US20130248465A1 - Return Fluid Separator - Google Patents
Return Fluid Separator Download PDFInfo
- Publication number
- US20130248465A1 US20130248465A1 US13/822,820 US201113822820A US2013248465A1 US 20130248465 A1 US20130248465 A1 US 20130248465A1 US 201113822820 A US201113822820 A US 201113822820A US 2013248465 A1 US2013248465 A1 US 2013248465A1
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- United States
- Prior art keywords
- tank
- separator
- screening device
- outlet
- rotary valve
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 52
- 238000012216 screening Methods 0.000 claims abstract description 58
- 239000007787 solid Substances 0.000 claims abstract description 44
- 238000005553 drilling Methods 0.000 claims abstract description 38
- 238000000034 method Methods 0.000 claims abstract description 16
- 239000002699 waste material Substances 0.000 claims abstract description 16
- 238000004891 communication Methods 0.000 claims abstract description 3
- 238000002955 isolation Methods 0.000 claims description 11
- 238000009826 distribution Methods 0.000 claims description 7
- 238000012546 transfer Methods 0.000 claims description 5
- 238000000576 coating method Methods 0.000 claims description 4
- 239000011248 coating agent Substances 0.000 claims description 3
- 235000003934 Abelmoschus esculentus Nutrition 0.000 description 19
- 240000004507 Abelmoschus esculentus Species 0.000 description 19
- 230000015572 biosynthetic process Effects 0.000 description 9
- 239000000463 material Substances 0.000 description 7
- 238000005520 cutting process Methods 0.000 description 6
- 238000012545 processing Methods 0.000 description 4
- 230000002706 hydrostatic effect Effects 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 239000000314 lubricant Substances 0.000 description 2
- 238000012423 maintenance Methods 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- 238000003860 storage Methods 0.000 description 2
- 241000282375 Herpestidae Species 0.000 description 1
- 239000004809 Teflon Substances 0.000 description 1
- 229920006362 Teflon® Polymers 0.000 description 1
- 238000005299 abrasion Methods 0.000 description 1
- 238000007664 blowing Methods 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- -1 chrome compound Chemical class 0.000 description 1
- 239000004927 clay Substances 0.000 description 1
- 239000002734 clay mineral Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- GUJOJGAPFQRJSV-UHFFFAOYSA-N dialuminum;dioxosilane;oxygen(2-);hydrate Chemical compound O.[O-2].[O-2].[O-2].[Al+3].[Al+3].O=[Si]=O.O=[Si]=O.O=[Si]=O.O=[Si]=O GUJOJGAPFQRJSV-UHFFFAOYSA-N 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 238000009499 grossing Methods 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 239000013049 sediment Substances 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 239000011343 solid material Substances 0.000 description 1
- 230000008961 swelling Effects 0.000 description 1
- 238000003466 welding Methods 0.000 description 1
Images
Classifications
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B07—SEPARATING SOLIDS FROM SOLIDS; SORTING
- B07B—SEPARATING SOLIDS FROM SOLIDS BY SIEVING, SCREENING, SIFTING OR BY USING GAS CURRENTS; SEPARATING BY OTHER DRY METHODS APPLICABLE TO BULK MATERIAL, e.g. LOOSE ARTICLES FIT TO BE HANDLED LIKE BULK MATERIAL
- B07B1/00—Sieving, screening, sifting, or sorting solid materials using networks, gratings, grids, or the like
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/01—Arrangements for handling drilling fluids or cuttings outside the borehole, e.g. mud boxes
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/06—Arrangements for treating drilling fluids outside the borehole
- E21B21/063—Arrangements for treating drilling fluids outside the borehole by separating components
- E21B21/065—Separating solids from drilling fluids
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B07—SEPARATING SOLIDS FROM SOLIDS; SORTING
- B07B—SEPARATING SOLIDS FROM SOLIDS BY SIEVING, SCREENING, SIFTING OR BY USING GAS CURRENTS; SEPARATING BY OTHER DRY METHODS APPLICABLE TO BULK MATERIAL, e.g. LOOSE ARTICLES FIT TO BE HANDLED LIKE BULK MATERIAL
- B07B2230/00—Specific aspects relating to the whole B07B subclass
- B07B2230/01—Wet separation
Definitions
- Embodiments disclosed here generally relate to a separator for drilling wastes. Specifically, embodiments disclosed herein relate to a separator for receiving a return fluid from a well and separating a solids phase from an effluent phase. More specifically, embodiments disclosed herein relate to separator for separating gumbo from drilling return fluid.
- Oilfield drilling fluid serves multiple purposes in the industry.
- the drilling mud acts as a lubricant to cool rotary drill bits and facilitate faster cutting rates.
- the mud is mixed at the surface and pumped downhole at high pressure to the drill bit through a bore of the drillstring. Once the mud reaches the drill bit, it exits through various nozzles and ports where it lubricates and cools the drill bit. After exiting through the nozzles, the “spent” fluid returns to the surface through an annulus formed between the drillstring and the drilled wellbore.
- drilling mud provides a column of hydrostatic pressure, or head, to prevent “blow out” of the well being drilled.
- This hydrostatic pressure offsets formation pressures thereby preventing fluids from blowing out if pressurized deposits in the formation are breeched.
