US20110023595A1 - Compact fluid disposal system and method for surface well testing - Google Patents
Compact fluid disposal system and method for surface well testing Download PDFInfo
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- US20110023595A1 US20110023595A1 US12/810,158 US81015808A US2011023595A1 US 20110023595 A1 US20110023595 A1 US 20110023595A1 US 81015808 A US81015808 A US 81015808A US 2011023595 A1 US2011023595 A1 US 2011023595A1
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Images
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/74—Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F15/00—Details of, or accessories for, apparatus of groups G01F1/00 - G01F13/00 insofar as such details or appliances are not adapted to particular types of such apparatus
- G01F15/08—Air or gas separators in combination with liquid meters; Liquid separators in combination with gas-meters
Definitions
- the present invention generally relates to well testing, and more particularly to a compact fluid disposal system and method for surface well testing.
- the three main objectives are to measure the volumetric flow-rate of individual phases, obtain samples and determine characteristics of the main fluids, and disposal off the effluents.
- metering technology has been developed to provide individual flow-rates without needing any separation, thanks to the use of multiphase meters that can measure the flow rate of the oil, gas and water in a oil well effluent without the need for separation.
- a separator is still required to separate liquid from gas to burn oil and flare gas, respectively. The separator is also needed when handling the clean-up phase to extract water from oil, when the resulting liquid is not burnable.
- An exemplary global surface platform employs a multiphase meter for metering and fluid sampling purposes. Downstream of the multiphase meter is a disposal system made up of a compact high pressure gas/liquid splitter and a combined low pressure free water knock out (FWKO)/holding tank.
- the exemplary platform can be used for the beginning of a well clean up phase, for clean up of a well in development, and to stabilize flow of a well.
- a compact fluid disposal and surface well testing system includes a multiphase meter for flow-metering and sampling of a received oil/gas/water stream and generating flow information for the received oil/gas/water stream; a compact gas/liquid splitter coupled to the multiphase meter and configured for generating a gas rich stream, and a liquid rich stream from the oil/gas/water stream based on the flow information from the multiphase meter; and a free water knock out (FWKO)/holding tank coupled to the compact gas/liquid splitter for receiving the liquid rich stream from the compact gas/liquid splitter and degassing the liquid rich stream and performing oil/water separation on the liquid rich stream.
- FWKO free water knock out
- a method for a fluid disposal and surface well testing system which may be a compact system.
- the method includes flow-metering and sampling a received oil/gas/water stream and generating flow information for the received oil/gas/water stream with a multiphase meter; generating a gas rich stream, and a liquid rich stream from the oil/gas/water stream based on the flow information from the multiphase meter with a compact gas/liquid splitter coupled to the multiphase meter; and receiving the liquid rich stream from the compact gas/liquid splitter and degassing the liquid rich stream and performing oil/water separation on the liquid rich stream with a free water knock out (FWKO)/holding tank coupled to the compact gas/liquid splitter.
- FWKO free water knock out
- FIG. 1 illustrates a typical scenario of gas and liquid flow-rate evolution against time for a well in development
- FIG. 2 illustrates a background art surface testing platform based on a horizontal gravity separator
- FIG. 3 illustrates a background art flow mixer used as a slug catcher
- FIG. 4 illustrates typical performance characteristics of the flow mixer of FIG. 3 ;
- FIG. 5 illustrates a background art vortex separator
- FIGS. 6-8 illustrate a background art low current-high voltage electro-coalescer
- FIGS. 9-17 illustrate an exemplary compact fluid disposal system and method for surface well testing, according to the present invention.
- FIG. 1 illustrates a typical scenario of gas and liquid flow-rate evolution against time for a well in development and for which a long cleanup phase, producing large volume of non-hydrocarbons fluids at surface, is needed before starting the usual flow-periods.
- FIG. 2 illustrates a background art surface testing platform based on a horizontal gravity separator.
- a surge tank is usually made of two separate compartments. One is used as a tank holder for mud or any fluids recovered at the very beginning of the clean-up. These fluids need to be flashed and degassed through that tank to be eventually dumped to rig tanks that can be offshore.
- the second compartment is traditionally used as a buffer when the oil flow-rate is very low during the transition zone between the end of the clean-up and the beginning of the flow-period, but also for calibration of oil flow-meters. Such calibration is referred to as “combined meter factor,” including both shrinkage and meter calibration against oil density.
