Untitled record

full description

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The present disclosure generally relates to systems and methods for rapidly changing the concentration of proppant carried in a clean fluid, and more specifically, manifold trailers configured to use multiple parallel pumps to deliver

<p>5 A mixture of proppant and clean fluid.</p>

To produce hydrocarbons (for example, oil, gas, and so on) from a subterranean formation, boreholes may be drilled that penetrate hydrocarbon-containing portions of the formation. Generally referred to as the portions of the subterranean formation that can From it hydrocarbons are produced as the "Production Zone".

<p>10 In some cases, a well bore formation can include many production areas at many locations along the wellbore.</p>

US Patent No. 0252262-2010 relates to a method for reducing proppant rates in fracturing fluids and to compositions and methods for their use.

International Application No. 040837-2007 relates to a hydraulic system with multiple pumps

<p>15th pumps, and more specifically, in a way to control a multi-pump . system</p>

.system

US Patent No. 6904982 relates to offshore drilling systems used to drill subsea wells. More specifically, the invention relates to a subsea pump and related control system for use in offshore drilling systems.

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US Patent No. 0059226-2010 relates to the formation of cracks in formations containing oil and gas to stimulate or increase production in oil and gas wells.

General description of the invention

Generally, after a borehole is drilled to the preferred depth, completions are performed. can include

<p>5 These completions include inserting a liner or casing into the wellbore, and sometimes, including cementing the casing or lining in place. Once the wellbore is completed as desired (lined, jacketed, open bore, or other known completion), a stimulation process can be performed to enhance hydrocarbon production in the wellbore. Examples of some general stimulations include hydraulic fracturing, acidification, fault acidification, and hydrojetting. . Stimulation processes are intended to increase</p>

<p>10 The flow of hydrocarbons from the subsurface formation surrounding the wellbore into the wellbore itself so that hydrocarbons can then be produced from the wellhead.</p>

In some applications, it may be preferable to create several faults individually and selectively at a predetermined distance from each other along a wellbore by creating several 'pay zones'. To maximize production, these faults must be multiple

<p>15th fractures with sufficient conductivity. The creation of several yielding zones is particularly characteristic when stimulating a wellbore formation or completion of a wellbore, and in particular, drilling a well that is significantly skewed or horizontal. Many of these yield areas can be created using a combination of tools which may include a mobile fracturing tool with perforating and fracturing capabilities or operable bushing assemblies placed in a downhole tubular element as disclosed</p>

<p>20 In US Patent No. 5,765.642.</p>

A typical formation spur could involve hydraulic fracturing of the formation and placement of proppant material in those faults. Typically, a fracturing fluid (comprising a clean fluid and proppant) is mixed on the surface before

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Pump it down the well to induce crack formation in the formation of interest. The creation of these faults will increase hydrocarbon production by increasing the flow paths to the wellbore.

Well workers will often attempt to perform "vertical fracturing" of the formation, which involves periodically inserting pulses or plugs of proppant into the clean fluid, supplying the production area

5 Targeted with a graded variable fracturing fluid. Theoretically, a graded variable fracturing fluid creates columns of proppant strategically placed within the fracturing formation, enhancing the conductivity. Ideally, the transition from a clean fluid to a mixture of a clean fluid and proppant is a sudden or sharp gradual change. However, conventional methods of mixing the proppant and the clean fluid often spread the transition between the clean fluid and proppant, resulting in the transition

10 Incremental rather than preferred incremental change.

Brief explanation of the drawings

The following figures are included to illustrate certain aspects of the present disclosure, and are not to be viewed as exclusive embodiments. Many modifications, changes, combinations and equivalents in form and function can be made to the revealed technical subject, as will become clear to those skilled in the field.

15th Once you take advantage of this disclosure.

Figure 1 is a simplified schematic view of a wellbore servicing system, according to one or more embodiments.

Figure 2 is a truncated projection of a pump according to the scheme given in Figure 1, according to one or more embodiments.

20 Figure 3 is a diagram of a performance plan according to the pump profile of the wellbore service system given in Figure 1, according to one or more embodiments.

Figure 4 is a schematic diagram of a conventional manifold and pump system.

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Figure 5 is a schematic diagram of a manifold and pump system configured to provide step changes in

Concentration of the proppant, according to one or more embodiments.

Figure 6 is a diagram of the conductive proppant concentration of a conventional locomotive manifold given in Figure 4 for the first illustrative step-change order figure.

<p>5 Figure 7 is a diagram of the concentration of conductive proppant from the pump and manifold system given in Fig. 5 to the step-change order figure in Fig. 6, according to one or more embodiments.</p>

Figure 8 is a second diagram of the conductive proppant concentration of a conventional pump-manifold system given in Figure 4 of the second illustrative step-change order figure.

