METHOD AND SYSTEM FOR SAMPLING MULTI-PHASE FLUID AT A PRODUCTION WELLSITE

BACKGROUND OF THE INVENTION

1. Field of the Invention

The present invention relates generally to techniques for performing wellsite operations. More specifically, the present invention relates to techniques for sampling fluid at a production wellsite.

2. Background of the Related Art

Oil rigs are positioned at wellsites for performing a variety of oilfield operations, such as drilling a wellbore, performing downhole testing and producing located hydrocarbons. Downhole drilling tools are advanced into the earth from a surface rig to form a wellbore. Drilling muds are often pumped into the wellbore as the drilling tool advances into the earth. The drilling muds may be used, for example, to remove cuttings, to cool a drill bit at the end of the drilling tool and/or to provide a protective lining along a wall of the wellbore. During or after drilling, a tubular may be cemented into place to line at least a portion of the wellbore. Once the wellbore is formed, production tools may be positioned about the wellbore to draw fluid to the surface.

During wellsite operations, it may be desirable to obtain downhole fluid samples to determine various parameters of the wellsite. Techniques for sampling are described, for example, in U.S. Pat. Nos. 2008/0135239, 6,467,544, 6,659,177, and 7,243,536. In some cases, the fluid may be separated during sampling as described, for example, in U.S. Pat. Nos. 7,434,694, 20080115469 and 20100059221. In some other cases, fluid may be sampled in zproduction or subsea operations as described, for example, in U.S. Pat. Nos. 2010/0058221, 2011/0005765, 2009/028836, and 6,435,279, and in PCT Application Nos. WO2010/106499, and WO2010/106500.

Despite the development of techniques for sampling, there remains a need to provide advanced techniques for sampling wellsite fluid. It is desirable that such measurements maintain the quality of the sample as it is collected and retrieved. The invention contained herein is directed at achieving these advanced techniques.

SUMMARY OF THE INVENTION

In at least one aspect, the techniques herein relate to a system for sampling fluid from a production wellsite. The production wellsite has a tubular extending into a subsea unit for producing a fluid therefrom and a port at the wellsite for accessing the fluid. The system includes an interface operatively connectable to the port for establishing fluid communication therewith, and a separation circuit operatively connectable to the interface for establishing fluid communication with the interface and the port. The separation circuit includes a pumping unit comprising a plurality of pumping chambers and at last one sample chamber. Each of the pumping chambers has a cylinder with a piston therein defining a fluid cavity and a buffer cavity. Each of the fluid cavities defines a separation chamber for receiving the fluid and allowing separation of the fluid therein into phases. Each of the buffer cavities has a buffer fluid selectively movable therebetween whereby the fluid flows through the separation circuit at a controlled rate (e.g., flow rate and/or pressure). The sample chambers are for collecting at least one sample of the phases of the fluid.

The system may also have a fluid separator upstream or downstream of the pumping unit; at least one sensor for detecting one of density, flow rate, pressure, temperature, composition, phase and combinations thereof; a pump for selectively moving the buffer fluid between the buffer cavities; a flushing unit for flushing fluid through the separation circuit; a remote operated vehicle operatively connectable to the separation circuit; a surface unit operatively connectable to the separation circuit; a plurality of valves for selectively diverting fluid through the separation circuit; at least one fluid control component comprising one of at least one pressure transmitter, at least one temperature sensor, at least one orifice, at least one restrictor, at least one probe, at least one meter, at least one flow diverter, at least one valve, at least one pump, at least one fluid separator, at least one flowline, and combinations thereof; an electrical component for operating the separation circuit; a retrievable skid for housing the interface and the separation circuit; a sand filter; and/or a temperature controller for selectively controlling temperature of the fluid.

The pumping unit may utilize a pressure differential at the port for selectively moving the buffer fluid between the buffer cavities. Operatively connectable may be hydraulically connectable and/or electrically connectable. The plurality of phases may be at least two of water, gas, oil, and/or sand. The plurality of pumping chambers may be positioned at an angle to facilitate separation therein.

In another aspect, the techniques herein may relate to a method of sampling fluid from the production wellsite. The method may involve establishing fluid communication between an interface and the port; establishing fluid communication between a separation circuit and the interface (the separation circuit comprising at least one sample chamber and a pumping unit, the pumping unit comprising a plurality of pumping chambers, the plurality of pumping chambers each having a cylinder with a piston therein defining a fluid cavity and a buffer cavity); selectively flowing the fluid between the separation circuit, the interface and the port at a controlled rate (e.g., flow rate and/or pressure) by selectively manipulating the buffer fluid between the buffer cavities of the plurality of pumping chambers; receiving the fluid in the fluid cavity of at least one of the plurality of pumping chambers and allowing separation of the fluid into a plurality of phases therein; and collecting at least one sample of at least one of the plurality of phases of the fluid in the at least one sample chamber.

The buffer fluid may be selectively manipulated using a pressure differential across the port or selectively manipulated using a pump. The method may also involve electrically connecting the separation circuit to the interface and the port for selective activation thereof, deploying at least a portion of the separation circuit with a remote operated vehicle deployed from a surface unit, retrieving at least a portion of the separation circuit with a remote operated vehicle deployed from a surface unit, flushing at least a portion of the fluid from the separation circuit, performing at least one pressure test, passing the downhole fluid through a fluid separator.

BRIEF DESCRIPTION OF THE DRAWINGS

So that the above recited features and advantages of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to the embodiments thereof that are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are, therefore, not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments. The figures are not necessarily to scale, and certain features and certain views of the figures may be shown exaggerated in scale or in schematic in the interest of clarity and conciseness.

