US3308887A - Well tester - Google Patents

Well tester Download PDF

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Publication number
US3308887A
US3308887A US333225A US33322563A US3308887A US 3308887 A US3308887 A US 3308887A US 333225 A US333225 A US 333225A US 33322563 A US33322563 A US 33322563A US 3308887 A US3308887 A US 3308887A
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Prior art keywords
members
mandrel
tester
housing
bypass
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US333225A
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English (en)
Inventor
Benjamin P Nutter
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Schlumberger Well Surveying Corp
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Schlumberger Well Surveying Corp
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Priority to US333225A priority Critical patent/US3308887A/en
Priority to DE19641433202 priority patent/DE1433202B1/de
Priority to ES0307483A priority patent/ES307483A1/es
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    • 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
    • E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
    • E21B49/088—Well testing, e.g. testing for reservoir productivity or formation parameters combined with sampling
    • 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

Definitions

  • Drill stem tests are normally performed by lowering a string of tools including a testing tool and packer to a desired depth of testing.
  • the packer is set usually Iby applying force through the drill string, the packer isolating or packing-off the formation to he tested.
  • a test valve in the testing tool is opened and closed by rotation of the drill string while the force on the drill string is lmaintained on the packer.
  • the number of times that such a valve may be opened and closed is limited to one or two separate openings and closings yand requires a given number of rotations for each operation.
  • Rotation or torquing of the drill string for opening and closing operations is disadvantageous in that all the threaded connections in a tubing string may not be completely made up, therefore the given number of rotations may be taken up by the string of tubing without effecting an operation of the valve in the tool. Also, the tubing string may become lodged in the hole intermediate the length of the tubing so that the string of tubing twists above the lodged point without transferring the rotating motion to the tool. Subsequently, the tubing string may twist itself free and then make several uncontrolled revolutions on the lower part of the tubing string which may adversely affect the valve operation.
  • Another object of the present invention is to provide an apparatus for making multiple tests of a formation utilizing longitudinal movement of the testing tool to perform the test operations.
  • a t.further object of the present invention is to provide a new and improved formation testing tool and an apparatus for packing-olf the well bore in such a way as to facilitate longitudinal movement of the testing tool and yet maintain the packer in a set condition.
  • a still further object of the present invention is to provide a new and improved series of full-opening tools which may 'be used in com-bination with the new and improved formation tester.
  • the present invention contemplates an apparatus for making mutliple tests on a formation. More particular-ly, the apparatus includes a series of tools each including telescopically mounted members arranged to selectively move between longitudinally spaced operating positions, the series of tools including tester means, bypass means, jar means, safety joint means and packer means.
  • the tester means includes means permitting opening and closing of a flow valve by longitudinal stroking movement of the drill string to place the telescoping members in spaced longitudinal positions and in each of such positions, force can positively be applied to the packer.
  • the bypass means includes means -for quick closing of the valve and delayed or retarded opening so that the tester valve can be operated.
  • the jar, and safety joint means are provided to uncouple the tester and tubing string from the packer in the event of sticking and are compatible to the operation of the tester Valve.
  • the packer means in one embodiment can be releasably latched against upward and downward movement in the well bore.
  • FIG. 1 is a view in elevation of a series of well tools suspended from a string of pipe and arranged for going in a well;
  • FIG. 2 is an elevationa-l view of an alternative apparatus connected in the series of tools for isolating the formation to be tested;
  • FIGS. 3A and 3B are detailed vertical sections of the well testing tool in accordance with the present invention.
  • FIG. 4 is a developed view of an index slot system used in the tester
  • FIG. 5 is a detailed Vertical section of a bypass valve
  • FIG. 6 is a detailed vertical section of a safety joint
  • FIG. 6A is a cross-sectional view of a safety joint taken along line A-A o-f FIG. 6;
  • FIG. 7 is a diagram which shows operating features of the safety joint
  • FIGS. 8 and 9 are detailed Vertical sections of a releasa'bly locked packer device
  • FIG. 10 is an enlarged detailed cross-sectional view taken along line 10-10 of FIG. 9 of a valve utilized in the packer device;
  • FIG. 11 is -a vertical section of an alternative embodiment of the testing tool and bypass section
  • FIGS. 12A and 12B are detailed vertical sections of an alternative combination of bypass and packer means.
  • a well tool 20 is -arranged to be connected to the lower end of a string of pipe or tubing 21 and includes a tester section 22, a bypass section 23, a jar section 24, a safety joint section 25, a packer section 26, and a perforated anchor section 27.
  • the anchor carries conventional pressure recorders 28 and has perforations 29 in the wall of the anchor section to permit fluid to flow into a bore in the packer mandrel and up through the string of tools. Two pressure recorders are provided, one recorder measuring pressure externally of the anchor and the other measuring pressure internally of the anchor.
  • the assembled tool 20 is attached to the string of pipe 21, and -lowered into the well bore to the formation to be tested.
  • the bypass section 23 of the well tool permits fluids in the well tbore to bypass ⁇ around the packer section 26 as the tool is lowered into the well bore and thereby permits a more rapid descent of the tool into the welll bore.
  • the anchor 27 is seated on the bottom of the borehole, further downward pressure on the tool will cause an elastomer packer element 125 to be expanded in the well bore to isolate the formation to be tested 'from the rest of the well bore.
  • Formation fluids enter the tool through the perforations 29 in the anchor section and flow upwardly through the various tools to the tester section 22. Valves in the tester section are opened and closed to flow and shut in the formation fluids.
  • 'Die recorders housed in the anchor section are used to measure the pressure of the iluids during the owing and shut-in periods.
  • FIG. 2 illustrates :an alternative method of locatingthe well tool tester with respect to the formation to be tested wherein a conventional wall anchor 31 is used to position the tool in the well bore at the desired depth and a pair of spaced packers 32 and 33 are utilized to straddle the formation to be tested.
  • the wall anchor 31 is also used to set the packers.
