|Publication number||US3850250 A|
|Publication date||Nov 26, 1974|
|Filing date||Sep 11, 1972|
|Priority date||Sep 11, 1972|
|Publication number||US 3850250 A, US 3850250A, US-A-3850250, US3850250 A, US3850250A|
|Inventors||Holden J, Wray G|
|Original Assignee||Halliburton Co|
|Export Citation||BiBTeX, EndNote, RefMan|
|Patent Citations (11), Referenced by (68), Classifications (15)|
|External Links: USPTO, USPTO Assignment, Espacenet|
United States Patent 1191 Holden et al.
[ Nov. 26, 1974  WELLBORE CIRULATING VALVE 3,306,366 2/1967 Muse 166/128 x 3,361,212 1/1968 Page, Jr. 166/224 R [751 lnlemorso 0mm, Gary wray 3,433,301 3/1969 McEver, Jr. 166/128 both of Duncan, Okla' 3,456,723 7 1969 Current et al. 166 134 x 3,507,327 4/1970 Chenoweth.......... 166/134  Asslgnee' gi Company Duncan 3,570,595 3 1971 'Berryman 166 226 3,664,415 5/1972 Wray et al. [66/5  Filed: Sept, 11, 1972 3,750,749 8/1973 Giroux 166/224 R  Appl 1 Primary Examiner-James R. Boler Attorney, Agent, or Firm-John H. Tregoning; Floyd  US. Cl 166/315, 166/226, 166/95 A. Gonzalez; James E. Cockfield  Int. Cl E21b 33/00  Field of Search 166/315, 224, 225, 226, 57 ABSTRACT 166/126,128,150, 152, 72, 73, 77.5, 95, 98, A 11b l l n f l 134, 181, 237, .5; 285/302, 303; 403/227, .clrcuamg especla a strmg of testmg tools u1t111zes a sequentially ratcheted 228, 345, 377, 294/8615, 86.21
mner mandrel wh1ch covers a senes of flow ports and d by a predetermined sequence of operations  References Clted 9 wh1ch move the mandrel away from the flow ports UNITED STATES PATENTS thereby communicating the annulus with the inner [S4123 bore of the tool, in seu 1 3,237,695 3/1966 Bostock et a1, 166/134 x 11 Clalms, 8Draw1ng Figures as 34 1 w 1Z PATEm gxavzslsm saw 3 BF 3 FIG. 2'
FIGVI WELLBORE CIRCULATING VALVE BACKGROUND OF THE INVENTION After an oil well has been encased and cemented it usually becomes desirable to test the formations penetrated by the wellbore for possible production rates and general productivity of the well. In doing so, a test string containing several different types of tools is utilized to indicate the productivity of the well. These tools may include a pressure recorder, a sample chamber, a closed-in pressure tester, hydraulic jar, one or more packers, and several other tools. In addition, it is preferable to include one or more circulating valves in the string.
The testing procedure requires the opening of a section of the wellbore to atmospheric or reduced pressure. This is accomplished by lowering the test string into the hole on drill pipe with the tester valves and sample chambers closed to prevent entry of well fluid into the drill pipe. With the string in place in the formation, packers are expanded to seal against the wellbore or casing and isolate the formation to be tested. Above the formation the hydrostatic pressure of the well fluid is supported by the upper packer. The well fluid in the isolated formation area is allowed to flow into the drill string by opening the tester valve. Fluid is allowed to continue flowing from the formation to measure the ability of the formation to produce. The formation may then be closed in to measure the rate of pressure buildup.
After the flow measurements and pressure buildup curves have been obtained, one or more samples can be caught and then the test string will be removed from the well.
At this point the importance of the circulating valve becomes important. Since it is not desirable to pull the testing string while it may still be full of formation fluids and/or high pressure gas due to the danger of explosion and fire at the surface, plus the resulting contamination of the rig and rig floor with the crude oil and other formation fluids which leads to dangerous and slippery footing, it is almost mandatory that the formation fluids be reversed out under controlled conditions and bledoff away from the rig floor.
To accomplish this reversing out, the inner bore of the test string and drill pipe must be opened near the test tools so that displacement fluid (usually drilling mud) from the annulus can flow into the string to force out the formation fluids at the top where they can be piped away from the rig. The hydrostatic pressure from the displacement fluid is usually considerably higher than the formation pressure due to the high density of the mud and the height of the mud column in the well, therefore displacement from the annulus into the string and up to the surface usually occurs without the need for pumping. All that is required is that the annulus be placed in fluid communication with the bore of the test string at the proper time. During testing and sampling operations the hydrostatic fluids in the annulus must be isolated from the formation fluids to prevent contamination of the tests and samples.
Thus, it is only after the testing and sampling is completed that it is desirable to reverse out the remaining formation fluids in the tubing.