- a steam exchanger is often used to enhance separation, but also to prevent gas hydrate formation at the choke level when there is some water present.
- a flow mixer is a purely static device, including a tank into which the multiphase flow is fed. Most of the dense part of the fluid is drained from the bottom of the tank through an ejector, while the least dense part is drained from the top and directed via a pipe back to the ejector, where it is mixed with the dense part of the fluid, according to the ejection ratio.
- FIG. 3 shows an existing flow mixer used as a slug catcher.
- FIG. 4 illustrates typical performance characteristics of the flow mixer of FIG. 3 .
- the typical performance characteristics of the flow mixer over time are illustrated by simulating a square-wave hold-up pattern 402 at the inlet to the unit and with outlet gas volume fraction (GVF) 404 and liquid levels 406 also plotted.
- VVF outlet gas volume fraction
- FIG. 5 shows a background art continuous flow separator that simultaneously separates liquid/liquid, liquid/solid and liquid/liquid/solid mixtures flowing through the separator at high flow rates.
- the separator is a continuous flow turbo machine that generates a strong centrifugal action or vortex capable of separating light and heavy liquids, such as oil and water, or any other combination of liquids and solids, at extremely high flow rates.
- This separator accomplishes this separation through the creation of a strong vortex in the flow, as the fluid flows through the machine. In oil and water mixtures, this vortex causes the heavier elements (e.g., water) to gravitate to the outside of the flow and the lighter elements (e.g., oil) to move to the center, which forms an inner core.
- a vortex separator while achieving separation, also acts as its own pump, moving the fluid mixture through the machine.
- the open design of the impeller blades makes the separator virtually non-clogable.
- the centrifugal force generated by causing the flow to rotate rapidly in a vortex about the centerline of the impeller is the fundamental separation mechanism for a vortex separator.
- a vortex separator is energy self-sufficient and provides its own motive force.
- FIGS. 6-8 illustrate a background art low current-high voltage electrostatic coalescer to make oil-water separation more efficient and cost-effective, and which is especially designed to improve separation and the quality of the produced oil and water.
- Separators often experience problems with emulsions and capacity limits.
- An electrostatic coalescer (which may also be herein referred to as “electro-coalescer”) can enhance the speed and efficiency of the separation process, by forcing small water droplets in the oil continuous phase to merge and form larger, faster sedimenting drops.
- electro-coalescer can enhance the speed and efficiency of the separation process, by forcing small water droplets in the oil continuous phase to merge and form larger, faster sedimenting drops.
- this technology has so far been unavailable for the turbulent conditions in the inlet separator.
- an electrostatic coalescer greatly improves both the oil and produced water quality, as shown in FIGS. 7-8 .
- the use of an electrostatic coalescer can provide increased ability to separate heavy oil, improve produced water quality, increase production, reduce emulsion breaker consumption, improve process control, and reduce heating requirements.
- the exemplary embodiments are directed to a novel system and method for fluid disposal for surface well testing applications.
- An exemplary surface platform employs a multiphase meter for metering and fluid sampling purposes including determining flow trends. Downstream of the multiphase meter is a disposal system made up of a compact high pressure gas/liquid splitter and a combined low pressure free water knock out FWKO/holding tank, which will be described in more detail hereinafter.
- the exemplary platform can be used for the beginning of a well clean up phase, wherein effluent is directly sent to a holding compartment of the FWKO/holding tank for degassing purposes or flows through to the compact gas/liquid splitter to handle gas pockets.
- the exemplary platform also can be used for clean up of a well in development, wherein effluent is pre-separated through the compact gas/liquid splitter, a liquid rich stream is sent to an oil/water separation compartment of the FWKO/holding tank for degassing and oil/water separation, water is extracted from a bottom of the FWKO/holding tank for disposal, and separated oil is pumped and burned with an oil burner (e.g., an EVERGREEN available from Schlumberger), and the gas rich stream is sent to a wet gas flare.
- an oil burner e.g., an EVERGREEN available from Schlumberger
- the exemplary platform can additionally be used to stabilize flow of a well, wherein the liquid rich stream includes less than 25% of water so that a resulting liquid is directly burnable through the oil burner and the gas rich stream is sent to the wet gas flare.
- the exemplary platform advantageously, enables a global foot print reduction between 40-60%, as compared to background art systems.