  • the tester section 22 generally includes .a telescopicallyarranged mandrel 36 and housing 41 respectively arranged for coupling between a pipe string 21 and the other sectionsV of the tool.
  • the tester mandrel 36 has a central bore 37 formed therein and intermediate of the Ilength of the bore is a closure plug or barrier 38 (FIG. 3B) shear pinned at 39 to the .mandrel and sealingly received therein.
  • the housing 41 is divided into an upper housing section 42 and lower housing section 43 which are rotatablyl connected to one another by interlocking and cooperating flanges 46, 47 on the sections 42, 43. Flanges 46, 47 provide a swivel type connection so that the upper housing 42 can be rotated with respect to the lower housing 43.
  • the upper housing 42 has an index pin 48 projecting in-to an indexing slot system 49 formed in the mandrel 36.
  • the indexing slot system is shown in a developed View in FIG. 4 and will hereinafter lbe more fully explained.
  • the upper housing 42 also has an internal recess 51 with an inwardly-projecting spline or lug 52 disposed intermediate of the length of the recess.
  • Housing spline S2 forms an abutment for an upper spline 54 projecting outwardly from the mandrel 36 into the housing recess 51. Splines 52, 54 are engaged and disengaged by opera-tion of the slot system.
  • Mandrel 36 further has a lower outwardly-extending spline 56 which is slidably received within a longitudinally-extending spline groove 57 in the interior of the lower housing.
  • the slot system as shown in FIG. 4 includes an upper pocket E, an intermediate pocket H and a pair of lower pockets G and A.
  • the upper pocket and intermediate pocket are longitudinally aligned relative to one another while lower pockets G and A are equidistantly spaced to either side of the intermediate pocket H.
  • Inclined and longitudinal slots are provided to connect the upper and lower pockets as well 1as the lower and intermediate pockets to one another and guide the index pin 48 in a predetermined manner. For example, if the index pin is initially in the lowermost pocket A, the following sequence of movements will produce the following described travel of the index pin:
  • the slot system functions to place the upper housing spline 52 and mandrel spline 54 in engagement when the index pin is in the intermediate pocket H so that downward forces can be transmitted from the mandrel 36 directly to the housing 41 and specifically, lower housing section 43 via the splines 52, 54 and the upper housing 42. In this manner, the mandrel 36 can be pushed down on the housing 41 to apply weight to the string of tools therebelow.
  • the splines are meshed when the index pin moves 'between points B and C on the slot system (by virtue of relative rotational displacement) and a collar 58 on the upper end of the mandrel 36 is brought into abutting relationship with the upper end 59 of the upper housing 42 when the index pin is moved to the upper pocket E so that the mandrel can again be pushed down on the housing.
  • the lower housing 43 ⁇ below the spline grooves 57, has a Ibore portion 61 with an enlarged internal diameter forming a cylinder 62 which receives a hydraulic delay piston 63 in the form of a sleeve between the cylinder wall and the mandrel.
  • This annulus formed between the bore 61 and mandrel 36 is filled with a hydraulic uid and sealed by floating annular piston and seal members 66 and 67, positioned at each end of the 4bore (FIGS. 3A, 3B).
  • the delay piston 63 abuts on one end against an upper, annular valve seat 68 formed by a flange 69 on the mandrel 36.
  • a delay valve spring 71 is disposed between a lower ange 72 on the mandrel 36 and the lower end of the piston 63.
  • Spring 71 normally urges the piston 63 toward the seat 68 on the valve seat ange 69.
  • the outer diameter of the piston 63 is less than the diameter of the bore 61 to form a restricted annular horr 73'.
  • a relief chamber 76 with a larger diameter so that when the piston 63 is moved into the relief chamber 76, a large Huid ow passage is provided between the piston and the housing. This permits the 'mandrel to jump, or make a sudden movement downwardly at a terminal portion of its downward travel, causing the collar 58 to strike and engage the upper end 59 of the housing 41 sending a shock wave to the surface through the string of pipe to -give the operator a surface indication that the index pin 48 is Within the mandrel slot E.
  • the fluid above the piston 63 will move the piston downwardly relative to the mandrel to compress the spring 71.
  • the inner wall of the piston is provided with longitudinal grooves 77 which permit the fluid to bypass between the piston 63 and the mandrel 36 so that lthe mandrel can Ibe picked lup relative to the housing relatively fast as compared to the downward movement of the mandrel.
  • the housing has a bore portion (FIG. 3B) which slidably and sealingly receives the lower end of the mandrel.
  • the housing 'bore portion is recessed to provide an annular ltrap or sample chamber 78 between the housing 41 and mandrel 36.
  • a flow port 79 is provided in the bore portion above the recess 78 and extends between the wall of the bore portion and an annular cavity '81 in communication with.
  • the bore portion is similarly provided with a ilow port 82 extending between the wall of the bore and an annular cavity y83 in the end of the housing.
  • the mandrel has spaced sealing elements 86 disposed to either side of a recessed portion 87, the sealing elements being arranged to seal .the mandrel 36 relative to the bore above each of the housing flow ports 79, 82.
  • the mandrel 36 also has a flow port 88 disposed above the upper seal and above the plug 38.
  • the mandrel 36 is threaded on its llower end at 89 so that a portion 36a of the mandrel below the threaded joint may be removed. Removal of the lower portion 36a also removes the lower sealing element 86 and thereby renders the mandrel 36 incapable of sealing oil the trap chamber 78. In this condition, when the mandrel 36 is moved up and down relative to the housing the lower ow port 82 is placed directly into and out of com- -munication with the mandrel port 88 through upper ow port 79 in the housing.
  • the bypass section 23 of the tool includes a tubular mandrel 91 telescopically received within a tubular housing 92, the mandrel and housing respectively being adapted for coupling in the string of tools 20.
  • a spline 93 on the upper part of the mandrel cooperates with a spline groove 94 in the bypass housing permitting relative reciprocation but preventing relative rotation therebetween.
