EA046397B1 - SYSTEM PULSATION DAMPENER DEVICE(S) FOR REPLACEMENT OF PULSATION DAMPENERS USING COMPRESSIVE MATERIAL - Google Patents

Description

Technical field

In general, the invention relates to the operation of systems designed for the reciprocating movement of fluid, and more particularly, to one or more products and/or devices for controlling pulsations after fluid flow aggregation systems, for example between an injection manifold and a riser, or after the consolidation of multiple flows fluid, and before connecting to the top drive or swivel in the drilling rig, and/or other non-traditional locations for pulsation dampers.

State of the art

Pulsation control in fluid transfer systems is constantly in need of improvement. Desirable improvements include reducing pump pulsation amplitudes for the downstream system and increasing flexibility in integrating pulsation dampers with other elements of the overall pumping system.

The essence of the invention

The fluid delivery system includes a surge damper coupled between the discharge manifold and the riser, either within the riser, or after consolidation of multiple fluid flows, or at other locations along the fluid flow path after the riser or consolidation, but (preferably) before the fluid enters the upper drive or swivel. Alone or in combination, these system pulsation dampeners are located at non-traditional locations along the fluid flow path, but can be used in conjunction with a primary or conventional pulsation dampener at the outlet of the mud pump, typically functioning as an additional pulsation dampening device(s). Alternatively, one or more system pulsation dampening devices may be used in place of the pulsation damper typically located at the outlet of the mud pump. In a simplified form, the system ripple dampening device(s) may be a resistive opening (eg, a diaphragm). Alternatively, the system pulsation damping device(s) may be a resistive orifice associated with a volume of fluid.

According to some embodiments, a fluid delivery system is provided including a system surge suppressor coupled between a discharge manifold and a riser. The system includes a fluid reservoir, fluid pump, manifold, system surge suppressor and piping. The fluid reservoir stores the fluid used in the drilling operation. The fluid pump pumps fluid from the fluid reservoir through the fluid supply system. The manifold is located downstream of the fluid pump and receives and combines fluids from one or more fluid pumps. The system pulsation damper accepts the combined fluid from the manifold and dampens residual pulsations from the manifold. The conduit receives the release of fluid from the system surge suppressor and moves the fluid received from the system surge suppressor further downstream.

In other embodiments, a fluid delivery system is provided including a system surge damper coupled downstream of fittings combining multiple fluid streams into a single stream. The system includes fittings that combine multiple fluid streams into one fluid stream, a system surge suppressor, and piping. The fluid pump pumps fluid from the fluid reservoir through the fluid supply system. The fluid flow is combined by fittings located downstream of the fluid pump, which together receive and combine fluid from one or more fluid pumps. The system pulsation damper receives the combined fluid flow and dampens residual pulsations. The piping receives the fluid outlet from the surge damper and moves the fluid received from the system surge damper further downstream.

In other embodiments, the fluid delivery system includes one or more system surge dampers in a fluid flow path within and/or downstream of a riser or downstream of fluid flow combining fittings, and in some embodiments, as close as possible to the top drive or swivel of the drilling rig , namely, to the top drive or swivel, or the inlet pipe of the top drive or swivel. One or more system surge suppressors typically function as additional surge suppressors in addition to the primary surge suppressor at the outlet of the mud pump and/or a surge suppressor between the injection manifold and the riser or downstream of fluid flow combining fittings. Therefore, the system may include some combination of (a) a main pulsation damper at the outlet of the mud pump, (b) a pulsation damper between the injection manifold and the riser or downstream of fittings combining fluid flows, and in embodiments with the riser and injection manifold (c) one or several pulsation dampers in the fluid flow path within and/or downstream of the riser.

In some preferred embodiments, the presence of a system pulsation damper eliminates the need to replenish the gas-filled pulsation damper or replace the compression material in commercially available filler-free pulse dampers.

- 1,046,397 tions.

Before reviewing the detailed description below, it may be useful to clarify the definitions of certain words and phrases used throughout this patent document. The terms include and contains, as well as their derivatives, mean inclusion without limitation, the term or is inclusive, meaning and/or, and the phrases associated with and associated with it, as well as their derivatives, can mean contain, be included in, connect with, contain, enter into, connect with, connect with, communicate with, interact with, alternate with, be placed next to, near, be associated with, have, have a property, etc. With regard to the definitions of certain words and phrases presented throughout this patent document, one skilled in the art will understand that in many cases, if not most cases, such definitions are used in the prior art, and the use of such certain words and phrases in the future.

Brief description of drawings

In order to more fully understand the present disclosure and the advantages thereof, reference will now be made to the following description taken in conjunction with the accompanying drawings, in which:

fig. 1 is a schematic view of a drilling system including a surge damper mounted between an injection manifold and a riser, in accordance with various embodiments of the present disclosure;

fig. 2 is a schematic view of a portion of a fluid delivery, drilling, or both system that includes a plurality of mud pumps, according to various embodiments of the present disclosure, that may be used in embodiments of a drilling system that includes a system surge damper. installed between the discharge manifold and the riser, as shown in FIG. 1;

fig. 3 is a schematic view of a portion of a system for fluid delivery, drilling, or both, including a combination of an injection manifold and a surge damper in one system device, the injection manifold system damper according to various embodiments of the present disclosure, which may also be used in embodiments of a drilling system; which includes a system pulsation damper installed between the mud pump(s) and the riser, as shown in FIG. 1;