<p>10 Figure 9 is a second diagram of the conductive proppant concentration of the manifold and pump system given in Fig. 5 to the step-change order figure in Fig. 8, according to one or more embodiments.</p>

Detailed description:

The present disclosure generally relates to systems and methods for rapidly changing the concentration of the portable proppant 15 in a clean fluid, and more specifically, manifold droppers intended for use in multiple pumps.

The parallelepiped to deliver a mixture of proppant and clean fluid.

The embodiments disclosed relate to a manifold locomotive with several pumps placed in parallel between a common inlet and a common outlet. The inflow of a fluid at the inlet can be with a gradual change in the fluid property, for example, the concentration of the proppant, and it is preferable to provide this

<p>20 Same gradual change in characteristic in outflow. Sharp or abrupt gradient changes can lead to effective pillar fracturing of a subterranean formation.</p>

While the disclosed methods and devices are discussed in terms of a locomotive manifold for use in an oil and/or gas well, the same principles and concepts can equally be used to deliver square wave pulses.

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Variety of formulation using parallel pumps. For example, current detection methods and devices can be applied equally to other fields or techniques that involve or need pumping.

As used herein, the term “proppant” or variant forms thereof refer to mixtures comprising one or more granular solids such as sand.

<p>5 Scale, sand covered with resin, sintered bauxite beads, metal beads or cards, ceramic particles, glass beads, polymer resin beads, or biodegradable materials such as ground nut shells, and the like. In certain embodiments, the proportion of the biodegradable proppant may fall in the range of 5-90%, as determined by the user of the process.</p>

As used herein, the phrase “proper filler” or various forms thereof refer to a carrier fluid

<p>10 For a proppant which is a mixture of a granular solid, such as sand, with a liquid, such as water or gel. Prop slurry can be any mixture capable of suspending and transporting proppant with a concentration of more than approximately 11 kilos of proppant per gallon of proppant. In certain embodiments, the proppant slurry may contain up to 12 kg of granular solid per gallon of fluid. In certain embodiments, it may include a slurry</p>

<p>15th Backing fillers also have other materials such as viscosity modifiers, thickening agents, and so on. In one illustrative embodiment, the LIQUIDSAND™ backing mortar may be commercially available from Halliburton Energy Services, Inc., Houston, Texas and disclosed in US Patent No. 5,799.734.</p>

In certain embodiments, the proppant slurry may comprise a water-containing fluid which does not

<p>20 It reacts negatively with the subterranean formation or other fluid components. For example, the fluid may include an aqueous metal or organic acid, an aqueous salt solution such as potassium chloride solution, ammonium chloride solution, a chloride solution</p>

aqueous organic quaternary ammonium chloride

solution, or similar.

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In certain embodiments, the support filler slurry may comprise a gel forming agent which may comprise substantially any of the viscosity compounds known to act in the preferred manner. The gel-forming agent, for example, may comprise largely any viscous agent of a polysaccharide polymer such as guar gum, types of

5 Guar derivatives such as hydroxypropylguar, derivatized cellulosics such as hydroxyethylcellulose, starch derivatives, polyvinyl alcohols, acrylarnides, xanthan gums, and the like. A specific example of a suitable gel-forming agent is guar, hydroxypropylguar, or carboxy.

<p>10 carboxymethyl hydroxypropylguar is present in an amount ranging from about 0.2 to about 0.75 by weight in the fluid.</p>

As used herein, the phrase “clean fluid” or variants thereof refers to a fluid that does not have significant amounts of proppant or other solids suspended in it. Clean fluids may include Barine solutions, including fresh water. Pararine solutions can sometimes contain

<p>15th Viscosity agents or friction reducing agents. The clean fluid can also be activator fluids such as barrin foam solutions or mixed with carbon dioxide based emulsifier fluids and fluids.</p>

carbon dioxide or nitrogen, acid mixture or oil.

As used herein, the phrase "fracking fluid", or various forms thereof, refer to a mixture of a clean fluid, proppant material, and proppant slurry in any proportion.

<p>20 Within this document, the reference identifier can be used as a generic number, eg “101” for an item type and alternatively used to indicate a special case or distinction, eg “101a” and “101b” are of the same item type.</p>

Referring to Figure 1, the wellbore 100 servicing system is shown. The wellbore 100 servicing system is configured for fracturing fluids in low permeability reservoirs, among other wellbore servicing tasks. in operations

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Fracking, wellbore servicing fluids, such as particle-laden fluids, are pumped at high pressure down the well into a wellbore. In this embodiment, the 100 wellbore servicing system introduces particulate-laden fluids into a portion of an underground hydrocarbon formation at sufficient pressure and velocity for casing pieces, to create perforation tunnels, and/or to form and extend faults within the hydrocarbon formation.