  • 'I'he spline 93 engages a flange 96 on the housing in an expanded position of the bypass section while a shoulder 97 on the mandrel engages the housing ilange 96 in a contracted position.
  • the sleeve piston 99 has a slightly smaller diameter than the diameter ofthe cylinder bore thereby forming a restricted annular oritce 103.
  • the ends of the annular chamber 98 formed between the mandrel and housing are closed by a pair of floating, compensation pistons 106, 107 which enclose a fluid within the chamber.
  • the lower end of the housing has a bypass port 111 while the lower end of the mandrel has a sealing element 112 so that, in the contracted position of the mandrel and housing, the bypass port is closed by the sealing element 112 and the compensating piston seal 107.
  • FIGS. 6, 6A and 7 illustrate the safety joint section 24 of the tool.
  • the safety joint section includes a tubular mandrel 113 telescopically received within a tubular housing 114, the mandrel and housing being adapted for coupling in the string of tools 20.
  • a threaded nut 115 is positioned between the mandrel 113 and housing 114 and engages threads 120 formed on the upper end of the housing 114.
  • the nut has an internal spline groove 123 formed thereon which cooperates with an external spline 124 formed on the mandrel 113. This spline arrangement provides for longiassembly.
  • a ilange 145 formed on the mandrel 113 limits the upward longitudinal travel of the mandrel with respect to the housing.
  • Two sets of lugs 146A, 146C and 146B, 146D are formed on the mandrel below the ange 145. The lugs in each set are spaced on the mandrel 180 from each other and the two sets are longitudinally spaced on the mandrel. Therefore, each of the lugs is spaced from the adjacent lug and is positioned longitudinally therefrom.
  • a longitudinal key 147 is positioned in the wall of the housing 114 and extends into the annular space between the housing and the mandrel.
  • the key has a longitudinal dimension which is greater than the longitudinal distance between the sets of lugs 146B, 146D and 146A, 146C.
  • An annular flange portion 148 formed in the inner bore of the housing 114 has annular recesses formed therein for receiving seal members 149. This ange portion having sealing members receives the lower end of the mandrel 113 in sliding engagement and seals the mandrel bore 151 from communication with an annular space 152 between the mandrel and housing which in turn communicates with the outside of the housing 114.
  • FIG. 7 shows in a developed view the relationship between the lugs 146A-146D and the key 147 as the safety joint is operated.
  • the lugs and key are positioned as shown in the elevational view of FIG. 6, and cross-sectional view FIG. 6A, that is, with the lug 146A positioned abutting the key 147.
  • the second diagram shows that if the mandrel 113 is raised relative to the housing 114 and rotated counterclockwise the lug A will be positioned above the key and will rotate with the mandrel until the lug B abuts the key 147.
  • the third diagram shows that subsequently if the mandrel 113 is lowered relative to the housing the lug B will drop below the key 147 and upon rotation of the mandrel counterclockwise, will rotate reltaive to key 147 until the lug C abuts the key 147. Thereafter, another upward movement on the mandrel and counterclockwise rotation of the mandel will raise the lug C above the key and rotate it 4relative to the key until the lug D abuts the key 147, thus completing 270 of rotative movement of the mandrel in the four diagrams shown in FIG. 7.
  • the splines 123, 124 located on the nut and mandrel, respectively, are meshed to rotate the nut with the mandrel 113. If the longitudinal rotative movement described relative to FIG. 7 is repeated enough times the nut 115 will be unscrewed from the mandrel 114 whereupon the mandrel 113 will be free to be withdrawn from the housing 114 thereby releasing or freeing tool members lpositioned in the tool string above the safety joint for withdrawal from the well bore.
  • the packer assembly is shown in FIGS. 8-10.
  • the packer assembly 26 includes telescopically-mounted mandrel 116 and housing 117 which are respectively arranged for coupling to the tool sections above and below the lower end of the mandrel is a flange 118 and an annular back-up plate 119.
  • An annular elastomer packing element is received on the mandrel between the lower back-up plate and an upper back-up plate 121.
  • the housing has a flange 122 abutting the upper back-up plate. It will be appreciated that if the housing 117 is moved downwardly relative to the mandrel 116, the packing element 125 can be expanded to engage the wall of the well bore as shown in FIG. 9.
  • the mandrel In the upper part of the mandrel and housing is a system for releasably retaining the packer element in an expanded condition.
  • the mandrel has upper 126 and lower flange portions slidably and sealingly received in the housing and forming a recess or chamber 128, 129 therebetween, the chamber being lled with a hydraulic fluid.
  • the housing has an inwardly-extending second 157 passageways from one another.
  • the differential pressures to control the spool valve are S, connecting the upper 132 and lower 133 passageways obtained in a manner which will hereinafter be more fully to one another, fluid will pass from the lower recess explained. portion 129 to the upper recess portion 128 when the The operation of the apparatus of FIGS. 3-1() may housing 117 is moved downwardly relative to the mandrel best be understood by use of the following table in con- 116 to the position shown in FIG. 9. With the packer nection with the description following.
  • the valve system includes a port 135 in the mandrel 116 opening to a recessed portion 136 of the piston between spaced seals 137 and a control port 138 in the piston opening to the valve 134.
  • the valve includes a sleeve 141 retained in a bore 142 of the housing, the sleeve 141 having a ⁇ first vannular groove 143 and ports in communication with a first passage 144 and a second annular groove and ports 156 in communication with a second passageway 157.
  • FIG. 10 illustrates both ⁇ upper 132 and lower 133 passageways for convenience of understanding although one of the passageways would not 'be seen in the section view.
  • a bore 158 inthe sleeve 141 opens at one end to the exterior of the tool and at the other end to the control port 138.
  • Received in the sleeve bore is a spool type piston 159 arranged for movement between a position placing the upper and lower passageways 132, 133 in 4communication and a position where the upper and lower passageways are isolated from one another.
