AU2011378455B2 - Downhole tester valve having rapid charging capabilities and method for use thereof - Google Patents
Downhole tester valve having rapid charging capabilities and method for use thereof Download PDFInfo
- Publication number
- AU2011378455B2 AU2011378455B2 AU2011378455A AU2011378455A AU2011378455B2 AU 2011378455 B2 AU2011378455 B2 AU 2011378455B2 AU 2011378455 A AU2011378455 A AU 2011378455A AU 2011378455 A AU2011378455 A AU 2011378455A AU 2011378455 B2 AU2011378455 B2 AU 2011378455B2
- Authority
- AU
- Australia
- Prior art keywords
- assembly
- fluid chamber
- valve
- fluid
- operating fluid
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Ceased
Links
- 238000000034 method Methods 0.000 title claims description 34
- 239000012530 fluid Substances 0.000 claims abstract description 324
- 230000009467 reduction Effects 0.000 claims description 5
- 238000012360 testing method Methods 0.000 description 24
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 16
- 238000004891 communication Methods 0.000 description 15
- 238000007667 floating Methods 0.000 description 15
- 230000015572 biosynthetic process Effects 0.000 description 8
- 229910052757 nitrogen Inorganic materials 0.000 description 8
- 239000007789 gas Substances 0.000 description 5
- 230000037361 pathway Effects 0.000 description 5
- 239000000654 additive Substances 0.000 description 2
- 230000000996 additive effect Effects 0.000 description 2
- 239000011261 inert gas Substances 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 230000003247 decreasing effect Effects 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000011946 reduction process Methods 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/008—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/081—Obtaining fluid samples or testing fluids, in boreholes or wells with down-hole means for trapping a fluid sample
- E21B49/0813—Sampling valve actuated by annulus pressure changes
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/04—Ball valves
Landscapes
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Analytical Chemistry (AREA)
- Testing Of Devices, Machine Parts, Or Other Structures Thereof (AREA)
- Check Valves (AREA)
Abstract
A downhole tester valve (100) includes a housing assembly (106) and a mandrel assembly (172, 174) that define therebetween an operating fluid chamber (176), a biasing fluid chamber (184) and a power fluid chamber (180). A valve assembly (126) disposed within the housing assembly (106) is operable between open and closed positions. A piston assembly (146) is operably associated with the valve assembly (126) such that annulus pressure entering the power fluid chamber (180) pressurizes operating fluid in the operating fluid chamber (176) which acts on the piston assembly (146) to shift the valve assembly (126) from the closed position to the open position and such that predetermined travel of the piston assembly (146) opens a bypass passageway (162) for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber (184), thereby enabling closure of the valve assembly (126) upon reducing annulus pressure by a predetermined amount.
Description
WO 2013/052050 PCT/US2011/055021 DOWNHOLE TESTER VALVE HAVING RAPID CHARGING CAPABILITIES AND METHOD FOR USE THEREOF 5 TECHNICAL FIELD OF THE INVENTION [0001] This invention relates, in general, to equipment utilized in conjunction with operations performed in subterranean wells and, in particular, to downhole tester valves operable for rapid charging of biasing fluid and methods for use thereof. 10 BACKGROUND OF THE INVENTION [0002] Without limiting the scope of the present invention, its background will be described with reference to downhole testing operations, as an example. [0003] Well testing and stimulation operations are commonly conducted on oil and gas wells 15 in order to determine production potential and to enhance the same, if possible. In flow testing a well, a testing string including a tester valve is typically lowered into the well on a string of drill pipe above a packer. After the packer is set, the tester valve is opened and closed periodically to determine formation flow, pressure and rapidity of pressure recovery. Commonly, the operation of such tester valves is responsive to pressure changes in the 20 annulus between the testing string and the wellbore casing. Many such tester valves also provide a biasing source, such as an inert gas like nitrogen, to aid in certain operations of the tester valve, including closure of the tester valve. [0004] In one such arrangement, annulus pressure is used to shift a ball valve assembly in the tester valve from the closed position to the open position. In addition, the annulus pressure is 25 used to charge the biasing source by, for example, compressing nitrogen in a chamber. When the annulus pressure is reduced, the compressed nitrogen is used to shift a ball valve assembly from the open position to the closed position. In this arrangement, a time delay feature, such as a fluid metering section, is used to allow the annulus pressure to first open the ball valve assembly and then charge the nitrogen. For example, it may be desirable to 30 increase the annulus pressure above a certain threshold within one or two minutes in order to open the ball valve assembly, thereafter it may be required that the annulus pressure be maintained at the elevated pressure for another ten or twenty minutes to fully charge the nitrogen.
-2 [00051 In certain circumstances, it may be desirable to close the tester valve shortly after opening the tester valve. It has been found, however, that during the period of time delay between opening the ball valve assembly and fully charging the nitrogen, closure of the tester valve is uncertain and in some cases not possible. A need has therefore 5 arisen for an improved tester valve that is operable for flow testing of a well. A need has also arisen for such an improved tester valve that operates responsive to annulus pressure. Further, a need has arisen for such an improved tester valve that does not have a time period during which closure of the tester valve is uncertain or impossible. 10 SUMMARY OF THE INVENTION [00061 The present invention disclosed herein is directed to a downhole tester valve that is operable to perform flow testing of a well. The downhole tester valve of the present invention is operated between the open position and the closed position responsive to annulus pressure. In addition, the downhole tester valve of the present 15 invention does not have a time period during which closure of the tester valve is uncertain or impossible. [0007] In one aspect, the present invention is directed to a downhole tester valve including: a housing assembly; a mandrel assembly disposed within the housing assembly defining therebetween an operating fluid chamber, a biasing fluid chamber and 20 a power fluid chamber; a valve assembly disposed within the housing assembly operable between open and closed positions; and a piston assembly operably associated with the valve assembly, the piston assembly having first and second sides, the piston assembly including a collet assembly and a snap sleeve having first and second positions relative to the collet assembly; wherein, an increase in annulus pressure entering the power fluid 25 chamber pressurizes operating fluid in the operating fluid chamber which acts on the first side of the piston assembly to shift the valve assembly from the closed position to the open position; wherein, predetermined travel of the piston assembly opens a bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber; and wherein, a reduction in annulus pressure reduces the operating fluid 30 pressure acting on the first side of the piston assembly such that the charged biasing fluid acting on the second side of the piston assembly shifts the valve assembly from the open position to the closed position; and wherein a first portion of the piston assembly is shiftable relative to a second portion of the piston assembly such that the collet assembly 25/06/15,dh-21390 - specipgs2-4 - cdn.docx,2 -3 releases the snap sleeve prior to the piston assembly shifting the valve assembly from the closed position to the open position. [0008] In one embodiment, the operating fluid is oil. In another embodiment, the power fluid is wellbore fluid. In a further embodiment, the biasing fluid is nitrogen. In 5 some embodiments, the piston assembly includes a collet assembly and a snap sleeve having first and second positions relative to the collet assembly. In this embodiment, a first portion of the piston assembly may be shiftable relative to a second portion of the piston assembly such that the collet assembly releases the snap sleeve prior to the piston assembly shifting the valve assembly from the closed position to the open position. In 10 certain embodiments, the piston assembly includes a check valve assembly having opposing check valves. In such embodiments, the check valves may be end of travel opposing check valves such that the travel of the piston within the downhole tester valve actuates one or more of the check valves. [0009] In another aspect, the present invention is directed to a method of operating 15 a downhole tester valve, said method including the steps of: positioning the downhole tester valve at a location in a wellbore, the downhole tester