FIG. 1 is a schematic view of a production wellsite having a sampling system for sampling fluid.

FIG. 2 is a schematic view of a sampling system having a separation circuit.

FIGS. 3A-3K are detailed, schematic views sequentially depicting operation of a sampling system having a separation circuit with a pumping unit.

FIGS. 4A-4C are schematic views of a separation circuit with a single sample chamber pumping unit.

FIGS. 5A-5B are schematic views of a separation circuit with a dual sample chamber pumping unit.

FIG. 6 is a schematic view of a separation circuit with a triple sample chamber pumping unit.

FIG. 7 is a schematic view of a separation circuit with a multiple sample chamber pumping unit.

FIG. 8 is a schematic diagram depicting a sample control architecture.

FIG. 9 is a flow chart of a method of sampling a fluid from a production wellsite.

DETAILED DESCRIPTION OF THE INVENTION

The description that follows includes exemplary apparatuses, methods, techniques, and/or instruction sequences that embody techniques of the inventive subject matter. However, it is understood that the described embodiments may be practiced without these specific details.

Sampling of multi-phase fluid from a production wellsite may be performed to determine parameters of the fluid as it is produced from the wellbore. Such sampling may involve phase enrichment, the separation of the fluid into phases (e.g., oil, water, gas, sand, etc.) and retrieval of sufficient volumes for a full range of testing (e.g., composition, density, etc.). The techniques used herein may be adaptable to a variety of conditions, such as various wellsite configurations (e.g., various ports), various fluid conditions (e.g., temperature, pressure, etc.), and/or the presence of debris. The techniques used herein may also be performed to maintain fluid conditions (e.g., temperature, pressure, etc.), to avoid phase composition changes of the fluid, to provide continuous fluid processing, to reinject unwanted fluids back to the wellsite, to retrieve samples by constant pressure vessel(s), etc.

FIG. 1 depicts an offshore wellsite 100 having a sampling system 101 in accordance with the invention. The wellsite 100 has a surface system 102 and a subsea system 104. The surface system 102 includes a rig 106, a platform 108, a vessel 110 and a surface controller 112. The surface controller 112 may be provided with hardware and software for operating the surface system 102 and subsea system 104.

The subsea system 104 includes a tubing (or conduit) 114 extending from the platform 108 to a subsea unit 116, a tubular 118 extending downhole from the subsea unit 116 into a wellbore 120, the sampling system 101, and a remote operated vehicle (ROV) 122 deployable from the vessel 110 to the sampling system 101. The subsea unit may include various subsea devices, such as a conveyance delivery system, manifold, jumper, etc. (not shown), may also be provided in the subsea system 104. While the wellsite 100 is depicted as a subsea operation, it will be appreciated that the wellsite 100 may be land or water based.

The sampling system 101 is connectable to a port 123 in the subsea unit 116 for sampling fluid flowing through tubular 118. The port 123 may be an inlet or fluid access to the fluid from the tubular 118. As shown, the subsea unit 116 is a wellhead, but may be any component of the wellsite that has fluids flowing therethrough, such as the manifold, jumper or other devices (not shown). The sampling system 101 is fluidly connectable to the port 123 of the subsea unit 116 for receiving fluid therefrom. Fluid may be passed between the subsea unit 116 and the sampling system 101 during sampling operations as described further herein.

The sampling system 101 may be deployed to the subsea location on a skid 125. The skid 125 may be self sufficient, or deployed and/or operated by the ROV 122. In some cases, the ROV 122 and the skid 125 may be a single unit deployable to the subsea location. The ROV 122 may be linked to the vessel 110 and controlled thereby. The ROV 122 may be linked to the sampling system 101 for communication therewith. The ROV 122 may be used to provide power and/or control signals to the sampling system 101, and/or to retrieve data and/or samples from the sampling system 101. Collected samples may be taken back to the surface for analysis by the ROV 122. While the ROV 122 may be used to provide communication, power, transportation of samples and/or other capabilities, such features may be provided by other devices and/or within the sampling system 101 and the like.

To operate the surface system 102, subsea system 104 and/or other devices associated with the wellsite 100, the surface unit 112 and/or other controllers may be positioned about the wellsite and placed in communication with various components of the surface system 102 and/or subsea system 104. These controllers may be linked and/or activated by any suitable communication means, such as hydraulic lines, pneumatic lines, wiring, fiber optics, telemetry, acoustics, wireless communication, etc. The surface system 102 and/or subsea systems 104 at the wellsite 100 may be automatically, manually and/or selectively operated via one or more controllers (e.g., surface unit 112). Some such controllers may be separate units at the surface, such as surface unit 112, or at other locations, such as incorporated as part of sampling system 101.

Referring to FIG. 2, a sampling system 201 usable as the sampling system 101 of FIG. 1 is depicted. The sampling system 201 includes an interface 224 operatively connectable to the port 123, and a separation circuit 225. The interface 224 may be used to fluidly connect the sampling system 201 to the port 123 for passing fluid therebetween. The sampling system 201 may have a separation circuit 225 for separating the fluid into phases, and a sample chamber 234 for collecting samples. The sampling system 201 may be provided with various valves, flowlines, or other flow devices to manipulate flow therethrough as will be described further herein.