- Two factors contributing to the hydrostatic pressure of the drilling mud column are the height (or depth) of the column (i.e., the vertical distance from the surface to the bottom of the wellbore) itself and the density (or its inverse, specific gravity) of the fluid used.
- various weighting and lubrication agents are mixed into the drilling mud to obtain the right mixture.
- drilling mud weight is reported in “pounds,” short for pounds per gallon.
- Another significant purpose of the drilling mud is to carry the cuttings away from the drill bit at the bottom of the borehole to the surface.
- a drill bit pulverizes or scrapes the rock formation at the bottom of the borehole, small pieces of solid material are left behind.
- the drilling fluid exiting the nozzles at the bit acts to stir-up and carry the solid particles of rock and formation to the surface within the annulus between the drillstring and the borehole. Therefore, the fluid exiting the borehole from the annulus is a slurry of formation cuttings in drilling mud.
- the cutting particulates must be removed.
- shale shakers Apparatus in use today to remove cuttings and other solid particulates from drilling fluid are commonly referred to in the industry as “shale shakers.”
- a shale shaker also known as a vibratory separator, is a vibrating sieve-like table upon which returning solids laden drilling fluid is deposited and through which clean drilling fluid emerges.
- gumbo shale sodium montmorillonite
- gumbo argillaceous sediments in which the predominant clay mineral is sodium montmorillonite
- Such heavy, high-volume solids are usually encountered when drilling top-hole sections of formation. If not removed, the soft, sticky, swelling clay cuttings, i.e., gumbo, may clog separator screens and/or otherwise adhere to surfaces of the processing equipment, fouling tools and plugging piping.
- gumbo is typically only encountered in approximately 1% of the entire well; however, removal of the gumbo may prolong the life of the equipment and is often necessary for efficient processing of the returned drilling waste.
- embodiments disclosed herein relate to a separator for drilling waste including a tank having an inlet and an outlet; a screening device disposed within the tank; a conduit coupled to the outlet; and a rotary valve coupled to the conduit.
- a separator for drilling waste including a tank having an inlet and an outlet; a trough in fluid communication with the tank; and a screening device having a plurality of members disposed within the tank, wherein the screening device is configured to direct an effluent phase through the plurality of members into the trough and a solids phase to the outlet.
- embodiments disclosed herein relate to a method of separating drilling waste including flowing a return fluid from a well to an inlet of a tank; and directing the return fluid against a screening device disposed within the tank, wherein an effluent phase of the return fluid passes through the screening device and wherein a solids phase of the return fluid falls to an outlet of the tank.
- FIG. 1 is a perspective view of a separator in accordance with embodiments disclosed herein.
- FIG. 2 is a perspective view of a rotary valve in accordance with embodiments disclosed herein.
- embodiments disclosed herein relate to a separator for drilling wastes. Specifically, embodiments disclosed herein relate to a separator for receiving a return fluid from a well and separating a solids phase from an effluent phase. More specifically, embodiments disclosed herein relate to separators for separating gumbo from drilling return fluid.
- Separator 100 includes a tank 102 having an inlet 104 and an outlet 106 .
- the inlet 104 is configured to receive a fluid for separating a fluids phase and a solids phase.
- inlet 104 receives a return fluid from a well. More specifically, in certain embodiments, inlet 104 receives a return fluid comprising gumbo.
- Separator 100 further includes a screening device 106 disposed within tank 102 .
- Screening device 106 may include a plurality of members disposed within the tank, wherein the screening device 106 is configured to separate a solids phase from an effluent phase of a return fluid.
- the plurality of members of the screening device 106 may include axially aligned longitudinal members 108 , as shown in FIG. 1 .
- the plurality of axially aligned longitudinal members 108 may be evenly spaced or may be spaced at varying distances.
- the plurality of members of the screening device 106 may be tubulars.
- screening device 106 may include a plurality of 2 inch diameter tubulars spaced approximately 2 inches apart. In other embodiments, the plurality of members may be solid bars.
- the screening device 106 may include a plurality of members, wherein the members are axially aligned horizontal members (not shown).
- the screening device 106 may include a plurality of axially aligned longitudinal members and axially aligned horizontal members, thereby forming a mesh of members.
- the spacing between the plurality of members of the screening device 106 may be selected based on the size of the desired solids phase to be separated from the return fluid.
- the plurality of members of the screening device 106 may be individually installed and aligned within the tank 102 .
- screening device 106 may include an assembled screen which includes the plurality of members.
- the screen may be placed inside the tank 102 and secured in place by any mechanism known in the art.
- tank 102 may include a track (not shown) in which the screen of the screening device 106 slides into.
- the screen may be mechanically fastened, e.g., by bolting, screwing, riveting, etc., welding the screen into place, or any combination thereof.
- the screening device 106 extends across a length L of the tank 102 , such that fluid entering the separator 100 may not bypass the screening device 106 around ends of the screening device 106 . Additionally, the screening device 106 extends across a width w of the tank 102 , such that fluid entering the separator 100 may not bypass the screening device 106 around sides of the screening device 106 . Accordingly, gumbo or solids larger than the spacing between the plurality of members of the screening device 106 are prevented from flowing up and out of, i.e., bypassing, the separator 100 .