valve having an operating fluid chamber, a biasing fluid chamber and a power fluid chamber; applying increased annulus pressure to the power fluid chamber to pressurize operating fluid in the operating fluid chamber; applying the pressurized operating fluid on a first side of a 20 piston assembly of the downhole tester valve to shift a snap sleeve of the piston assembly from a first position to a second position relative to a collet assembly of the piston assembly and to shift a valve assembly of the downhole tester valve from a closed position to an open position; responsive to predetermined travel of the piston assembly, opening a bypass passageway for the pressurized operating fluid to charge biasing fluid 25 in the biasing fluid chamber; reducing the annulus pressure to reduce the operating fluid pressure acting on the first side of the piston assembly; and shifting the valve assembly from the open position to the closed position responsive to the charged biasing fluid acting on a second side of the piston assembly. [00101 In a further aspect, the present invention is directed to a method of operating 30 a downhole tester valve, said method including the steps of: positioning the downhole tester valve at a location in a wellbore, the downhole tester valve having an operating fluid chamber, a biasing fluid chamber and a power fluid chamber; applying increased annulus pressure to the power fluid chamber to pressurize operating fluid in the operating fluid chamber; applying the pressurized operating fluid on a piston assembly 25/06/15,dh-21390 - specipgs2-4 - cdin.docx,3 -4 of the downhole tester valve to shift a valve assembly of the downhole tester valve from a closed position to an open position; responsive to predetermined travel of the piston assembly, opening a bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber; and reducing annulus pressure at a 5 predetermined rate to retain the valve assembly in the open position without the continued application of the increased annulus pressure; wherein reducing annulus pressure at the predetermined rate further includes reducing annulus pressure in stages. [00111 In an additional aspect, the present invention is directed to a method of operating a downhole tester valve, said method including the steps of: positioning the 10 downhole tester valve at a location in a wellbore, the downhole tester valve having an operating fluid chamber, a biasing fluid chamber and a power fluid chamber; increasing annulus pressure to a level below a predetermined level; applying the increased annulus pressure to the power fluid chamber to pressurize operating fluid in the operating fluid chamber; applying the pressurized operating fluid on a piston assembly of the downhole 15 tester valve to shift a valve assembly of the downhole tester valve from a closed position to an open position; responsive to predetermined travel of the piston assembly, opening a bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber; and increasing annulus pressure above the predetermined level to disable further operation of the valve assembly; wherein increasing annulus pressure 20 above the predetermined level further includes increasing annulus pressure above a burst pressure of a rupture disk. [0011A] The invention may also provide a method of operating a downhole tester valve, said method including the steps of: positioning the downhole tester valve at a location in a wellbore, the downhole tester valve having an operating fluid chamber, a 25 biasing fluid chamber and a power fluid chamber; applying increased annulus pressure to the power fluid chamber to pressurize operating fluid in the operating fluid chamber; preventing application of the pressurized operating fluid on a piston assembly until annulus pressure is increased above a predetermined level; increasing annulus pressure above a burst pressure of a rupture disk; applying the pressurized operating fluid on a 30 first side of the piston assembly of the downhole tester valve to shift a valve assembly of the downhole tester valve from a closed position to an open position; responsive to predetermined travel of the piston assembly, opening a bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber; reducing the annulus pressure to reduce the operating fluid pressure acting on the first side of the 25/06/15,dh-21390 - specipgs2-4 - cdm.docx,4 - 4a piston assembly; and shifting the valve assembly from the open position to the closed position responsive to the charged biasing fluid acting on a second side of the piston assembly. [0011B] In another aspect there is provided a method of operating a downhole tester 5 valve, said method including the steps of: positioning the downhole tester valve at a location in a wellbore, the downhole tester valve having an operating fluid chamber, a biasing fluid chamber and a power fluid chamber; increasing annulus pressure to a level below a predetermined level; applying the increased annulus pressure to the power fluid chamber to pressurize operating fluid in the operating fluid chamber; applying the 10 pressurized operating fluid on a piston assembly of the downhole tester valve to shift a valve assembly of the downhole tester valve from a closed position to an open position; responsive to predetermined travel of the piston assembly, opening a bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber; reducing annulus pressure; applying operating fluid pressurized by the charged biasing 15 fluid on the piston assembly to shift the valve assembly from the open position to the closed position; and increasing annulus pressure above the predetermined level to disable further operation of the valve assembly. BRIEF DESCRIPTION OF THE DRAWINGS 20 [00121 For a more complete understanding of the features and advantages of the present invention, reference is now made to the detailed description of the invention along with the accompanying figures in which corresponding numerals in the different figures refer to corresponding parts and in which: [0013] Figure 1 is a schematic illustration of an offshore oil and gas platform 25 operating a downhole tester valve according to an embodiment of the present invention; [00141 Figures 2A-G are quarter sectional views of a downhole tester valve according to an embodiment of the present invention; and [00151 Figures 3A-F are cross sectional views at various locations along a downhole tester valve according to an embodiment of the present invention. 30 25/06/15,dh-21390 - specipgs2-4 - cdm.docx,4 WO 2013/052050 PCT/US2011/055021 DETAILED DESCRIPTION OF THE INVENTION [0016] While the making and using of various embodiments of the present invention are discussed in detail below, it should be appreciated that the present invention provides many applicable inventive concepts, which can be embodied in a wide variety of specific contexts. 5 The specific embodiments discussed herein are merely illustrative of specific ways to make and use the invention, and do not delimit the scope of the invention. [00171 Referring to figure 1, a downhole tester valve is being deployed from an offshore oil and gas platform that is schematically illustrated and generally designated 10. A semi-submersible platform 12 is centered over a submerged oil and gas formation 14 located 10 below sea floor 16. A subsea conduit 18 extends from deck 20 of platform 12 to wellhead installation 22, including blowout preventers 24. Platform 12 has a hoisting apparatus 26 and a derrick 28 for raising and lowering pipe strings such as drill string 30. A wellbore 32 has been drilled through the various earth strata including formation 14. Wellbore 32 has a casing string 34 installed therein. 15 [0018] In the illustrated embodiment, a testing string 36 is shown disposed in wellbore 32, with blowout preventer 24 closed thereabout. Testing string 36 includes upper drill pipe string 30 which extends downward from platform 12 to wellhead 22. A hydraulically operated test tree 38 is positioned between upper drill pipe string 30 and intermediate pipe string 40. A slip joint 42 may be included in string 40 for enabling proper 20 positioning of downhole equipment and to compensate for tubing length changes due to pressure and temperature changes. Below slip joint 42, intermediate string 40 extends downwardly to a downhole tester valve 44 of the present invention. Therebelow is a lower pipe string 46 that extends to tubing seal assembly 48, which stabs into packer 50. When set, packer 50 isolates a wellbore annulus 52 from the lower portion of wellbore 54. Packer 50 25 may be any suitable packer well known to those skilled in the art. Tubing seal assembly 48 permits testing string 36 to communicate with lower wellbore 54 through a perforated tailpipe 56. In this manner, formation fluids from potential producing formation 14 may enter lower wellbore 54 through perforations 58 in casing 34 and be routed into testing string 36. [0019] After packer 50 is set in wellbore 32, a formation test controlling the flow of 30 fluid from potential producing formation 14 through testing string 36 may be conducted using variations in pressure affected in upper annulus 52 by pump 60 and control conduit 62, with associated relief valves (not shown). Formation pressure, temperature and recovery time may be measured during the flow test through the use of instruments incorporated in testing string 5 WO 2013/052050 PCT/US2011/055021 36, as downhole tester valve 44 is opened and closed in accordance with the present invention. [0020] Even though figure 1 depicts the present invention in a vertical wellbore, it should be understood by those skilled in the art that the present invention is equally well 5 suited for use in wellbores having other directional configurations including horizontal wellbores, deviated wellbores, slanted wells, lateral wells and the like. Accordingly, it should be understood by those skilled in the art that the use of directional terms such as above, below, upper, lower, upward, downward, uphole, downhole and the like are used in relation to the illustrative embodiments as they are depicted in the figures, the upward direction being 10 toward the top of the corresponding figure and the downward direction being toward the bottom of the corresponding figure, the uphole direction being toward the surface of the well and the downhole direction being toward the toe of the well. [0021] Referring now to figures 2A-G, therein is depicted an exemplary embodiment of a downhole tester valve 100 in accordance with an embodiment of the present invention. 