The sampling system 201 may be operated at certain conditions to maintain quality parameters, such as pressure and temperature of the fluid, and/or to cope with fluctuating inlet rates. For example, the sampling system 201 may be manipulated to maintain multiphase mixtures of live hydrocarbon at or near saturation pressure. At saturation pressure, decreases in pressure may result in the liberation of gas within the fluid (which may be gas or water), or the condensation of liquid within the gas phase, which may cause a deviation of the fluid composition and/or an unrepresentative sample. Liberation of gas may also amplify the mixture velocity (similar to opening a bottle containing a carbonated drink) and further inhibit separation. Variations of pressure may be inherent to systems where fluid is received at high pressure and released at low pressure. The separation circuit 225 may be used to dampen variation of speed in the intake of fluid and facilitate fluid separation, thereby minimizing phase composition change.

The sampling system 201 may use a differential pressure ΔP at the port 123 to facilitate flow through the separation circuit 225. The differential pressure may be a pressure difference across the subsea unit 116 (e.g., across a production choke valve, a choked flow control or another area of delta pressure). This differential pressure may provide sufficient pressure between a high pressure side and a low pressure side of the subsea unit 116 to drive fluid flow. The high pressure side of the fluid flow stream may be used to bring the sampling fluid into the sampling system 201. The lower pressure side of the flow stream may be used to allow fluid discharge from the sampling system back into the wellbore via outtake flowline 226b. The flowlines 226a,b may be interchangeable to permit fluid to pass in either direction therethrough. The discharged fluid may be replaced with the same volume of sampled fluid. Thus, the differential pressure at the interface 123 may be used to draw fluid into the sampling system 201.

The sampling system 201 may be usable at a wellsite with or without a differential pressure at the port 123. A pumping unit 247 may be used to draw fluid through the interface 123 and into the sampling system 201. The pumping unit 247 may include one or more pumping chambers 234a,b. The pumping unit 247 may be used to manipulate fluid flow therethrough to control pressure, to control fluid temperature, and/or to separate the fluid as is passes through the sampling system 201. Fluid may be collected in the pumping unit 247 and stabilized to allow it to separate into phases within the pumping chambers 234a,b. Separated fluid may be collected in pumping chamber 234a,b or diverted to a sample chamber 234c inside or outside of the pumping unit 247.

One or more sample or pumping chambers 234a-c may be used in the separation circuit 225 to collect samples of separated fluid. The sample chambers 234a-c used herein may be conventional sample chambers used for collecting fluid samples. The sample chambers 234c may have a cylinder 266 with a piston 268 slidably positionable therein to define a sample cavity 270 for receiving the downhole fluid and a buffer cavity 272 having a buffer fluid therein. Optionally, the sample chambers 234c may have additional features, such as a charging chamber 273 with a second buffer fluid (e.g., Nitrogen). The sample chambers 234c may be provided with additional pistons, charging chambers, charging fluids and/or other features as desired. Pump chambers 234a,b may be the same as sample chambers 234c.

The pump 247 and/or separator 246 may be used to control the flow as it is passed through the separation circuit 225. In some cases, fluid flow may need adjustment, such as where differential pressures across the sampling system 201 is too high, where the fluid separator 246 may be flooded, when samples are taken at downstream conditions, and/or where sampling rate variations are induced by quick pressure variations (or flashes) received from the pump 247. To provide necessary adjustments, the pump 247 may be varied, the fluid separator 246 may be activated to absorb fluid variations, the pump 247 may be installed upstream of the fluid separator 246, and/or the pump may be operated in “braking” mode to adjust flow rates.

The separation circuit 225 may have additional functions and features. For example, a separator 246 may optionally be provided upstream or downstream of the pump to facilitate separation of the fluid into phases as it passes through the separation circuit 225. A temperature controller, such as the thermal barrier 233 may also be provided to control temperature (actively or passively) in the sampling system and/or of the fluid. The individual sample chambers 234 may also have temperature controllers to selectively maintain and/or reduce temperature. The temperature may be adjusted to achieve a desired temperature and/or to maintain certain properties (e.g., phases).

FIGS. 3A-3K each show a detailed, schematic view of a sampling system 301 usable as the sampling systems 101, 201 of FIGS. 1,2. These figures sequentially depict the sampling system 301 performing a sampling operation. The sampling system 301 is depicted as having a separation circuit (or module) 325 and an interface 324 operatively coupled to the port (or tree) 123. Fluid may be passed into the sampling system 301, separated into phases for sampling, and collected for retrieval.

The port 123 may have various devices for fluidly connecting the sampling unit 301 to fluid in the subsea unit 116 (see FIG. 1). The port 123 as shown has a flushing fluid 382, a tree control 384 and production fluid access flowlines 386a,b in fluid communication with the subsea unit 116, but may vary with the wellsite features. Interface 324 may have various devices for operatively interacting with the port 123 to facilitate flow of the fluid between the subsea unit 116 and the sampling system 301. The separation circuit 325 is fluidly, electrically and/or hydraulically connected to the port 123 via the interface 324. The interface 324 as shown has various flowlines 226a,b and valves 335a-h for fluid interaction with the port 123 and the separation circuit 325. The interface 324, port 123, and separation circuit 324 also have links 393 for electrical and/or hydraulic coupling therebetween (and with the ROV 122 and the surface unit 112 if present).

Intake flowline 226a and outtake flowline 226b of interface 324 are fluidly connected to the production fluid access flowlines 386a,b in port 123, and to circuit flowlines 326a,b in the separation circuit 325 for fluid communication therebetween. Connectors 388a,b fluidly connect the circuit flowlines 326a,b of the separation circuit 325 to the intake flowline 226a and outtake flowline 226b, and electrically and/or hydraulically connect the interface 324 with the separation circuit 325 for electrical and/or hydraulic interaction therebetween and with port 123. Valves 355a,b are connected to production flowlines 386a,b and valves 335a-h are positioned in intake/outtake flowlines 226a,b of the interface 324 for selectively diverting flow therethrough. A connector 388b electrically and/or hydraulically connects the interface 324 with the separation circuit 325 for electrical and/or hydraulic interaction therebetween, and with port 123.