- the screening device 106 may be disposed within tank 102 at a predetermined angle a with respect to a wall of the tank 102 .
- the predetermined angle a may vary based on the size and shape of the tank 102 , the specific configuration of the screening device 106 (e.g., the number and spacing of the plurality of members), and the solids phase to be separated from the return fluid (e.g., the size and expected quantity of gumbo to be filtered).
- screening device 106 may be disposed at an angle a between about 10 and about 80 degrees from the side of the tank. In other embodiments, the screening device 106 may be disposed at an angle a of between about 20 and about 45 degrees from the side of the tank.
- screening device 106 may be disposed within tank 102 such that a first end 110 is positioned higher than a second end 112 within the tank 102 .
- first end 110 and second end 112 may refer to all ends of the plurality of aligned members of the screening device 106 , an end of a screen having a plurality of aligned members, or both.
- the first end 110 of the screening device 106 may be disposed proximate a first upper edge 114 of the tank 102 and the second end 112 may be disposed proximate an opposite lower end 116 of the tank 102 .
- tank 102 may include a non-flat bottom surface 118 to assist in guiding the separated solids phase toward the outlet 106 of the tank 102 .
- the bottom surface 118 of the tank 102 may be conical or angled toward the outlet 106 .
- the effluent phase of return fluid that passes through the screening device may then be transferred from the tank 102 to a separate container, distribution vessel, or secondary separators (not shown).
- a trough 120 or other conduit may be coupled to the tank 102 along a side of the screening device 106 opposite the inlet 104 .
- the trough 120 is configured to transfer the effluent phase to the separate container, distribution vessel, or secondary separators.
- a conduit 122 is coupled to the outlet 106 of the tank 102 and configured to transfer the separated solids phase from the separator 100 to other process equipment, for example, a secondary separator 126 , storage container, or an overboard line.
- An isolation valve 124 may be coupled to the conduit 122 to close the conduit 122 , thereby stopping flow of the solids phase through the conduit 122 .
- the flow of solids phase may be stopped to allow, for example, maintenance to be performed on one or more components of the process equipment, e.g., secondary separator 126 , downstream of the conduit 122 .
- isolation valve 124 is shown disposed proximate the center of the conduit 122 , one of ordinary skill in the art will appreciate that the isolation valve 124 may be disposed anywhere along the length of the conduit 122 .
- the isolation valve 124 may be disposed proximate the outlet 106 or between the outlet 106 and a first end 129 of the conduit 122 .
- the isolation valve may be any type of valve known in the art, for example a knife gate valve.
- a rotary valve 128 is coupled to a second end 130 of the conduit 122 .
- a rotary valve 128 is a DM 500 Airlock, commercially available from Mac Equipment, Kansas City, Mo.
- the rotary valve 128 includes a material inlet 132 into a housing 134 .
- a rotor 136 extends into a chamber 135 of the housing 134 .
- a plurality of vanes 138 are coupled to the rotor 136 and extend therefrom into the chamber 135 .
- the rotor 136 is coupled to a motor (not shown) that rotates the rotor 136 and, therefore, the vanes 138 inside the chamber 135 .
- the separated solids phase 144 of the return fluid flows from the conduit 122 ( FIG. 1 ) to the material inlet 132 of the rotary valve 128 and into a partitioned segment of the chamber 135 disposed between the vanes 138 of the rotary valve 128 .
- the motor turns the rotor 136 and vanes 138
- the solids phase 144 is rotated or moved, as indicated by arrow R, through the housing 134 of the rotary valve 128 from the material inlet 132 to a material outlet 140 of the rotary valve 128 .
- the rotary valve 128 may be operated at varying speeds based on, for example, the consistency of the solids phase, the size of the rotary valve, and the flow rate of the solids phase. In one embodiment, the rotary valve 128 may be operated at 19 revolutions per minute.
- the rotary valve 128 may also include various features that allow the valve 128 to process gumbo material. For example, in certain embodiments, the rotary valve 128 may be modified to include a radiused pocket rotor, thereby smoothing out the portion where the blades are welded to the shaft, a Nedox coating to improve the resistance to abrasive particles in the gumbo, and air jets along the discharge to aide in removing material that might otherwise stick to the discharge.
- the Nedox coating is a chrome compound that may be sprayed onto the rotor 136 and vanes 138 and includes a Teflon compound infused into the pores to provide an abrasion resistant, slick surface to assist in transferring the solids phase (e.g., gumbo) through the rotary valve 128 from the separator 100 ( FIG. 1 ).
- a Teflon compound infused into the pores to provide an abrasion resistant, slick surface to assist in transferring the solids phase (e.g., gumbo) through the rotary valve 128 from the separator 100 ( FIG. 1 ).
- Arrows 142 in FIG. 2 show introduction of air into the chamber 135 of the rotary valve 128 to assist in removing material from the rotary valve 128 .
- Rotary valve 128 may thus be used to facilitate the transference of gumbo from separator 100 ( FIG. 1 ) to secondary process equipment, such as secondary separator 126 ( FIG. 1 ).
- secondary separators 126 may include separators for high-volume solids, such as the Mongoose® Shaker, commercially available from M-I Swaco, L.L.C., in Houston, Tex.
- the effluent phase may pass through separator 100 through trough 120 to a flow distribution vessel (not shown).
