US20130333877A1 - System and Method of Assessing a Wellbore Servicing Fluid or a Component Thereof - Google Patents

System and Method of Assessing a Wellbore Servicing Fluid or a Component Thereof Download PDF

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Publication number
US20130333877A1
US20130333877A1 US13/526,049 US201213526049A US2013333877A1 US 20130333877 A1 US20130333877 A1 US 20130333877A1 US 201213526049 A US201213526049 A US 201213526049A US 2013333877 A1 US2013333877 A1 US 2013333877A1
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Prior art keywords
fluid
test
organisms
size
component
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US13/526,049
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English (en)
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Erica Lynne TRICKEY
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Halliburton Energy Services Inc
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Halliburton Energy Services Inc
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Priority to US13/526,049 priority Critical patent/US20130333877A1/en
Assigned to HALLIBURTON ENERGY SERVICES, INC. reassignment HALLIBURTON ENERGY SERVICES, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: TRICKEY, ERICA LYNNE
Priority to PCT/US2013/043933 priority patent/WO2013191883A2/fr
Priority to BR112014031128A priority patent/BR112014031128A2/pt
Priority to EP13728305.7A priority patent/EP2831266A2/fr
Priority to AU2013277594A priority patent/AU2013277594B2/en
Priority to CA2877106A priority patent/CA2877106C/fr
Priority to EA201492171A priority patent/EA201492171A1/ru
Priority to MX2014014440A priority patent/MX358634B/es
Publication of US20130333877A1 publication Critical patent/US20130333877A1/en
Abandoned legal-status Critical Current

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    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/03—Specific additives for general use in well-drilling compositions
    • C09K8/035—Organic additives
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2520/00—Use of whole organisms as detectors of pollution