5 Support fill materials, such as sand grains, are mixed with the wellbore service fluid to keep the faults open so that hydrocarbons can be produced from the aquifer hydrocarbon formation and flow into the wellbore. This hydraulic fracturing creates a highly conductive fluid connection between the wellbore and the hydrocarbon subterranean formation.

As shown, a wellbore service system can include a 100 wellbore mixer 114

10 Combine it with a 118 wellbore servicing manifold via one or more flowlines

116. As used herein, the term “tug manifold for wellbore services” is meant to mean that it collectively includes a truck and/or tug comprising one or more pump manifolds for receiving, regulating, and/or distributing wellbore service fluids during wellbore service operations. . In the embodiment shown, a wellbore service manifold 118 is coupled to three positive displacement 120 pumps across

15th 122 outlet flowlines and 124 inlet flowlines. 122 outlet flowlines supply fluid to the pumps 120 from the manifold for wellbore services 118. Inlet flowlines 124 supply fluid to the manifold for wellbore services 118 from the 120 pumps.

Together, the three positive displacement pumps make up a 120 pump group. in a

20 Alternative embodiments, however, may be many or few positive displacement pumps used in a wellbore servicing operation and/or pumps other than positive displacement pumps may be. The wellbore servicing manifold 118 generally includes manifolds from which wellbore servicing fluids flow to wellhead 132 through one or more flowlines

134.

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Each pump 120 is also equipped with a pump monitor 136 which monitors many of the operational characteristics of the pumps 120 and associated pump monitors 136. More specifically, the pump monitors 136 include any sensors needed to monitor, record, report, connect, display, and and/or recording as many operational characteristics of the 120 pumps as will be described in more detail

5 below.

Referring now to Figure 2, the 120 pump is shown in more detail. In this embodiment, the 120 pump is a positive displacement pump of the HT-400™ Triplex type, which is produced by

power end The pump includes 120 Halliburton Energy Services power terminals. a company

502 The 504 fluid end is attached to the 502 power end. The 502 power end includes

10 A 506 crankshaft reciprocatingly moves the 508 plunger into the 516 hole. Fluid tip 504. The 504 fluid tip also includes a 510 compression chamber through which fluid flows through the 512 suction valve. The fluid is pumped out of the airlock 510 through the relief valve 514 when the piston 508 moves toward the airlock 510.

15th The 520 sensor uses a pump monitor 136 pump monitor a timing number 522 marker attached to the crankshaft 506 crankshaft to monitor the number of turns of the crankshaft 506. The 136 pump monitor also includes a 528 multi-purpose sensor to sense the necessary operational characteristics of the pump 120 and/or pit treatment fluid Well, including output pressure, hours at pressure ranges, hours at power ranges, horsepower hours, operating hours

20 The pump for each drive gear, and combinations thereof. The 524 controller receives signals from the 520 and 528 sensors and is configured to monitor, record, report, communicate, display, and/or record information received to the 524 by the 520 and 528 sensors. Of course, the 524 controller can be connected The control device 524 has systems, computers, monitors, other control devices, and/or other equipment suitable for monitoring the pump. 120 monitoring the pump.

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It will also be recognized that the communication between the controller 524 and other systems is one-way and can occur via a two-way communication link 526. Of course, in alternative embodiments, the pump display 136 can be independent, can communicate in a unidirectional manner, and may include Other systems or components that do not monitor, record, report, communicate, display, and/or record

5 Information received to the controller 524 by the sensors, 528, 520 sensors. In this embodiment, the display 530 is in communication with the controller 524 and can selectively display any of the aforementioned operational characteristics of the pump 120, the remaining life rating, and/or the life expectancy rating of the pump 120.

Referring again to Figure 1, the mixer 114 mixes the solid and liquid components to achieve a fluid

<p>10 Well mixed borehole service. As depicted, one or more proppants 102, clean fluid 106, and additives 110 may be fed to the mixer 114 via feedlines 104, 108 and 112, respectively. The clean fluid 106 may be potable water, non-potable water, untreated water, treated water, hydrocarbon-based fluids or other fluids. The mixing conditions of the 114 mixer can be selected, including the time period,</p>

<p>15th The method of stirring, pressure, and temperature of the mixer 114, by those skilled in the art, was aided by this detection to produce a homogeneous mixture having the preferred composition, density and viscosity. In alternative embodiments, however, sand or proppant, water and additives may be pre-mixed and/or stored in a storage tank prior to being fed into the 118 wellbore service manifold.</p>