  • a spring 161 is provided to normally urge the piston to a position placing the passageways in fluid communication with one another.
  • the piston in the position illustrated has a first portion 162 closing olf the sleeve ports leading to passageway, the first portion, however, having a slightly smaller diameter than the bore of the sleeve permitting some fluid leakage to occur.
  • the piston 159 will assume the illustrated position where the first portion 162 of the piston isolates the first 144 and
  • the piston is shifted so that a recessed portion 163 ofthe piston places passageways 144, 157 in communication with one another.
  • valve 134 (FIG. l0) is open because the pressure of the fluids within the packer mandrel 116 are the same as the pressure of the fluids on the exterior of the tool so that the spring 161 places the spool piston 159 in a position where the upper and lower passageways 132, 133 are in uid communication.
  • bypass 23 is held in an expanded position by the weight of the tool attached to the bypass housing 92 so that the bypass port 119 is open and fluid can pass through the packer mandrel 116 and return tothe Well bore via the bypassport 111.
  • the sample chamber 78 and test ports are closed while the index pin is disposed in the pocket A.
  • the packer element Upon reaching the level of the test, the packer element is expanded. This occurs because the packer mandrel 116 is xed relative to the well bore. Fixing the mandrel may be by contact with the bottom by the perforated anchor 27 or by setting a hook wall anchor as shown in FIG. 2. It should be noted that for use of a hook wall packer, the conventional J slot control can be operated because all of the sections are spline connected to permit rotation. While splines are not shown in the packer assembly 26, it will be appreciated that this connection can easily be furnished between the mandrel 116 and upper housing 117.
  • the packer mandrel is fixed and a downwardy motion on the string of pipe is transmitted through the tool sections to move the upper packer housing 117 relative to the packer mandrel 116 and expand the packer element 125.
  • the bypass section 23 contracts to close the bypass port 111 bringing the bypass mandrel shoulder 97 into abutment with the bypass housing.
  • the fluid in the delay system is trapped 4below the piston 63 and very slowly meters through the restricted orifice 73.
  • the tester mandrel shoulder 58 engages the upper housing end 59
  • the bypass shoulder 97 engages the bypass housing 92 and downward pressure on the string of pipe can be maintained on the packer element to ensure that it will be fully expanded.
  • the index pin has traveled from position C into the slot E.
  • Condition 4 After fluid has flowed for a sufficient period of time, say fteen minutes, the tester is closed for, say, five minutes to obtain a shut-in pressure. To close the tester the string of pipe is picked up a suicient distance to index the pin from the upper pocket E to the lower pocket G and then set down to index the pin to the intermediate pocket H.
  • the delay valve in the tester opens to permit quick bypass of iluid and movement of the tester section to the expanded condition.
  • the delay valve in the bypass retards movement of the bypass to an expanded position and the closed valve 134 in the packer assembly prevents release of the expanded packer element 125.
  • the splines 52, 54 in the tester section are meshed once again and the mandrel spline 54 disposed above the housing spline 52.
  • a gas flowmeter 19 (FIG. l) is connected to the string of pipe at the surface. As fluids enter the string of pipe the displacement of air in the pipe is indicated by the flowmeter. At a point where the formation uid ow stabilizes the gas flow becomes constant indicating completion of the test.
  • the packer element 125 In order to retrieve the tool string 20 and the fluid sample which may be trapped in the chamber 78 when end section 36a is attached to the tester mandrel, the packer element 125 must be contracted to release the tools from the well bore. This step may 4be accomplished by picking up on the tool string to close the tester valve and trap a iluid sample at formation pressures. Thereafter, the bypass mandrel 91 is lifted up relative to the bypass housing 92. A continued lifting force on the mandrel 91 will permit sutlicient lluids to leak by the bypass piston 99 through the restricted Anlagen 103 to allow the mandrel and seal 112 to uncover the bypass port 111.
  • the opening of port 111 subjects the inner bore of the tool sections to the hydrostatic pressure of the well uids thereby increasing the inner bore pressure and consequently communicating the increased pressure with the control port 4138 of the packer.
  • This pressure in turn acts with spring 161 to move the piston 159 forward and open the valve 134 to connect the upper and lower passageways 132 and 13-3.
  • the valve opening permits expanding movement of the l'packer mandrel and housing to release the packer element 125 from compression and engagement with the well bore.
  • the jar section 24 (FIG. 1) may be of the type set forth in a vco-pending application for Well Jar Systems, Ser. No. 280,829 now Patent No. 3,251,426, and owned by the assignee of the present invention.
  • the safety joint 25 described heretofore in the description, may lbe utilized.
  • the tubing string is rotated above the safety joint to release t-he upper part of the string for retrieval to the surfa-ce.
  • it may be necessary to lower an explosive element or string shot into the full open bore of the tool string to the level of the joint whereupon the shot is detonated to loosen the joint for subsequent unthreading by rotation of the tubing string.
  • the knock out plug 38 which serves the purpose of blocking the tester section mandrel bore 37 during flow testing of the well may be removed by dropping an object in the bore of the tubing string which object serves to shear the pin 39 to knock out the plug 38. This opens the bore for lowering of the string shot to the safety joint section 25.
  • a plug 85 is threadably received in'the wall of the lower tester housnig 43 (FIG. 6B). Manipulation of the tester members will permit sealing oif of this plug port for removal of the plu-g and insertion of test instruments while maintaining the sample at reservoir conditions. Subsequently, the tester mandrel is moved to uncover the plug port and place the instruments in communication with the sample chamber for analysis of the trapped fluid.
  • T-he applicant has set forth a preferred embodiment of the apparatus to perform the multiple testing operation. There are many forms of apparatus which could be utilized to perform this method of operation.
  • One such alternative embodiment of a tester and bypass section of the tool is shown schematically in FIG. 11.