Separation circuit 325 may include a pumping unit 347, a flushing unit 349, sample chambers 334(a-g) and valves 352(a-l). Separation circuit 325 has sample chambers 334a-d fluidly connected to circuit flowlines 326b and sample chambers 334e-g fluidly connected to circuit flowline 326a. The sample chambers 334a-g may be the same as sample chamber 224 of FIG. 2, or may vary as desired. Sample chambers 334a-d may be used to collect samples of the downhole fluid drawn into the separation circuit 325.

Sample chamber 334e as depicted is the flushing unit 349 fluidly connected to flowline 326b for selectively flushing fluid from the separation circuit 325. The flushing unit 349 may include one or more sample chambers 334e fluidly connected about the separation circuit 325. The flushing unit 349 may also be fluidly connected to the sample chambers 334a-d by circuit flowline 374e1. Valves 352g-j may selectively permit passage of fluid between the sample chambers 334a-d and flushing unit 349. Flushing unit 349 may be used to flush fluid from the sample chambers 334a-d and the flowline.

Sample chambers 334f,g as depicted are pumping chambers 334f,g used as the pump 347 for selectively pumping fluid through the separation circuit 325. The pumping unit 347 includes two pumping chambers 343f,g for selectively manipulating fluid flow through the sampling unit 301, but one or more such chambers or other pumping devices may be used. The pumping chambers 343f,g are fluidly connected to circuit flowlines 326a,b. Sample chambers 334f,g have sample cavities 370f,g with sample flowlines 374f1-g1 fluidly connected to circuit flowline 326a for receiving or discharging fluid therefrom.

Buffer cavities 372f,g of pumping chambers 334f,g are fluidly connected together by a buffer flowline 376g. A pump 374 may be provided between the buffer cavities 372f,g for manipulating flow into the pump 347, for example, to draw fluid through the separation circuit 325 at a desired rate. Fluid may be drawn into the sample cavities 370f,g of the sample chambers 343f,g for separation therein. Separation may occur by gravitational separation in the sample cavities 370f,b. A sand filter 373 may also optionally be provided.

The fluid may then be selectively pumped out of the sample cavities 370f,g, through sample flowlines 374f2-g2 to the sample chambers 334a-d. Valves 352b-e,k-o may be used to selectively divert fluid to the sample chambers 334a-d. Sample chambers 334a-d may be in selective fluid communication with sample cavities 370f-g via flowlines 374a1-d1 for receiving fluid therefrom. Sensors 380 in sample flowlines 374f2,g2 may be provided to determine when to allow fluid to divert. Once the sensors 380 detect a given phase of a fluid, the fluid may be diverted into a sample cavity 370a-d of a desired sample chamber 334a-d. Sample chambers 334a-d may be used to collect and store separated fluid for retrieval to the surface. The separation circuit 325 may optionally be provided with a separator 246 for separating the fluid.

The separation circuit 325 may also be provided with electrical components 390a,b,c electrically coupled to the ROV 122 and the surface unit 112. Electrical component 390a is depicted as a communication unit, such as a transceiver, for communicating with the ROV 122 (or other communication devices). Electrical component 390b may be a power source, such as a power supply or battery, electrically coupled to a power source 392a in the ROV 122 and/or the surface unit 112. Electrical component 390c may be a computer unit, such as a controller, processor, and/or database, electrically linked to the surface unit computer 392b via ROV 122. The ROV 122 may also be provided with a hydraulic source 392c for powering the fluid devices, such as valves in the separation circuit 325, interface 324 and/or port 123. The links 393 may be used, for example, to power, activate and/or control components, such as valves of the sampling system 301 and/or port 123.

During operation, commands may be sent, for example, from the surface unit 112 and/or ROV 122 to the separation circuit 325, interface 324 and/or port 123 to activate various flow control devices, such as sample chambers 334a-g, pump 347, valves 352a-o or other devices therein. Each of the FIGS. 3A-3G sequentially depict steps of a sampling operation. In the initial step of FIG. 3A, the valves 352a-j,m,o are closed and valves 352k,l,n are open.

In the hot stab step of FIG. 3B, a connection is established between separation circuit 325 and interface 324 via connector 388a,b for hydraulic and/or electrical interaction between separation circuit 325 and interface 324. As also shown in FIG. 3B, valves 352a,f,k,l,n,o are opened for performing a pressure test. The pressure test may be used to verify that the hot stab connection between the port 123, interface 324 and/or sampling circuit 325 is working satisfactorily. The pressure test may be performed, for example, by using pumping unit 347 to draw fluid into the sampling circuit from flushing unit 349. Sensors 380 (and/or other sensors) may be used to monitor pressure and relay data to the ROV 122 and/or surface unit 112 as necessary.

In step 3 of FIG. 3C, a pressure test may be performed by opening port valves 355a,b to the tree flushing fluid 382, and opening interface valves 335b,c,f,g. As shown in FIG. 3C (and after performing the hot stab test of FIG. 3B), the fluid of the pumping unit 347 and flushing unit 349 may be used to perform the pressure test on valves 335a-b of interface 324. In some cases, flushing fluid from charging tank 382 may be used to perform the pressure test on valves 335a-b.

Interface valves, such as 335a,b,e,f and/or others, may be opened by link 392c as shown in FIG. 3D. The interface valves 335a,e may to fluidly link hydraulic unit 392c with the charging tank 382. Sensors may be provided about port 123 to measure pressure. Data gathered by these sensors may be captured by the computer unit 390c and passed to the ROV 122 and/or surface unit 112, for example, when a connection is provided in 388b.