- the flow envelope is about the same, and potentially greater than the background art platforms, especially for large gas flow-rates.
- the term “system” may also be referred to herein as “apparatus.”
- the exemplary platform can include exemplary components, including the gas/liquid splitter, the combination FWKO/holding tank, and a wet gas flare.
- the FWKO/holding tank also can be referred to as a two phase separator, i.e., it can separate oil and free water. It is usually a vertical separator used mainly to extract any free water from oil for disposal. Any gas entering the FWKO/holding tank is vented off.
- the exemplary components are described, for example, in terms of principle of operation, size, and weight, expected performance, and the like.
- FIGS. 9-17 there is illustrated an exemplary compact fluid disposal system and method for surface well testing, according to the present invention.
- flow-metering and sampling is provided by a multiphase meter 1902 (e.g., a PHASE-TESTER, or Vx TECHNOLOGY available from Schlumberger) located upstream or downstream of a choke manifold 1904 depending on the well head closing pressure.
- An oil/gas/water stream 1932 is delivered from a flow head 1906 .
- a gas/liquid splitter (GLSP) system 1908 operating at high pressure (HP) (e.g., up to 1400 psig, and with a minimum additional cost up to 2160 psig).
- HP high pressure
- the gas/liquid splitter system 1908 receives flow information 1930 from the multiphase meter 1902 and separates a multiphase stream 1910 from a well into separate streams, including a gas rich stream 1912 sent to a wet gas flare 1914 , and a liquid rich stream 1916 sent to a second stage FWKO/holding tank 1918 operating at low pressure (LP) (e.g., 0 to 150 psig) or directly to an oil burner 1920 .
- LP low pressure
- the second stage 1918 further includes a gas venting output 1927 , an output 1922 to a rig tank or pit, e.g., for water to the pit, over board rejection, storage tank or water treatment system, and an output 1924 to a transfer pump 1926 that transfers an oil stream 1928 to the oil burner 1920 .
- the gas/liquid splitter system 1908 can use the centrifugal forces of the fluid, but in a further exemplary embodiment external power, for example, supplied by an electrical motor, and the like, can be employed.
- the gas/liquid splitter system 1908 can employ similar principles as the vortex separator of the background art (e.g., a Voraxial separator available from Enviro Voraxial Technology, Inc.) or any other suitable continuous flow separator.
- the gas/liquid splitter system 1908 is configured for gas/liquid separation instead of oil/water separation, and advantageously the requirements in terms of separation efficiency can be much lower (e.g., it is possible to accept a non-negligible volume of liquid into the gas exit, and some gas bubbles into the liquid outlet).
- the compactness, i.e., relatively small footprint of the exemplary vortex-like system can be slightly undersized, as compared to an application where the separation efficiency has to be close to 100%.
- a further advantage is the relatively low rotation speed of the impeller that can be employed with the exemplary system, which helps to not induce too much shearing on the liquid to facilitate the later oil/water separation via a gravity effect.
- a mixing system for example, based on the background art flow mixer designs can be placed upstream to dump slugs and prevent the impeller of the GLSP from water hammering effects.
- some real time flow-metering data coming from the multiphase meter 1902 can be used to provide an efficient forward control of the employed control valves.
- the wet gas flare 1914 can be capable of accepting up to 30-40% of liquid, in mass ratio.
- the second stage 1918 can be a vertical tank, operating at low pressure (e.g., max 150 psig) for cost reasons, but also to enable degassing of the liquid.
- the tank 1918 can basically have the same configuration as known double compartment surge tanks.
- the second stage 1918 includes some novel differences in both the design and the mode of operation.
- a first compartment e.g., of 50 BBL capacity
- is configured as a tank holder for early cleanup e.g., mud and dirty fluids in place in the completion and the rate-hole
- the function of the first compartment is to hold dirty fluids for degassing, before rejection into a rig tank (e.g., offshore) or eventually for burning later on, if the fluid is burnable (e.g., offshore and on-shore).
- the fluid burn-ability also can be estimated from the multiphase meter in real time measurements for discriminating oil-based mud (OBM) from oil or diesel.
- OBM oil-based mud
- a second compartment (e.g., 50 BBL capacity) is provided and is configured as an oil/water vertical separator or so called free water knock-out (FWKO).