- the flow distribution vessel (not shown) may be used to divert the flow of effluent phase between various separators (not shown).
- a method of separating drilling waste is now disclosed with reference to FIG. 1 .
- a return fluid from a well is flowed to inlet 104 of tank 106 .
- the return fluid may include drilling muds and drilling waste, including gumbo. Due to the position of the screening device 106 in the tank 102 , the return fluid is directed against the screening device 106 . As the return fluid hits the screening device 106 , an effluent phase of the return fluid passes through the screening device, thereby filtering out or separating the solids phase of the return fluid, which, as mentioned above, may include gumbo.
- the effluent flows through the trough 120 coupled to the tank 102 for further processing or storage.
- the effluent may be transferred by the trough 120 to a flow distribution vessel (not shown), which directs the effluent to one or more separators.
- separators may include multiple deck separators, such as the MD-3 Shale Shaker, commercially available from M-I Swaco, L.L.C., in Houston, Tex.
- the solids phase separated by the screening device 106 falls to the bottom surface 108 of the tank 102 .
- the curvature or angling of the bottom surface 108 of the tank 102 helps direct the solids phase of the return fluid to the outlet 106 of the tank 122 .
- the solids phase is transferred to the rotary valve 128 which is operated to transfer the solids phase to secondary process equipment.
- rotary valve 128 may be operated to transfer the solids phase to a secondary separator 126 , which may further filter or dry the solids phase.
- a distribution box 146 may be disposed downstream of the rotary valve 128 and configured to separate the solids phase between one of a plurality of secondary separators 126 a , 126 b, 126 c.
- a distribution box 146 may be disposed downstream of the rotary valve 128 and configured to separate the solids phase between one of a plurality of secondary separators 126 a , 126 b, 126 c.
- the isolation valve 124 may be actuated to close the valve 124 to prevent solids phase from flowing to the rotary valve 128 .
- the isolation valve 124 may be closed to allow maintenance or cleaning work on the secondary process equipment, e.g., secondary separator 126 .
- embodiments disclosed herein provide for a separator for receiving a return fluid from a well and separating a solids phase from an effluent phase that reduces or prevents splash-over or bypassing of the screening device. Furthermore, embodiments disclosed herein may provide a separator for efficiently separating gumbo from a drilling return fluid. Advantageously, embodiments disclosed herein provide a separator that allows gumbo to settle down in a tank rather than flowing over a shaker. Additionally, embodiments disclosed herein provide a separator having a rotary valve configured to gradually feed gumbo from a receiving tank to a shaker, overboard, or other processing equipment.
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- Mining & Mineral Resources (AREA)
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- Environmental & Geological Engineering (AREA)
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- General Life Sciences & Earth Sciences (AREA)
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Abstract
A separator for drilling waste including a tank comprising an inlet and an outlet; a screening device disposed within the tank; a conduit coupled to the outlet; and a rotary valve coupled to the conduit. A separator including a tank having an inlet and an outlet; a trough in fluid communication with the tank; and a screening device having a plurality of members disposed within the tank, wherein the screening device is configured to direct an effluent phase through the members into the trough and a solids phase to the outlet. A method of separating drilling waste including flowing a return fluid to an inlet of a tank; and directing the return fluid against a screening device disposed within the tank, wherein an effluent phase of the return fluid passes through the screening device and wherein a solids phase of the return fluid falls to an outlet of the tank.
Description
- 1. Field of the Invention
- Embodiments disclosed here generally relate to a separator for drilling wastes. Specifically, embodiments disclosed herein relate to a separator for receiving a return fluid from a well and separating a solids phase from an effluent phase. More specifically, embodiments disclosed herein relate to separator for separating gumbo from drilling return fluid.
- 2. Background Art
- Oilfield drilling fluid, often called “mud,” serves multiple purposes in the industry. Among its many functions, the drilling mud acts as a lubricant to cool rotary drill bits and facilitate faster cutting rates. Typically, the mud is mixed at the surface and pumped downhole at high pressure to the drill bit through a bore of the drillstring. Once the mud reaches the drill bit, it exits through various nozzles and ports where it lubricates and cools the drill bit. After exiting through the nozzles, the “spent” fluid returns to the surface through an annulus formed between the drillstring and the drilled wellbore.
- Furthermore, drilling mud provides a column of hydrostatic pressure, or head, to prevent “blow out” of the well being drilled. This hydrostatic pressure offsets formation pressures thereby preventing fluids from blowing out if pressurized deposits in the formation are breeched. Two factors contributing to the hydrostatic pressure of the drilling mud column are the height (or depth) of the column (i.e., the vertical distance from the surface to the bottom of the wellbore) itself and the density (or its inverse, specific gravity) of the fluid used. Depending on the type and construction of the formation to be drilled, various weighting and lubrication agents are mixed into the drilling mud to obtain the right mixture. Typically, drilling mud weight is reported in “pounds,” short for pounds per gallon. Generally, increasing the amount of weighting agent solute dissolved in the mud base will create a heavier drilling mud. Drilling mud that is too light may not protect the formation from blow outs, and drilling mud that is too heavy may over invade the formation. Therefore, much time and consideration is spent to ensure the mud mixture is optimal. Because the mud evaluation and mixture process is time consuming and expensive, drillers and service companies prefer to reclaim the returned drilling mud and recycle it for continued use.