fig. 4 is an illustration of one combination of a pressure manifold and a system surge damper according to various embodiments of the present disclosure;

fig. 5 is a schematic view of a drilling system including another surge dampening mechanism that may be installed in, adjacent to, or downstream of a riser, in accordance with various embodiments of the present disclosure;

fig. 6A-6E are enlarged schematic views of various designs of system pulsation dampening device(s) implementing the ripple damping portion(s) of the diaphragm assembly of FIG. 6, used as a system ripple dampening device(s);

fig. 7 is a schematic view of another redundant design of system pulsation dampening device(s) that may be installed in, adjacent to, or downstream of a riser, in accordance with various embodiments of the present disclosure, for implementing part(s) of the pulsation damping diaphragm assembly from fig. 5;

fig. 8 is a schematic view of a fluid delivery system or drilling system including fittings integrating multiple fluid flows, according to various embodiments of the present disclosure, which may also be used in embodiments of a drilling system that includes a system surge damper installed downstream of the multiple fluid flow fittings. fluid flows;

fig. 9 is a high-level flow diagram of a fluid supply and pulsation damping process in a fluid supply system according to various embodiments of the present disclosure;

fig. 10A-10C - types of gas-filled pulsation damper;

fig. 11A-11B illustrate components of a commercially available filler-free pulsation damper;

fig. 12A-12B are cutaway views and schematic views, respectively, of a maintenance-free reactive system surge damper according to embodiments of the present disclosure; and figs. 13 is a view illustrating the placement of a system ripple damper according to embodiments of the present disclosure.

Detailed description

Fig. 1-13 are discussed below, but the various embodiments used to describe the principles of the present disclosure in this document are presented for illustration purposes only and should in no way be construed as limiting the scope of the disclosure. Specialists in this

It will be appreciated by those in the art that the principles of the present disclosure can be implemented in any suitably configured discharge manifold damper or system damper that can be used to control or partially control pulsation amplitudes.

Reciprocating systems, such as reciprocating pumping systems and similar equipment, function in various types of cyclic hydraulic systems. For example, reciprocating mud pumping systems are used on a drilling rig to circulate drilling mud or drilling fluid. Pressure peaks in the pumped fluid increase with each pulsation, deterioration of the pump, fluid pump consumables, and equipment downstream of the pump, such as the measurement equipment used to determine drilling parameters, and the swivel mud pipe and mud pipe packing. Failure to regulate such pressure peaks will inevitably impact the performance and life of the pump, fluid pump consumables, and all upstream and downstream components. In addition, pressure peaks can interfere with signal detection by instruments, so that misalignment of pressure peaks can also affect signal detection and/or the quality of signal detection in (for example) drilling measurements.

Pulsation control equipment is typically placed directly upstream or downstream of the reciprocating pump, often having a relative size and configuration corresponding to the target volume moved per pump stroke and the maximum allocated amplitude of pressure peaks to which the pumping system may be subjected. during each pulsation. By doing so, pulsation control equipment helps reduce pump load and minimize the impact of pulsation amplitudes on the pump, pump fluid consumables, and upstream and downstream equipment. As a result, pulsation control equipment improves the performance and life of the pump, fluid pump consumables, and any equipment upstream or downstream of the pump.

However, pulsations can also occur further downstream of the mud pumps as the fluid moves through the pipeline to its intended location. These pulsations may increase when it becomes necessary to direct fluid down different paths or when multiple streams of fluid must be combined and directed into a single stream. In most systems, these downstream pulsations are not taken into account. These downstream pulsations can cause damage to downstream components and increased noise in downstream instruments and sensors.

As used herein, the term system pulsation damper refers to the pulsation damper installed between the discharge manifold and the riser shown in FIG. 1 and 2, the combination of the discharge manifold and pulsation damping device shown in FIG. 3, the pulse damper manifold shown in FIG. 4, the pulsation dampening device(s) with a diaphragm assembly shown in FIG. 5, 6 and 7, and a system pulsation control damper located after the point where discharges from multiple pumps are consolidated into a single stream, shown in FIG. 8.

In fig. 1 is a schematic view of a drilling system 100 including a surge damper 102 mounted between an injection manifold 104 and a riser 106, in accordance with various embodiments of the present disclosure. An embodiment of the drilling system 100 is shown in FIG. 1 is for illustration purposes only. Fig. 1 does not limit the scope of this disclosure to any particular implementation of a drilling system.

Now regarding FIG. 1, the drilling system 100 includes at least one surge damper 102, at least one injection manifold 104, at least one riser 106, at least one mud pump 108, and at least one drilling fluid reservoir 110. fluid and at least one flow line 112, a surge damper 113 conventionally located at the outlet of the drilling fluid pump 108, and at least one drilling rig 114. The drilling system 100 performs the operation of pumping drilling fluid or other fluids down into the drilled area. at this point, the well to protect the drill bit 128 from overheating, ensure lubrication of the drill bit and move cuttings to the surface.

A fluid pump or mud pump 108 may pump fluid or mud from the mud tank 110 through a flow line 112 toward the drilling rig 114. The drilling system 100 may use multiple mud pumps 108 to continue drilling in the event of a failure. one pump 108 for drilling fluid. In addition, a pulsation damper 102 may be installed in the flow line 112 of each mud pump 108 to further reduce pulsations. In addition, the drilling fluid reservoir 110 may be referred to as a fluid reservoir, wherein the fluid reservoir stores fluid used during the drilling process.