In a back flushing step of FIG. 3E, fluid is pumped from flushing unit 349 by pumping fluid in pumping unit 347 from buffer cavity 372f to buffer cavity 372g. This pumping action causes fluid to flow from sample cavity 370g out through flowline 326b and through port 386b. This step may also be performed by flushing the fluid out through flowline 326a and through port 386b by closing valve 352f and opening valve 352a. Fluid may also be flushed through sample cavities 370e,f,g and discharged through flowline 226b of interface 324, out through the port outlet 386a and back to the subsea unit 116.

In an intake step of FIG. 3F, fluid is pumped by pump 347 from buffer cavity 372g into buffer cavity 372f. Valves 352b-e,g-j,m is closed and valves 352a,f,k,l,n,o are open. Valves 352k, l are redirected to fluidly connect sample cavities 370f,g to flowline 226b for drawing fluid into sample cavities 370f,g.

In another intake step of FIG. 3G, fluid is pumped by pump 347 from buffer cavity 372f into buffer cavity 372g. Valves 352b-e,g-j,m is closed and valves 352a,f,k,l,n,o are open. Valves 352j,k,l are redirected to fluidly connect sample cavities 370f,g to flowline 226b for drawing fluid into sample cavities 370f,g, and discharging fluid from fluid cavity 370g to flowline 226a.

In FIG. 3H, pumping is completed, pump 347 is turned off. As fluid flows into the sample chambers 334f,g, the pistons 368f,g fall to receive sampling fluid into sample cavities 370f,g. While sample chambers 334f,g are depicted as having equal volumes of selected phases, any amounts may selectively be collected in any of the chambers.

In a sampling step of FIG. 3I, valves 352a-d,g-i,o are closed, valves 352e,f,j-n are open, and valves 352j,k are redirected to allow fluid to flow from flowline 226b and into fluid cavity 370g. Buffer fluid from buffer cavity 372g passes into buffer cavity 372f. Fluid from fluid cavity 370f is passed into fluid cavity 370d. Buffer fluid from buffer cavity 372d is passed into fluid cavity 370e.

In another sampling step of FIG. 3J, valves 352a-c,e,f,g,h,j,m are closed, and valves 352d,i,k,l,n,o are opened. Buffer fluid from buffer cavity 372f passes into buffer cavity 372g. Fluid from fluid cavity 370g is passed into fluid cavity 370e. Buffer fluid from buffer cavity 372d is passed into sample chamber 334e. Valve 352l is diverted to allow fluid to flow from intake flowline 226b into sample chamber 334g. In a final flushing step of FIG. 3K, valves 352a,f,i,k,l,n are open, and valves 352b-e,g-h,j,m,o are closed. Valve 352k is redirected to fluidly connect sample cavities 370e,f to flowlines 226b. The steps may be repeated as desired to sample from one or more sample chambers 334. Additional steps may be performed to selectively divert fluid as desired and/or optionally to reverse flow.

FIGS. 4A-4C are schematic views of a separation circuit 425a1-a3, respectively, each having a single pumping/sample chamber 434. The separations circuits 425a1-a3 may act as pumping units 447. Flow into the pumping/sample chamber 434 may be achieved by using differential pressure pumping as previously described with respect to FIG. 2. The pumping chambers have cylinders 466 with pistons 468 therein defining a fluid cavity 470 and a buffer cavity 472. Fluid from the wellbore (e.g., 120 of FIG. 1) may be drawn into intake flowline 426a and collected in the fluid cavity 470.

In the differential pressure configuration of FIG. 4A, the separation circuit 425 may be provided with a flow controller, such as orifice 476, used in combination with valves 452 (or other proportional control device). The separation circuit 425a1 may be used to define a hydraulic fluid flow rate for buffer fluid to exit the buffer cavity 472 through outtake flowline 426b, thereby lowering the pressure in fluid cavity 470 and drawing fluid therein. The fluid drawn into the fluid cavity 470 may be permitted to separate into phases therein. The flow rate at which the buffer fluid exits the buffer cavity 472 may be used to define the rate that fluid can enter the fluid cavity 470. Sensors (or pressure gauges) 438 and/or a fluid monitor 475 may be provided for monitoring the flow through the pumping chamber 434.

Flow into the pumping/sample chamber 434 may also be achieved by pumping as shown in FIGS. 4B-4C. Using pump 474 to facilitate moving fluid in and out of the separation circuit 425 can be used, for example, when no differential pressure is available from the subsea unit 116. In the pumping configurations of FIGS. 4B and 4C, the separation circuits 425a2,a3 are provided with a hydraulic pump 474 fluidly connected to the buffer cavity 472. A sample may be collected in fluid cavity 470 by opening the inlet and outlet valves 452 of the separation circuit 425a1 and activating the pump 474. The pump 474 may be used to pull the hydraulic fluid out of the buffer cavity 470, which draws fluid into the fluid cavity 470 (similar to drawing fluid into a syringe). In FIG. 4B, the pump 474 is used to pump buffer fluid back out outtake flowline 226b as the sample is drawn into the fluid cavity 470. Valve 452 in flowline 426b may be activated to allow fluid flow to discharge through outtake flowline 426b. In FIG. 4C, the buffer fluid is pumped with a bi-directional pump 474 into a reservoir 440 for reuse.