- Another significant purpose of the drilling mud is to carry the cuttings away from the drill bit at the bottom of the borehole to the surface. As a drill bit pulverizes or scrapes the rock formation at the bottom of the borehole, small pieces of solid material are left behind. The drilling fluid exiting the nozzles at the bit acts to stir-up and carry the solid particles of rock and formation to the surface within the annulus between the drillstring and the borehole. Therefore, the fluid exiting the borehole from the annulus is a slurry of formation cuttings in drilling mud. Before the mud can be recycled and re-pumped down through nozzles of the drill bit, the cutting particulates must be removed.
- Apparatus in use today to remove cuttings and other solid particulates from drilling fluid are commonly referred to in the industry as “shale shakers.” A shale shaker, also known as a vibratory separator, is a vibrating sieve-like table upon which returning solids laden drilling fluid is deposited and through which clean drilling fluid emerges.
- In the North Sea and the United States Gulf Coast, drillers commonly encounter argillaceous sediments in which the predominant clay mineral is sodium montmorillonite (commonly called “gumbo shale” or “gumbo”). Such heavy, high-volume solids are usually encountered when drilling top-hole sections of formation. If not removed, the soft, sticky, swelling clay cuttings, i.e., gumbo, may clog separator screens and/or otherwise adhere to surfaces of the processing equipment, fouling tools and plugging piping. Those of ordinary skill in the art will appreciate that gumbo is typically only encountered in approximately 1% of the entire well; however, removal of the gumbo may prolong the life of the equipment and is often necessary for efficient processing of the returned drilling waste.
- Accordingly, there exists a need for more separators that more efficiently process drilling waste or drilling muds.
- In one aspect, embodiments disclosed herein relate to a separator for drilling waste including a tank having an inlet and an outlet; a screening device disposed within the tank; a conduit coupled to the outlet; and a rotary valve coupled to the conduit.
- In another aspect, embodiments disclosed herein relate to a separator for drilling waste including a tank having an inlet and an outlet; a trough in fluid communication with the tank; and a screening device having a plurality of members disposed within the tank, wherein the screening device is configured to direct an effluent phase through the plurality of members into the trough and a solids phase to the outlet.
- In another aspect, embodiments disclosed herein relate to a method of separating drilling waste including flowing a return fluid from a well to an inlet of a tank; and directing the return fluid against a screening device disposed within the tank, wherein an effluent phase of the return fluid passes through the screening device and wherein a solids phase of the return fluid falls to an outlet of the tank.
- Other aspects and advantages of the invention will be apparent from the following description and the appended claims.
-
FIG. 1 is a perspective view of a separator in accordance with embodiments disclosed herein. -
FIG. 2 is a perspective view of a rotary valve in accordance with embodiments disclosed herein. - In one aspect, embodiments disclosed herein relate to a separator for drilling wastes. Specifically, embodiments disclosed herein relate to a separator for receiving a return fluid from a well and separating a solids phase from an effluent phase. More specifically, embodiments disclosed herein relate to separators for separating gumbo from drilling return fluid.
- Referring to
FIG. 1 , aseparator 100 is shown.Separator 100 includes a tank 102 having aninlet 104 and anoutlet 106. Theinlet 104 is configured to receive a fluid for separating a fluids phase and a solids phase. In one embodiment,inlet 104 receives a return fluid from a well. More specifically, in certain embodiments,inlet 104 receives a return fluid comprising gumbo. -
Separator 100 further includes ascreening device 106 disposed within tank 102.Screening device 106 may include a plurality of members disposed within the tank, wherein thescreening device 106 is configured to separate a solids phase from an effluent phase of a return fluid. The plurality of members of thescreening device 106 may include axially alignedlongitudinal members 108, as shown inFIG. 1 . The plurality of axially alignedlongitudinal members 108 may be evenly spaced or may be spaced at varying distances. In one embodiment, the plurality of members of thescreening device 106 may be tubulars. For example,screening device 106 may include a plurality of 2 inch diameter tubulars spaced approximately 2 inches apart. In other embodiments, the plurality of members may be solid bars. - In an alternate embodiment, the
screening device 106 may include a plurality of members, wherein the members are axially aligned horizontal members (not shown). In yet other embodiments, thescreening device 106 may include a plurality of axially aligned longitudinal members and axially aligned horizontal members, thereby forming a mesh of members. One of ordinary skill in the art will appreciate that the spacing between the plurality of members of thescreening device 106 may be selected based on the size of the desired solids phase to be separated from the return fluid. - The plurality of members of the
screening device 106 may be individually installed and aligned within the tank 102. Alternatively,screening device 106 may include an assembled screen which includes the plurality of members. In this embodiment, the screen may be placed inside the tank 102 and secured in place by any mechanism known in the art. For example, tank 102 may include a track (not shown) in which the screen of thescreening device 106 slides into. Additionally, the screen may be mechanically fastened, e.g., by bolting, screwing, riveting, etc., welding the screen into place, or any combination thereof. - As shown, the