Typically, the pulsation damper 113 is located along the flow line 112 at the outlet of the pump 108

- 3 046397 for drilling fluid and upstream of the injection manifold 104. The injection manifold 104 may be located below the flow line 112 and attached and/or coupled to the drilling rig 114 to allow fluid transfer. The injection manifold 104 can receive a variety of different fluid flows from a variety of mud pumps 108. In such a case, the injection manifold 104 may combine all fluid flows to direct one fluid flow upward to the riser 106. Other functions traditionally performed by the injection manifold are to provide an auxiliary connection for an additional pump, and in systems with multiple risers having operational redundancy, switching fluid flow paths from one riser to another in the event of damage to one riser. However, it will be appreciated by those skilled in the art that some systems dispense with the injection manifold and simply combine the output streams of multiple mud pumps into one line near or downstream of the mud pumps, and then move the combined flow along one line. to the base and up to the riser.

When fluid flows from multiple mud pumps are combined (with or without a pressure manifold), pulsations in the resulting combined fluid flow may increase due to the varying pulsations generated by the mud pumps 108 being used. For example, one drilling system 100 may use different types and sizes of mud pumps 108 that create variations or pulsations in fluid flow along the pipe. In addition, the mud pumps 108 may be located at different distances from the injection manifold 104. The mud pumps 108 may start at different times, have a different off-cycle than other mud pumps 108, or they can simply work with different piston stroke lengths. Any of the previously mentioned operating parameters affect the flow of fluids or drilling fluid into the injection manifold 104, resulting in pulsations in the wellbore.

The riser 106 may be mounted on the drilling rig 114 and extend upward on the drilling rig 114 to allow fluid to flow through a rotary hose 116 connected to a swivel 118, the swivel 118 being connected to a rotary hook 120. The riser 106 receives an outlet from a discharge manifold that includes includes a system pulsation damper 102. The injection manifold 104 may include multiple outlets to the riser 106 in the event of damage to a portion of the injection manifold 104 or associated piping.

The swivel 118 may function as a bypass for fluid flow into the kelly liner 122 (or more accurately, into the kelly). The kelly 122 is connected to the drill string 124. Fluid flows through the kelly 122 and drill string 124, down the wellbore 126 to a drill bit 128 located at the distal end of the drill string 124. The kelly 122 is typically driven by rotary table 130. More modern systems may include a top drive for rotating the drill string 124 as an alternative to a rotary table and liner for rotating the kelly, and the present disclosure can also be used in such top drive configurations.

In drilling systems, pulsation dampers 113 may be installed near mud pumps 108 to reduce pump loads and minimize pulsation amplitudes from mud pumps 108. However, when fluid is combined in injection manifold 104 into a single stream and directed to riser 106, significant energy and pulsation amplitudes can be created by combining flows from mud pumps 108 or by moving flow directly to riser 106, which then moves to the rest of the system. , located downstream, described in this application. The amplitudes of the generated pulsations can be greater as more mud pumps 108 are used to ensure fluid reaches the injection manifold 104, as pulsations from multiple pipes receiving fluid from the multiple mud pumps 108 combine and accumulate in the injection manifold, and then they are carried into the riser 106. These pulsations can cause wear and damage to components, including connections near the swivel 118, the drive pipe 122, and other components such as the swivel solution pipe, which functions as a conduit for fluid flowing through the swivel 118, and packing (seals) for the mortar pipe (both not shown). Instruments used to monitor and measure drilling operating parameters may also be damaged by residual pulsations from the mud pump 108. Even the slightest pulsation from the discharge manifold can distort the measurement values.

Therefore, an additional system pulsation damper 102 is installed between the injection manifold 104 and the riser 106 to reduce residual pulsations from the mud pump 108 and to reduce pulsations resulting from the pooling of fluid flows in the injection manifold 104. The system pulsation damper 102 reduces pulsations and is similar to a conventional The pulsation damper 113 and any other system pulsation damping device(s) described in this application may create a drop in internal or external pressure in the passing fluid to further reduce high frequency pulsations and improve overall performance.

- 4 046397 extinction characteristics. In some embodiments, the system pulsation damper 102 may be a gas-filled damper. Like a conventional pulsation damper 113 and any other system pulsation dampening device(s) described herein, the system pulsation damper 102 may be a hydropneumatic or gas-filled high-pressure vessel containing compressed air or nitrogen and a chamber (or membrane box) that separates the process fluid. fluid from gas filling. Like the conventional pulsation damper 113 and any other system pulsation dampening device(s) described herein, in some embodiments the system pulsation damper 102 may be a spherical or cylindrical flow damper. In some embodiments, reactive dampers may be used that rely on the compressibility of the process fluid contained in the damper shell and a resistive device matched to or integrated with the pulsation damper to dampen pump pulsations.

The system pulsation damper 102 may be connected to the discharge manifold 104 via a connecting hose. System surge suppressor 102 may have a flanged outlet connection, and a quick connect adapter flange may be used to connect surge suppressor 102 to discharge manifold 104. Additionally, system surge suppressor 102 may be coupled to riser 106 via a connecting hose.