- the purpose of such a compartment is to extract as clean as possible aqueous fluid (e.g., water or brine) and send the remaining stream 1924 , which is mainly oil with less than 25% water, to the oil burner 1920 via the transfer pump 1926 .
- a heating system also is included to raise the liquid temperature and enhance the oil/water separation by reducing the oil viscosity.
- an optional electro-coalescer system can be employed (e.g., a background art electrostatic system, such as a VIEC-based system, available from Aibel) to break emulsions and enhance separation and enhance the purity of the extracted water.
- FIGS. 10-12 further detail the exemplary mode of operation of the exemplary surface platform 1900 .
- an exemplary flow path at the beginning of the cleanup phase for example, when the fluids are in place in the completion (e.g., including oil-based mud (OBM), water-based mud (WBM), diesel, fresh water or brine or solid loaded brine).
- OBM oil-based mud
- WBM water-based mud
- the effluent might be directly sent to the holding compartment of the second stage 1918 for degassing purposes or it could also flow through the GLSP-HP (Gas/Liquid splitter) system 1908 to first safely handle gas pockets.
- the gas/liquid separation energy e.g., via rotation of the impeller in that case can be fully provided, for example, by an electrical motor.
- FIG. 11 is shown an exemplary flow path after the uploading sequence of fluids in place in the completion and partly the rate-hole.
- This case is specifically addressing large clean-up for wells in development, for example, when a large volume of water based fluids (e.g., not burnable) have to be recovered at the surface.
- the effluent is primarily pre-separated through the gas/liquid splitter (GLSP-HP) system 1908 .
- the liquid rich stream 1916 is then sent to the oil/water separation compartment of the FWKO-LP system 1918 for degassing and oil/water separation.
- the water (e.g., with water purity basically of the same order of magnitude as water extracted from a conventional horizontal gravity separator) then is extracted from the bottom and disposed in an appropriate manner.
- the separated oil 1924 (e.g., containing up to 25% of water) then is pumped as an oil stream 1928 by the transfer pump 1926 and burned with the oil burner 1920 .
- the gas rich stream 1912 for example, eventually including a large quantity of liquid is sent to the wet gas flare 1914 .
- FIG. 12 is shown the situation of an exemplary stabilized flow-period.
- there is normally less than 25% of water in the liquid rich stream 1916 so that the resulting liquid is directly burnable through the oil burner 1920 .
- the gas rich stream 1912 can still be sent to the wet gas flare 1914 .
- Table 1 compares the exemplary compact set-up described with reference to FIGS. 9-12 with the background art set-up described with reference to FIG. 2 .
- Table 1 provides a comparison in terms of foot print:
- the exemplary compact platform includes novel features, including the combination of the multiphase meter 1902 , gas/liquid splitter system 1908 , the wet gas flare 1914 , the combined FWKO/holding tank 1918 , and the oil burner 1920 .
- the exemplary gas/liquid splitter system 1908 includes a flow mixer, for example, used to minimize the effect of sudden changes of gas volume fraction (GVF) and pressure fluctuations, which typically occurs when the flow is slugging, while also facilitating the system controllability.
- VVF gas volume fraction
- the size of the liquid volume (or surge flow) in slug flow conditions is fairly complex to determine, but can be estimated at around 2 BBL.
- a 2 BBL flow mixer is enough to prevent a multiphase, multi-stage, centrifuge pump from slug flow.
- the exemplary embodiments can employ a smaller mixer capacity (e.g., typically 1 BBL), for example, to increase the robustness of the gas/liquid splitter system 1908 against slugs due to low rotation speed and small impeller diameter, to minimize the slug dampening so that the splitter remains controllable under GVF and/or high dynamic flow-rate (e.g., this is related to the speed of control valve actuation downstream of the splitter outlets), and to provide for compactness.
- a smaller mixer capacity e.g., typically 1 BBL
- FIG. 13 shows the exemplary G/L splitter 2500 of the gas/liquid splitter system 1908 , and which operates on a principle of operation similar to that of the background art vortex-type system.
- the exemplary G/L splitter 2500 provides for a simple mechanical design with only one part rotating impeller 2502 and with no dynamic vibration induced by solid sticking of a rotating chamber, as used in background art centrifuge systems.
- the impeller 2502 design prevents clogging (e.g., due to a large opening area), and similar kind of flow (e.g., light fluid core with some re-circulation) can be achieved as with the background art vortex-type systems.