FIGS. 5A-5B are schematic views of a separation circuit 425b1,b2 having two pumping/sample chambers 434a,b that may form a pumping unit 447. In this version, the sample chambers 434a,b are connected in parallel. The fluid cavity 470a of the pumping/sample chamber 434a has two sample flowlines 474a1,a2, and the fluid cavity 470b of the sample chamber 434b has two sample flowlines 474b1, b2. The sample flowlines 474a1, b1,b2 are fluidly connected to the intake flowline 226a for passage of fluid into the sample cavity 470a for sampling. The sample flowline 474a2 is fluidly connected to the outtake flowline 226b for passage of fluid from the sample cavity 470a for discharge.

Each of the pumping/sample chambers 434a,b have a shared buffer flowline 476. The buffer flowline 476 fluidly connects the buffer cavity 472a,b of each of the sample chambers 434a,b to allow buffer fluid to pass therebetween. The buffer cavities 472a,b may be charged with, for example, about 50% buffer fluid. As fluid is drawn into one of the sample cavities 470a,b of one of the pumping/sample chambers 434a,b, buffer fluid may be passed between the buffer cavities 472a,b of each of the sample chambers 434a,b to adjust pressure therebetween. The buffer fluid may also be manipulated between the buffer cavities 472a,b to draw fluid into the sample cavities 470a,b.

Similar to the technique described with respect to FIG. 4A, flow into the pumping/sample chambers 434a,b may be achieved by using differential pressure pumping as shown in FIG. 4A. In the pressure differential configuration of FIG. 5A, differential pressure may be used as the motive force to drive the pistons 468a,b back and forth by selectively switching the inlet valves 552a-b (and optionally 552c-d) and creating a pumping action. The upstream pressure from intake flowline 226a may be used to push the piston 468a down while collecting the well fluid in sample cavity 470a and transferring the hydraulic fluid between buffer cavities 472a,b. This will then lift the piston 470b in sample chamber 434b to discharge the well fluid out of sample cavity 470b.

The fluid drawn into the sample cavities 470a,b may be permitted to gravitationally separate. As fluid separates, fluid may be selectively passed from the sample cavities 470a,b and monitored by sensors (or phase detectors) 580a,b. Sensors 580a,b may be provided to measure or detect the phases of the fluid during the discharge cycle at the outlet of a sample cavity 470a,b. Output from the sensors 580a,b may be used to activate the movement of the sample chambers to pump fluid through the pumping/sample chambers 434a,b to capture selected phases of the fluid. Sensor 580c may also be provided to monitor the buffer fluid. The sensor 580c may also be used to activate reverse pumping action when a single target phase concentration is required, or switch the outlet flow to a separate downstream collection vessel (not shown) designated for the collection of the detected phase.

The separation circuit 425b1 may be flow controlled to help determine the rate that the sample is collected. Sampling rates for this type of system may range from about 0.1 liters/min to about 20 liters/min. In cases where the separation circuit system 425b1 is used for water phase sample collection and the well fluid flow has very low water cut, full cylinder cycling may need to be reduced until sufficient water is collected in the pumping/sample chamber 434a,b to overcome system detection response times and dead spaces that may exist in an upper portion of the pumping/sample chamber 434a,b and associated piping and valves upstream of the separation circuit 425b1.

Similar to the technique described with respect to FIGS. 4B-4C, flow into the pumping/sample chamber 434a,b may be achieved by pumping as shown in FIG. 5B. In the pumping configuration of FIG. 5B, the separation circuit 425b2 is provided with a hydraulic pump 474 fluidly connected to the buffer flowline 476. A sample may be collected in sample cavity 470a by opening the inlet and outlet valves 552a,b of the separation circuit 425b2 and activating the pump 474. The pump 474 may be used to pull the hydraulic fluid out of the buffer cavity 472a which is replaced by an equal volume of sampled fluid in the sample cavity 470a (similar to drawing fluid into a syringe). In FIG. 5B, the pump 474 is used to pump buffer fluid between buffer cavities 472a,b.

The pumping/sample chambers 434a,b can also be piston type sample chambers used to help control sample pressures. Sample cavity 470a of chamber 434a may be charged with 100% hydraulic fluid, while sample cavity 470b of sample chamber 434b may be charged with 0% buffer fluid. Valves 552a,b may be opened to permit fluid from intake flowline 226 to enter sample cavities 470a,b. Valve 552c may be selectively adjusted to control the rate of hydraulic fluid (which in turn controls the sampling fluid(s) volumetric rate). The hydraulic fluid may be allowed to flow until, for example, the total hydraulic fluid is transferred. The transfer may be verified by hydraulic fluid totalized or loss of flow through sensor 580b. A sensor 580c may detect the selected phase or desired interface discharged from the sample cavity 470a, or a predetermined amount of hydraulic fluid is transferred based on a short cycling time requirement (i.e. low water cut fluid for a “water only sample”).

Once operation is complete, valves 552a,b may be closed, and the cycle reversed. Valves 552a,b may then be re-opened. Valve 552c may be left in the previous position or changed as necessary depending on the cycle time from the previous cylinder cycle. Cycling and sampling may continue in this alternating sequence until a desired quantity of selected phase is captured. The hydraulics from the sample chambers 434a,b may be discharged out outtake flowline 226b, or recycled back to a hydraulic system for use when the sample chambers are discharged for analysis.