The system pulsation damper 102, located in front of the riser 106, reduces the amplitudes of both low-frequency and high-frequency pulsations, allowing the swivel grout pipe and packing, as well as other components, to last longer. In addition, the system pulsation damper 102 reduces noise and pulsation levels, making signals easier to detect by the operator on the rig 114 performing measurements while drilling (MWD) and logging while drilling (LWD). In addition, the system pulsation damper 102 helps reduce downhole tool interference, which can pick up residual pulsations that impair detection and distort downhole tool data.

In fig. 2 is a schematic view of a portion 200 of a system for fluid delivery, drilling, or both, including a plurality of mud pumps 208, according to various embodiments of the present disclosure, which may be used in embodiments of the drilling system 100 shown in FIG. 1, including a system pulsation damper 102 installed between the discharge manifold 104 and the riser 106. That is, except for the replacement of components from FIG. 1 by their counterparts shown in FIG. 2, the rest of the drilling system of the embodiments of FIG. 2 can be coordinated with additional structures shown in FIG. 1. An embodiment of a drilling system portion 200 is shown in FIG. 2 is for illustration purposes only. Fig. 2 does not limit the scope of this disclosure to any particular implementation of a drilling system.

Regarding FIG. 2, the drilling and/or fluid delivery system portion 200 for supplying fluid, drilling, or both includes at least one system surge damper 202, at least one injection manifold 204, at least one riser 206 and a plurality of mud pumps 208. Components of the drilling system portion 200 may be used in place of similar components of the drilling system 100 shown in FIG. 1.

A system pulsation damper 202 is installed between the injection manifold 204 and the riser 206. A plurality of drilling fluid pumps 208 can simultaneously move fluid into the injection manifold 204, creating vibrations in the injection manifold 204. The pulsation damper 202 can be installed in a similar manner as described in this application, corresponding a method for installing a pulsation damper 102 to attenuate the pulsations generated by the plurality of mud pumps 208 as fluid streams enter, intersect, and combine into a single output stream at the injection manifold 204.

In fig. 3 is a schematic view of a portion 300 of a system for fluid delivery, drilling, or both, including a combination injection manifold and surge damper device 302, according to various embodiments of the present disclosure, which may also be used in embodiments of a drilling system 100 that includes itself is a pulsation damper 102 installed between the mud pump(s) and the riser, as shown in FIG. 1. That is, with the exception of replacing the components from FIG. 1 by their counterparts shown in FIG. 3, the rest of the drilling system of the embodiments of FIG. 3 can be coordinated with additional structures shown in FIG. 1. An embodiment of a drilling system portion 300 is shown in FIG. 3 is for illustration purposes only. Fig. 3 does not limit the scope of this disclosure to any particular implementation of a drilling system.

Now regarding FIG. 3, the drilling and/or fluid delivery system portion 300 includes at least one combination injection manifold and surge damper device 302, a plurality of mud pumps 304, and at least one riser 306.

Injection manifolds can increase the pulsation experienced by the drilling system due to the fact that injection manifolds typically have connections or piping that

- 5 046397 accepts fluid from multiple directions from various mud pumps. Injection manifolds often have angular bends through which each fluid stream must pass before the injection manifold combines the individual streams into a single stream. As fluid enters the manifold and moves along bends in the discharge manifold, additional vibrations can be generated.

A combination pressure manifold and pulsation damper device 302 may be used in place of the pressure manifold. Instead of combining separate fluid streams into a single stream in the case of tight bends, the fluids can be placed in the housing of the combined injection manifold and surge damper device 302, where they can be manipulated. Pulsation dampers often have a volume of space, or reservoir, in the damper in which some fluid can accumulate and the pulsations can be reduced before moving out of the pulsation damper. The combined injection manifold and surge damper device 302 can receive individual fluid streams from a plurality of mud pumps 304. The pressure manifold and pulsation damper combination device 302 may have a conduit installed on the outer surface of the pressure manifold and pulsation damper combination device 302. In the case of a spherical type or a cylindrical type pulsation dampener, the piping may be mounted at a selected location on a spherical or cylindrical pulsation damper body. Fluid received at the pressure manifold/pulse damper combination device 302 may be deposited in the internal volume of the pressure manifold/pulse damper combination device 302, and fluid present in the internal volume of the pressure manifold/pulse damper combination device 302 will exit the pressure manifold/pulse damper combination device 302. pulsation damper device 302 to move into riser 306. Combining a discharge manifold and pulsation damper device 302, various receiving fluids can be combined to control pulsations to reduce them in combination with, for example, rotation of the fluids in the chamber.

Since the combination pressure manifold and pulsation damper device 302 includes an internal volume, problems associated with the use of the pressure manifold can be eliminated. The discharge manifold/pulsation damper combination device 302 eliminates the kinks associated with a pressure manifold, thereby reducing vibrations generated when individual fluid flows intersect, and the pressure manifold/pulsation damper combination device 302 provides pulsation damping effects when receiving individual fluid streams. . Therefore, individual fluid streams may be combined within the volume of the pressure manifold/pulse damper combination device 302 and then one combined stream may be released from the pressure manifold/pulse damper combination device 302 to move into the riser 306, with reduced or minimal energy being transferred to the riser 306 and into other downstream components.

In fig. 4 illustrates a pressure manifold/pulse damper combination device 400 according to various embodiments of the present disclosure, which may be used in embodiments of a drilling system 100 that includes a surge damper 102 mounted between the mud pump(s) and the riser, as this shown in Fig. 1-3, or in embodiments of the drilling system 100 that includes a surge damper 302 located downstream of multiple fluid flow fittings, as shown in FIG. 8. An embodiment of a combination discharge manifold and surge damper device 400 is shown in FIG. 4 is for illustration purposes only. Fig. 4 does not limit the scope of this disclosure to any particular ripple damper implementation or ripple damper method.