- similar kind of flow e.g., light fluid core with some re-circulation
- also provided are low electric power consumption by an electric motor 2504 the possibility to add an additional solid outlet if needed, and a light phase discharge pipe with a fixed diameter (e.g., no adjustable weir with complex cinematic need be employed).
- Differences from the background art vortex-type system include additional novel features of the G/L splitter 2500 , such as a multiphase mixture inlet 2506 that is tangential (e.g., to minimize shearing), the electrical motor 2504 provided in an oil chamber 2508 to obtain a pressure balanced dynamic sealing of a shaft 2510 (e.g., retain pressure between the oil bath surrounding the electrical motor and the separation chamber, which may also be accomplished by a magnetic coupling) to reduce friction, and increase the life time and prevent leaks, the re-use of parts already designed for electrical submersible pumping (ESP, e.g., electrical motor, and impeller), and an automatic gas/liquid interface control of the device.
- ESP electrical submersible pumping
- the G/L splitter 2500 also is configured to separate gas from liquid by employing different impeller and centrifuge forces, as compared to the background art vortex-type system.
- a low rotation speed is used for the employed diameter (e.g., typically 1800 rpm for a 4′′ separation chamber), and with a constant rotation speed to avoid use of a variable frequency drive (VFD) and thus to advantageously reduce size and cost.
- the G/L splitter 2500 further includes gas rich and liquid rich stream outlets 2512 and 2514 , respectively.
- FIGS. 14-15 show an exemplary phase-frequency detector (PFD) of the exemplary GLSP-HP system 1908 , and including a flow mixer 2606 for providing output stream 2608 to the G/L splitter 2500 .
- PFD phase-frequency detector
- two motorized control valves 2602 and 2604 are placed downstream of the gas rich outlet 2512 (producing a stream 1912 ) and the liquid rich outlet 2514 (producing a stream 1916 ), respectively.
- electrical actuators are employed instead of pneumatic actuators, advantageously, to obtain quick reacting valves.
- An advanced controller system is provided, for example, based on proportional-integral-derivative (PID) regulation or a Neural network, and using the real time flow-measurements delivered by the Vx meter.
- PID proportional-integral-derivative
- no sub-system for large size particle or metallic debris collection (e.g., typically 1 mm diameter or bigger) need be employed.
- a system can be employed to protect the centrifuge from destructive impacts to the impeller, and to prevent clogging of the liquid rich outlet 2514 .
- large damaging solids e.g., solids above 1 mm diameter
- the exemplary system of FIGS. 14-15 further includes a by-pass system 2702 and the centrifuge 2500 motor housing 2704 .
- the targeted flow-envelope of the exemplary system can be the same or larger than that of the background art systems (e.g., roughly 60 MMSCD & 6000 BLPD or 40 MMSCF & 15,000 BLPD @ 1440 psig).
- the volume of the separation chamber is defined as:
- the volume for the liquid ring and gas core will be approximately and respectively:
- the residence time of the liquid and the gas in the separation chamber would respectively be:
- the average liquid droplet size entrained into the outlet gas stream is calculated, as follows (e.g., based on the Stokes law):
- the above droplets sizes are not used to determine the separation efficiency, but rather for enabling one to qualitatively compare the separation efficiency of the invention's exemplary system with the background art horizontal gravity separator.
- the velocity of the liquid and the gas are respectively 0.05 m/s and 0.5 m/s at maximum capacity.
- the size of the gas droplets in the liquid leaving the exemplary separator from the oil outlet would be around 400-500 microns (e.g., under the assumption of a 10 cp oil viscosity) for 1 minute retention time.
- the gas/liquid interface needs to stay in between acceptable limits.
- the radius of the interface has to be kept larger than the radius of the gas core extraction tube and lower than the radius of the separation chamber to avoid sending a large amount of gas into the liquid leg.
- FIG. 16 shows an exemplary sensor system 2800 to locate the gas/liquid interface, for example, based on capacitive measurements.
- the exemplary sensor system 2800 includes, at an end of the separation tube 2500 , shown in FIG. 13 , two annular perforated support plates 2802 supporting capacitive electrodes or armors 2804 .
- the separation tube 2500 includes a separation chamber housing 2806 .