Several methods of accomplishing this are currently in use. One of these methods involves covering the ports through the tubing wall with an inner sleeve which is shear pinned to the tubing wall. When the sleeve is to be opened a weighted bar is dropped through the tubing to strike the sleeve and shear the pins, moving the sleeve downward to uncover the ports and communicate the annulus with the tubing bore. The disadvantages of this device are obvious; a deviated hole may cause the bar to bind in the tubing thereby blocking the tubing and preventing opening of the circulating valve sleeve and removing any chance of reversing out. Also slant holes may reduce the speed of the bar moving down the tubing because of friction between the bar and the tubing wall. A reduction in speed could lower the striking force of the bar to the point where the shear pins will not break and reversing out will not be possible. Also when some of the extremely heavy formation fluids are being recovered the bar may not be heavy enough in these fluids to shear the pins in the circulating valve, or there may be enough trash collected in the valve sleeve to cushion I the impact of the bar and prevent shearing of the pins.
Other types of circulating valves utilize reciprocal or rotational movement to operate the valve sleeve. The rotationally operated circulating valve suffers from the disadvantage that often the string may bind in the well bore so that the string has enough flexibility to allow rotation by twisting above the circulating valve. The operator at the surface may have no way of knowing that the rotation is not accomplishing the desired effect, or if he knows he may have no way of correcting it. The same defect occurs in the reciprocating tools, they may become lodged in a deviated well and the circulating valve becomes inoperable.
In addition, the above described circulating valves are unsatisfactory in offshore wells because the blowout preventers must be opened in order to manipulate the drill string or drop the opening bar into the pipe in order to open the circulating valve. This becomes extremely dangerous because well blowout, explosion, and fire become a possibility when the blowout preventers are released and this remains a constant threat until the preventers are closed.
The apparatus of this invention overcomes these difficulties by opening in response to controlled fluctuations in annulus pressure, requiring no manipulation nor activating members inserted onto the tubing.
BRIEF DESCRIPTION OF THE DRAWINGS FIG. I, which is broken into FIGS. 1a through If for convenience in drawing, illustrates a partial crosssectional view of the apparatus of this invention.
FIG. 2 is an elevational view of the latch mandrel showing the orientation of the latch blocks.
FIG. 3 is a blown-up cross sectional view of the threads on the latch mandrel and pull mandrel.
DESCRIPTION OF THE PREFERRED EMBODIMENTS FIG. 1 depicts the preferred embodiment of the circulating valve apparatus 1 in which a tubular latch mandrel 2 is concentrically and slidably located inside a segmented tubular housing 3. Mandrel 2 has an external beveled shoulder 20 for engaging an internal beveled shoulder 30 in housing 3. This limits downward movement of mandrel 2 in housing 3. Housing 3 has one or more ports 31 through the wall thereof which communicate from the inner bore 32 of housing 3 to the annular area 33 between the tool 1 and the well cas- In its lowermost position, skirt 21 of latch mandrel 2 covers ports 31 and prevents fluid communication therethrough. Circular seals 34 located in internal grooves 35 of housing 3 provide fluid-tight seals between housing 3 and mandrel skirt 21 above and below ports 31.
Valve sleeve 4 is a tubular sleeve having an upper skirt 40 and a lower flanged end 41, with the skirt 40 being slidably located coaxially inside the latch mandrel skirt 21 and having a circular seal 42 located in annular groove 43 for providing a fluid-tight seal between skirt 21 and skirt 40. Flanged end 41 extends out of mandrel skirt 21 and is enlarged greater than the OD of skirt 21 to prevent skirt 21 from sliding over the flanged end. Abutment of skirt 21 on flanged end 41 limits downward movement of mandrel 2. Flanged end 41 is further extended into an inner annular recessed groove 36 in housing 3 which prevents upward or downward movement of valve sleeve 4 in housing 3. A circular seal 44 is located annularly around flange 41 to provide fluid-tight sealing contact with housing 3.
Latch mandrel 2 has one or more windows 22 through the wall thereof near the upper end 23 of the mandrel. Located in windows 22 are curved latch blocks 24 having curved internal threaded surfaces 25 located on their inward faces. Retainer pins 26 are fixedly attached to the edges of latch blocks 24 and arranged to abut recessed shoulders 27 of windows 22 to limit inward movement of blocks 24 in windows 22.
Latch blocks 24 are arranged to move outwardly from windows 22 in response to wedging forces pushing them outward. Spring elements 28 encircle blocks 24 in grooves 29 and latch mandrel 2 and provide a spring force tending to press blocks 24 inwardly in windows 22 thereby providing a constant but yieldable restraining force thereon.