Now regarding FIG. 4, the combination discharge manifold and pulsation damper device 400 can be used in the systems 100, 200 and 300 described in this application. The ripple damper manifold includes a housing 402. The housing 402 shown in FIG. 4 is a spherical or cylindrical body corresponding to various pulse absorbers having a spherical or cylindrical body. However, it is possible to use a body having other shapes to have different shapes of the ripple damper body, such as those shown in FIG. 1-3.

In addition, the surge damper manifold 400 may include a reservoir 404 in the interior of the housing 402. The reservoir 404 may collect a volume of fluid 406 from upstream mud or fluid pumps passing through a plurality of upstream connections 408 in a fluid delivery system or to a drilling system, such as the systems described with respect to FIGS. 1-3. The fluid received from the upstream connections 408 is combined into a fluid volume 406. At least a portion of the fluid volume 406 can then exit the surge damper manifold 400 as a single fluid stream through the downstream connection 410. Thus, combining the discharge manifold and the pulsation damper device 400 can completely replace the discharge manifold, reducing vibrations caused by multiple fluid streams passing through the discharge manifold and providing pulsation dampening for all flows entering the combined pressure manifold and pulsation damper device 400.

- 6 046397

In fig. 5 is a schematic view of a drilling system including an alternative system surge damper mechanism(s) that may be installed in, adjacent to, or downstream of the riser, in accordance with various embodiments of the present disclosure. An embodiment of drilling systems 500 is shown in FIG. 5 is for illustration purposes only. Fig. 5 does not limit the scope of this disclosure to any particular implementation of a drilling system. Although in FIG. 5 does not show a conventional surge damper located at the outlet of the mud pump(s), or a system surge damper between the discharge manifold and the riser, those skilled in the art will recognize that one or more system surge dampers not schematically shown in FIG. 5 may be used without such conventional pulsation dampers, or both such conventional and system pulsation dampers may be used.

In the system of FIG. 5, pulsation damping is provided or enhanced by several different types of diaphragm structures located at one location or multiple locations in or near the riser 506, or in the fluid flow path downstream of the riser. One or more diaphragm assemblies 502a, 502b, 502c, 502d._. 502n, each containing system pulsation dampening device(s), may be located at various locations along the fluid flow path. The pulsation dampening diaphragm assembly may be located in the inlet pipe or connected to the inlet pipe of the top drive or swivel (depending on what is used in the rig), as illustrated by the diaphragm assembly 502a. The pulsation dampening diaphragm assembly may be located between the hose 516 and the end of the top drive or swivel inlet pipe, as illustrated by the diaphragm assembly 502b. The pulsation damping diaphragm assembly may be located immediately downstream of the riser 506, between the end of the riser 506 and the beginning of a hose 516 that connects the riser 506 to the top drive or swivel (depending on what is used on the rig), as illustrated by the diaphragm assembly 502c. . Alternatively, the pulsation dampening diaphragm assembly may be located further along the hose/pipe system, as illustrated by diaphragm assembly 502d. In yet another case, the pulsation dampening diaphragm assembly may be located in the derrick side riser 506, possibly at or near one end of the riser 506 (although it may be located anywhere along the length of the riser 506), as this illustrated by diaphragm assembly 502n. A single pulsation-damping diaphragm assembly may be used, or multiple pulsation-damping diaphragm assemblies may be used at various locations along the fluid flow path, including one of the locations shown in FIG. 5, or multiple pulsation dampening diaphragm assemblies may be used in the top drive or swivel inlet pipe (in the area of the diaphragm assembly 502a), between the hose and the top drive or swivel inlet pipe (in the area of the diaphragm assembly 502b), between the riser 506 and the hose 516 ( in the area of the diaphragm assembly 502c), multiple pulsation-damping diaphragm assemblies in the hose 516 (in the area of the diaphragm assembly 502d), and/or multiple pulsation-damping diaphragm assemblies in the riser 506 (in the area of the diaphragm assembly 502n). Those skilled in the art will recognize that varying amounts and locations of pulsation damping diaphragm assemblies may be suitable for different applications. In addition, the pulsation dampening diaphragm assemblies may be located at locations other than those shown in FIG. 5, such as the end (outlet) of the riser or at the connection with the swivel or top drive in the case of a hose connected to the riser. As noted above, each pulsation damping diaphragm assembly can create an internal or external pressure drop in the passing fluid to enhance high frequency pulsation damping. These diaphragm assemblies may or may not include fluid volumes to further improve performance.