- the housing 2806 and the gas rich stream outlet (also referred to herein as “light phase extraction pipe”) 2512 are used as a support for the electrodes 2804 . This creates 4 cylindrical capacitive cells 2808 , as shown in FIG. 16 .
- the exemplary sensor system 2800 can be configured with the following exemplary geometrical data, including a length of the capacitor armor 2804 of 50 mm, a gap between R 2 and R 3 of 5 mm, a gap between R 1 and R 2 of 3 mm, and a gap between R 3 and R 4 of 3 mm. Accordingly, one can compute the order of magnitude of capacity to be measured based on the following table, as follows.
- the gas/liquid interface will be at radius R, so that R 3 ⁇ R ⁇ R 4 , and the following exemplary algorithm can be employed:
- ⁇ r - liq C liq 2 ⁇ ⁇ ⁇ ⁇ ⁇ 0 ⁇ H ⁇ ⁇ ln ⁇ ( R 4 R 3 )
- ⁇ r - gas C gas 2 ⁇ ⁇ ⁇ ⁇ ⁇ 0 ⁇ H ⁇ ⁇ ln ⁇ ( R 2 R 1 )
- FIG. 17 further illustrates the combined FWKO/holding tank 1918 used as the exemplary low pressure second stage and using the external geometry, for example, of a background art double compartment (e.g., 2 ⁇ 50 BBL) surge tank.
- a background art double compartment e.g. 2 ⁇ 50 BBL
- the novel features include the internal design, and the way the vessel capacity is used.
- there is one compartment (eventually both) used as a holding tank for mud and dirty fluids recovered at the beginning of the clean-up phase. This provides retention time and enables the fluid degassing, which is mandatory in case of rejection into rig tanks, for example.
- the second compartment is traditionally used for shrinkage and oil flow meter calibration (e.g., using the combined meter factor method), but also as buffer for oil.
- a first compartment 2902 also is employed for early cleanup fluids collection and degassing.
- a volume of 50 BBL for the first compartment 2902 is sufficient to hold a volume of fluid initially in place in the temporary completion and the rate hole (e.g., 3000 ft long of 31 ⁇ 2′′ ID tubing and which gives a 35 BBL volume).
- the fluids can be sent to a rig tank, with the surge tank compartment 2902 being configured to provide a buffer capacity, while still enabling degassing.
- the first compartment 2902 includes inlet 2904 (e.g., for diesel, OBM, WBM, completion fluid, solids from wellbore cleanup) and outlets 2906 (e.g., for degassed diesel, OBM, WBM, completion fluid, solids from wellbore cleanup for rig tank storage, pit or burning via the oil burner), 2908 (e.g., solid drain for holding tank) and 2910 (e.g., solid drain for FWKO), as shown in FIG. 17 .
- inlet 2904 e.g., for diesel, OBM, WBM, completion fluid, solids from wellbore cleanup
- outlets 2906 e.g., for degassed diesel, OBM, WBM, completion fluid, solids from wellbore cleanup for rig tank storage, pit or burning via the oil burner
- 2908 e.g., solid drain for holding tank
- 2910 e.g., solid drain for FWKO
- a second compartment 2912 is configured as a vertical oil/water separator (e.g., free water knock out).
- the separation stage 2912 enables one to extract the water volume with an oil-in-water content similar to what could be obtained from the background art horizontal separator.
- the compartment 2912 also can be used as a buffer for oil in the transition zone between the end of the clean-up and the flow period, when the oil flow-rate can be very low and below the minimum flow-rate required by the oil burner 1920 .
- an auto-adjustable floating smart weir 2914 in order to optimize the combined oil buffer and oil/water separation compartment 2912 and to unobtrusively monitor liquid levels.
- the auto-adjustable floating smart weir 2914 essentially comprises a radial collector connected to a flexible tube/bellow, wherein one end is attached to outlet 2926 of the compartment 2912 .
- the auto-adjustable floating smart weir 2914 is positioned just below the gas/liquid interface, and adjusts automatically regardless of the position of the gas/liquid interface on the oil/water interface.
- inlet/outlet 2918 for steam heating e.g., 10 Barg, 130° C.