15 Downhole tester valve 100 includes an upper adaptor 102 having threads 104 at its upper end, whereby downhole tester valve 100 may be secured to drill pipe or other components within the testing string. Downhole tester valve 100 has a housing assembly 106 that is secured to upper adaptor 102 at its upper end. Housing assembly 106 is formed from a plurality of housing members that are threadedly, sealing, weldably or otherwise secured together. 20 Housing assembly 106 includes upper housing member 108, an upper housing connector 110, an upper intermediate housing member 112, an intermediate housing connector 114, a lower intermediate housing member 116, a lower housing connector 118 and a lower housing member 120. At its lower end, lower housing member 120 is secured to a lower adaptor 122 having threads 124 at its lower end, whereby downhole tester valve 100 may be secured to 25 drill pipe or other components within the testing string. Even though a particular arrangement of tubulars has been described and depicted as forming housing assembly 106, it is understood by those skilled in the art that other arrangements of tubular components and the like could alternatively be used to form a housing assembly without departing from the principles of the present invention. 30 [0022] Generally positioned within upper housing member 108 is a valve assembly 126. Valve assembly 126 includes an upper cage support 128, a ball cage 130, an upper annular seat 132 that is downwardly biased by one or more springs 134, a pair of operating pins 136 (only one being visible in figure 2B), a rotating ball member 138, a lower annular seat 140 and a lower cage support 142. Together, the components of valve assembly 126 6 WO 2013/052050 PCT/US2011/055021 cooperate to open and close the central pathway 144 of downhole tester valve 100 to selectively allow and prevent fluid flow therethrough. [0023] Generally positioned within upper intermediate housing member 112 is a piston assembly 146. Piston assembly 146 includes a valve operating member 148 that is 5 coupled at its upper end (see figure 2B) to operating pins 136 of valve assembly 126. Piston assembly 146 also includes a check valve assembly 150, a snap sleeve 152, a split ring 154 and a collet assembly 156 that is securably coupled at its lower end to intermediate housing connector 114. In the illustrated embodiment, check valve assembly 150 is slidably and sealingly positioned between valve operating member 148 and upper intermediate housing 10 member 112. Check valve assembly 150 includes a pair of oppositely disposed check valves 158, 160, having a fluid passageway 162 therebetween that may be referred to as a bypass passageway. Check valves 158, 160 each has a stem that is extendable outwardly from check valve assembly 150, the operation and purpose of the stems are discussed in greater detail below. In the illustrated embodiment, split ring 154 is received in a radially reduced section 15 of valve operating member 148. A gap exists between split ring 154 and the lower surface of check valve assembly 150 and likewise, gap exists between split ring 154 and an upper shoulder of a snap sleeve 152, the operation and purpose of the gaps are discussed in greater detail below. Collet assembly 156 includes a plurality of collet fingers 164, only one being visible in the figure 2D. Each collet finger 164 has a detent 166. Snap sleeve 152 includes a 20 pair of annular grooves 168, 170 that are designed to selectively and releasably cooperate with detents 166 of collet fingers 164. [0024] Generally positioned within lower intermediate housing member 116 is an upper mandrel 172. In the illustrated embodiment, upper mandrel 172 is threadedly and sealably coupled to intermediate housing connector 114 at its upper end and sealably coupled 25 to lower housing connector 118 at its lower end. Generally positioned within lower housing member 120 is a lower mandrel 174. In the illustrated embodiment, lower mandrel 174 is sealably coupled to lower housing connector 118 at its upper end and threadedly and sealably coupled to lower adaptor 122 at its lower end. Together, upper mandrel 172 and lower mandrel 174 may be referred to herein as a mandrel assembly. Even though a particular 30 arrangement of tubulars has been described and depicted as forming the mandrel assembly, it is understood by those skilled in the art that other arrangements of tubular components and the like could alternatively be used to form a mandrel assembly without departing from the principles of the present invention. 7 WO 2013/052050 PCT/US2011/055021 [00251 Together, lower intermediate housing member 116 and upper mandrel 172 define a generally annular operating fluid chamber 176, which extends between a lower surface of intermediate housing connector 114 and an upper surface of a floating piston 178 that is disposed between lower intermediate housing member 116 and upper mandrel 172. 5 Preferably, operating fluid chamber 176 contains an operating fluid in the form of a substantially incompressible fluid such as an oil including hydraulic fluid. Lower intermediate housing member 116 and upper mandrel 172 also define a generally annular power fluid chamber 180, which extends between a lower surface of floating piston 178 and an upper surface of lower housing connector 118. Power fluid chamber 180 is aligned with 10 one or more housing ports 182 that extend through lower intermediate housing member 116 to provide fluid communication with annulus fluid pressure. In the illustrated embodiment, a housing port 182 is depicted in dashed lines as it is not actually located in the illustrated cross section but instead is circumferentially offset from the illustrated view. Together, lower housing member 120 and lower mandrel 174 define a generally annular biasing fluid chamber 15 184, which extends between a lower surface of floating piston 186 that is disposed between lower housing member 120 and lower mandrel 174 and an upper surface of lower adaptor 122. Preferably, biasing fluid chamber 184 contains a biasing fluid in the form of a compressible fluid such as a gas and more preferably, biasing fluid chamber 184 contains an inert gas such as nitrogen. 20 [0026] Downhole tester valve 100 includes an operating fluid communication network. In the present invention, operating fluid is used not only to actuate the valve assembly between open and closed positions but also for rapid charging of the biasing fluid after shifting the valve assembly from the closed position to the open position. The operating fluid communication network includes a plurality of fluid passageways that are formed in 25 various section of housing assembly 106. In the illustrated embodiment, operating fluid used to downwardly shift piston assembly 146 and open valve assembly 126 has a communication path from operating fluid chamber 176 through fluid passageway 188 in intermediate housing connector 114 and fluid passageway 190 in upper intermediate housing member 112. The operating fluid is then operable to act on an upper surface of check valve assembly 150 of 30 piston assembly 146. [00271 As explained in greater detail below, after the operating fluid has downwardly shifted piston assembly 146 causing valve assembly 126 to open, the operating fluid has a communication path through fluid passageway 162 in check valve assembly 150, through the annular region between upper intermediate housing member 112 and valve operating member WO 2013/052050 PCT/US2011/055021 148, through fluid passageway 192 in intermediate housing connector 114 (a portion of which is depicted in dashed lines in figures 2D and 2E, and as best seen in figure 3A), through fluid passageway 194 in lower intermediate housing member 116 (a portion of which is depicted in dashed lines in figures 2E and 2F, and as best seen in figure 3B) and through fluid 5 passageway 196 in lower housing connector 118 (a portion of which is depicted in dashed lines in figure 2F, and as best seen in figure 3C). The operating fluid is then operable to act on an upper surface of floating piston 186. [0028] As explained in greater detail below, after the operating fluid has charged the