FIG. 6 is a schematic view of a separation circuit 425c having three sample chambers 434a-c. Sample chambers 434a,b act as pumping unit 447, while sample chamber 434c collects samples of fluid. In this version, multiple sample chambers 434a,b,c may be connected in parallel. The sample cavity 470a of the sample chamber 434a has two sample flowlines 474a1,a2, the sample cavity 470b of the sample chamber 434b has two sample flowlines 474b1, b2, and the sample cavity 470c of the sample chamber 434c has two sample flowlines 474c1, c2. The sample flowlines 474a1,b1,c1 are fluidly connected to the intake flowline 226a for passage of fluid into the sample cavities 470a,b,c for sampling. The sample flowlines 474a2,b2,c2 are fluidly connected to the outtake flowline 226b for passage of fluid from the sample cavity 470a,b,c for discharge.

Each of the sample chambers 434a,b,c have a shared buffer flowline 476. The buffer flowline 476 fluidly connects the buffer cavity 472a,b,c of each of the sample chambers 434a,b,c to allow buffer fluid to pass therebetween. The buffer flowline 476 may also be fluidly linked to outtake flowline 226b. As fluid is drawn into sample cavities 470a,b,c of the sample chambers 434a,b, buffer fluid may be passed between the buffer cavities 472a,b of each of the sample chambers 434a,b, or discharged to outtake flowline 226b to adjust pressure therebetween. Buffer fluid may optionally be passed to fluid tank 440 for storage and reuse.

The separation circuit 425c may use pump 474 to pump buffer fluid through outtake flowline 226b or to the hydraulic reservoir 440. The hydraulic reservoir 440 may be used, for example, when a sample is concentrated with a particular fluid phase. Sensors (e.g., phase detector) 580a,b,c in flowline 474a2,b2,c2 to detect fluid exiting sample cavity 470a,b,c, in a similar manner as the separation circuit 425b2 of FIG. 5B. The fluid in the pumping chamber(s) 434a-b may be allowed to separate. Once a desired phase is detected by the sensor(s) 580a-c, fluid may be captured in one of the sample chambers 434a-c, or in one or more additional sample chambers (not shown). Valves 552a-r or other valves, such as valves 452, may be activated to selectively divert the fluid to capture the desired samples.

FIG. 7 is a schematic view of a complex separation circuit 425d having multiple pumping and sample chambers 434a-f in a sample storage configuration. In this version, multiple pumping chambers 434a-b are connected in parallel, and sample chambers 434c-f are connected in series. The sample chambers 434a,b form the pumping unit 447 for selectively drawing fluid through the separation circuit 425d. One or more sample chambers 434c-f may be used to collect samples of separated fluid.

The sample cavity 470a-f of each of the sample chambers 434a-f has a flowline 474a1-f1 and a flowline 474a2-f2. The flowlines 474a1,b1,b2 are fluidly connected to the intake flowline 226a for passage of fluid into the sample cavities 470a-f for sampling. The sample flowlines 474a2, b2,c1-f1,c1-f2 are fluidly connected to the outtake flowline 226b for passage of fluid from the sample cavity 470a-f for discharge.

Buffer cavities 472a,b of the sample chambers 434a-b are fluidly connected by a buffer flowline 476. Each of the sample chambers 434c-f have a buffer flowline 474c-f fluidly connected to outtake flowline 226b. The flowlines 474c-f fluidly connect the buffer cavities 472c-f of their respective sample chambers 434c-f to allow buffer fluid to pass therebetween.

In the sampling configuration of FIG. 7, sample chambers 434a,b act as pump 447 to reciprocate and draw fluid from intake flowline 226a. Fluid may be selectively drawn into sample cavities 470a,b and/or withdrawn from buffer cavities 472a,b. The reciprocating action of the sample chambers 434a,b may be used to selectively pump fluid from sample cavities 470a,b into one or more of the sample cavities 470c-f of sample chambers 434c-f. A pump 474 may be provided in the buffer flowline 476 to draw fluid into the sample cavities 470a,b.

Fluid passed into sample cavities 470c-f of sample chambers 434c-f may be stored or discharged through outtake flowline 226b. As fluid is passed into sample cavities 470c-f, buffer fluid may be discharged to outtake flowline 226b through buffer flowlines 474c-f. The selective reciprocation may be used to selectively discharge portions of the fluid that may gravitationally separate in the sample cavities 470c-f. The pumping and/or sample chambers 434a-f may be tilted to facilitate separation and/or diversion of separated fluid.

As also depicted in FIG. 7, the sample chambers 434c-f may optionally have flushing fluids in charging chambers 473c-f. While certain sample chambers 434a-f are shown for pumping and for storage, any number of sample chambers 434a-f may be used in various arrangements to pump and collect fluid. Sensors 580a-c may be provided to detect the phases of the fluid passing through the sample cavities 470a-f to detect desired phases for collection. Valves 552a,b or other valves may be selectively activated based on the detect fluid to divert fluid to sample cavities 434c-f for collection, or to discharge fluid through outtake flowline 226b.

The sample chambers described herein may be used to pump and/or store fluid. For example, the sample chambers may be arranged to provide for the segregation of the multiphase fluid when, for example, a “water only” sample is desired. Sample chambers herein may function as a dual action pump into a selected sample chamber for storage. As the fluid flows into a selected storage sample chamber, the water phase may separate from the fluid and settle to the bottom of the sample chamber while the oil and gas phase may be slowly discharged out the top and back into the production flow. The angle of the storage cylinder may be positioned to optimize separation. The angle may be selected to take advantage of a ‘boycott effect’ during phase separation.

The sample chambers described herein may optionally have flushing fluids in charging chambers. The sample chambers (or sample storage cylinders or storage bottles) used herein can be of several different types and orientation. Sample chambers may be single piston, dual piston or non-piston type. The orientation of the cylinders may be positioned in a vertical or angled position. The degree of angle that the sample chamber may be positioned may be selected based on the functionality and efficiency of intended performance or use, or to reduce the height of the sample chamber within a confined or limited space.