screening device 106 extends across a length L of the tank 102, such that fluid entering theseparator 100 may not bypass thescreening device 106 around ends of thescreening device 106. Additionally, thescreening device 106 extends across a width w of the tank 102, such that fluid entering theseparator 100 may not bypass thescreening device 106 around sides of thescreening device 106. Accordingly, gumbo or solids larger than the spacing between the plurality of members of thescreening device 106 are prevented from flowing up and out of, i.e., bypassing, theseparator 100. Thescreening device 106 may be disposed within tank 102 at a predetermined angle a with respect to a wall of the tank 102. The predetermined angle a may vary based on the size and shape of the tank 102, the specific configuration of the screening device 106 (e.g., the number and spacing of the plurality of members), and the solids phase to be separated from the return fluid (e.g., the size and expected quantity of gumbo to be filtered). For example,screening device 106 may be disposed at an angle a between about 10 and about 80 degrees from the side of the tank. In other embodiments, thescreening device 106 may be disposed at an angle a of between about 20 and about 45 degrees from the side of the tank. - Specifically,
screening device 106 may be disposed within tank 102 such that afirst end 110 is positioned higher than asecond end 112 within the tank 102. As used herein,first end 110 andsecond end 112 may refer to all ends of the plurality of aligned members of thescreening device 106, an end of a screen having a plurality of aligned members, or both. For example, thefirst end 110 of thescreening device 106 may be disposed proximate a firstupper edge 114 of the tank 102 and thesecond end 112 may be disposed proximate an oppositelower end 116 of the tank 102. - As shown, the
inlet 104 of the tank 102 is located below thefirst end 110, i.e., the upper end, of thescreening device 106. Thus, as fluid enters the tank 102 throughinlet 104, the fluid is directed against thescreening device 106. An effluent phase of the fluid passes through thescreening device 106 and a solids phase sized larger than the spacing between the plurality of members of thescreening device 106 is trapped or separated from the effluent phase and falls to the bottom of the tank 102. As shown inFIG. 1 , tank 102 may include a non-flatbottom surface 118 to assist in guiding the separated solids phase toward theoutlet 106 of the tank 102. For example, thebottom surface 118 of the tank 102 may be conical or angled toward theoutlet 106. - The effluent phase of return fluid that passes through the screening device may then be transferred from the tank 102 to a separate container, distribution vessel, or secondary separators (not shown). A
trough 120 or other conduit may be coupled to the tank 102 along a side of thescreening device 106 opposite theinlet 104. Thetrough 120 is configured to transfer the effluent phase to the separate container, distribution vessel, or secondary separators. - A
conduit 122 is coupled to theoutlet 106 of the tank 102 and configured to transfer the separated solids phase from theseparator 100 to other process equipment, for example, asecondary separator 126, storage container, or an overboard line. Anisolation valve 124 may be coupled to theconduit 122 to close theconduit 122, thereby stopping flow of the solids phase through theconduit 122. The flow of solids phase may be stopped to allow, for example, maintenance to be performed on one or more components of the process equipment, e.g.,secondary separator 126, downstream of theconduit 122. Although theisolation valve 124 is shown disposed proximate the center of theconduit 122, one of ordinary skill in the art will appreciate that theisolation valve 124 may be disposed anywhere along the length of theconduit 122. For example, in one embodiment, theisolation valve 124 may be disposed proximate theoutlet 106 or between theoutlet 106 and afirst end 129 of theconduit 122. The isolation valve may be any type of valve known in the art, for example a knife gate valve. - A
rotary valve 128 is coupled to asecond end 130 of theconduit 122. One example of arotary valve 128 is a DM500 Airlock, commercially available from Mac Equipment, Kansas City, Mo. As shown inFIG. 2 , therotary valve 128 includes amaterial inlet 132 into ahousing 134. Arotor 136 extends into achamber 135 of thehousing 134. A plurality ofvanes 138 are coupled to therotor 136 and extend therefrom into thechamber 135. Therotor 136 is coupled to a motor (not shown) that rotates therotor 136 and, therefore, thevanes 138 inside thechamber 135. Accordingly, the separated solids phase 144 of the return fluid flows from the conduit 122 (FIG. 1 ) to thematerial inlet 132 of therotary valve 128 and into a partitioned segment of thechamber 135 disposed between thevanes 138 of therotary valve 128. As the motor turns therotor 136 andvanes 138, thesolids phase 144 is rotated or moved, as indicated by arrow R, through thehousing 134 of therotary valve 128 from thematerial inlet 132 to amaterial outlet 140 of therotary valve 128. - The
rotary valve 128 may be operated at varying speeds based on, for example, the consistency of the solids phase, the size of the rotary valve, and the flow rate of the solids phase. In one embodiment, therotary valve 128 may be operated at 19 revolutions per minute. Therotary valve 128 may also include various features that allow thevalve 128 to process gumbo material. For example, in certain embodiments, therotary valve 128 may be modified to include a radiused pocket rotor, thereby smoothing out the portion where the blades are welded to the shaft, a Nedox coating to improve the resistance to abrasive particles in the gumbo, and air jets along the discharge to aide in removing material that might otherwise stick to the discharge. The Nedox coating is a chrome compound that may be sprayed onto therotor 136 andvanes 138 and includes a Teflon compound infused into the pores to provide an abrasion resistant, slick surface to assist in transferring the solids phase (e.g., gumbo) through therotary valve 128 from the separator 100 (FIG. 1 ). One of ordinary skill in the art will appreciate that other coatings may be applied to therotor 136 andvanes 138 to reduce adhesion of the solids phase to therotary valve 128.Arrows 142 inFIG. 2 show introduction of air into thechamber 135 of therotary valve 128 to assist in removing material from therotary valve 128.Rotary valve 128 may thus be used to facilitate the transference of gumbo from separator 100 (FIG. 1 ) to secondary process equipment, such as secondary separator 126 (FIG. 1 ). - Referring back to