biasing fluid and annulus pressure is reduced, the operating fluid has a communication path 10 through fluid passageway 196 in lower housing connector 118 (a portion of which is depicted in dashed lines in figure 2F, and as best seen in figure 3C), through fluid passageway 194 in lower intermediate housing member 116 (a portion of which is depicted in dashed lines in figures 2F and 2E, and as best seen in figure 3B), through fluid passageway 192 in intermediate housing connector 114 (a portion of which is depicted in dashed lines in figures 15 2E and 2D, and as best seen in figure 3A) and through the annular region between upper intermediate housing member 112 and valve operating member 148. The operating fluid is then operable to act on a lower surface of check valve assembly 150. [0029] In addition, the operating fluid communication network of downhole tester valve 100 includes a metered fluid pathway between operating fluid chamber 176 and the 20 upper side of floating piston 186, the purpose and operation of which is discussed in greater detail below. In the illustrated embodiment, a fluid pathway 198 in intermediate housing connector 114 includes a metering section 200 having a fluid resistance assembly such as an orifice disposed therein to limit the rate at which operating fluid can pass therethrough. Fluid pathway 198 is in fluid communication with fluid pathway 202 in lower intermediate housing 25 member 116 (as best seen in figures 2E, 2F and 3B) which is in fluid communication with fluid passageway 204 in lower housing connector 118 (as best seen in figures 2F, 2G and 3C). The operating fluid is then operable to act on an upper surface of floating piston 186. [0030] The operation of downhole tester valve 100 will now be described. In one operating mode, downhole tester valve 100 is run downhole on a testing string in the closed 30 position as depicted in figures 2A-2G. A packer positioned downhole of downhole tester valve 100 on the testing string may be set which creates a sealed annulus between the casing string and the testing string above the packer as seen in figure 1. Depending upon the tests to be performed, it may be desirable to open and close downhole tester valve 100 numerous times. During run in and prior to operation, the pressure in operating fluid chamber 176 and 9) WO 2013/052050 PCT/US2011/055021 biasing fluid chamber 184 are generally equalized to wellbore or annulus pressure due to fluid communication through port 182 acting on floating piston 178 and fluid passing through metering section 200 of downhole tester valve 100 acting on floating piston 186. [0031] To open downhole tester valve 100, annulus pressure is increased to a 5 predetermined level. The annulus pressure enters downhole tester valve 100 via port 182 and acts on floating piston 178. Pressure is increased in operation fluid chamber 178 which forces operating fluid into fluid passageways 188 and 198. Fluid travel is resisted through fluid passageway 198 by metering section 200. The fluid in passageway 188 is communicated to fluid passageway 190 which in turn is communicated to an upper surface of 10 check valve assembly 150 of piston assembly 146. In this configuration, check valve 158 allows downward flow therethrough but, downward flow is prevented by check valve 160. The fluid pressure generates a downward force on check valve assembly 150 which is transmitted through piston assembly 146 to annular groove 170 of snap sleeve 152 and detents 166 of collet fingers 164. When the downward force of annular groove 170 is 15 sufficient to cause radial outward expansion of collet fingers 164, snap sleeve 152 begins to translate downwardly relative to collet assembly 156. The lower surface of check valve assembly 150 then closes the gap and moves into contact with the upper surface of split ring 154 which causes valve operating member 148 to begin downward travel. It is noted that having the gap between the lower surface of check valve assembly 150 and the upper surface 20 of split ring 154 ensures that the force required to overcome the spring force of collet assembly 156 and the force required to rotate ball member 138 are not additive of one another, instead, the spring force of collet assembly 156 is overcome prior to operation of ball member 138. The fluid pressure acting on check valve assembly 150 now moves all the components of piston assembly 146, with the exception of collet assembly 156, downwardly. 25 The downward movement of valve operating member 148 also caused downward movement of operating pins 136 which rotates ball member 138 to the open position. [0032] When ball member 138 is fully open, a lower surface of operating pins 136 may contact an upper surface of lower cage support 142. In addition, a stem mechanism of check valve 160 comes in contact with an upper surface of collet assembly 156 which opens 30 check valve 160 as piston assembly 146 nears its end of travel. When check valve 160 opens, a bypass passageway is established allowing operating fluid to pass from fluid passageway 162 into the annular region between upper intermediate housing member 112 and valve operating member 148 and communicate fluid pressure through fluid passageway 192, fluid passageway 194 and fluid passageway 196. The operating fluid is then operable to act on an 10 WO 2013/052050 PCT/US2011/055021 upper surface of floating piston 186 which compresses or charges the biasing fluid in biasing fluid chamber 184. As such, the present invention enables rapid charging of the biasing fluid as soon as the valve assembly is operated from the closed position to the open position. This rapid charging enables immediate closure of the valve assembly using the rapidly charged 5 biasing fluid. [0033] For example, when it is desired to return downhole tester valve 100 to the closed position, annulus pressure is decreased to a predetermined level which reduces the pressure in operating fluid chamber 176, fluid passageway 188, fluid passageway 190 and on the top side of check valve assembly 150. Fluid does not travel upwardly through check 10 valve assembly 150, however, as check valve 158 prevents such upward flow. The charged biasing fluid in biasing fluid chamber 184 now acts as the energy source for operating valve assembly 126. The biasing fluid acts on the lower surface of floating piston 186 which pressurizes the operating fluid above floating piston 186 in fluid passageway 196, fluid passageway 194, fluid passageway 192 and the annular region between upper intermediate 15 housing member 112. The pressurized operating fluid acts on the lower surfaces of check valve assembly 150 of piston assembly 146. The fluid pressure generates an upward force on check valve assembly 150 which is transmitted through piston assembly 146 to annular groove 168 of snap sleeve 152 and detents 166 of collet fingers 164. When the upward force of annular groove 168 is sufficient to cause radial outward expansion of collet fingers 164, 20 snap sleeve 152 begins to translate upwardly relative to collet assembly 156. An upper surface of snap sleeve 152 then closes the gap and moves into contact with the lower surface of split ring 154 which causes valve operating member 148 to begin upward travel. The gap between the upper surface of snap sleeve 152 and the lower surface of split ring 154 ensures that the force required to overcome the spring force of collet assembly 156 and the force 25 required to rotate ball member 138 are not additive of one another, instead, the spring force of collet assembly 156 is overcome prior to operation of ball member 138. The fluid pressure acting on check valve assembly 150 now moves all the components of piston assembly 146, with the exception of collet assembly 156, upwardly. The upward movement of valve operating member 148 also caused upward movement of operating pins 136 which rotates 30 ball member 138 to the closed position. [0034] When ball member 138 is fully closed, an upper surface of operating pins 136 may contact a lower surface of ball cage 130. In addition, a stem mechanism of check valve 158 comes in contact with a lower surface of upper housing connector 110 which opens check valve 158 as piston assembly 146 nears its end of travel. When check valve 158 opens, 11 WO 2013/052050 PCT/US2011/055021 operating fluid is allowed to pass from fluid passageway 162 into fluid passageway 190 and fluid passageway 188 to return to operating fluid chamber 176, which substantially equalizes pressure in power fluid chamber 180, operating fluid chamber 176 and biasing fluid chamber 184. This returns downhole tester valve 100 to its running configuration, in which it is ready 5 to be operated to its open position with an increase in annulus pressure. [00351 In another operating mode, it may be desirable to maintain downhole tester valve 100 in the open position without keeping annulus pressure at the elevated level. In this case, once valve assembly 126 has been shifted from the closed position to the open position and the operating fluid has rapidly charged the biasing fluid as described above, annulus 10 pressure is stepped down to a desired annulus pressure slowly or in increments. For example, instead of lowering annulus pressure from the predetermined elevated pressure to its original pressure in a rapid one step process, the annulus pressure can be lower at a predetermined