Definitions

  • Hydrocarbons such as oil and gas
  • Hydrocarbons are often produced from wells that penetrate hydrocarbon-bearing subterranean formations or portions thereof.
  • a subterranean formation is prepared for the production of oil and/or gas therefrom by drilling a wellbore into the subterranean formation.
  • a drilling fluid is circulated through the wellbore to remove cuttings and cool and lubricate the drilling apparatus.
  • cementing is conventionally accomplished by pumping a cementitious composition into an annular space between the casing and wellbore walls and allowing the composition to set in place.
  • stimulation operations are often serviced by stimulation operations to improve the recovery of hydrocarbons therefrom.
  • stimulation operations include hydraulic fracturing operations, acidizing treatments, perforating operations, or the like.
  • Stimulation operations often involve introducing various wellbore servicing fluids into at least some part of the subterranean formation at various rates, pressures, and/or amounts.
  • drilling operations may be necessary throughout the service life of a wellbore and thereafter, for example, clean-out operations, fluid-loss control operations, a well containment operation, a well-kill operation, or the like.
  • additional servicing operations may also entail introducing servicing fluids into the subterranean formation, for example, to increase production from the wellbore, to isolate a zone or segment of the subterranean formation, to cease the production of fluids from the subterranean formation, or for some other purpose.
  • a method of assessing a wellbore servicing fluid or a component thereof comprising providing a plurality of test organisms, wherein providing the plurality of test organisms comprises introducing at least a portion of a population of the test organisms into a first section of a first fluid vessel, wherein the first section of the first fluid vessel is separated from a second section of the first fluid vessel by a first divider, wherein the first divider is configured to retain an organism of at least a first size and to allow passage of an organism less than the first size, allowing at least a portion of the organisms of a size less than the first size to pass through the first divider and into the second section of the first fluid vessel, and draining the at least a portion of the organisms of the size less than the first size from the first fluid vessel into a fluid receptacle, allowing the at least a portion of the organisms of a size less than the first size to mature for a predetermined duration, dividing the matured test organisms into a control group and at
  • FIG. 1 is a diagram of an embodiment of a wellbore fluid assessment method
  • FIG. 2 is a schematic of an embodiment of a wellbore fluid assessment system.
  • connection Unless otherwise specified, use of the terms “connect,” engage,” “couple,” attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described.
  • subterranean formation shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.
  • the WFA method 1000 generally comprises the steps of providing test organisms 110 , dividing the test organisms into a control group and at least one test group 120 , subjecting the at least one test group to a wellbore servicing fluid or a component thereof 130 , and assessing the acceptability of the wellbore servicing fluid and/or the wellbore servicing fluid component 140 . Also disclosed herein is a method of servicing a wellbore.
  • such a wellbore servicing method generally comprises, after assessing the acceptability of a wellbore servicing fluid or a component thereof, for example, as by the WFA method disclosed herein, communicating the wellbore servicing fluid and/or a wellbore servicing fluid comprising the wellbore servicing fluid component into a wellbore.
  • the step of providing the test organisms 110 generally comprises the process by which a suitable number of one or more suitable test organisms is made available for use in the remainder of the WFA method 1000 .
  • the step of providing the test organisms may generally comprise the sub-steps of culturing a population of test organisms and selecting organisms for use in the WFA method 1000 from the population of test organisms.
  • a suitable test organism may be characterized as an aquatic and/or marine organism.
  • a suitable test organism may be an organism whose suitability for testing, as will be disclosed herein, is dependent upon size and/or life stage.
  • the term test organism may refer to any suitable organism at any life stage.
  • the test organism may comprise a member of the genus Acartia.
  • Acartia is a genus of marine calanoid copepods.
  • the members of Acartia may be characterized as epipelagic, for example, generally being native to oceanic environments at depths of not more than about 600 feet (e.g., not often found below 200 meters).
  • the members of Acartia may be characterized as planktonic, for example, feeding on unicellular plants and animals, such as phytoplankton and zooplankton, including Chaetoceros socialis, Skeletonema costatum and Flagellata.
  • test organism 1000 may be employed in the WFA method 1000 .
  • An alternative example of a suitable test organism includes, but is not limited to Cyprinodon variegatus, which is a minnow.
  • the test organism may comprise virtually any egg-bearing aquatic organism, for example, Danio rerio (zebrafish) and other species that lay their eggs in open water.
  • the test organisms may be provided and/or present within a suitable fluid and/or composition, referred to herein as an environmental fluid.
  • the environmental fluid in which the test organisms are provided generally refers to a fluid and/or composition that is substantially similar to the natural environment of a given test organism.
  • the test organisms may be provided within an aqueous solution (e.g., water).
  • the aqueous solution may comprise sediment (e.g., mud), as may be appropriate for a given organism.
  • such a substantially aqueous fluid comprises less than about 50% nonaqueous component(s), alternatively less than about 45%, 40%, 35%, 30%, 25%, 20%, 15%, 10%, 5%, 4%, 3%, 2% or 1% nonaqueous component(s).
  • the water may comprise an inorganic monovalent salt, an inorganic multivalent salt, or both.
  • salts as may be present within the water include water-soluble chloride, bromide and carbonate, hydroxide and formate salts of alkali and alkaline earth metals, zinc bromide, and combinations thereof.
  • the salt or salts in the water may be present in an amount ranging from greater than about 0.01% by weight to a saturated salt solution. In a particular embodiment, the salt or salts in the water may be present in an amount ranging from about 5% to about 25% by weight; alternatively, about 20% by weight.
  • a test organism culturing and separation (TOCS) system 2000 for example, as may be utilized in the step of providing the test organisms 110 , particularly, for use in both the sub-step of culturing a population of test organisms and the sub-step of selecting organisms for use in the WFA method 1000 , is illustrated.
  • the TOCS system 2000 is generally configured for culturing the test organisms and allowing the selection of some portion of the test organisms on the basis of size.
  • the TOCS system 2000 comprises a first fluid vessel 210 , generally defining a fluid reservoir, for example, being configured to retain a suitable fluid (e.g., an environmental fluid).
  • the first fluid vessel 210 may be configured to retain a suitable volume of fluid.
  • the reservoir of the first fluid vessel 210 may comprise a volume of about 1 gallon, 2 gallons, 3, gallons, 4 gallons, 5 gallons, 8 gallons, 10 gallons, 12 gallons, 15 gallons, 20 gallons, 25 gallons, 30 gallons, 40 gallons, 50 gallons, 60 gallons, 70 gallons, 80 gallons, 90 gallons, 100 gallons, or more.