FIG. 1 , while solids phase is separated from a primarily effluent phase of the drilling waste, the solids phase may be directed to asecondary separator 126. In one embodiment,secondary separators 126 may include separators for high-volume solids, such as the Mongoose® Shaker, commercially available from M-I Swaco, L.L.C., in Houston, Tex. The effluent phase may pass throughseparator 100 throughtrough 120 to a flow distribution vessel (not shown). The flow distribution vessel (not shown) may be used to divert the flow of effluent phase between various separators (not shown). - A method of separating drilling waste is now disclosed with reference to
FIG. 1 . A return fluid from a well is flowed toinlet 104 oftank 106. The return fluid may include drilling muds and drilling waste, including gumbo. Due to the position of thescreening device 106 in the tank 102, the return fluid is directed against thescreening device 106. As the return fluid hits thescreening device 106, an effluent phase of the return fluid passes through the screening device, thereby filtering out or separating the solids phase of the return fluid, which, as mentioned above, may include gumbo. The effluent flows through thetrough 120 coupled to the tank 102 for further processing or storage. In one embodiment, the effluent may be transferred by thetrough 120 to a flow distribution vessel (not shown), which directs the effluent to one or more separators. These separators may include multiple deck separators, such as the MD-3 Shale Shaker, commercially available from M-I Swaco, L.L.C., in Houston, Tex. - Due to the position or alignment of the
screening device 106 in the tank 102, as described above, the solids phase separated by thescreening device 106 falls to thebottom surface 108 of the tank 102. The curvature or angling of thebottom surface 108 of the tank 102 helps direct the solids phase of the return fluid to theoutlet 106 of thetank 122. The solids phase is transferred to therotary valve 128 which is operated to transfer the solids phase to secondary process equipment. For example,rotary valve 128 may be operated to transfer the solids phase to asecondary separator 126, which may further filter or dry the solids phase. In one embodiment, a distribution box 146 may be disposed downstream of therotary valve 128 and configured to separate the solids phase between one of a plurality ofsecondary separators secondary separators 126 may vary. - The
isolation valve 124 may be actuated to close thevalve 124 to prevent solids phase from flowing to therotary valve 128. Theisolation valve 124 may be closed to allow maintenance or cleaning work on the secondary process equipment, e.g.,secondary separator 126. - Advantageously, embodiments disclosed herein provide for a separator for receiving a return fluid from a well and separating a solids phase from an effluent phase that reduces or prevents splash-over or bypassing of the screening device. Furthermore, embodiments disclosed herein may provide a separator for efficiently separating gumbo from a drilling return fluid. Advantageously, embodiments disclosed herein provide a separator that allows gumbo to settle down in a tank rather than flowing over a shaker. Additionally, embodiments disclosed herein provide a separator having a rotary valve configured to gradually feed gumbo from a receiving tank to a shaker, overboard, or other processing equipment.
- While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.
Claims (20)
1. A separator for drilling waste comprising:
a tank comprising an inlet and an outlet;
a screening device disposed within the tank;
a conduit coupled to the outlet; and
a rotary valve coupled to the conduit.
2. The separator of claim 1 , further comprising a trough coupled to the tank configured to remove an effluent phase of the drilling waste.
3. The separator of claim 1 , further comprising an isolation valve coupled to the conduit.
4. The separator of claim 3 , wherein the isolation valve is disposed between the outlet and the rotary valve.
5. The separator of claim 1 , wherein the inlet is disposed on a side of the tank.
6. The separator of claim 1 , wherein the screening device is disposed in the tank at a predetermined angle.
7. The primary separator of claim 6 , wherein the screening device extends from a first upper edge of the tank to an opposite lower end of the tank.
8. The primary separator of claim 6 , wherein the inlet is disposed below an upper edge of the screening device.
9. The primary separator of claim 1 , wherein the screening device comprises a plurality of axially aligned longitudinal members.
10. The primary separator of claim 1 , wherein the rotary valve comprises a rotor and a coating applied to the rotor.
11. The primary separator of claim 1 , wherein the rotary valve comprises air jets disposed proximate a discharge end of the rotary valve.
12. A separator for drilling waste comprising:
a tank comprising an inlet and an outlet;
a trough in fluid communication with the tank; and
a screening device comprising a plurality of members disposed within the tank,
wherein the screening device is configured to direct an effluent phase through the plurality of members into the trough and a solids phase to the outlet.
13. The separator of claim 12 , further comprising a conduit coupled to the outlet.
14. The separator of claim 12 , further comprising a rotary valve coupled to the conduit.
15. The separator of claim 12 , further comprising an isolation valve coupled to the conduit.
16. A method of separating drilling waste comprising:
flowing a return fluid from a well to an inlet of a tank; and
directing the return fluid against a screening device disposed within the tank, wherein an effluent phase of the return fluid passes through the screening device and
wherein a solids phase of the return fluid falls to an outlet of the tank.