The screen of the Mixer 140 observes many of the operational characteristics of the Mixer 114 in much the same way

<p>20 The pump screen 136 monitors the operating characteristics of the pump 120. Both the pump screens 136 and the mixer screen 140 can provide information to a master controller 138 that is in communication with the pump screens 136 and the mixer screen 140. The mixer screen 140 is also able to display The selectivity of any observed operating characteristics of the mixer 114 and/or the estimation of the remaining life and/or the estimation of the viability potential of the mixer 114.</p>

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Referring now to Figure 3, while continuing with reference to Figure 1, a wellbore service system 100 delivers wellbore servicing fluids to wellhead 132 according to the realized pumping profile 200. “Pumping profile” refers to a performance plan for an operational characteristic of a wellbore service system. It will be recognized that a single pumping form may include one or more performance plans and the feasibility of the wellbore service system in accordance with

<p>5 for one or more forms of pumping, either sequentially or sequentially. It will be recognized that a single pumping form may include one or more performance plans for a single operational characteristic. In other words, a pumping profile may include one or more performance plans for one or more operational characteristics of a wellbore service system and a wellbore service system may operate under one or more forms of pumping.</p>

Continuing with reference to Figure 3, the pumping figure illustrated 200 includes a performance plan for a rate

<p>10 The flow, shown in curve 202, and a performance plan for the output pressure, shown in curve 204, to be supplied by the 121 pump assembly (Figure 1) over a period of time. As shown, the 121 pump group's job is to deliver pit service fluids The well is down the well at a rate of about 100 bpm for the first 200 minutes of operation After the first 200 minutes of operation, the required flow rate increases 202 over the course of 10 minutes</p>

<p>15th Roughly up to a new preferred flow rate of about 150 bpm. After reaching the rate</p>

Flow of about 150 bpm, the task of the 121 pump group is to continue to deliver about 150 bpm until about the 320th minute of operation.

At the same time, the task of the 121 pump group is to deliver wellbore service fluids down the well at a pressure of approximately 24.13 MPa over the full 320 operating life.

<p>20 minute, as shown by curve 204. It will be recognized that in other embodiments and in this embodiment when working with alternative pumping forms, the task of the 121 pump group can be to deliver the wellbore service fluids down the well at various other pressures and flow rates over the life of Operation of the pump group 121. The pump figure 200 is an example of a pump form that includes a set of performance plans as long as the pump figure 200 includes both of the performance plan 202 </p>

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for the combined pump group flow rate and performance plan 204 for the combined pump group pressure.

Figure 4 is a schematic diagram of a conventional manifold trailer 300. In this example, there are five positive displacement Q5-Q1 pumps that are fluidly connected between

5 An intake manifold 302 and an outlet manifold 304. The intake manifold 302 has a single inlet 306 connected to the flow line 116 in Figure 1 from the mixer 114, and the exit manifold 304 has a single outlet 308 connected to the flow line 134 of Figure 1 that goes to the wellhead 132 The connections where the flow through a single pipe is divided into two flows through two pipes, and where the flows through the two pipes are combined into a single flow through a single pipe, are marked with the letters of

<p>10 "A" to "K" and does not include the letter "I" to avoid confusion. The flow rate is indicated in each segment</p>

Pipe to the FXY variable, where the lowercase letter "X" is the connection to the source and the lower letter "Y" is the connection to the destination. For example, FAC is the flow rate from link A to link C. Once the start is complete, the flow rate at inlet 306 and at outlet 308 should be the same and are denoted by the variable F1.

<p>15th Each pipe section between the connections, and between the connections and individual pumps A5-Q1, can be of a different length and/or a different diameter. The size of each pipe section has at least one variable of interest and is denoted by the variable VXY, using the same capital letters "X" and "Y" as applied to FXY flowrate, with VXY and FXY denoting the volume and flow rate within the same pipe section.</p>

<p>20 When operating, the fluid entering the inlet can be 306 from the homogenizer 114 with a gradual change in the concentration of the proppant. When F1 flow is divided to pass through two or more pumps Q5-Q1 and then combined, the integration of the gradual change in flow from outlet 308 depends on travel times through each separate path through the 300 manifold. For example, the first path could be From Entrance 306 to Exit 308 is a 306-FDBA-</p>

<p>25 308-KH While the first path from Entrance 306 to Exit 308 can be</p>

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306-308-KHG- ECA Since the initial segment 306-A and final segment 308-K are common to both paths, it will be recognized that the remaining intermediate paths create many differences in path properties.