In one preferred embodiment, the system pulsation damper eliminates the need to replenish the gas-filled pulsation damper or replace the compression material in commercially available filler-free pulsation dampers. In system 500, gas-filled pulsation damper 501 has at least a housing 1001 and a cover 1002 and is shown in FIG. 10A-10C. It is noteworthy that gas-filled pulsation dampers are typically located above the conduit through which the pumped fluid passes when using a cross, although this path for the system pulsation damper 501 in FIG. 5 not shown. A cross section of a gas-filled pulsation damper is shown in FIG. 10A-10C. As shown in FIG. 10A, the gas-filled pulsation damper 1000 includes a housing body 1001 having an upper opening covered by a cover 1002, which together define an internal cavity 1003 connected to the pump system fluid conduit (not shown) through a lower opening 1004. A flexible inner chamber 1005 in the internal cavity 1003 is filled with compressible gas. Fluid from the attached conduit enters and/or leaves the cavity 1003 through the lower opening 1004. The pressure of this fluid and the pressure of the compressible gas in the chamber 1005 causes the lower surface of the chamber 1005, which is in contact with the fluid of the pumping system, to shear and the volume occupied by the gas in chamber 1005, changes. The high pressure of the pumped fluid causes the chamber 1005 and the gas in it to be strongly compressed to a smaller volume, while in the medium pressure range or when moving from high pressure to low pressure, the chamber and the gas in it are caused to expand to a larger volume, and at low pressure - 7 046397 In this case, the chamber 1005 and the gas therein will expand greatly to the maximum volume allowed by the internal cavity 1003 of the housing body 1001 and the cover 1002. Therefore, the compressed gas in the chamber 1005 absorbs the pressure pulses in the pump fluid and reduces the peak pressure that may occur. However, compressed gas should be refilled periodically (for example, monthly, bimonthly, quarterly, or semiannually). Regarding FIG. 5, instead of replenishing chamber 1005, chamber 1005 is simply removed. One or more system pulsation dampers are installed at this location(s) in the manner discussed above, eliminating the need for gas-filled pulsation damper 501 and its additional maintenance. In many, if not most, cases, ripple damping performance can be improved by such a replacement.

Alternatively, at least one housing 1001 of a commercially available filler-free pulsation dampener 501 of the type shown in FIG. 11A and 11B. Again, unfilled surge dampers are typically positioned above the flow line of the pumped fluid, although this path for system surge damper 501 in FIG. 5 not shown. Filler-free pulsation dampers are often not as effective at reducing pressure pulsations as gas-filled pulsation dampers. The components of commercially available filler-free pulsation dampeners are shown in FIG. 11A and 11B. In the ripple damper shown in FIG. 11A and 11B, the gas-filled chamber is not used. As shown in FIG. 11A, the filler-free surge damper includes a housing 1100. The housing has a removable top portion with inlets and outlets for fluid passage into and out of the housing. Cell 1101, shown (twice) in FIG. 11B is suspended in the housing and has a top projection that is sealed against the interior of housing 1100. Cage 1101 includes an open top portion with openings through the side wall and a bottom surface thereof (resulting in forming a “cage” or basket). Cage 1101 holds compression material 1102 located within the cage. The compression material shown in this example contains a multi-layer system of compression disks, each of which is segmented into four quarter wedges. As fluid enters the pulsation damper housing 1100 and passes through the open top and/or openings in the side wall and bottom surface of the cage 1101, the fluid is distributed throughout the compression material, with the pumping system applying pressure to various surfaces of the compression material. , which encourages the material working in compression to compress under the influence of pressure and thereby weaken pressure surges.

However, the filler-free (i.e., does not require replenishment of the gas medium, which is necessary in the case of gas-filled chambers) pulsation damper of FIG. 11A and 11B are maintenance free. After some time in operation (e.g., after 12 months), the compression material 1102 may become clogged and/or distorted by the drilling fluid and typically requires replacement due to loss of elasticity and/or accumulation of solids in the surge damper, necessitating shutdown. pumping system. In addition, the compression material(s) are typically manufactured and selected to operate within a precisely defined or predetermined pressure range. Changes in the system's nominal operating pressure, whether intentional or due to changing operating conditions, may require replacement of the compression material and also shutdown of the pumping system. Regarding FIG. 5, when maintenance of the commercially available filler-free pulsation damper 501 becomes necessary, instead of replacing the compression material 1102, the seal can be replaced with a gasket and the compression material 1102 (and optionally the cage 1101 as well) simply removed. One or more truly maintenance-free system pulsation dampers are installed in the field in the manner discussed above, eliminating the need for a commercially available, filler-free pulsation damper 501 and further maintenance thereof. In many, if not most, cases, the performance of the pulsation damper can be improved by this replacement.

In fig. 6A-6E are side sectional views and cross sections of ripple dampening diaphragm assemblies 502x, which may be used as any one of the diaphragm assemblies 502a, 502b, 502c, 502d and/or 502n to implement one or more system ripple dampening devices. As shown in FIG. 6A, one exemplary pulsation dampening diaphragm assembly 502x includes a slightly larger volume that can be created by (for example) inserting a length of pipe 622 having a larger internal diameter (by only 1-2 inches). .08 cm) larger) than the pipe has for the fluid flow path before or after the pulsation-damping diaphragm assembly. At the end of the enlarged volume is an element that creates resistance to fluid flow or pressure drop, such as a diaphragm or pressure tube. In the example shown in FIG. 6A and 6B, a diaphragm 624 or 626 is provided (see FIG. 6E). However, those skilled in the art will appreciate that a pressure tube may be used instead. In accordance with the prior art, the total area of the openings of the diaphragm 624 or 626 is selected in combination with an increased volume to dampen pulsations in the fluid flow through

- 8 046397 riser 506 and hose 516. As shown in FIG. 6C, a diaphragm 624 or 626 may be located at the opposite end (relative to the direction of fluid flow) of the enlarged volume formed by pipe section 622. Alternatively, the diaphragm 624 or 626 may be located in the middle of the enlarged volume or somewhere in the middle. Numerous diaphragms can be located in one enlarged volume. As shown in FIG. 6D, the simple form pulsation damping diaphragm assembly 502x includes only a diaphragm 624 or 626 that does not provide any resistance to fluid flow created by an adjacent or surrounding enlarged volume in the fluid flow path. As shown in FIG. 6D, the diaphragm 624 may have multiple openings. As shown in FIG. 6E, the ripple dampening diaphragm assembly 502x may include a single hole diaphragm 626. As noted above, diaphragm assemblies may or may not include fluid volumes to further improve performance. In fig. 6A and 6C show an extended portion 622 that may contain a volume of liquid.

