which completely destroyed the premises, like many unfortunate distilleries before and since. The distillery is now owned by drinks giant Diageo, who also own Caol Ila amongst others, and Talisker have a nice, slightly-varied, core range of whiskies, such as Storm and Port Ruighe. Diageo also allows for some Limited Edition Annual Releases, including older age statements, but it is the 10 that I believe is the jewel in the Talisker crown – it isn't part of the popular Classic Malts of Scotland range, alongside Lagavulin 16 and Dalwhinnie 15, for nothing.
For me, it's not a stretch to describe the Talisker 10 as an essential whisky, particularly for those looking to find their feet in a landscape abundant with whisky choices. The 10 regularly wins awards and continues to do so, from a Gold in the International Wine + Spirit competition in 2013, to the more recent World Whisky Award 2018 Gold Medal. The longevity and continued success, whilst never deviating from the expected quality, allow the 10 to remain a stand-out whisky. The fact it can be picked up for as little as £30 just adds to the appeal.
With a mid-range PPM ((Phenol) Parts Per Million) of 22, it has a light smokiness, a salty whiff infused from its proximity to the sea, and vibrant gold colour radiating from the clear glass bottle. Sounds great so far, but is it enjoyable to drink? (Spoiler: Yes, it is).
Nose: Rising from the glass, which has rested for about 5 minutes, is the unmistakable salty, briney aroma of the sea. It's almost easy to get lost in it, until the pepper shows up to the party. There's a sweet yet dull hint of seaweed too, and a brief closing of the eyes brings a lovely toffee scent to the senses. 8.5/10
Palate: There's a warming, mellow peatiness which hits first, followed by a wee bit of spice and pepper as well, which marries with the smokiness and envelops the inside of my mouth. It then makes way for a wonderful salted caramel richness which also carries a hint of pears. 8.5/10
Finish: If there's a weak point – and after all my cheering – it's in the finish. A medium one, with the spice still lingering, and a faint iodine bitterness to it. Any fruitiness disappears quite quickly, but it's a small gripe given the price of the 10, availability, and all-round performance. 7/10
Total: 24/30 – A wise purchase for any whisky fan!
Published by Whisky, Aye?
Bipedal primate with opposable thumbs. Also like whisky.	View all posts by Whisky, Aye?
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2 thoughts on "Review No. 7 – Talisker 10 Year Old"
Alex Cochrane says:
Had a Talisker last night. Thoroughly enjoyed it!
Whisky, Aye? says:
Great choice, Alex! You can never go wrong with a Talisker!
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