If the latency across all paths is the same, the gradient will be transformed at the input

5 Basically intact to outlet 308. However, in practice, the lengths and diameters of the pipe sections, which can be supplied as flexible hoses, vary between some or all of the pipe sections. This leads to different latencies along each path, which in turn causes the gradient spread across many paths to arrive at exit 308 at different times, which increases the change in the proppant concentration in the flow from outlet 208, i.e., the gradient deterioration .

10 The following equations relate to the first and second illustrative pathways identified above, ie, 306-BA-308-KHFD and 306-308-KHGECA. In general, pumps Q5-Q1 can be identical pumps and operate at a general pumping speed, this is the parsed configuration below for the configuration in Figure 4. The latency of each pipe section is denoted by the variable TXY, using the same underscores "X" and “Y” as applied to the respective pipe section,

15th T1 indicates the latency for Track 1, excluding the common lane elements 306-A and 308-K .

THK + TFH + TDF + TBD + TQ1B + TAQ1 = T1

TQ5K + TJQ5 + TGJ + TEG + TCE + TAC = T2

F1/V1 = T1 (track size 1/track flow rate 1)

F2/V2 = T2 (track size 2/track flow rate 2)

20 F = F2 = F1 (pumps Q1, Q5 are identical, at general speed)

Therefore, the ratio of latencies along the two paths is:

V2/V1 = T2/T1

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The sizes of the two tracks are:

VHK + VFH + VDF + VBD + VQ1B + VAQ1 = V1

VQ5K + VJQ5 + VGJ + VEG + VCE + VAC = V2

For this example, if the pipe sections connected to pumps Q1 and Q5 are identical and equal to 5 V and all the pipe sections between the nodes are identical and equal to V except for pipe sections BD and FH of size V2, that is, twice as large as the other pipe sections, the time ratio it will be:

(V + V + V + V + V + V)/( 2V + V + V + 2V + V + V) = T2/T1

1.33 = 6V / 8V = T2/T1

<p>10 Thus, for the simplified example presented, it will be seen that changing the properties of the two pipe sections, for example using a flexible hose that is twice as long as other hoses, can produce a large variation in travel times along many of the flow paths across the 300 manifold. If all five flow paths are to be taken into account and the more realistic distinction is that each pipe section has a different volume and each pump Q5-Q1 provides a different flow rate, it becomes clear that</p>

<p>15th The gradual change in the proppant concentration in the inlet flow 306 may be significantly degraded as it travels through many of the flow paths of the locomotive manifold 300. This effect is discussed in more detail for Figs 6 and 8.</p>

Figure 5 is a schematic diagram of a 400 manifold trailer configured to provide stepwise changes in proppant concentration, according to one or more embodiments. In this example, there is

<p>20 Five positive displacement pumps Q5-Q1 which communicate between the intake manifold 402 having an inlet 406 and an exit manifold 404 output manifold having outlet 408. Node identifiers are assigned similarly to those in Figure 4 and the arrangement of piping segments is similar between the nodes in Figure 5 in Many aspects with the arrangement given in Figure 4. As can be seen, </p>

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Reposition of outlet 408 at the exit manifold tip 404 near pump Q1, compared to

Closer to outlet 308 of pump Q5 in Figure 4, it provides certain advantages which will be described below.

On the 400 manifold, travel times for each track can be adjusted across several pumps Q5-Q1 independently by varying the operating speed of individual pumps Q5.-Q1

5 The latency of the HK-Q5-JG flow path can be initially calculated for an optional flowrate from the Q5. The pump flow rate Q4 can then be computed so that the latency of the GH-Q4 matches the latency of the HK-Q5-JG Once this is done, the latencies of the lanes should be FHK-Q5-JGE and F-H-Q4- GE is the same and the flow rate of pump Q3 can then be calculated so that the path latency F-Q3-E matches that

10 the previous two tracks. This process can be repeated with pumps Q2 and then Q1.

The various speed rates of the Q5-Q1 pump create a common latency across all flow paths between inlet 406 and outlet 408, however the combined flow rate of the Q5-Q1 pumps operating at the same flow rates may not be the preferred flow rate. The flow rate of each Q5-Q1 pump can be adjusted by the ratio of the total required flow rate to the combined flow rate 15 resulting in a combined flow rate equal to the preferred flow rate while maintaining the relationship between

Flow rates for pumps Q4-Q1 to pump Q5. This will maintain an overall latency for all flow paths. Furthermore, this can provide a clean transition for the stepwise change in proppant concentration from inlet 406 to outlet 408. It is clear to those skilled in the art that a general latency can be obtained by initializing all flow paths

BDFH-Q4-GECA, BDF-Q3-ECA, BD-Q2-CA, B-Q1-A 20

and B-DFHK-Q5-JGECA to be the same size. Using the same volume per flow path, the Q5-Q1 pumps can operate at the same flow rate. Likewise, flow path sizes in the manifold can be adjusted so that the Q5-Q1 pumps can be run at any preferred flow rate ratio to each other.