Pull mandrel is a tubular cylindrical sleeve located concentrically within the latch mandrel 2, having a helical thread 50 which engages and matches the helical thread 25 inside latch blocks 24. Alternatively, instead of threads at 25 and 50, circular parallel grooves could be used in the latch blocks and on mandrel 5. Referring now to FIG. 3, threads 50 have a sloped face 62 on their lower leading edge and a slightly sloped face 63 on their upper trailing edge. Threads 25 have a slightly sloped face 64 on their lower edge and a sloped face 65 on their upper edge. This allows downward longitudinal movement of pull mandrel 5 through latch mandrel 2 by means of wedging action of the sloping face of threads 50 on the sloping face of threads 25, which wedging action forces latch blocks 24 outward and allows telescopic movement of mandrel 5 into mandrel 2. The wedging forces required to move latch blocks 24 outward and allow mandrel 5 to telescope into mandrel 2 must necessarily be less than those holding mandrel skirt 21 in position in housing 3, which are the friction forces of seal rings 34 and 42.
Upward movement of pull mandrel 5 results in abutment of the backwardly sloped faces 63 and 64 of threads 50 and 25 which results in likewise upper movement of latch mandrel 2. A subsequent downward movement of pull mandrel 5 into latch mandrel 2 achieves another wedging outward of latch blocks 24 and allows the pull mandrel to take another bite on the latch mandrel, and through this ratcheting type of action, will allow a sequential train of upward and downward movements of the pull mandrel to result in a complete extension of the latch mandrel and skirt out of the annular area between the valve sleeve 4 and housing 3.
Faces 63 and 64 of threads 50 and 25 respectively are illustrated having a slight back slope of around 2 to 10, with a preferable angle of about 5. This provides a positive locking engagement of threads 50 and 25 when they are moving in such a relationship, one to the other, that faces 64 are abutted with faces 63. It is contemplated that the back angle of faces 63 and 64 with the vertical in FIG. 3 may be anywhere from 0 to 60 and the forward angle of faces 62 and 65 may be from about 10 to about with the vertical.
A preferred angle for faces 62 and 65 for optimum strength and good wedging action appears to be around 45.
Upward travel of the latch mandrel about the pull mandrel will be limited by abutment of the upper mandrel end 23 with exterior annular shoulder 51 attached to the pull mandrel. Shoulder 51 may be an integrally formed shoulder or can be a threaded collar fixedly attached to the upper end of mandrel 5.
Threadedly attached to the upper end of housing 3 is adapter 6 which has an internally projecting shoulder 61. This shoulder may be formed by machining adapter 6 with a smaller ID than that of the housing at the point where they are threadedly attached. Spacer 7 is slidably located within housing 3 and around the upper extension mandrel 8 so that upward travel of the pull mandrel is limited by abutment of shoulder 51, spacer 7, and shoulder 61.
Referring to FIGS. 1a to If which are continuations of FIG. 1 and show the apparatus broken in order to more easily locate the drawings on the page in as large a detail as possible, adapter 6 is shown threadedly engaged in the intermediate housing 9 which, in conjunction with upper housing 10, contains the power section 11 for actuating the valve section 1.
Extension mandrel 8 extends upwardly through adapter 6 and intermediate housing 9 and is threadedly engaged in the cylindrical orifice mandrel 12. A cylindrical piston mandrel 13 is fixedly attached to the upper end of orifice mandrel 12 via lower section 14 and has an extended upper skirt section 15.
Adapter collar 16, having a narrowed ID, is threadedly secured to upper housing 10 and has an exterior tubular extension 17 threadedly attached to its upper end, and concentric inner extension 18 fixedly attached interiorly thereto.
Thus, it can be seen in FIGS. 1d and 1e that the power section generally consists of a stationary outer casing and a slidable inner member, with the outer casing consisting substantially of adapter 6, intermediate housing 9, upper housing 10, adapter collar 16, tubular extension 17, and inner extension 18. The slidable inner member consists of extension mandrel 8, orifice mandrel 12, piston mandrel 13, lower section 14, and upper skirt 15.
A differential piston arrangement is provided by differential piston area 19 on the upper end of piston mandrel 13. This area works in conjunction with piston chamber 37 to provide a power actuating source for the power section 11. Piston chamber 37 is formed by the relatively large inner diameter of housing 10 and the narrow inner diameters of adapter collar 16 and housing 10. A gas-tight seal is provided by circular seals 38 located in exterior annular grooves 39 on piston mandrel 13. Power fluid access to the differential piston area 19 is achieved through one or more ports 45 through the wall of upper housing 10, communicating with annular space 46 between the enlarged upper section of piston mandrel 13 and housing 10. Piston chamber 37 is shown in broken construction to reduce the length of the drawing. In actuality, it is considerably longer than pictured and can be made of any variable length which results in sufficient volume to provide the desired spring effect. In one embodiment, this chamber comprises approximately one-half of the length of the power section and contains an inert gas under pressure to provide a return force on face 47 of piston mandrel 13 so that after the pressure is removed from the actuating fluid in area 46 the compressed gas in chamber 37 forces piston mandrel 13 back down to its initial lower position.