  • the tester and bypass section shown in FIG. l1 includes a tester section 173 which has an index system and spline arrangement similar to that described with reference to the tester embodiment shown in FIGS. 3A and 3B.
  • the hydraulic delay piston shown in the embodiment in FIGS. 3A and 3B may be utilized in this embodiment although not shown in FIG. 11.
  • the tester section further has an ori-tice plug 174 positioned in a tester mandrel 176.
  • a tester housing 177 likewise has a plug 178 positioned in -a bore formed in the housing and connected to the housing by spider-fingers 179 arranged around the bore of the housing. These fingers, being spaced apart, permit uid flow Iaround the plug 178.
  • a bore formed in the tester mandrel is sized to slide over the plug 178 positioned in the tester housing and a seal member 181 which is formed on the plug 178 serves to seal the bore of the tester mandrel from the bore of the tester housing.
  • the tester mandrel In the operation of this tester the tester mandrel is raised by an upward movement on the drill pipe to expose the bottom of the tester mandrel bore to formation fluids owing into the tester housing from below as indicated by the arrows in FIG. 11. T o close the tester, -downward movement on the tester mandrel places the tester mandrel bore over the plug 178 and seal member 181 to seal the tester mandrel bore from fluids owing into the tester housing.
  • the bypass section 186 which is suspended below the tester section 173, has a mandrel 187 that is hreadedly secured at its upper end to the bottom of the tester housing, the lofwer end portion being telescopically connected to a bypass housing 188 by any suitable means (not shown), for example the spline, groove and flange arrangements shown in FIG. 5.
  • a bypass housing 188 has bypass ports 189 formed therein.
  • a seal 191 which is positioned on the bypass mandrel serves to seal off the bypass ports 189 when the bypass mandrel is in a down position as shown in FIG. ll.
  • a packer 192 which is positioned below the bypass 186 may depend for its expanded condition upon the bypass valve or port 189 being closed to prevent hydrostatic pressure in the well bore from entering the interior of the bypass housing. Therefore, the maintenance of the bypass in a 1closed position is important and will be explained.
  • the -bypass is maintained in its closed position by the action of iiuid forces on exposed areas of the tester and bypass members (FIG, 1l). After the bypass is closed, the forces, which act down on the tester housing and bypass mandrel, are maintained greater than the forces acting up on the tester housing and bypass mandrel.
  • the forces acting down can be calculated by multiplying the hydrostatic pressure in the well bore Ph times the difference between the area of the tester housing andthe area of the ltester mandrel (A1-A2).
  • the forces acting up on the system may be calculated by multiplying the hydrostatic pressure Ph times the area of the testerhousing minus the area of the bypass mandrel (A1-A3) plus the formation pressures Pf times the area of the bypass mandrel minus the area of the tester mandrel (A3-A2).
  • the latter calculation, ⁇ A3-A2 represents the effective area of the tool subjected to formation pressures which is in effect the difference in areas between the top and bottom of the bypass mandrel 187 that is exposed to formation fluid.
  • the total force Fd down may be calculated by subtracting the forces up from the forces down as shown in the following equation:
  • FIGS. 12A and 12B An alternative bypass and packer which is the subject of applicants Patent No. 3,020,959 for Well Packers is shown in FIGS. 12A and 12B.
  • This packer and bypass tool includes a mandrel 201 and a housing 202.
  • a series of openings 203 in the mandrel wall provide a bypass for fluids around a packer element 204, when expanded, which is positioned on the outer wall of the housing 202.
  • the mandrel is slidably received within the housing and upon downward movement of the mandrel with respect to the housing, seals 206 positioned in the mandrel above the bypass ports 203 are received within a recess 207 formed in the upper end of the housing to seal off the bypass ports from the well bore above the packer element 204.
  • This locking of the mandrel is advantageous in that an upward pull on the mandrel cannot open the bypass ports or tend to unseat the packer. This is particularly useful when the packer is used in conjunction with an auxiliary tool such as a formation tester which requires longitudinal movement of the tubing string to operate ⁇ the tester.
  • a jar and a safety joint may be provided in the tool string to facilitate retrieval of the well tool in such emergencies.
  • the packer and bypass tool is full-opening to allow for lowering of or retrieval of other small diameter tools through the bore of the tool.
  • Different well testing apparatus is usually designed for use in open and cased well bores.
  • this invention is primarily directed to apparatus for testing open well bores it will be appreciated that features of the present invention can have application for testing apparatus for cased well bores.
  • Apparatus for testing earth formation conditions in a well bore containing well fluids comprising:
  • flow conduit means extendible in a well bore to earth formations to be tested and including a string of pipe, tester means, and packing-off means, said packing-off means being below said tester means and arranged to selectively isolate a section of the well bore from the well lluid therein, said tester means including telescoping tubular members, one of said members having rotatively coupled parts, one of said parts having longitudinally spaced abutments, the other of said members having an abutment, and indexing means between said one part and said other member for selectively positioning said other member abutment on one of said part abutments by longitudinal movement of said other member and rotation of said one part.
  • packing-off means being arranged to selectively isolate a section of the well bore from the well liuid therein by the application of a downward force
  • said tester means having telescopically arranged members adapted for coupling between a string of pipe and said packing-oilc means and longitudinally movable between contracted and expanded positions,
  • valve means in said tester means for selectively opening said tester means to fluid flow in one of said positions and closing said tester means to uid flow in the other of said positions,
  • indexing means interconnecting said one part and said other tester member for selectively positioning said abutment means in said positions whereby a downward force can be applied in each of said positions
  • valve means for delaying telescopic movement of said tester members to a position opening said valve means.
  • barrier means in one of said members dividing said longitudinal opening through said member into an upper and lower passageway
  • said means including spaced abutment means arranged for contact in spaced longitudinal positions for transmitting downward forces in said spaced longitudinal positions,
  • valve means in said members operative for connecting said upper and lower passageways in one of said positions to permit fluids to pass from one of said passageways to the other of said passageways and operative in said other position for closing said passageways from fluid communication with one another,
  • delay means for retarding longitudinal movement between said rst and second tubular members when moving toward a position where said valve means permit the passage of iluid between said passageways.