In fig. 7 is a schematic view of an alternative redundant design for system pulsation dampening device(s) that may be installed in, adjacent to, or downstream of a riser, in accordance with various embodiments of the present disclosure, to implement the pulsation damping portion(s). diaphragm assembly from Fig. 5. In the embodiment of FIG. 7, the pulsation dampening diaphragm assembly 502x includes a first assembly 701 and a second assembly 702, each of which includes an enlarged volume and a diaphragm that are located on two parallel fluid flow paths along with control valves 703, 704, 705 and 706 (manually operated or automatically) used for control on two flow paths. This design provides redundancy in the event of failure of the pulsation damping diaphragm assembly and can therefore be used as a low flow device in some high flow applications.

In fig. 8 is a schematic view of a fluid delivery system or drilling system 800 including fittings integrating multiple fluid flows, according to various embodiments of the present disclosure, which may also be used in embodiments of a drilling system 100 that includes a surge damper 102 located downstream of the fittings. , combining numerous fluid flows. An embodiment of the drilling system 800 is shown in FIG. 8 is for illustration purposes only. Fig. 8 does not limit the scope of this disclosure to any particular embodiment of the drilling system.

An injection manifold is not always in the path of fluid flow into the rig. On some drilling rigs, fluid streams supplied by different mud pumps are introduced together from simple fittings that combine multiple fluid streams into a single stream. Now regarding FIG. 8, the drilling system 800 includes at least one fitting 802 and/or 804, a plurality of mud pumps 304, and a conduit 806 receiving combined fluid flows.

A system pulsation damper 102, 202, 302, 402, or 502x (system pulsation damper 302 is shown in FIG. 6) may be used in conduit 806 after fittings 802 and/or 804. Pulsation dampers, such as a system pulsation damper 102, 202 , 302, 402 or 502x, often have a volume of space, or reservoir, within the damper in which a certain amount of fluid can be stored and pulsations are reduced before the fluid moves out of the damper. System pulsation damping device 102, 202, 302, 402 or 502x may receive combined fluid flows from the supply of mud pumps. The fluid received by the system pulsation damper device 102, 202, 302, 402, or 502x may be deposited in the internal volume of the pulsation damper 102 or 202, the discharge manifold and pulsation damper combination device 302, the pulsation damper manifold 400, or the pulsation damper device(s). 502x with diaphragm assembly. The fluid contained in the interior of the system pulsation dampening device exits the system pulsation damping device to travel to the drilling rig 114 via conduit 806. The system pulsation damping device may control the pulsations to reduce them in combination with, for example, creating rotation in the chamber.

Since the system pulsation dampening device includes an internal volume, problems associated with the use of a discharge manifold can be eliminated. The system pulsation damping device does not have the bends associated with a discharge manifold, thereby reducing the vibrations generated when the individual flows intersect, and the system pulsation dampening device also produces a pulsation damping effect when it receives the combined fluid streams. Therefore, the combined fluid streams can exit the system surge damper to move toward the drilling rig 114 with reduced or minimal energy transferred to the remaining downstream components.

In fig. 9 is a flowchart of a fluid supply and pulsation dampening process 900 in a fluid supply system 100 or 500 according to various embodiments of the present disclosure. For example, process 900 of FIG. 9 may be implemented by the system 100 shown in FIG. 1, or the system 500 shown in FIG. 5, or through these

- 9 046397 systems modified in accordance with FIG. 2, 3 or 4 (without corresponding manifold steps).

Now regarding FIG. 9, the process begins at step 902. At step 902, one or more pumps receive fluid from one or more fluid reservoirs, such as the mud reservoir 110 described in this application. At step 904, one or more fluid pumps direct one or more fluid streams downstream through the fluid delivery system. At step 906, the manifold receives one or more fluid streams and combines the one or more fluid streams into a single fluid stream. At step 908, the surge damper receives one fluid stream from the manifold.

At step 910, the installed system pulsation damper dampens the residual ripple generated by the manifold. In some embodiments, the system surge damper may perform damping operations where one or more flows are received by the surge damper as if the surge damper were a combination pressure manifold and surge damper device replacing the pressure manifold in the fluid delivery system. At step 912, the pipeline receives fluid withdrawn from the system surge damper. In some embodiments, the conduit may be a riser, such as riser 106. At step 914, fluid moves downstream through the conduit. At step 916, one or more additional system pulsation dampers installed dampen any residual pulsations in the fluid flow.