A mechanical spring can be used in place of or in conjunction with the inert gas in chamber 37 to vary the restoring force on piston 14. This variance can also be obtained by either varying the initial pressure of inert gas in chamber 37 or by varying the volume of chamber 37, or by both means.
Actuating force can be varied by increasing or decreasing the differential area 19 of piston 13 by reducing the OD of piston 13 below face 19, or by increasing the ID of housing and the OD of piston face 19, or by both methods.
Sharp upward movement of the inner member within the outer members is prevented by the reaction of the orifice mandrel in the dampener chamber 48. The orifice mandrel 12 has an integral orifice collar 49 which moves slidably in annular chamber 48 formed between housing 9 and the narrowed section 52 of mandrel 12. Chamber 48 is filled with some durable non-corrosive fluid such as hydraulic oil and is a fluid-tight sealed chamber. As mandrel 12 moves upward in housing 9, collar 49 must traverse sealed chamber 48 which is filled with fluid. To do so, the fluid above the collar must traverse through orifice channel 53 to below the collar. Circular seals 54 located in grooves 55 in collar 49 seal against the inside of housing 9 and prevent leakage of fluid around collar 49. The effect of moving collar 49 through chamber 48 and allowing fluid to flow only through the restricted orifice channel is that movement of the inner mandrels in the outer housing is dampened to prevent sudden large movements therein. As the movement actuating force increases, the dampening force of the orifice arrangement increases correspondingly.
When the actuating force on piston face 19 is removed, it is desirable that the mandrels 12 and 13 be allowed to move downward relatively unrestricted so a bypass check valve arrangement is provided at 56 to allow fluid to flow from the lower side of collar 49 through channel 57 to the upper side in chamber 48 relatively unhindered, thereby bypassing orifice channel 53. This is provided since the spring constant of the gas spring in chamber 37 is preset at a non-excessive level to prevent damage to the apparatus through sudden sharp return of the piston mandrel to its initial position. Channels 53 and 57 are in continuous fluidic communication with the lower side of collar 49 through chamber 58 which is an annular chamber passing completely around the exterior circumference of the extension mandrel 8. Likewise, chamber 48 is an annular chamber completely surrounding mandrel 8. There may be one or more orifice channels 53, and one or more bypass channels 57.
In operation the entire apparatus is connected into a testing string, for instance, by threading the upper ends of extensions 17 and 18, and the threaded lower end 59 of the valve section 1 into the test string.
The string can then be lowered into the hole and the formation tested. The use of this apparatus is particularly advantageous in conjunction with the annulus pressure operated sampler disclosed in US. Pat. No. 3,664,415. The advantages of pressure operated tools are particularly felt when operating in an offshore well where it is highly preferable to maintain the blowout preventer rams closed at all times which naturally prevents any type of manipulation of the test string to operate the various tools in the well. The types of manipulations commonly used are rotation and reciprocation or combinations of the two, all of which cannot be performed with the blowout preventers in place.
Therefore, the tool of this invention is extremely safe and advantageous for use in offshore wells and unpredictable high pressure inland wells. When the tool string is in place in the well and the blowout preventers are closed in on the testing tools the sampler can be activated by applying hydraulic pressure to the annulus between the tool string and the casing.
The increase in annulus pressure reacts through ports 45 and against differential area 19, forcing piston mandrel 13 upward against the spring means in chamber 37. As the piston mandrel moves upward it simultaneously pulls orifice mandrel 12, extension mandrel 8, pull mandrel 5, latch mandrel 2 and skirt 21 upward until shoulder 51 contacts spacer 7, thereby preventing any further upward movement of the inner mandrel section. After the testing or other operations in the various parts of the string have been completed, the annulus pressure is removed and the spring means in chamber 37 forces the inner mandrel system back down to its initial position by working against piston face 47. Upon this downward return movement, pull mandrel 5 is extended into latch mandrel 2, thereby accomplishing the ratcheting action described beforehand. Then when another testing operation is required and the annulus pressure is again increased, the mandrels are moved upward another increment. The number of sequential pressure variations in the annulus fluid required to open the circulating valve 1 can be determined by the total length upward the latch mandrel must move to expose ports 31, divided by the incremental amount the mandrel moves during each individual pressurization of the annulus fluid. For instance in one embodiment, the latch mandrel must move ten inches toexpose the circulating valve ports 31 and each incremental advance is limited to one inch, therefore to actuate the circulating valve the annulus mustbe pressured ten times. This allows the annulus to be pressurized nine times to perform other testing operations through the other tools in the string without actuating the circulating valve, which preferably is opened after the completion of all testing and sampling, immediately prior to removing the test string from the well.