  • a second tubular member having a longitudinal opening therethrough and slidably received for telescoping movement within said first tubular member
  • barrier means in one of said members dividing said longitudinal opening through said second tubular member into an upper and lower passageway
  • said means including spaced abutments arranged for contact in spaced longitudinal positions for transmitting downward forces in said spaced longitudinal positions,
  • valve means in said members operative for connecting said upper and lower passageways in one of said positions to permit iiuid to pass from one of said passageways to the other of said passageways and operative in said other position for closing said passageways from Huid communication with one another,
  • said delay means having shunt means permitting relatively fast telescoping movement between said first and second tubular members when moving toward the relative position where said valve means close said passageways.
  • Apparatus for use in a well bore comprising:
  • valve means in said members operative for connecting said upper and lower passageways in one of said positions to permit uids to pass trom one of said passageways to the other of said passageways and operative in another of said positions for closing said passageways from fluid communication with one another,
  • bypass means arranged for coupling to said tubular members
  • bypass means having a mandrel and housing
  • bypass mandrel and housing being relatively movable between expanded and contracted positions and including valve means providing a liuid communication path between the exterior and interior of the well apparatus in one of said positions, and
  • Apparatus in a well bore containing a well tluid for ow testing the well including:
  • valve means in said tester members for controlling ilow through said tester members in said positions
  • packer means including telescopically mounted members, and a packer element disposed on one of said packer lmembers and arranged to be expanded by relative motion between said telescoping packer members,
  • bypass valve means intermediate said tester members and said packer members for providing a uid communication path between the annulus spaces in said well bore .above and below said packer means,
  • bypass ⁇ means further including telescopically arranged tubular members movable between expanded and contracted positions
  • safety joint means intermediate said tester members and said packing means, said safety joint means including telescoping members mounted for longitudinal movement and arranged to selectively resist rota-tive movement,
  • safety joint members capable of being rendered separable by a series of longitudinal and rotative motions on one of said members
  • safety joint means bypass means, packer means and tester means each having a full-opening bore therethrough.
  • Apparatus for testing earth formations in a well bore containing well i'luids comprising telescopieally arranged inner and outer tubular members adapted for coupling between a string of pipe and packer means,
  • said inner tubular members having a removable plug portion normally closing off its bore, a test port above said plug portion, and seal means on said inner tubular members below said port, said outer tubular member having a bore portion with longitudinal spaced openings in fluid communication with one another .through the body of said tubular member,
  • a well testing tool comprising: first and second telescopically arranged members adapted for coupling in a tool string, said members having passageways and valve means for selectively placing said passageways in cornmunication, means securing said members to one another, at least one abutment means mounted on one of said members for rotation relative to both of said members, at least one abutment means mounted on the other ot said members, and index means including cam means cooperable between said first mentioned abutment means and one of said members for positioning said abutment means in engagement in one longitudinal position of said members whereby forces in one direction can be transmited from one of said members to the other through said abutment means and for rotating said first mentioned abutment means relative to both of said members in response to longitudinal motion of one of said members to disengage said abutment means to permit relative movement of said members to another longitudinal position.
  • a well testing tool comprising first and second telescopically arranged members adapted for coupling in a well string, said members having passageways and valve means for selectively placing said passageways in cornmunication, means securing said members to one another, at least one abutment means mounted on one of said members for rotation relative to both of said members, at least one abutment means mounted on the other of said members, index means for positioning said abutment means in engagement in one longitudinal position of said members for transmitting forces in one Adirection and operable to -disengage said abutment means to permit movement of said members to another longitudinal position, and means on said members engageable in said other longitudinal position for transmitting forces in said one direction.
  • a flow evaluating tool for use in a well bore said tool having inner and outer tubular members telescopically movable between first and second relative positions, said members having passageways and valve means placing said passageways in communication in one of the relative positions and out of communication in the other of the relative positions, -a first abutment on one of said members, a second abutment on the other of said members engageable with said first abutment when said members are in the relative position where said passageways are out of communication so that downward forces can be transmitted from one member to the other, and index means separate from said abutment means for angularly displacing one of said abutments relative to the other to disengage said abutments so said members can be moved to the relative position where said passageways are placed in communication ⁇ 13.
  • a flow evaluating tool for use in a well bore said tool having inner and outer tubular members telescopical- 1y movable between rst and second relative positions,
  • said members having pasageways and valve means placing said passageways in communication in Vone of the relative positions and out of communication in the other of the relative positions, one of said members having a rotatable portion, a first abutment on said rotatable portion, a second abutment on the other of said members engageable with said first abutment when said members are in the relative position where said pasageways are out of communication so that downward forces can be transmitted from one member to the other, index means for angularly displacing one of said abutments relative to the other to disengage said abutments so that said members can be moved to the relative position where said passageways are placed in communication, and a third abutment on said one of said members longitudinally spaced from said first abutment and engageable with said other of said members when said members are in the relative position where said passageways are placed in communication so that downward forces can be transmitted from one member to the other.
  • a well tool comprising: inner and outer tubular members telescopically movable lbetween first and second relative positions, said members having passageways and valve means placing said passageways in communication in one of the relative positions and out of communication in the other of the relative positions; a first abutment on one of said members; a second abutment on the other of said members engageable with said first abutment when said members are in the relative position where said passageways are out of communication so that downward forces can be transmitted from one member to the other; and index means, including a part rotatable relative to said members solely responsive to longitudinal reciprocation of one of said members, for angularly displacing one of said abutments relative to the -other to disengage said abutments so that said members can be moved to the relative position where said passageways are placed in communication.