rate such as in a plurality of stages, wherein the annulus pressure is lower incrementally in each stage. In this scenario, as the annulus pressure is reduced, there is a reduction in the 15 pressure in operating fluid chamber 176, fluid passageway 188, fluid passageway 190 and on the top side of check valve assembly 150. Fluid does not travel upwardly through check valve assembly 150, however, as check valve 158 prevents such upward flow. The charged biasing fluid in biasing fluid chamber 184 acts on the lower surface of floating piston 186 which pressurizes the operating fluid above floating piston 186 in fluid passageway 196, fluid 20 passageway 194, fluid passageway 192 and the annular region between upper intermediate housing member 112 and valve operating member 148. The pressurized operating fluid acts on the lower surfaces of check valve assembly 150 of piston assembly 146. The fluid pressure generates an upward force on check valve assembly 150 which is transmitted through piston assembly 146 to annular groove 168 of snap sleeve 152 and detents 166 of 25 collet fingers 164. [0036] In this case, however, the upward force of annular groove 168 is insufficient to cause radial outward expansion of collet fingers 164 and snap sleeve 152 does not translate upwardly relative to collet assembly 156. The pressure differential between biasing fluid chamber 184 and operating fluid chamber 176 is equalized over time due to the operation of 30 metering section 200, which allows fluid flow therethrough at a predetermined rate. After a time delay period, for example 10 or 20 minutes, when substantial equalization has occurred, the next stage of the annulus pressure reduction may occur. At the end of the rate controlled annulus pressure reduction, downhole tester valve 100 remains in the open position without keeping annulus pressure at the elevated level. It is noted that at any time during the staged I1? WO 2013/052050 PCT/US2011/055021 annulus pressure reduction process or thereafter, if it is desired to close downhole tester valve 100, annulus pressure is simply increased to a sufficient level to charge the biasing fluid in biasing fluid chamber 184 in the manner discussed above, wherein annulus pressure is used to pressurize the operation fluid in operation fluid chamber 176 which is communicated 5 through the operating fluid network via fluid passageways 188, 190 and 162, the annular region between upper intermediate housing member 112 and valve operating member 148, and fluid passageways 192, 194 and 196 to the top side of floating piston 186. The annulus pressure is then reduced such that the charged biasing fluid in biasing fluid chamber 184 acts as the energy source for operating valve assembly 126 to the closed position as described 10 above. [00371 In additional operating mode, it may be desirable to run downhole tester valve 100 into the well in the open position. In this case, pressure is applied to port 182 at the surface to pressurize operating fluid in operating fluid chamber 176 as described above, in such a manner as to shift piston assembly 146 downwardly, which opens valve assembly 126 15 and actuates check valve 160 to enable rapid charging of biasing fluid in biasing fluid chamber 184. Thereafter, communication can be established between fluid passageway 192 and fluid passageway 188 via a bypass fluid passageway 206 in intermediate housing connector 114, as best seen in figure 3D. This can be accomplished by partially retracting plugs 208, 210 to allow fluid communication thereby. This allows for equalization of the 20 pressure in operating fluid chamber 176 and biasing fluid chamber 184. The pressure to port 182 may be released after communication is allowed between fluid passageway 192 and fluid passageway 188 via bypass fluid passageway 206. Thereafter, plugs 208, 210 are repositioned to isolate fluid passageway 192 from fluid passageway 188 and downhole tester valve 100 may be run into the well in the open position. When it is desired to close downhole 25 tester valve 100, annulus pressure is applied, as described above, to charge the biasing fluid in biasing fluid chamber 184 then annulus pressure is reduced such that the charged biasing fluid in biasing fluid chamber 184 acts as the energy source for operating valve assembly 126 to the closed position. [0038] In a further operating mode, it may be desirable to prevent operation of 30 downhole tester valve 100 during certain annulus pressure variations. For example, if other annulus pressure operated tools are going to be actuated prior to operation of downhole tester valve 100, a rupture disk 210 (as seen in figure 3E) may be positioned in fluid passageway 188 to prevent the communication of pressure from operation fluid chamber 176 to piston assembly 146. Other pressure operated tools may then be operated, so long as the annulus 13 WO 2013/052050 PCT/US2011/055021 pressure remains below the burst pressure of rupture disk 210. When it is desired to operate downhole tester valve 100, annulus pressure can be increased above the burst pressure of rupture disk 210. Thereafter, downhole tester valve 100 will operate as described above. [0039] In yet another operating mode, it may be desirable to disable operation of 5 downhole tester valve 100. For example, once the tests performed with downhole tester valve 100 have been completed, it may be desired to permanently leave downhole tester valve in the open or closed position. In either case, as best seen in figure 3F, a rupture disk 212 and a shuttle valve 214 may be installed in a bypass passageway 216 between fluid passageway 192 and fluid passageway 188. In the illustrated embodiment, pressure from 10 fluid passageway 188, which is in communication with operating fluid chamber 176 and therefore the annulus pressure, is routed to one side of rupture disk 212. The other side of rupture disk 212 defines an air chamber at low pressure. In this case, once testing operations have been completed, increasing the annulus pressure above the burst pressure of rupture disk 212 will burst rupture disk 212 causing shuttle valve 214 to shift and open bypass 15 passageway 216 between fluid passageway 192 and fluid passageway 188. In this configuration, downhole tester valve 100 is disabled as operating fluid chamber 176 and biasing fluid chamber 184 are permanently equalized as pressure is routed around metering assembly 200. It is noted that in order to disable downhole tester valve 100 in the closed position, annulus pressure must be raised at a predetermined rate such as a slow rate or 20 incrementally as described above to enable the pressure differential between biasing fluid chamber 184 and operating fluid chamber 176 is equalized over time due to the operation of metering section 200, which allows fluid flow therethrough at a predetermined rate. In this manner, the annulus pressure can be raised above the burst pressure of rupture disk 212 without operating downhole tester valve 100 from the closed position to the open position. 25 [0040] While this invention has been described with reference to illustrative embodiments, this description is not intended to be construed in a limiting sense. Various modifications and combinations of the illustrative embodiments as well as other embodiments of the invention will be apparent to persons skilled in the art upon reference to the description. It is, therefore, intended that the appended claims encompass any such modifications or embodiments. 30 14
Claims (18)
1. A downhole tester valve including: a housing assembly; 5 a mandrel assembly disposed within the housing assembly defining therebetween an operating fluid chamber, a biasing fluid chamber and a power fluid chamber; a valve assembly disposed within the housing assembly operable between open and closed positions; and 10 a piston assembly operably associated with the valve assembly, the piston assembly having first and second sides, the piston assembly including a collet assembly and a snap sleeve having first and second positions relative to the collet assembly; wherein, an increase in annulus pressure entering the power fluid chamber 15 pressurizes operating fluid in the operating fluid chamber which acts on the first side of the piston assembly to shift the valve assembly from the closed position to the open position; wherein, predetermined travel of the piston assembly opens a bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing 20 fluid chamber; and wherein, a reduction in annulus pressure reduces the operating fluid pressure acting on the first side of the piston assembly such that the charged biasing fluid acting on the second side of the piston assembly shifts the valve assembly from the open position to the closed position; and 25 wherein a first portion of the piston assembly is shiftable relative to a second portion of the piston assembly such that the collet assembly releases the snap sleeve prior to the piston assembly shifting the valve assembly from the closed position to the open position. 30
2. The downhole tester valve as recited in claim 1 wherein the piston assembly further includes a check valve assembly having opposing check valves. 25/06/15,dh-21390 - claims - cdm.docx,15 - 16
3. The downhole tester valve as recited in claim 2 wherein the check valve assembly further includes end of travel opposing check valves.