The number of pressure variations required to open the circulating valve can easily be varied by several methods. For instance, lengthening spacer 7 will reduce the length of the increments and require more increments to accomplish the opening. Should it be desirable to reduce the number of increments the spacer 7 could be shortened to increase the incremental travel of latch mandrel 2 upward.
The number of increments could also be varied by varying the distance between ports 31 and the lower end of skirt 21 by either moving the position of ports 31 up or down in the housing 3 and/or varying the length of the skirt 21 extending below ports 31.
Another feature of the circulating valve of this invention is the immediate responsive opening. When the final upward increment of the skirt 21 is achieved to open ports 31, the lower end of skirt mandrel 21 is pulled out of contact with the lowermost seal 34 allowing high pressure annulus fluid to flow almost instantaneously into the space below skirt 21 between housing 3 and valve sleeve 4. This fluid is prevented from entering the bore by contact of skirt 21 with upper seal 34 and seal 42. Thus, the high pressure fluid reacts against the bottom face 60 of the lower end of skirt 2], which face 60 acts as a differential pressure area between the high pressure annulus fluid and the relatively low pressure in the inner bore 32. This results in a slamming upward of the latch mandrel which assures a fully opened immediately responsive circulating valve.
It should be reemphasized that for proper operation of the circulating valve, springs 28 should not be any stronger than what is required to maintain latch blocks 24 in threaded engagement with pull mandrel 5 when it is moving upward. Thus, downward movement of pull mandrel 5 into latch mandrel 2 will be possible without sliding the latch mandrel downward because the frictional retaining force of seals 34 and 42 is substantially larger than the force required to push mandrel 5 through the latch blocks in mandrel 2.
Although a specific preferred embodiment of the present invention has been described in the detailed description above, the description is not intended to limit the invention to the particular forms or embodiments disclosed herein, since they are to be recognized as illustrative rather than restrictive and it will be obvious to those skilled in the art that the invention is not so limited. For example, while the circulating valve is described in combination with pressure operated actuating means, it is clear that other actuating means could be employed without need for modifying the circulating valve. For instance, a reciprocating actuator could replace the power section 11 and be attached to pull mandrel 5. Vertical reciprocation of the test string from the surface would serve to move the pull mandrel up and down in the latch mandrel just as the power section does with the same resulting ratcheting action which moves the mandrel out .of its covering position over ports 31.
Likewise, a rotational actuating means could be utilized in conjunction with the circulating valve to move mandrel 2 upward in the housing 3. Since the mating threads in' the latch blocks 24 and on pull mandrel 5 are preferably formed as normal helical threads, it is clear that rotating the pull mandrel by any normal means of rotation, such as for instance rotating the test string at the surface, would result in the latch mandrel being threaded upward or downward onto the pull mandrel. 6
housing 3. This limiting means would serve only to prevent rotational movement and not longitudinal axial movement of the latch mandrel. Thus, the invention is declared to cover all changes and modifications of the specific example of the invention herein disclosed for purposes of illustration, which do not constitute departures from the spirit and scope of the invention.
What is claimed is 1. Apparatus for use in testing well formations comprising:
actuating means responsive to hydraulic pressure for producing vertical, reciprocal motion for an indefinite number of times;
valve means responsive to unidirectional motion for allowing fluid communication from an annulus area exterior to a test string to an open bore within the test string after a selected number of unidirectional motions; and
means connecting said actuating means to said valve means for transferring unidirectional movement to said value means from the reciprocal movement produced by said actuating means.
2. The apparatus of claim 1 wherein said means connecting said actuating means to said valve means includes means for ratcheting said valve means from a closed position to a fully opened position in a series of sequential increments, with each sequential increment occurring in response to a vertical, reciprocal motion of said actuating means.
3. The appartus of claim 2 wherein said valve means includes means responsive to initial fluid communication from said annulus area to said open bore for supplying immediate opening upon performance of the last of said sequential increments.
4. The apparatus of claim 1 wherein said actuating means comprises means responsive to changes in pressure in said annulus exterior to said test string for producing vertical, reciprocal movement; said responsive means having a differential area piston means for producing vertical movement in one direction upon increases in said annulus pressure, and spring means opposing said vertical movement for producing vertical return movement in the opposite direction when said annulus pressure increases are removed.
5. The apparatus of claim 4 further comprising:
dampener means within said actuating means for preventing sudden substantial increases in annulus pressure from causing sudden vertical reciprocation of said power means, said dampener means providing an opposing force to the force of said increasing hydraulic pressure in said annulus; and
means for allowing bypass of said dampener means upon said vertical return movement of said piston means.