  • Apparatus for testing earth formation conditions in a well bore containing well fluids comprising: flow conduit means extendible in the well bore to the earth formations to be tested and including a string of pipe, tester means, and packingolf means, said packing-ofi me-ans being below said tester means and arranged to selectively isolate a section of the well bore from the well fluid therein, said tester means including telescoping tubular members, one of said members having relatively rotatable parts and longitudinally spaced abutments, the other of said members having an abutment, and indexing means between one of said parts and said other member for selectively positioning said other member abutment on one of said abutments on said parts by longitudinal movement of said other member ⁇ and rotation of one of said parts.
  • Apparatus for testing earth formation conditions in a well bore containing well fiuids comprising: packingoff means dependently coupled .to tester means, said packing-off means being arranged to selectively isolate a section of the well bore from the well uid therein, said tester means having telescopically arranged members adapted for coupling between a string of pipe and said packing-off means and longitudinally movable between contracted and expanded positions, valve means in said tester means for selectively opening said tester means to Huid flow in one of said positions and closing said tester means to fiuid ow in the other of said positions, one of said tester members having relatively rotatable parts, said parts and said other members respectively having abutment means providing at least two longitudinal positions of butment, and means interacting between one of said parts and said other tester member for selectively positioning said abutment means in said positions.
  • Apparatus for testing earth formation conditions in a well bore containing well fluids comprising: packingoff means dependently coupled to tester means, said packing-off means being arranged to selectively isolate a section of the well bore from the well fluid therein by the application of a downward force, said tester means having telescopically arranged members adapted for coupling between the string of pipe and said packing-off means and longitudinally movable between contracted and expanded positions, valve means in said tester means for selectively opening said tester means to liuid ⁇ flow in one of said positions and closing said tester means to fluid flow in the other of ⁇ said positions, one ⁇ of said tester members having relatively rotatable parts, said .parts and said other members respectively having abutment means providing at least two longitudinal positions of abutment, indexing means interacting between said parts and said other tester member for selectively positioning said abutment means in said positions whereby downward force can be applied in each of said positions, and means for delaying telescopic movement of said tester members to a position opening said valve
  • Apparatus in a well bore containing well liuid for flow testing the well including: telescopically arranged tester members movable between spaced longitudinal positions, valve means in said tester members for controlling flow through said tester members in said positions, packer means including telescopically mounted members, and a packer element disposed on one of said packer members and arranged to be expanded by relative motion betweenv'said telescoping packer members, means for releasably holding said telescopic packer members against movement when said packer element is expanded, by-pass valve means intermediate said tester -members and said packer members providing a fiuid communication path between the annular spaces in s-aid well bore above and below said packer means, said by-pass means further including teles-copically arranged tubular members movable between expanded and contracted positions, means for delaying the movement of said lby-pass members to a position wherein said fluid communication path is provided, and safety joint means operable in response to manipulation of the string of pipe.
  • a well tool for use in a well bore a first tubular member having ya bore therein, a second tubular member having a longitudinal opening therethrough and slidably received for telescoping movement within said first tubular member lbetween at least two longitudinal relative positions, removable closure means in one of said members for dividing said bore and longitudinal opening into an upper and lower passageway, means for limiting relative movement between said members in said at least two positions so that forces on one of said members can be transmitted to the other of said members in each of said relative positions, valve means in said members operative for connecting said upper and lower passageways in one of said positions to permit uids to flow from one of said passageways to the other of said passageways and operative in another of said positions for closing said passageways from fiuid communication with one another, and shear release means connecting said closure means to said one of said members so that said closure means can be forceably removed by dropping a weighted member through the inner tubular member to provide said members with a longitudinal access passageway therethrough.
  • a well tool for use in a well bore a first tubular member, a second tubular member having a longitudinal opening therethrough and slidably received for telescoping movement within said first tubular member, barrier means in one of said members dividing said longitudinal opening through said member into an upper and lower passageway, means on said members for limiting relative movement between said members for at least two longitudinal positions, said means including spaced abutment means arranged for engagement in spaced longitudinal positions for ltransmitting downward forces in said longitudinal positions, Valve means in said members operative for connecting said upper and lower passageways in one senses?

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Sampling And Sample Adjustment (AREA)
  • Pipe Accessories (AREA)
  • Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
US333225A 1963-12-24 1963-12-24 Well tester Expired - Lifetime US3308887A (en)

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US333225A US3308887A (en) 1963-12-24 1963-12-24 Well tester
DE19641433202 DE1433202B1 (de) 1963-12-24 1964-12-21 Vorrichtung zum Untersuchen von Erdformationen in Spuelung enthaltenden Bohrloechern
ES0307483A ES307483A1 (es) 1963-12-24 1964-12-23 Un aparato para examinar formaciones terrestres.