4. A method of operating a downhole tester valve, said method including the 5 steps of: positioning the downhole tester valve at a location in a wellbore, the downhole tester valve having an operating fluid chamber, a biasing fluid chamber and a power fluid chamber; applying increased annulus pressure to the power fluid chamber to 10 pressurize operating fluid in the operating fluid chamber; applying the pressurized operating fluid on a first side of a piston assembly of the downhole tester valve to shift a snap sleeve of the piston assembly from a first position to a second position relative to a collet assembly of the piston assembly and to shift a valve assembly of the downhole tester valve from a closed position to an 15 open position; responsive to predetermined travel of the piston assembly, opening a bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber; reducing the annulus pressure to reduce the operating fluid pressure acting 20 on the first side of the piston assembly; and shifting the valve assembly from the open position to the closed position responsive to the charged biasing fluid acting on a second side of the piston assembly. 25
5. The method as recited in claim 4 wherein opening the bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber further includes actuating at least one check valve in a check valve assembly. 30
6. The method as recited in claim 5 wherein actuating the at least one check valve in the check valve assembly further includes actuating the at least one check valve responsive to travel of the piston assembly. 25/06/15,dh-21390 - claims - cdm.docx,16 - 17
7. The method as recited in claim 4 wherein opening the bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber further includes opening a bypass passageway through the piston assembly. 5
8. The method as recited in claim 4 further including preventing application of the pressurized operating fluid on the piston assembly until annulus pressure is increased above a predetermined level. 10
9. The method as recited in claim 8 wherein increasing annulus pressure above the predetermined level further includes increasing annulus pressure above a burst pressure of a rupture disk.
10. A method of operating a downhole tester valve, said method including the 15 steps of: positioning the downhole tester valve at a location in a wellbore, the downhole tester valve having an operating fluid chamber, a biasing fluid chamber and a power fluid chamber; applying increased annulus pressure to the power fluid chamber to 20 pressurize operating fluid in the operating fluid chamber; applying the pressurized operating fluid on a piston assembly of the downhole tester valve to shift a valve assembly of the downhole tester valve from a closed position to an open position; responsive to predetermined travel of the piston assembly, opening a bypass 25 passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber; and reducing annulus pressure at a predetermined rate to retain the valve assembly in the open position without the continued application of the increased annulus pressure; 30 wherein reducing annulus pressure at the predetermined rate further includes reducing annulus pressure in stages. 25/06/15,dh-21390 - claims - cdm.docx,17 - 18
11. The method as recited in claim 10 wherein reducing annulus pressure at the predetermined rate further includes substantially equalizing pressure in the biasing fluid chamber and the operating fluid chamber by passing operating fluid through a metering section of the downhole tester valve. 5
12. A method of operating a downhole tester valve, said method including the steps of: positioning the downhole tester valve at a location in a wellbore, the downhole tester valve having an operating fluid chamber, a biasing fluid chamber 10 and a power fluid chamber; increasing annulus pressure to a level below a predetermined level; applying the increased annulus pressure to the power fluid chamber to pressurize operating fluid in the operating fluid chamber; applying the pressurized operating fluid on a piston assembly of the 15 downhole tester valve to shift a valve assembly of the downhole tester valve from a closed position to an open position; responsive to predetermined travel of the piston assembly, opening a bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber; and 20 increasing annulus pressure above the predetermined level to disable further operation of the valve assembly; wherein increasing annulus pressure above the predetermined level further includes increasing annulus pressure above a burst pressure of a rupture disk. 25
13. The method as recited in claim 12 further including reducing annulus pressure and applying operating fluid pressurized by the charged biasing fluid on the piston assembly to shift the valve assembly from the open position to the closed position prior to increasing annulus pressure above the predetermined level. 30
14. The method as recited in claim 13 further including increasing annulus pressure above the predetermined level at a predetermined rate. 25/06/15,dh-21390 - claims - edn.docx,18 - 19
15. The method as recited in claim 14 wherein increasing annulus pressure above the predetermined level at the predetermined rate further includes increasing annulus pressure in stages. 5
16. The method as recited in claim 13 wherein increasing annulus pressure above the predetermined level at the predetermined rate further includes substantially equalizing pressure in the biasing fluid chamber and the operating fluid chamber by passing operating fluid through a metering section of the downhole tester valve. 10
17. A method of operating a downhole tester valve, said method including the steps of: positioning the downhole tester valve at a location in a wellbore, the downhole tester valve having an operating fluid chamber, a biasing fluid chamber and a power fluid chamber; 15 applying increased annulus pressure to the power fluid chamber to pressurize operating fluid in the operating fluid chamber; preventing application of the pressurized operating fluid on a piston assembly until annulus pressure is increased above a predetermined level; increasing annulus pressure above a burst pressure of a rupture disk; 20 applying the pressurized operating fluid on a first side of the piston assembly of the downhole tester valve to shift a valve assembly of the downhole tester valve from a closed position to an open position; responsive to predetermined travel of the piston assembly, opening a bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing 25 fluid chamber; reducing the annulus pressure to reduce the operating fluid pressure acting on the first side of the piston assembly; and shifting the valve assembly from the open position to the closed position responsive to the charged biasing fluid acting on a second side of the piston 30 assembly. 25/06/15,dh-21390 - claims - cdm.docx,19 - 20
18. A method of operating a downhole tester valve, said method including the steps of: positioning the downhole tester valve at a location in a wellbore, the downhole tester valve having an operating fluid chamber, a biasing fluid chamber 5 and a power fluid chamber; increasing annulus pressure to a level below a predetermined level; applying the increased annulus pressure to the power fluid chamber to pressurize operating fluid in the operating fluid chamber; applying the pressurized operating fluid on a piston assembly of the 10 downhole tester valve to shift a valve assembly of the downhole tester valve from a closed position to an open position; responsive to predetermined travel of the piston assembly, opening a bypass passageway for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber; 15 reducing annulus pressure; applying operating fluid pressurized by the charged biasing fluid on the piston assembly to shift the valve assembly from the open position to the closed position; and increasing annulus pressure above the predetermined level to disable further 20 operation of the valve assembly. 25/06/15,dh-21390 - claims - edm.docx,20