- bellows 2920 an optional electro-coalescer 2916 (e.g., an electro-static type)
- outlets 2922 e.g., for gas venting 1927
- 2926 e.g., for sending oil to the oil burner via the transfer pump 1926
- 2928 e.g., for sending water to the pit, over board rejection, storage tank or water treatment system
- inlet 2924 e.g., for liquid (oil/water) from the gas/liquid splitter liquid rich stream 1916
- inlet 2924 e.g., for liquid (oil/water) from the gas/liquid splitter liquid rich stream 1916
- the combined oil buffer and oil/water separation compartment 2912 is at least as efficient as the background art horizontal separators.
- the vertical FWKO 2912 can extract water with the same purity as the background art horizontal separator, because although a vertical vessel is less efficient than a horizontal vessel, the increased size of the volume of the vertical vessel is much larger than that of the horizontal vessel.
- the exemplary operating mode of the FWKO 2912 can include an oil/water interface (e.g., when present) being maintained constantly at approximately one third of the bottom of the vessel, and with the total liquid level (e.g., oil) varying between a low and a high level (e.g., so as to be able to act as an oil buffer).
- the separation compartment 2912 can be heated via a low cost steam circulation coil or heat exchanger 2930 (e.g., employing SS316 1 ⁇ 2′′ diameter tubing and approximately 25 meter long). This heating capability, advantageously, can reduce the oil viscosity and help the oil/water separation, especially for low oil types (e.g., low API cases).
- T fuild inlet 40 degC
- the serpentine e.g., clean tube
- the thermal energy transferred from the steam to the liquid is 2.6 MBTU (753 kW), as compared to the heat provided with a conventional steam exchanger of 4.3 MBTU, and while also heating the gas.
- the heating system 2930 can be combined with the electro-coalescer module 2916 (e.g., a background art electrostatic system) to deal with difficult emulsion cases.
- the electro-coalescer module 2916 e.g., a background art electrostatic system
- Table 8 summarizes the functions of the tank in the background art set up and the exemplary invention compact set-up.
- the exemplary embodiments are directed to an exemplary surface testing platform employing a multiphase meter for flow-metering and sampling, and reducing the global foot-print from about 40 to about 60%.
- the overall estimated cost is significantly of the same order of magnitude as background art platforms based on the horizontal gravity separator.
- the exemplary platform is able to handle up to 60 MMSCFD for gas and 15,000 BLPD for liquid at a 1440 psig downstream choke pressure (e.g., a slightly larger operating envelope than a background art platform, in terms of disposal).
- the exemplary platform introduces novel components, including a compact gas/liquid splitter based on a vortex technology (e.g., centrifugation via an impeller and separation in a fixed wall chamber), a wet gas flare having a capability to accept up to 30-40% of liquid in mass ratio, and a combined holding tank/FWKO smart system.
- Gas/liquid pre-separation can be made at a maximum pressure of 1440 psig. However, this maximum pressure can be upgraded to 2160 psig with a reasonable extra cost (e.g., by replacing 600 RF flanges with RTJ Class 900 flanges), boosting the gas capacity by a factor 1.5 (e.g., 90 MMSCFD), and while maintaining the same foot-print.
- the exemplary gas/liquid splitter is based on a simplified centrifuge system, having a small diameter and low rotation speed, and thus being more reliable than background art systems based on large cylinders rotating at high speed.
- the low rotation speed can minimize the liquid shearing, while not creating very fine dispersed droplets into the continuous phase.
- the gas/liquid splitter system has a volume of 1 BBL while providing a low hydrocarbon inventory at high pressure and while improving safety.
- two gas/liquid splitters can be installed in parallel to handle up to 180 MMSCFD (e.g., in such a case, an 88 mm multiphase meter can be employed).
- the exemplary compact platform can extract water with the same oil-in-water content as background art platforms employing a steam exchanger.
- a combination of methanol/glycol and kinetic retardant injection instead of heating, can be employed.
- An exemplary way to manage the cleanup of this invention, especially the uploading of the fluids in place in the completion and the rate-hole when there is a lack of pressure, will foster the use of this technology in industry.
- An additional electro-coalescing system can be employed and can significantly improve the purity of the extracted water during the clean-up phase, facilitating the following water polishing step (if needed).
- All or a portion of the devices and subsystems of the exemplary embodiments can be conveniently implemented by the preparation of application-specific integrated circuits or by interconnecting an appropriate network of conventional component circuits, as will be appreciated by those skilled in the electrical art(s).
- the exemplary embodiments are not limited to any specific combination of hardware circuitry and/or software.