In fig. 12A and 12B are a cutaway view and a schematic view, respectively, of a maintenance-free reactive system surge damper according to embodiments of the present disclosure. Only wear-resistant and simple components are used in small quantities, allowing for easy repairs and long-term operation without adjustment. Gas filling (ie, chamber and valves/sensors) or the use of compression materials is eliminated, so maintenance is minimal (ie, periodic inspection) and cap removal is not required. The maintenance-free reactive system damper 1200 has no moving parts and uses the pumped fluid to dampen pulsations. High amplitude pump pulsation fluid 1201 is received through the inlet and low amplitude pump pulsation fluid 1202 is discharged through the outlet, with fluid 1203 in the housing reactively dampening the pump pulsation, that is, the pumped medium reacts with the system fluid mass to reduce pulsation. An optional, removable differential pressure control assembly 1204 may help reduce pump fluid pressure pulsations.

In fig. 13 illustrates an installation with a system pulsation damper according to embodiments of the present disclosure. In the example shown, each of two three-cylinder pumps having coupled outlets includes a suction stabilizer 1301 coupled to the inlet and a gas-filled (or unfilled) pulsation damper 1302 at the outlet. In such configurations, space and support are key and inflow/outflow into/out of the pipeline is required. If such optionally installed gas assemblies 1301, 1302 are used, the pump skid and piping must be modified and space is required in the pump compartment. The space and expense of meeting such requirements can be eliminated by using a single, suitably installed system ripple damper 501.

To upgrade the system from FIG. 13, all gas cartridges located in the reservoirs of the suction stabilizer 1301 are removed and (optionally) replaced with a more efficient mesh tube for unfilled operation. Likewise, all gas-filled chambers in the optionally installed gas dampers 1302 are removed and it is possible to fill the reservoirs with fluid during operation to provide initial damping control (also without replacing the piping). Alternatively, diaphragms or similar devices may be installed in the fluid flow path downstream of the reservoirs of existing optionally installed gas suppressors 1302. A separate reactive system surge suppressor 501 is added to the pump system flow line connected when using a simple connection when using high pressure outlet connectors to remove slow pulsations. The size of the system pulsation damper 501 is determined based on an analysis of the overall structure, the location of the damper downstream of the pumps, and the legacy damping equipment. It is preferable to locate the system pulsation damper 501 where pressure pulsations accumulate (for example, in the network flow after the discharges of individual pumps are combined), and preferably as close as possible to the pump(s).

Although the present disclosure has been described using exemplary embodiments, various changes and modifications may be suggested by one skilled in the art. The present disclosure is intended to cover such changes and modifications as come within the scope of the appended claims.

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Claims (13)

CLAIM 1. A fluid supply method comprising the steps of removing elastomeric compression material from an internal volume of a reactive surge damper housing, the housing being coupled to the outlet of at least one fluid pump for pumping fluid through a fluid supply system into a borehole; receiving fluid pumped by said at least one fluid pump into a first conduit connected to an outlet of said at least one fluid pump; at least partially damping pressure pulsations in the receiving fluid using a reactive pulsation damper body without compressive material during movement into a second conduit for supply to the borehole, and damping pulsations in a fluid transferred into and through the second conduit using one or more pulsation dampers connected within a second conduit downstream of the housing and configured to dampen residual pressure pulsations in a fluid transported through the second conduit. 2. The fluid supply method of claim 1, further comprising receiving fluid from said at least one fluid pump at a manifold located downstream of the fluid pump. 3. The fluid supply method of claim 1, wherein said one or more pulsation dampers are configured to receive fluid from said at least one fluid pump and fluid from another fluid pump. 4. The fluid supply method of claim 3, wherein said one or more pulsation dampers are configured to discharge one single combined fluid including fluid from said at least one fluid pump and fluid from another fluid pump. 5. The fluid supply method of claim 3, further comprising removing elastomeric compression material from the interior of a second housing for a second jet surge damper coupled to the outlet of another fluid pump, said one or more surge dampers being disposed in within the first conduit downstream of the housing and downstream of the second housing, after the location at which the pumped fluid outlets of the at least one fluid pump and the other fluid pump are aggregated. 6. The fluid supply method of claim 1, wherein said one or more pulsation dampers are positioned between the riser and said at least one fluid pump. 7. The fluid supply method of claim 6, wherein said one or more pulsation dampers are coupled to a plurality of fluid pumps including said at least one fluid pump. 8. The fluid supply method of claim 1, wherein said one or more pulsation dampers includes a single pulsation damper coupled between the riser and a plurality of fluid pumps including said at least one fluid pump, wherein said single the pulsation damper is configured to receive all fluid flows from a plurality of fluid pumps, discharge one single output fluid stream, and provide pulsation damping for said single output fluid stream. 9. The fluid supply method of claim 1, wherein said one or more pulsation dampeners are sized to remove slow pulsations not removed by the reactive pulsation damper housing. 10. A method of upgrading a fluid supply system to a borehole, including a reactive pulsation damper associated with the release of at least one fluid pump designed to pump fluid through the fluid supply system to the borehole, including the steps of removing the elastomeric operating compressing material from the internal volume of the reactive pulsation damper housing and connecting the system pulsation damper to a pipeline receiving fluid pumped by said at least one fluid pump downstream from the reactive pulsation damper housing, wherein the system pulsation damper is configured to damp residual pulsations pressure in the fluid moving through the pipeline. 11. The method of claim 10, further comprising receiving fluid from said at least one fluid pump at a manifold located downstream of said at least one fluid pump. 12. The method of claim 10, wherein the system pulsation damper is configured to receive fluid from said at least one fluid pump and fluid from the other fluid pump. 13. The method according to claim 12, in which the system pulsation damper is configured to release -