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To facilitate a better understanding of the current disclosure, the following examples of preferred or illustrative embodiments are presented. In no way should the following examples be considered as limiting or limiting the scope of disclosure.

Examples

Total preferred flow rate = 25 barrels per minute (bpm); all pumps are used

5 Q5-Q1 shown in Figure 5; Volume of all pipe sections connected to a pump, VP . = 0.3

barrel; The volume of all pipe segments connected between the nodes, VN = 0.5 barrels.

The pump speed of the Q5 pump is randomly selected to be half of the total preferred flow rate:

12.5 = 2/25 = Q5 barrels per minute

10 The size of the pipe sections carrying the flow of the Q5 pump only:

VKH + VQ5K + VJQ5 + VGJ = VGH(5)

Thus, the transition time between nodes G and H through pump Q5, after replacing the above assumed volumes:

Q5/VGH(5) = TGH

Q5/(0.5 + 0.3 + 0.3 + 0.5) = Q5/(VKH + VQ5K + VJQ5 + VGJ) = TGH 15

0.128 = 12.5/1.6 = TGH min

By switching to pump Q4, which connects the same nodes G and H .:

0.6 = 0.3 + 0.3 = VQ4H + VGQ4 = VGH(4)

4.69 = 0.128/0.6 = TGH / VGH(4) = Q4 barrels per minute

20 For pump Q3, it is first necessary to calculate the latency between the E and F nodes of pump Q5:

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Q5/ (VHF + VKH + VQ5K + VJQ5 + VGJ + VEG) = TEF

0.208 = 12.5/(2.6) = TEF min

Then the flow rate Q3 can be calculated to match the said latency between nodes E and

:F

0.6 = 0.3 + 0.3 = VQ3F + VEQ3 = VEF(3) 5

2.88 = 0.208/0.6 = TEF / VEF(3) = Q3 barrels per minute

For pump Q2, it is first necessary to calculate the transition time between nodes C and D of pump Q5:

Q5/(VFD + VHF + VKH + VQ5K + VJQ5 + VGJ + VEG + VCE) = TCD

TCD = 12.5/(3.6) = 0.288 min

10 Then the flow rate Q2 can be calculated to match the said latency between nodes C and

:D

0.6 = 0.3 + 0.3 = VQ2D + VCQ2 = VCD(2)

2.08 = 0.288/0.6 = TCD / VCD(2) = Q2 bpm

For pump Q1, it is first necessary to calculate the latency between nodes A and B of pump Q5:

VFD + VHF + VKH + VQ5K + VJQ5 + VGJ + VEG + VCE + VAC) = TAB 15 Q5/(VDB +

0.368 = 12.5/(4.6) = TAB min

Then the flow rate Q1 can be calculated to match the said latency between nodes A and

:B

0.6 = 0.3 + 0.3 = VQ1B + VAQ1 = VAB(1) 20

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1.63 = 0.288/0.6 = TAB / VAB(1) = Q1 barrels per minute

Thus, the calculated flow rates for the five pumps are Q1-Q5 = 12.5; Q4 = 4.69; 2.88 = Q3; 2.08 = Q2; and 1.63 = Q1. The reported total flow rates are 23.78 bpm, which is somewhat less than the preferred 25 bpm. reach

5 The ratio of the preferred flow rate to the specified flow rate 25/ 23.78 = 1.05. Thus, the flow rate of each pump Q5-Q1 is adjusted by this ratio to be Q5 = 13.14; 4.93 = Q4; 3.03 = Q3; 2.19 = Q2; and 1.71 = Q1. The stated exact flow rates are 25 bpm, the preferred flow rate, while an overall latency is maintained across the flow paths associated with each pump such that a gradual, non-deteriorating change will appear in the fluid entering the

10 Entrance 406 is generally from Exit 408.

To change the total flow delivered from outlet 408 while maintaining the overall latency, the flow rates for all pumps Q5-Q1 can be adjusted by a common ratio. For example, to increase the total flow rate from 25 to 40 bpm (60% increase), the individual flow rates of each Q5-Q1 pump can be increased by 60% of the existing single flow rate.

15th In actual fact, the calculations are more complex as the true volumes of each pipe section have to be determined and entered into the equations described above. In addition, the internal volumes of the Q5-Q1 pumps themselves as well as the sizes of any fittings, valves, and ports located in each pipe section must be added to the calculated volume for each path.