- one or more general purpose computer systems, microprocessors, digital signal processors, micro-controllers, and the like can be employed and programmed according to the teachings of the exemplary embodiments of the present inventions, as will be appreciated by those skilled in the computer and software arts.
- Appropriate software can be readily prepared by programmers of ordinary skill based on the teachings of the exemplary embodiments, as will be appreciated by those skilled in the software art(s).
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Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
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US12/810,158 US20110023595A1 (en) | 2007-12-24 | 2008-12-24 | Compact fluid disposal system and method for surface well testing |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
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US1654207P | 2007-12-24 | 2007-12-24 | |
PCT/US2008/088314 WO2009082758A1 (en) | 2007-12-24 | 2008-12-24 | Compact fluid disposal system and method for surface well testing |
US12/810,158 US20110023595A1 (en) | 2007-12-24 | 2008-12-24 | Compact fluid disposal system and method for surface well testing |
Publications (1)
Publication Number | Publication Date |
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US20110023595A1 true US20110023595A1 (en) | 2011-02-03 |
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Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US12/810,158 Abandoned US20110023595A1 (en) | 2007-12-24 | 2008-12-24 | Compact fluid disposal system and method for surface well testing |
Country Status (4)
Country | Link |
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US (1) | US20110023595A1 (de) |
EP (1) | EP2225539A4 (de) |
BR (1) | BRPI0821846A2 (de) |
WO (1) | WO2009082758A1 (de) |
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US20120150451A1 (en) * | 2010-12-13 | 2012-06-14 | Halliburton Energy Services, Inc. | Optical Computation Fluid Analysis System and Method |
WO2012118617A3 (en) * | 2011-03-03 | 2012-12-27 | Halliburton Energy Services, Inc. | Dispersing separated hydrocarbon gas into separated oil during surface well testing for improved oil mobility |
CN107238463A (zh) * | 2017-05-24 | 2017-10-10 | 西南石油大学 | 一种测试气体多级接触后最小混相压力的装置及方法 |
US20180128087A1 (en) * | 2016-05-26 | 2018-05-10 | Leroy Thomas Kuhn | Method and Apparatus for Separating and Measuring Multiphase Immiscible Fluid Mixtures |
CN108431178A (zh) * | 2015-12-22 | 2018-08-21 | 卡梅伦解决方案公司 | 用于减少空间和重量的上部采油设备系统 |
RU2681790C2 (ru) * | 2017-06-07 | 2019-03-12 | Общество с ограниченной ответственностью НАУЧНО-ПРОИЗВОДСТВЕННОЕ ПРЕДПРИЯТИЕ ГЕОФИЗИЧЕСКОЙ АППАРАТУРЫ "ЛУЧ" | Система для автоматического измерения объемного газосодержания и вихревой дегазации бурового раствора |
US11504648B2 (en) * | 2016-09-27 | 2022-11-22 | Schlumberger Technology Corporation | Well clean-up monitoring technique |
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CN107218034B (zh) * | 2017-06-02 | 2020-10-23 | 西南石油大学 | 一种模拟天然气水合物钻井多种扩径段流动状态变化实验装置 |
CN107656036B (zh) * | 2017-11-15 | 2023-07-25 | 兰州城市学院 | 一种高温高压动态封缝堵气效果评价实验装置及其评价方法 |
US11808615B2 (en) * | 2018-07-26 | 2023-11-07 | Schlumberger Technology Corporation | Multiphase flowmeters and related methods |
CN112161737B (zh) * | 2020-09-26 | 2022-06-07 | 首盛建设集团有限公司 | 一种基于信息技术的水利工程用监测装置 |
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RU2681790C2 (ru) * | 2017-06-07 | 2019-03-12 | Общество с ограниченной ответственностью НАУЧНО-ПРОИЗВОДСТВЕННОЕ ПРЕДПРИЯТИЕ ГЕОФИЗИЧЕСКОЙ АППАРАТУРЫ "ЛУЧ" | Система для автоматического измерения объемного газосодержания и вихревой дегазации бурового раствора |
Also Published As
Publication number | Publication date |
---|---|
EP2225539A4 (de) | 2016-06-29 |
BRPI0821846A2 (pt) | 2015-06-30 |
EP2225539A1 (de) | 2010-09-08 |
WO2009082758A1 (en) | 2009-07-02 |
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