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| AU2015252060A AU2015252060B2 (en) | 2011-10-06 | 2015-11-04 | Downhole tester valve having rapid charging capabilities and method for use thereof |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| PCT/US2011/055021 WO2013052050A1 (en) | 2011-10-06 | 2011-10-06 | Downhole tester valve having rapid charging capabilities and method for use thereof |
Related Child Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| AU2015252060A Division AU2015252060B2 (en) | 2011-10-06 | 2015-11-04 | Downhole tester valve having rapid charging capabilities and method for use thereof |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| AU2011378455A1 AU2011378455A1 (en) | 2014-04-24 |
| AU2011378455B2 true AU2011378455B2 (en) | 2015-08-06 |
Family
ID=48044028
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| AU2011378455A Ceased AU2011378455B2 (en) | 2011-10-06 | 2011-10-06 | Downhole tester valve having rapid charging capabilities and method for use thereof |
Country Status (5)
| Country | Link |
|---|---|
| US (1) | US8701778B2 (en) |
| EP (1) | EP2748418B1 (en) |
| AU (1) | AU2011378455B2 (en) |
| BR (1) | BR112014008147A2 (en) |
| WO (1) | WO2013052050A1 (en) |
Families Citing this family (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US9359864B2 (en) | 2013-11-06 | 2016-06-07 | Team Oil Tools, Lp | Method and apparatus for actuating a downhole tool |
| WO2015117221A1 (en) * | 2014-02-04 | 2015-08-13 | Rapid Design Group Inc. | Pressure activated completion tools and methods of use |
| CA3045006A1 (en) * | 2017-02-10 | 2018-08-16 | Halliburton Energy Services, Inc. | Hydrostatic equalizing stem check valve |
| US10982507B2 (en) * | 2019-05-20 | 2021-04-20 | Weatherford Technology Holdings, Llc | Outflow control device, systems and methods |
Citations (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5826660A (en) * | 1996-06-18 | 1998-10-27 | Schlumberger Technology Corporation | Dual action valve including a built in hydraulic circuit |
Family Cites Families (77)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3494417A (en) * | 1968-01-29 | 1970-02-10 | Otis Eng Corp | Well tools |
| US3976136A (en) * | 1975-06-20 | 1976-08-24 | Halliburton Company | Pressure operated isolation valve for use in a well testing apparatus and its method of operation |
| US4125165A (en) * | 1977-07-21 | 1978-11-14 | Baker International Corporation | Annulus pressure controlled test valve with locking annulus pressure operated pressure trapping means |
| US4234043A (en) * | 1977-10-17 | 1980-11-18 | Baker International Corporation | Removable subsea test valve system for deep water |
| US4113012A (en) * | 1977-10-27 | 1978-09-12 | Halliburton Company | Reclosable circulation valve for use in oil well testing |
| US4341266A (en) * | 1980-09-15 | 1982-07-27 | Lynes, Inc. | Pressure operated test tool |
| US4422506A (en) | 1980-11-05 | 1983-12-27 | Halliburton Company | Low pressure responsive APR tester valve |
| US4444268A (en) * | 1982-03-04 | 1984-04-24 | Halliburton Company | Tester valve with silicone liquid spring |
| US4448254A (en) * | 1982-03-04 | 1984-05-15 | Halliburton Company | Tester valve with silicone liquid spring |
| US4515219A (en) * | 1983-09-19 | 1985-05-07 | Halliburton Company | Low pressure responsive downhole tool with floating shoe retarding means |
| US4489786A (en) * | 1983-09-19 | 1984-12-25 | Halliburton Company | Low pressure responsive downhole tool with differential pressure holding means |
| US4537258A (en) * | 1983-09-19 | 1985-08-27 | Halliburton Company | Low pressure responsive downhole tool |
| US4633952A (en) * | 1984-04-03 | 1987-01-06 | Halliburton Company | Multi-mode testing tool and method of use |
| US4621695A (en) * | 1984-08-27 | 1986-11-11 | Camco, Incorporated | Balance line hydraulically operated well safety valve |
| US4589485A (en) * | 1984-10-31 | 1986-05-20 | Halliburton Company | Downhole tool utilizing well fluid compression |
| US4617999A (en) * | 1984-11-28 | 1986-10-21 | Halliburton Company | Downhole tool with compression chamber |
| US4577692A (en) * | 1985-03-04 | 1986-03-25 | Hughes Tool Company | Pressure operated test valve |
| US4753292A (en) | 1985-07-03 | 1988-06-28 | Halliburton Company | Method of well testing |
| US5156207A (en) * | 1985-09-27 | 1992-10-20 | Halliburton Company | Hydraulically actuated downhole valve apparatus |
| US4667743A (en) | 1985-12-12 | 1987-05-26 | Halliburton Company | Low pressure responsive tester valve with ratchet |
| US4691779A (en) * | 1986-01-17 | 1987-09-08 | Halliburton Company | Hydrostatic referenced safety-circulating valve |
| US4665983A (en) | 1986-04-03 | 1987-05-19 | Halliburton Company | Full bore sampler valve with time delay |
| US4736798A (en) * | 1986-05-16 | 1988-04-12 | Halliburton Company | Rapid cycle annulus pressure responsive tester valve |
| US4694903A (en) | 1986-06-20 | 1987-09-22 | Halliburton Company | Flapper type annulus pressure responsive tubing tester valve |
| US4729430A (en) | 1986-10-27 | 1988-03-08 | Halliburton Company | Pressure limiter for a downhole pump and testing apparatus |
| US4706746A (en) * | 1986-10-27 | 1987-11-17 | Halliburton Company | Downhole inflatable packer pump and testing apparatus |
| US4756364A (en) * | 1986-12-10 | 1988-07-12 | Halliburton Company | Packer bypass |
| US4848463A (en) | 1988-11-09 | 1989-07-18 | Halliburton Company | Surface read-out tester valve and probe |
| US4903765A (en) | 1989-01-06 | 1990-02-27 | Halliburton Company | Delayed opening fluid sampler |
| US5050681A (en) * | 1990-07-10 | 1991-09-24 | Halliburton Company | Hydraulic system for electronically controlled pressure activated downhole testing tool |
| US5180015A (en) * | 1990-10-04 | 1993-01-19 | Halliburton Company | Hydraulic lockout device for pressure controlled well tools |
| US5103906A (en) | 1990-10-24 | 1992-04-14 | Halliburton Company | Hydraulic timer for downhole tool |
| US5058674A (en) | 1990-10-24 | 1991-10-22 | Halliburton Company | Wellbore fluid sampler and method |
| US5127477A (en) * | 1991-02-20 | 1992-07-07 | Halliburton Company | Rechargeable hydraulic power source for actuating downhole tool |
| US5101907A (en) * | 1991-02-20 | 1992-04-07 | Halliburton Company | Differential actuating system for downhole tools |
| US5101904A (en) * | 1991-03-15 | 1992-04-07 | Bruce Gilbert | Downhole tool actuator |
| US5180007A (en) * | 1991-10-21 | 1993-01-19 | Halliburton Company | Low pressure responsive downhold tool with hydraulic lockout |
| US5209303A (en) * | 1991-11-20 | 1993-05-11 | Halliburton Company | Compressible liquid mechanism for downhole tool |
| US5228516A (en) * | 1992-01-14 | 1993-07-20 | Halliburton Company | Tester valve |
| US5316087A (en) * | 1992-08-11 | 1994-05-31 | Halliburton Company | Pyrotechnic charge powered operating system for downhole tools |
| US5335731A (en) * | 1992-10-22 | 1994-08-09 | Ringgenberg Paul D | Formation testing apparatus and method |
| US5558162A (en) * | 1994-05-05 | 1996-09-24 | Halliburton Company | Mechanical lockout for pressure responsive downhole tool |
| US5482119A (en) * | 1994-09-30 | 1996-01-09 | Halliburton Company | Multi-mode well tool with hydraulic bypass assembly |
| US5649597A (en) | 1995-07-14 | 1997-07-22 | Halliburton Company | Differential pressure test/bypass valve and method for using the same |
| US5819853A (en) | 1995-08-08 | 1998-10-13 | Schlumberger Technology Corporation | Rupture disc operated valves for use in drill stem testing |