Sample chambers used for sampling and/or storing may be of a single phase fluid design or a multiphase fluid design. The sample chambers may also be designed and certified for department of transportation (DOT) requirements, for example, if the samples are retrieved and transported for analysis. Sample chambers may also be used with an auto-closing feature which isolates and closes the cylinder when a predefined quantity of fluid has been captured in the sample chamber. Such auto-closing features can be incorporated in the design and used when increased safety is desired during the sampling process.

The sampling systems herein may use segregated samples, concentrated or phase enhanced samples, and/or well flow representative samples. Segregated samples may involve phase segregated samples where the phases of the multiphase fluid may be separated inside the sample bottles. These segregated samples may be transported in the sample chamber to an analysis lab, or can be further processed by a decanting procedure with the sampling system.

Concentrated or phase enhanced samples may be used where a single phase is needed for analysis. The sample collected may be enhanced during the cycling or discharge cycle using a phase detector. The sampling system can detect phases selected during a cylinder discharge cycle and divert that phase to a sample chamber (e.g., 334e) for discharging the oil and gas.

Well flow representative samples may involve selection of a sampling interface location or utilization of a permanent or insertable probe into a wellhead. It may be possible to obtain fluid in the sampling flow line with correct phase volume proportion to the main flow line. Various phases (e.g., gas, oil, water, etc.) may be present; however, in some cases only water cut (Vw/(Vo+Vw)) or GVF (Vg/(Vo+Vw+Vg)) may be obtained. Empirical correlations may be developed to establish a systematic deviation between sample line phase volumetrics and main line volumetrics such that main line phase volumes can be determined from sample line volumes.

Collection of samples for phase volume determination may be obtained in a “one shot” sample, whereby the fluid may be extracted from the main flow line at a set rate of displacement to fill a single sample chamber in a single cycle of a sample chamber piston. A sample cavity may then be isolated and phase volumes determined either in situ (subsea) or at surface or after transport to a laboratory.

FIG. 8 is a schematic diagram depicting a sampling tool 800 usable with the surface unit 112 of FIG. 1. The various controls and components of FIG. 8 may be used to control the operation of the sampling systems herein. These controls and components may be used, for example, to activate the surface unit 112, ROV 122, sampling system 101 and/or port 123. The sensors used herein may send signals to the sampling tool 800 and flow control devices, such as valves and pumps, may be activated to divert fluid for separation and sampling. Part or all of the sampling tool 800 may be positioned in various locations about the wellsite for operation of desired components. The sampling tool 800 may gather information, make decisions, send commands and/or perform operations as desired.

The sampling tool 800 may include sampling controls 894, ROV controls 895, sampling skid & ROT controls 899, offsite data collection and monitoring 891, surface equipment 893b, and subsea equipment 893a. The sampling controls 894 may include sampling components, such as operator controls, data collection, and process controller & logic solvers. The sampling skid & ROT control 899 may include skid components, such as control valves & sensors, data collection, process controller, I/O, and logic solvers.

The ROV controls 895 may include ROV surface control 896, and ROV & ROT control 897 linked by an umbilical 898. The ROV surface control may include ROV components, such as power generators, communications, operator controls. The ROV & ROT control 892 may include power JP, communication interface and hydraulic systems.

FIG. 9 depicts a method 900 for sampling fluid from a wellbore. The method may involve positioning (990) a sampling system about a wellsite (e.g., deploying via an ROV), establishing (991) fluid communication between an interface and the port, establishing (992) fluid communication between a separation circuit and the interface (the separation circuit comprising at least one sample chamber and a pumping unit, the pumping unit comprising a plurality of pumping chambers, the plurality of pumping chambers each having cylinder with a piston therein defining a fluid cavity and a buffer cavity), selectively flowing (993) the fluid between the separation circuit, the interface and the port at a controlled rate (e.g., flow rate and/or pressure) by selectively manipulating the buffer fluid between the buffer cavities of the plurality of pumping chambers, receiving (994) the fluid in the fluid cavity of at least one of the plurality of pumping chambers and allowing separation of the fluid into a plurality of phases therein, and collecting (995) at least one sample of at least one of the plurality of phases of the fluid in the at least one sample chamber. The buffer fluid may be selectively manipulated using a pressure differential across the port, and/or selectively manipulated using a pump.

The method may also involve electrically connecting the separation circuit to the interface and the port for selective activation thereof, deploying at least a portion of the separation circuit with a remote operated vehicle deployed from a surface unit, retrieving at least a portion of the separation circuit with a remote operated vehicle deployed from a surface unit, flushing at least a portion of the fluid from the separation circuit, performing at least one pressure test, and/or passing the downhole fluid through a fluid separator. The steps may be performed in various orders and repeated as desired.

While the present disclosure describes specific aspects of the invention, numerous modifications and variations will become apparent to those skilled in the art after studying the disclosure, including use of equivalent functional and/or structural substitutes for elements described herein. For example, the sampling system herein may use one or more pumping chambers in various circuit arrangements to selectively separate and/or manipulate fluid flow into one or more sample chambers for sampling.

Plural instances may be provided for components, operations or structures described herein as a single instance. In general, structures and functionality presented as separate components in the exemplary configurations may be implemented as a combined structure or component. Similarly, structures and functionality presented as a single component may be implemented as separate components. These and other variations, modifications, additions, and improvements may fall within the scope of the inventive subject matter.

METHOD AND SYSTEM FOR SAMPLING MULTI-PHASE FLUID AT A PRODUCTION WELLSITE

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