6. The apparatus of claim 1 wherein said valve means further comprises:
an outer tubular housing having one or more ports through the wall thereof;
an inner concentric tubular valve sleeve located within and fixedly attached to said housing;
a first mandrel slidably located between said housing ancl said sleeve and arranged in a first initial position to cover said ports and in a final position to expose said ports; and
wherein said means connecting said actuating means to said valve means further comprises:
a second mandrel arranged within said first mandrel and adapted to move vertically within said first mandrel and said housing; and
ratchet means between said first mandrel and said second mandrel for allowing said second mandrel to disengage from said first mandrel upon downward movement of said second mandrel in said first mandrel, and for latching said first mandrel to said second mandrel upon upward movement of said second mandrel.
7. The apparatus of claim 6 further comprising:
first travel limiting means between said second mandrel and said first mandrel for limiting the extent of total accumulated travel of said second mandrel in said first mandrel; and
second travel limiting means between said second mandrel and said tubular housing for limiting the amount of travel said second mandrel may move said first mandrel with each vertical, reciprocal motion of said actuating means.
8. A circulating valve for communicating the bore of a pipe string with the area exterior to said pipe string, said valve comprising:
a tubular cylindrical outer housing having one or more ports through the wall thereof;
means for connecting said valve between two sections of a pipe string;
inner mandrel means slidably located within said housing and arranged to sealingly cover said ports in one position and expose said ports in a second position;
pull mandrel means slidably located for reciprocal movement within said housing and connected to said inner mandrel means;
ratcheting means between said inner mandrel means and said pull mandrel means for allowing telescopic inward movement of said pu1l mandrel means with respect to said inner mandrel means, and for latching said pull mandrel means to said inner mandrel means to prevent telescopic outward movement of said pull mandrel means with respect to said inner mandrel means;
first limiting means on said pull mandrel means for limiting said inward telescopic movement of said inner mandrel means with respect to said pull mandrel means; and
second limiting means between said pull mandrel means and said housing for limiting reciprocal movement of said pull mandrel means in said hous' 9. The valve of claim 8 further comprising quick response opening means having a valve sleeve inside of said housing and said inner mandrel means, said valve sleeve being attached to said housing, differential area piston means on said inner mandrel between said housing and said valve sleeve, and seal means between said inner mandrel means, said valve sleeve, and said housing.
10. The valve of claim 8 wherein said ratcheting means further comprises:
one or more latch block openings through the wall of said inner mandrel means;
latch block means in each of said openings;
said latch block means having a curved block generally matching the curvature of said inner mandrel and having an internally grooved helical thread therein;
an externally grooved helical thread on said pull mandrel means adapted to mate with and engage said thread in said latch block means; means for preventing said latch block means from dropping inward through said openings; and
spring means for providing a continuous inward yieldable pressure against said latch block means in said openings.
11. A method of reverse circulating a displacement fluid through a string of well tools located in a closed-in well, said method comprising:
applying pressure to said displacement fluid in the annulus between said well tools and the casing of the well;
moving a first mandrel in response to said pressure application, thereby pulling a second mandrel latched to said first mandrel;
removing said annulus pressure;
unlatching said first mandrel from said second mandrel and moving said first mandrel with respect to said second mandrel in response to a means opposing movement of said first mandrel until said first mandrel has returned to its original position; repeating the above steps a predetermined number of times, thereby activating a flow means; and flowing annulus fluid through said flow means into said tool string.