| US5906220A (en) * | 1996-01-16 | 1999-05-25 | Baker Hughes Incorporated | Control system with collection chamber |
| US5813460A (en) | 1996-06-03 | 1998-09-29 | Halliburton Energy Services, Inc. | Formation evaluation tool and method for use of the same |
| US5791414A (en) | 1996-08-19 | 1998-08-11 | Halliburton Energy Services, Inc. | Early evaluation formation testing system |
| US5887654A (en) | 1996-11-20 | 1999-03-30 | Schlumberger Technology Corporation | Method for performing downhole functions |
| US5826657A (en) | 1997-01-23 | 1998-10-27 | Halliburton Energy Services, Inc. | Selectively locking open a downhole tester valve |
| US5826662A (en) | 1997-02-03 | 1998-10-27 | Halliburton Energy Services, Inc. | Apparatus for testing and sampling open-hole oil and gas wells |
| US5890542A (en) | 1997-04-01 | 1999-04-06 | Halliburton Energy Services, Inc. | Apparatus for early evaluation formation testing |
| US6065355A (en) | 1997-09-23 | 2000-05-23 | Halliburton Energy Services, Inc. | Non-flashing downhole fluid sampler and method |
| US5984014A (en) * | 1997-12-01 | 1999-11-16 | Halliburton Energy Services, Inc. | Pressure responsive well tool with intermediate stage pressure position |
| US6109351A (en) * | 1998-08-31 | 2000-08-29 | Baker Hughes Incorporated | Failsafe control system for a subsurface safety valve |
| US6325146B1 (en) | 1999-03-31 | 2001-12-04 | Halliburton Energy Services, Inc. | Methods of downhole testing subterranean formations and associated apparatus therefor |
| GB9913557D0 (en) * | 1999-06-10 | 1999-08-11 | French Oilfield Services Ltd | Hydraulic control assembly |
| EP1228290A4 (en) | 1999-11-05 | 2005-03-23 | Halliburton Energy Serv Inc | Drilling formation tester, apparatus and methods of testing and monitoring status of tester |
| US7096976B2 (en) | 1999-11-05 | 2006-08-29 | Halliburton Energy Services, Inc. | Drilling formation tester, apparatus and methods of testing and monitoring status of tester |
| US6536530B2 (en) * | 2000-05-04 | 2003-03-25 | Halliburton Energy Services, Inc. | Hydraulic control system for downhole tools |
| US6427778B1 (en) * | 2000-05-18 | 2002-08-06 | Baker Hughes Incorporated | Control system for deep set subsurface valves |
| US6491104B1 (en) | 2000-10-10 | 2002-12-10 | Halliburton Energy Services, Inc. | Open-hole test method and apparatus for subterranean wells |
| US6622554B2 (en) | 2001-06-04 | 2003-09-23 | Halliburton Energy Services, Inc. | Open hole formation testing |
| WO2003062595A1 (en) * | 2002-01-22 | 2003-07-31 | Baker Hughes Incorporated | System and method for a failsafe control of a downhole valve in the event of tubing rupture |
| CA2425724C (en) * | 2002-04-16 | 2006-01-31 | Schlumberger Canada Limited | Tubing fill and testing valve |
| BR0313826A (en) | 2002-08-27 | 2005-07-05 | Halliburton Energy Serv Inc | Formation fluid sample bottle, single-phase formation assessment tool, pressurization piston, down-hole fluid sampling method, and method for extracting a single-phase fluid sample from a wellbore formation and maintaining the sample in a single phase |
| US7201230B2 (en) * | 2003-05-15 | 2007-04-10 | Halliburton Energy Services, Inc. | Hydraulic control and actuation system for downhole tools |
| US7191844B2 (en) * | 2004-01-09 | 2007-03-20 | Schlumberger Technology Corp. | Inflate control system for inflatable straddle stimulation tool |
| US7197923B1 (en) * | 2005-11-07 | 2007-04-03 | Halliburton Energy Services, Inc. | Single phase fluid sampler systems and associated methods |
| US7389821B2 (en) | 2006-11-14 | 2008-06-24 | Baker Hughes Incorporated | Downhole trigger device having extrudable time delay material |
| US7552774B2 (en) * | 2006-12-05 | 2009-06-30 | Baker Hughes Incorporated | Control line hydrostatic minimally sensitive control system |
| US7464755B2 (en) | 2006-12-12 | 2008-12-16 | Schlumberger Technology Corporation | Methods and systems for sampling heavy oil reservoirs |
| US20090250224A1 (en) * | 2008-04-04 | 2009-10-08 | Halliburton Energy Services, Inc. | Phase Change Fluid Spring and Method for Use of Same |
| US8540035B2 (en) * | 2008-05-05 | 2013-09-24 | Weatherford/Lamb, Inc. | Extendable cutting tools for use in a wellbore |
| US7926575B2 (en) * | 2009-02-09 | 2011-04-19 | Halliburton Energy Services, Inc. | Hydraulic lockout device for pressure controlled well tools |
| US8157016B2 (en) * | 2009-02-23 | 2012-04-17 | Halliburton Energy Services, Inc. | Fluid metering device and method for well tool |
| US20110083859A1 (en) * | 2009-10-08 | 2011-04-14 | Schlumberger Technology Corporation | Downhole valve |
-
2011
- 2011-10-06 WO PCT/US2011/055021 patent/WO2013052050A1/en active Application Filing
- 2011-10-06 AU AU2011378455A patent/AU2011378455B2/en not_active Ceased
- 2011-10-06 BR BR112014008147A patent/BR112014008147A2/en not_active Application Discontinuation
- 2011-10-06 EP EP11873594.3A patent/EP2748418B1/en not_active Not-in-force
-
2012
- 2012-09-25 US US13/626,618 patent/US8701778B2/en active Active
Patent Citations (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5826660A (en) * | 1996-06-18 | 1998-10-27 | Schlumberger Technology Corporation | Dual action valve including a built in hydraulic circuit |
Also Published As
| Publication number | Publication date |
|---|---|
| AU2011378455A1 (en) | 2014-04-24 |
| US20130087326A1 (en) | 2013-04-11 |
| EP2748418A1 (en) | 2014-07-02 |
| EP2748418A4 (en) | 2016-05-11 |
| EP2748418B1 (en) | 2018-10-24 |
| US8701778B2 (en) | 2014-04-22 |
| BR112014008147A2 (en) | 2017-04-11 |
| WO2013052050A1 (en) | 2013-04-11 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CA2442981C (en) | Mechanically opened ball seat and expandable ball seat | |
| US7866392B2 (en) | Method and apparatus for sealing and cementing a wellbore | |
| US6216785B1 (en) | System for installation of well stimulating apparatus downhole utilizing a service tool string | |
| US7523787B2 (en) | Reverse out valve for well treatment operations | |
| US4116272A (en) | Subsea test tree for oil wells | |
| US7543651B2 (en) | Non-elastomer cement through tubing retrievable safety valve | |
| AU735560B2 (en) | Pressure responsive well tool with intermediate stage pressure position | |
| US9133686B2 (en) | Downhole tester valve having rapid charging capabilities and method for use thereof | |
| US5890542A (en) | Apparatus for early evaluation formation testing | |
| EP2959098B1 (en) | Autofill and circulation assembly and method of using the same | |
| US4804044A (en) | Perforating gun firing tool and method of operation | |
| US8701778B2 (en) | Downhole tester valve having rapid charging capabilities and method for use thereof | |
| US11828127B2 (en) | Tubing hanger with shiftable annulus seal | |
| EP2923035B1 (en) | Downhole tool anchoring system | |
| AU2015252060B2 (en) | Downhole tester valve having rapid charging capabilities and method for use thereof | |
| NL2032590A (en) | Hydraulic setting chamber isolation mechanism from tubing pressure during production and stimulation of the well | |
| US9745827B2 (en) | Completion assembly with bypass for reversing valve | |
| CA2358896C (en) | Method and apparatus for formation isolation in a well | |
| CN116457550A (en) | Downhole tool actuator with viscous fluid gap path | |
| WO2015191417A1 (en) | System and methodology using annulus access valve | |
| US9915125B2 (en) | Wellbore strings containing annular flow valves and methods of use thereof | |
| AU2003248454A1 (en) | Mechanically Opened Ball Seat and Expandable Ball Seat | |
| AU2012384917A1 (en) | Control line damper for valves |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| FGA | Letters patent sealed or granted (standard patent) | ||
| MK14 | Patent ceased section 143(a) (annual fees not paid) or expired |