Figure 6 is a 600 plot of the conductive proppant 610 concentration of the locomotive 20 simulation of a conventional 300 manifold given in Fig. 4. An order figure 602 representing the filler concentration is depicted

The supportive flux entering the inlet 306 as the change from zero to 1.36 kilograms in a first stepwise change. The form of the 602 command is then maintained at 1.36 kilograms for 30 seconds, then returns to zero in a second gradual change and is held at zero for 30 seconds, then this cycle is repeated. It can be seen that many of the transition times of the Q5-Q1 pumps manifest themselves

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In several latencies of the gradient change at exit 308. In the example in Figure 6, the change in the concentration of the proppant 610 is propagated over a time period of about 10 s in both the up and down directions.

Figure 7 is a diagram of 700 concentration of conductive proppant 710 from the locomotive simulation

5 The illustrative manifold 400 in Fig. 5 is of the same shape as step-change order 602 in Fig. 6, according to one or more embodiments. It can be seen that when the transition times between inlet 406 and outlet 408 are the same for all pumps Q5-Q1, the conductive proppant concentration 710 shows much the same gradual change as the command figure 602 is shifted only slightly in time.

10 Figure 8 is a diagram of another conductive proppant concentration 810 from a conventional 300 manifold in Figure 4. In this example, a command figure 802 is depicted representing the proppant concentration of the inflow into the inlet 306 as the change from zero to 1.36 kilo Garm's first gradual change. The form of the 802 command is then maintained at 1.36 kilograms for 15 seconds, then returns to zero in a second gradual change and is held at zero for 15 seconds, then this is repeated

15th session. It can be seen that the effect of different transition times increases when the command pulse duration decreases. as tall as

15 sec pulse and gradient change propagation over a period of 10 sec There is only a short time period of about 5 sec when the proppant concentration in the proppant concentration output 810 is at the order level.

Figure 9 is a 900 diagram for the 910 conductive proppant concentration of a locomotive manifold

20 400 in Fig. 5 is the same as the 802 step-change order in Fig. 8, according to one or

More than incarnations. It can be seen that although the pulse width is reduced from 30 s to 15 s, the conductive proppant concentration 910 exhibits the same gradual change as the command figure 802.

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In short, the revealed manifold configuration and accompanying calculations allow for determination of individual pump velocities that collectively provide a shunt for gradient change from input to output without deterioration to gradient, but rather to a more abrupt or more rapid gradual change in the proppant concentration .

5 Embodiments disclosed here include:

(a) A method for providing a stepwise change in the concentration of a proppant. The method may include selecting a first flow rate for a first pump connected between a first input node and a first output node, calculating a first latency of a fluid flow at the first flow rate through a first flow path extending from the first inlet node, through the first pump, to the first outlet node, and calculating a first flow rate 10 A second flow of a second pump connects between the first input node and the first output node such that the time of the second transition of the fluid flow through a flow path is

A second extending from the first inlet node, through the second pump, and to the first outlet node, equal to the first latency.

b- A multi-pump manifold including a first pump that is fluidly coupled between a first inlet node and a first outlet node, a first flow path extending from the first inlet node, through the first pump, and to the first inlet node

<p>15th First outlet, a second pump that is fluidly coupled between the first inlet node and the first outlet node, a second flow path extending from the first inlet node, through the second pump, and to the first outlet node that does not pass through any part of the first flow path, a third pump that is fluidly coupled between the inlet node a second and a second outlet node, a third flow path extending from the second inlet node, through the first inlet node, through the first pump, through the first inlet node, and to the second outlet node, and a four flow path extending from</p>

<p>20 The second inlet node, through the third pump, and to the second outlet node that does not pass through any part of the first, second, or third flow paths.</p>

Each embodiment (a) and (b) may include one or more of the following additional elements in any combination: Element 1: where it further comprises the simultaneous operation of the first and second pumps respectively at the first and second flow rates. Element 2: where the time calculation includes

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The first movement is calculated by calculating the volume of a first fluid within the first flow path and dividing the volume of the first fluid by the first flow rate. Element 3: Where the calculation of the second latency time involves calculating the volume of a second fluid within the second flow path and dividing the volume of the second fluid by the second flow rate. Element 4: where the second flow path does not pass through any part of the first flow path. Element 5: where

<p>5 It also includes determining the calculated total flow rate by summing at least the first and second flow rates, determining the ratio of the preferred total flow rate to the calculated total flow rate, and calculating the first and second controlled flow rates by multiplying the first and second flow rates respectively by the ratio. Element 6: It also includes the simultaneous operation of the first and second pumps, respectively, at the first and second set flow rates. Element 7: Where it includes</p>