|Cited Patent||Filing date||Publication date||Applicant||Title|
|US3071151 *||Nov 5, 1958||Jan 1, 1963||Otis Eng Co||Pressure responsive control valve for well tubing|
|US3126965 *||Dec 9, 1960||Mar 31, 1964||Valve for well pipe|
|US3237695 *||Nov 30, 1962||Mar 1, 1966||Otis Eng Co||Hydraulically set well packer|
|US3306366 *||Apr 22, 1964||Feb 28, 1967||Baker Oil Tools Inc||Well packer apparatus|
|US3361212 *||Sep 3, 1965||Jan 2, 1968||John S. Page Jr.||String fluid controlled sleeve valve|
|US3433301 *||Oct 5, 1967||Mar 18, 1969||Schlumberger Technology Corp||Valve system for a well packer|
|US3456723 *||Jun 30, 1967||Jul 22, 1969||Camco Inc||Hydraulically set well packer|
|US3507327 *||Sep 4, 1964||Apr 21, 1970||Baker Oil Tools Inc||Retrievable subsurface well tools|
|US3570595 *||Nov 22, 1968||Mar 16, 1971||Schlumberger Technology Corp||Hydraulically operable valves|
|US3664415 *||Sep 14, 1970||May 23, 1972||Halliburton Co||Method and apparatus for testing wells|
|US3750749 *||Apr 19, 1971||Aug 7, 1973||Halliburton Services||Swivel control head and method of control|
|Citing Patent||Filing date||Publication date||Applicant||Title|
|US3986554 *||May 21, 1975||Oct 19, 1976||Schlumberger Technology Corporation||Pressure controlled reversing valve|
|US4064937 *||Feb 16, 1977||Dec 27, 1977||Halliburton Company||Annulus pressure operated closure valve with reverse circulation valve|
|US4083409 *||May 2, 1977||Apr 11, 1978||Halliburton Company||Full flow bypass valve|
|US4109724 *||Oct 27, 1977||Aug 29, 1978||Halliburton Company||Oil well testing valve with liquid spring|
|US4109725 *||Oct 27, 1977||Aug 29, 1978||Halliburton Company||Self adjusting liquid spring operating apparatus and method for use in an oil well valve|
|US4273194 *||Feb 11, 1980||Jun 16, 1981||Camco, Incorporated||Annular flow control safety valve|
|US4324293 *||Apr 29, 1980||Apr 13, 1982||Halliburton Services||Circulation valve|
|US4328866 *||Mar 7, 1980||May 11, 1982||Halliburton Company||Check valve assembly|
|US4373582 *||Dec 22, 1980||Feb 15, 1983||Exxon Production Research Co.||Acoustically controlled electro-mechanical circulation sub|
|US4417622 *||Jun 9, 1981||Nov 29, 1983||Halliburton Company||Well sampling method and apparatus|
|US4444268 *||Mar 4, 1982||Apr 24, 1984||Halliburton Company||Tester valve with silicone liquid spring|
|US4445571 *||Aug 20, 1981||May 1, 1984||Halliburton Company||Circulation valve|
|US4448254 *||Sep 14, 1982||May 15, 1984||Halliburton Company||Tester valve with silicone liquid spring|
|US4452313 *||Apr 21, 1982||Jun 5, 1984||Halliburton Company||Circulation valve|
|US4474242 *||Jun 29, 1981||Oct 2, 1984||Schlumberger Technology Corporation||Annulus pressure controlled reversing valve|
|US4489786 *||Sep 19, 1983||Dec 25, 1984||Halliburton Company||Low pressure responsive downhole tool with differential pressure holding means|
|US4515219 *||Sep 19, 1983||May 7, 1985||Halliburton Company||Low pressure responsive downhole tool with floating shoe retarding means|
|US4537258 *||Sep 19, 1983||Aug 27, 1985||Halliburton Company||Low pressure responsive downhole tool|
|US4552218 *||Sep 26, 1983||Nov 12, 1985||Baker Oil Tools, Inc.||Unloading injection control valve|
|US4557333 *||Sep 19, 1983||Dec 10, 1985||Halliburton Company||Low pressure responsive downhole tool with cam actuated relief valve|
|US4573535 *||Nov 2, 1984||Mar 4, 1986||Halliburton Company||Sleeve-type low pressure responsive APR tester valve|
|US4627492 *||Sep 25, 1985||Dec 9, 1986||Halliburton Company||Well tool having latching mechanism and method of utilizing the same|
|US4633952 *||Apr 3, 1984||Jan 6, 1987||Halliburton Company||Multi-mode testing tool and method of use|
|US4655288 *||Jul 3, 1985||Apr 7, 1987||Halliburton Company||Lost-motion valve actuator|
|US4657082 *||Nov 12, 1985||Apr 14, 1987||Halliburton Company||Circulation valve and method for operating the same|
|US4657083 *||Nov 12, 1985||Apr 14, 1987||Halliburton Company||Pressure operated circulating valve with releasable safety and method for operating the same|
|US4665983 *||Apr 3, 1986||May 19, 1987||Halliburton Company||Full bore sampler valve with time delay|
|US4669539 *||Jun 18, 1986||Jun 2, 1987||Halliburton Company||Lock for downhole apparatus|
|US4673890 *||Jun 18, 1986||Jun 16, 1987||Halliburton Company||Well bore measurement tool|
|US4711305 *||Dec 31, 1986||Dec 8, 1987||Halliburton Company||Multi-mode testing tool and method of testing|