17. The method of claim 16 , further comprising moving the solids phase from the outlet through a conduit to a rotary valve.
18. The method of claim 17 , further comprising actuating the rotary valve to transfer at least a portion of the solids phase to a secondary separator.
19. The method of claim 16 , further comprising flowing the effluent through a trough coupled to the tank to a flow distribution vessel.
20. The method of claim 16 , further comprising actuating an isolation valve.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/822,820 US20130248465A1 (en) | 2010-09-15 | 2011-09-15 | Return Fluid Separator |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US38319610P | 2010-09-15 | 2010-09-15 | |
US13/822,820 US20130248465A1 (en) | 2010-09-15 | 2011-09-15 | Return Fluid Separator |
PCT/US2011/051676 WO2012037301A2 (en) | 2010-09-15 | 2011-09-15 | Return fluid separator |
Publications (1)
Publication Number | Publication Date |
---|---|
US20130248465A1 true US20130248465A1 (en) | 2013-09-26 |
Family
ID=45832232
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US13/822,820 Abandoned US20130248465A1 (en) | 2010-09-15 | 2011-09-15 | Return Fluid Separator |
Country Status (4)
Country | Link |
---|---|
US (1) | US20130248465A1 (en) |
EP (1) | EP2616628A4 (en) |
MX (1) | MX2013002966A (en) |
WO (1) | WO2012037301A2 (en) |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11499290B2 (en) | 2017-07-14 | 2022-11-15 | Vermeer Manufacturing Company | Hydro excavation vacuum apparatus having deceleration vessels and methods for hydro excavating a site |
US11525239B2 (en) | 2018-04-30 | 2022-12-13 | Vermeer Manufacturing Company | Shaker assemblies having positioning devices |
US11890782B2 (en) | 2020-06-05 | 2024-02-06 | Vermeer Manufacturing Company | Mixing systems having disk assemblies |
Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
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US7255329B1 (en) * | 2006-11-23 | 2007-08-14 | Domino Machine Inc. | Gate valve with offset valve stem |
Family Cites Families (6)
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ES336622A1 (en) * | 1966-02-10 | 1968-06-01 | Baburek Svoboda Drahny | Method of treating liquid suspensions. (Machine-translation by Google Translate, not legally binding) |
US6223906B1 (en) * | 1997-10-03 | 2001-05-01 | J. Terrell Williams | Flow divider box for conducting drilling mud to selected drilling mud separation units |
US20060113220A1 (en) * | 2002-11-06 | 2006-06-01 | Eric Scott | Upflow or downflow separator or shaker with piezoelectric or electromagnetic vibrator |
US7597219B2 (en) | 2005-12-16 | 2009-10-06 | Owens Corning Intellectual Capital, Llc | Rotary valve for handling solid particulate material |
US20070163927A1 (en) * | 2006-01-05 | 2007-07-19 | M-I L.L.C. | Vapor extracting and separator cleaning apparatus |
US7527726B2 (en) | 2006-01-25 | 2009-05-05 | Q'max Solutions Inc. | Fluid treatment apparatus |
-
2011
- 2011-09-15 WO PCT/US2011/051676 patent/WO2012037301A2/en active Application Filing
- 2011-09-15 MX MX2013002966A patent/MX2013002966A/en unknown
- 2011-09-15 EP EP11825907.6A patent/EP2616628A4/en not_active Withdrawn
- 2011-09-15 US US13/822,820 patent/US20130248465A1/en not_active Abandoned
Patent Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7255329B1 (en) * | 2006-11-23 | 2007-08-14 | Domino Machine Inc. | Gate valve with offset valve stem |
Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11499290B2 (en) | 2017-07-14 | 2022-11-15 | Vermeer Manufacturing Company | Hydro excavation vacuum apparatus having deceleration vessels and methods for hydro excavating a site |
US11560689B2 (en) | 2017-07-14 | 2023-01-24 | Vermeer Manufacturing Company | Hydro excavation vacuum apparatus having an adjustment system for adjusting a dewatering system screen |
US11905677B2 (en) | 2017-07-14 | 2024-02-20 | Vermeer Manufacturing Company | Airlocks for conveying material, hydro excavation vacuum apparatus having airlocks, and methods for hydro excavating a site |
US11525239B2 (en) | 2018-04-30 | 2022-12-13 | Vermeer Manufacturing Company | Shaker assemblies having positioning devices |
US11890782B2 (en) | 2020-06-05 | 2024-02-06 | Vermeer Manufacturing Company | Mixing systems having disk assemblies |
Also Published As
Publication number | Publication date |
---|---|
MX2013002966A (en) | 2013-10-28 |
EP2616628A2 (en) | 2013-07-24 |
EP2616628A4 (en) | 2014-11-26 |
WO2012037301A3 (en) | 2012-08-09 |
WO2012037301A2 (en) | 2012-03-22 |
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Legal Events
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AS | Assignment |
Owner name: M-I L.L.C., TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:SHERWOOD, JOE;REEL/FRAME:030476/0409 Effective date: 20130502 |
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STCB | Information on status: application discontinuation |
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