<p>10 Also, the fluid is pumped into a borehole using the first and second pumps, where the fluid includes a fracturing fluid. Element 8: It also includes the calculation of a third latency of the fluid flow at the first flow rate through a third flow path extending from a second inlet node, through the first inlet node, through the first pump, through the first outlet node, to a second outlet node, and a calculation of a third flow rate For a third pump connected between the second inlet node and the second outlet node so that the latency is four</p>

<p>15th For the fluid to flow through a four flow path extending from the second inlet node, through the third pump, and to the second outlet node equal to the travel time of the first. Element 9: The four flow paths do not pass through any part of the first, second, or third flow paths. Element 10: It also includes the simultaneous operation of the first, second, and third pumps, respectively, at first, second, and third flow rates. Element 11: It also includes pumping fluid into a borehole using pumps</p>

<p>20 First, second, and third, where the fluid includes a fracturing fluid. Element 12: where it also includes the calculation of a fifth latency of the fluid flow at the first flow rate through a fifth flow path extending from a third inlet node, through the second inlet node, through the first inlet node, through the first pump, through the first outlet node, through the second outlet node , and to a third outlet node, and calculate the four flow rate for a four connected pump between the third inlet node and the third outlet node so that the latency time</p>

<p>25 A sixth of the fluid flow through a sixth flow path extending from the third inlet node, through the four pumps, and to the third outlet node equal to the fifth transition time. Element 13: Where the flow path does not pass</p>

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VI through any part of the first, second, third, fourth, or fifth flow paths. Element 14: It also includes the simultaneous operation of the first, second, third, and four pumps, respectively, at the first, second, third and four flow rates. Element 15: It also includes pumping the fluid into a borehole using the first, second, third, and four pumps, where the fluid includes

5 fracturing fluid.

Element 16: where it also includes an inlet manifold with a flow path to the second inlet node that does not pass through any part of the first, second, or third flow paths, and an outlet manifold with a flow path from the second outlet node that does not pass through any part of the The first, second, or third flow. Element 17: it also includes a clean fluid source, a proppant slurry source, and a mixer

<p>10 fluidly coupled to the clean fluid source, the proppant slurry source, and the manifold inlet, the mixer shall be configured to accept selected quantities of at least one of the clean fluid and the proppant slurry, mixing the clean fluid and the proppant slurry to obtain a generally uniform mixture, and delivering the mixture to the manifold inlet. Element 18: where it also includes a controller associated with the first, second, and third pumps, wherein the controller is configured to accept a first nominal flow rate, nominal flow rate</p>

<p>15th Second, third nominal flow rate, simultaneous operation of first pump at first nominal flow rate, second pump at second nominal flow rate, third pump at third nominal flow rate, accepting a preferred total flow rate, calculating first CFR, second CFR , and a third controlled flow rate by multiplying the first, second, and third nominal flow rates respectively by the ratio of the total required rate over the sum of the nominal flow rates</p>

<p>20 At least the first, second, and third, and run the first pump synchronously at the first CFR, the second pump at the second CFR, and the third pump at the third CFR.</p>

Thus, the present invention is well adapted to achieve the stated purposes and advantages as well as those inherent in it. The specific embodiments disclosed above are illustrative only, as the invention may be modified

<p>25 . and implement it in different but equally clear ways for those skilled in the field immediately after benefiting from the</p>

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10

15

The information here. Furthermore, there are no restrictions on construction or design details mentioned herein, other than as described in the safeguards below. Thus, it will be clear that the specific illustrative embodiments disclosed above can be changed, combined, or modified, and all such variations fall within the scope and substance of the present invention. The invention illustratively disclosed herein may be properly carried out in the absence of any element not specifically disclosed herein and/or any optional element disclosed herein. While formulations and methods have been described as “comprising,” “containing,” or “involving” many components or steps, formulations and methods can also “mainly consist of” or “consist of” many components and steps. All figures and ranges disclosed above may vary in quantity. Wherever a minimum and upper numeric range is disclosed, any number and any contained range that falls within the range shall be specifically disclosed. Specifically, it must be recognized that each range of values ​​(as "about A to about B", or equivalently, "about A to B", or equivalently, "about A-B") What is disclosed herein shows any number and range included in the broader range of values ​​Also, terms in the claims have their express normal meaning, unless clearly and publicly specified otherwise by the patentee.Moreover, indefinite devices are defined, as It is used in elements of protection, here as meaning one or more of the elements to which it refers. In the event of any inconsistency in the uses of a word or term in this specification and one or yi y

More than patents or other documents can be included here for reference, definitions that comply with this specification should be used.

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