|US4817723 *||Jul 27, 1987||Apr 4, 1989||Halliburton Company||Apparatus for retaining axial mandrel movement relative to a cylindrical housing|
|US5168931 *||Sep 30, 1991||Dec 8, 1992||Halliburton Company||Fluid control valve|
|US5335731 *||Oct 22, 1992||Aug 9, 1994||Ringgenberg Paul D||Formation testing apparatus and method|
|US5341883 *||Jan 14, 1993||Aug 30, 1994||Halliburton Company||Pressure test and bypass valve with rupture disc|
|US5355959 *||Sep 22, 1992||Oct 18, 1994||Halliburton Company||Differential pressure operated circulating and deflation valve|
|US5383520 *||Sep 22, 1992||Jan 24, 1995||Halliburton Company||Coiled tubing inflatable packer with circulating port|
|US5456322 *||Aug 18, 1994||Oct 10, 1995||Halliburton Company||Coiled tubing inflatable packer with circulating port|
|US6352119||May 12, 2000||Mar 5, 2002||Schlumberger Technology Corp.||Completion valve assembly|
|US6698514||May 2, 2002||Mar 2, 2004||Varco I/P, Inc.||Remote operated coil connector apparatus|
|US7108071||Apr 30, 2002||Sep 19, 2006||Weatherford/Lamb, Inc.||Automatic tubing filler|
|US7281584 *||Jun 27, 2002||Oct 16, 2007||Smith International, Inc.||Multi-cycle downhill apparatus|
|US7533729||Nov 1, 2005||May 19, 2009||Halliburton Energy Services, Inc.||Reverse cementing float equipment|
|US7814839||Jan 4, 2008||Oct 19, 2010||OCS Intellitrak, Inc.||Inverted conveyor|
|US7866402 *||Oct 11, 2007||Jan 11, 2011||Halliburton Energy Services, Inc.||Circulation control valve and associated method|
|US7909095||Oct 7, 2008||Mar 22, 2011||Halliburton Energy Services, Inc.||Valve device and associated methods of selectively communicating between an interior and an exterior of a tubular string|
|US7926573||Sep 2, 2008||Apr 19, 2011||Halliburton Energy Services, Inc.||Circulation control valve and associated method|
|US7997208||Aug 30, 2008||Aug 16, 2011||OCS Intellitrak, Inc.||Angle line transfer for overhead conveyors|
|US8096363||Dec 9, 2010||Jan 17, 2012||Halliburton Energy Services, Inc.||Circulation control valve and associated method|
|US8579255 *||Oct 20, 2008||Nov 12, 2013||Baker Hughes Incorporated||Step ratchet mechanism|
|US20040154839 *||Jun 27, 2002||Aug 12, 2004||Mcgarian Bruce||Multi-cycle downhill apparatus|
|US20080210523 *||Jan 4, 2008||Sep 4, 2008||Owens Donald E||Inverted conveyor|
|US20090065217 *||Oct 20, 2008||Mar 12, 2009||Bj Services Company||Step ratchet mechanism|
|US20090095463 *||Sep 2, 2008||Apr 16, 2009||Halliburton Energy Services, Inc.||Circulation control valve and associated method|
|US20090095486 *||Oct 11, 2007||Apr 16, 2009||Williamson Jr Jimmie R||Circulation control valve and associated method|
|US20100050899 *||Aug 30, 2008||Mar 4, 2010||Tabler Charles P||Angle line transfer for overhead conveyors|
|US20100084130 *||Oct 7, 2008||Apr 8, 2010||Halliburton Energy Services, Inc.||Valve device and associated methods of selectively communicating between an interior and an exterior of a tubular string|
|US20110079393 *||Dec 9, 2010||Apr 7, 2011||Halliburton Energy Services, Inc.||Circulation control valve and associated method|
|DE2841724A1 *||Sep 25, 1978||May 3, 1979||Halliburton Co||Ventilgeraet zur verwendung in einer oelbohrung|
|DE3115467A1 *||Apr 16, 1981||Mar 4, 1982||Halliburton Co||Zirkulationsventil|
|EP0023113A1 *||Jul 10, 1980||Jan 28, 1981||Otis Engineering Corporation||Actuator for use in a tubing string to operate a foot valve|
|EP0068985A2 *||Jun 18, 1982||Jan 5, 1983||Schlumberger Technology Corporation||Annulus pressure controlled reversing valve|
|EP0068985A3 *||Jun 18, 1982||Sep 18, 1985||Schlumberger Technology Corporation||Annulus pressure controlled reversing valve|
|EP0158465A2 *||Mar 12, 1985||Oct 16, 1985||Halliburton Company||Multi-mode testing tool|
|EP0158465A3 *||Mar 12, 1985||Apr 19, 1989||Halliburton Company||Multi-mode testing tool|
|EP0511821A2 *||Apr 28, 1992||Nov 4, 1992||Halliburton Company||Well tool bypass apparatus|
|EP0511821A3 *||Apr 28, 1992||Mar 24, 1993||Halliburton Company||Well tool bypass apparatus|
|EP0513844A1 *||Mar 12, 1985||Nov 19, 1992||Halliburton Company||Operating assembly for a multi-mode testing tool|
|WO2002088514A1 *||Apr 30, 2002||Nov 7, 2002||Weatherford/Lamb, Inc.||Automatic tubing filler|
|U.S. Classification||166/374, 166/319|
|International Classification||E21B34/12, E21B34/10, E21B49/08, E21B34/00, E21B49/00|
|Cooperative Classification||E21B34/12, E21B34/108, E21B49/001, E21B49/087|
|European Classification||E21B49/08T, E21B49/00A, E21B34/12, E21B34/10T|