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Cited By (21)

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US3358755A (en) * 1965-07-27 1967-12-19 Halliburton Co Multiple closed in pressure sampling apparatus and method
US3442328A (en) * 1967-12-11 1969-05-06 Schlumberger Technology Corp Well tool valve actuators
US3442327A (en) * 1967-12-11 1969-05-06 Schlumberger Technology Corp Well tool valve actuators
US3446280A (en) * 1967-10-26 1969-05-27 Schlumberger Technology Corp Actuating means for well tools
US3494419A (en) * 1968-04-24 1970-02-10 Schlumberger Technology Corp Selectively-operable well tools
US3499487A (en) * 1966-12-23 1970-03-10 Halliburton Co Well tool with hydraulic impedance mechanism
US3552492A (en) * 1969-07-23 1971-01-05 Schlumberger Technology Corp Well tool safety joint
DE2126916A1 (de) * 1970-06-01 1971-12-16 Schlumberger Technology Corp., New York, N.Y. (V.St.A.) Bohrlochprüfgerät
US4320800A (en) * 1979-12-14 1982-03-23 Schlumberger Technology Corporation Inflatable packer drill stem testing system
US4408485A (en) * 1981-06-22 1983-10-11 Schlumberger Technology Corporation Rotary straddle tester apparatus with safety joint back-off clutch
US4553598A (en) * 1981-08-06 1985-11-19 Schlumberger Technology Corporation Full bore sampler valve apparatus
US4597439A (en) * 1985-07-26 1986-07-01 Schlumberger Technology Corporation Full-bore sample-collecting apparatus
US5622223A (en) * 1995-09-01 1997-04-22 Haliburton Company Apparatus and method for retrieving formation fluid samples utilizing differential pressure measurements
US5741962A (en) * 1996-04-05 1998-04-21 Halliburton Energy Services, Inc. Apparatus and method for analyzing a retrieving formation fluid utilizing acoustic measurements
US5934374A (en) * 1996-08-01 1999-08-10 Halliburton Energy Services, Inc. Formation tester with improved sample collection system
US20100206579A1 (en) * 2009-02-19 2010-08-19 Schlumberger Technology Corporation Fail as is mechanism and method
US20110017448A1 (en) * 2008-01-11 2011-01-27 Douglas Pipchuk Zonal testing with the use of coiled tubing
US20120181021A1 (en) * 2011-01-14 2012-07-19 Paul David Ringgenberg Rotational test valve with tension reset
US8991492B2 (en) 2005-09-01 2015-03-31 Schlumberger Technology Corporation Methods, systems and apparatus for coiled tubing testing
US9428990B2 (en) 2011-01-14 2016-08-30 Halliburton Energy Services, Inc. Rotational wellbore test valve
US10066478B2 (en) 2016-01-07 2018-09-04 Baker Hughes, A Ge Company, Llc Indicating apparatus, system, and method

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Publication number Priority date Publication date Assignee Title
US3358755A (en) * 1965-07-27 1967-12-19 Halliburton Co Multiple closed in pressure sampling apparatus and method
US3499487A (en) * 1966-12-23 1970-03-10 Halliburton Co Well tool with hydraulic impedance mechanism
US3446280A (en) * 1967-10-26 1969-05-27 Schlumberger Technology Corp Actuating means for well tools
US3442328A (en) * 1967-12-11 1969-05-06 Schlumberger Technology Corp Well tool valve actuators
US3442327A (en) * 1967-12-11 1969-05-06 Schlumberger Technology Corp Well tool valve actuators
US3494419A (en) * 1968-04-24 1970-02-10 Schlumberger Technology Corp Selectively-operable well tools
US3552492A (en) * 1969-07-23 1971-01-05 Schlumberger Technology Corp Well tool safety joint
DE2126916A1 (de) * 1970-06-01 1971-12-16 Schlumberger Technology Corp., New York, N.Y. (V.St.A.) Bohrlochprüfgerät
FR2093947A1 (de) * 1970-06-01 1972-02-04 Schlumberger Technology Corp
US4320800A (en) * 1979-12-14 1982-03-23 Schlumberger Technology Corporation Inflatable packer drill stem testing system
US4408485A (en) * 1981-06-22 1983-10-11 Schlumberger Technology Corporation Rotary straddle tester apparatus with safety joint back-off clutch
US4553598A (en) * 1981-08-06 1985-11-19 Schlumberger Technology Corporation Full bore sampler valve apparatus
EP0210110A3 (en) * 1985-07-26 1988-10-05 Schlumberger Technology Corporation Full-bore sample-collecting apparatus
EP0210110A2 (de) * 1985-07-26 1987-01-28 Schlumberger Technology Corporation Vorrichtung zur Entnahme von Proben mit hindernisfreiem Kanal
US4597439A (en) * 1985-07-26 1986-07-01 Schlumberger Technology Corporation Full-bore sample-collecting apparatus
US5622223A (en) * 1995-09-01 1997-04-22 Haliburton Company Apparatus and method for retrieving formation fluid samples utilizing differential pressure measurements
US5741962A (en) * 1996-04-05 1998-04-21 Halliburton Energy Services, Inc. Apparatus and method for analyzing a retrieving formation fluid utilizing acoustic measurements
US5934374A (en) * 1996-08-01 1999-08-10 Halliburton Energy Services, Inc. Formation tester with improved sample collection system
US8991492B2 (en) 2005-09-01 2015-03-31 Schlumberger Technology Corporation Methods, systems and apparatus for coiled tubing testing
US20110017448A1 (en) * 2008-01-11 2011-01-27 Douglas Pipchuk Zonal testing with the use of coiled tubing
US8763694B2 (en) 2008-01-11 2014-07-01 Schlumberger Technology Corporation Zonal testing with the use of coiled tubing
US9581017B2 (en) 2008-01-11 2017-02-28 Schlumberger Technology Corporation Zonal testing with the use of coiled tubing
US8256518B2 (en) 2009-02-19 2012-09-04 Schlumberger Technology Corporation Fail as is mechanism and method
US20100206579A1 (en) * 2009-02-19 2010-08-19 Schlumberger Technology Corporation Fail as is mechanism and method
US20120181021A1 (en) * 2011-01-14 2012-07-19 Paul David Ringgenberg Rotational test valve with tension reset
CN103299027A (zh) * 2011-01-14 2013-09-11 哈利伯顿能源服务公司 具有张力复位的旋转测试阀
US8662180B2 (en) * 2011-01-14 2014-03-04 Halliburton Energy Services, Inc. Rotational test valve with tension reset
CN103299027B (zh) * 2011-01-14 2016-03-16 哈利伯顿能源服务公司 具有张力复位的旋转测试阀
AU2012205356B2 (en) * 2011-01-14 2016-07-21 Halliburton Energy Services, Inc. Rotational test valve with tension reset
US9428990B2 (en) 2011-01-14 2016-08-30 Halliburton Energy Services, Inc. Rotational wellbore test valve
US10066478B2 (en) 2016-01-07 2018-09-04 Baker Hughes, A Ge Company, Llc Indicating apparatus, system, and method

Also Published As

Publication number Publication date
DE1433202B1 (de) 1970-03-19
ES307483A1 (es) 1965-05-01

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