  • the first fluid vessel 210 may be configured to allow for fluid drainage therefrom.
  • the first fluid vessel is configured such that fluids may flow, via gravity, to a common point (e.g., general locale) within the reservoir of the first fluid vessel and be drained therefrom.
  • the first fluid vessel 210 generally comprises an inverted, pyramidal configuration (e.g., a four-sided pyramid and/or tetrahedron).
  • a similar fluid vessel may comprise an inverted conical configuration (e.g., a circular or ovular cone).
  • the first fluid vessel 210 may be formed by any suitable process or combination of processes.
  • a first fluid vessel may be formed as a single, unitary structure, for example, as may be formed from a molding process.
  • a first fluid vessel may be formed from two or more operably-joined sub-components, such as a plurality of sides and a bottom, each of which has been formed by a suitable process and which have been assembled to yield the first fluid vessel.
  • the first fluid vessel 210 may be formed from a suitable material.
  • the first fluid vessel 210 may be formed from a non-metallic material (e.g., to limit the potential for corrosion upon exposure to aqueous, salt-containing fluids).
  • the first fluid vessel 210 may be formed, at least partially, from a material characterized as transparent, alternatively, substantially transparent, alternatively, translucent, (e.g., to allow visual inspection of the contents of the first fluid vessel 210 ).
  • suitable material include composite materials, such as fiber-glass; glass; plastics or other polymeric materials, such as plexi-glass or polycarbonate; or combinations thereof.
  • first fluid vessel 210 may remain open at the top.
  • a first fluid vessel may comprise a lid or like top portion, at least a portion of which may be permanent, semi-permanent, removable, hinged, or combinations thereof.
  • the first fluid vessel comprises a first section 211 and a second section 212 .
  • the first section 211 is separated from the second section 212 by a suitable divider 213 .
  • the first section 211 and the second section 212 are each defined partially by the divider 213 and partially by the walls of the first fluid vessel 210 .
  • the divider 213 may be substantially configured to form at least a partial barrier within the first fluid vessel 210 .
  • FIG. 1 in the embodiment of FIG.
  • the divider 213 may comprise a substantially horizontally-oriented structure having substantially the same shape as a horizontal cross-section of the first fluid vessel 210 .
  • the divider may have a substantially square shape.
  • the divider may have a substantially round shape.
  • a divider (and the corresponding cross-section of the first fluid vessel 210 ) may have any suitable shape, for example, at least partially dependent upon a substantially horizontal, cross-sectional shape associated with the first fluid vessel, for example, a regular or irregular rectangle, pentagon, hexagon, heptagon, octagon, or oval, or any other suitable shape.
  • the divider 213 may be permanently and/or semi-permanently attached to walls of first fluid vessel 210 . Also, in an embodiment, the divider 213 may be characterized as removable. Alternatively, a divider may be free-floating and/or free setting within the first fluid vessel.
  • the divider 213 may be generally configured to separate a material(s) on the basis of size, for example, by retaining matter of a given size while allowing the passage of matter of a smaller size.
  • each of the dividers 213 comprises a mesh-like material, such as a screen, a fabric, or the like.
  • a mesh material may generally comprise any suitable type or configuration of mesh. Examples of suitable mesh materials may include, but are not limited to, synthetic fibers, metallic fibers, wires, natural fibers, the like, or combinations thereof.
  • the mesh material comprises a nylon fiber, a suitable example of which is commercially-available from Nytex Composites Co., Ltd.
  • the mesh material comprising the divider may be characterized as having a suitable mesh size.
  • mesh size is used to refer to the sizing of a particular mesh material. Generally, mesh size may refer approximately to the greatest size of material (e.g., test organism) that will pass through a particular mesh size, for example, the nominal opening. The mesh size may also refer to the inside dimension of each opening in the mesh (e.g., the inside diameter of each square).
  • the mesh material may be characterized as having a mesh size (e.g., openings) in of from about 60 microns to about 120 microns, alternatively, of from about 80 microns to about 100 microns, alternatively, of about 90 microns.
  • the mesh material may be characterized as having a mesh size of 230 mesh to about 170 mesh, alternatively, of about 200 mesh, in accordance with the Tyler standardized mesh sizing.
  • the first fluid vessel 210 is configured to selectively allow fluid outflow therefrom.
  • the first fluid vessel 210 comprises a valve 215 and a flow conduit 216 .
  • the valve 215 and flow conduit 216 are configured to convey fluid from the second section 212 of the first fluid vessel 210 and, for example, into a suitable fluid receptacle, as will be disclosed herein, for example, a basin, a tub, or the like.
  • the valve 215 may comprise any suitable type or configuration of valve. Examples of suitable types and configurations of valves include, but are not limited to ball valves, gate valves, disc valves, butterfly valves, globe valves, or the like.
  • the valve 215 may be in fluid communication with the reservoir of the first fluid vessel 210 . Particularly, the valve 215 .
  • the valve may be positioned approximately at the bottom of reservoir generally being defined by the first fluid vessel 210 (e.g., approximately at the common point of drainage, such that fluid will flow out of the reservoir, by gravity, via the valve 215 when the valve is so-configured).
  • the flow conduit may comprise any suitable type and/or size of such flow conduit.
  • suitable types of flow conduits include, but are not limited to, pipes, hoses, or combinations thereof.
  • the flow conduit 216 may be permanently, semi-permanently, and/or removably coupled (e.g., via a glued, threaded, or fitted connection) to the outlet of the valve 215 .
  • the flow conduit 216 may be of a suitable length to allow the fluid to be conveyed therethrough to reach and/or flow into the appropriate fluid receptacle.
  • the flow conduit may be of sufficient length to allow the fluid to flow into such fluid receptacle at an angle (e.g., such that the fluid flowing into the tub and/or container at an angle less than perpendicular).
  • the TOCS system 2000 further comprises a fluid receptacle 230 .
  • the fluid receptacle 230 may comprise any suitable form and/or configuration.
  • such a fluid receptacle 230 may comprise a container, a tub, a fluid vessel, a bucket, or the like.
  • the first fluid vessel 210 may be positioned at a suitable height, for example, a height allowing for flow of a fluid by gravity from the first fluid vessel 210 into the fluid receptacle 230 .
  • the difference in height between the first fluid vessel 210 and the fluid receptacle 230 may be any suitable distance as may be determined by one of skill in the art viewing this disclosure.
  • the first fluid vessel 210 and/or fluid receptacle 230 may be positioned on platform suitable to support the tub; alternatively, the first fluid vessel 210 and/or fluid receptacle 230 may be fitted with any suitable configuration of legs, stands, or the like.
  • a TOCS system like TOCS system 2000 may be employed in one or more of culturing the test organisms and separating the test organisms on the basis of size.
  • culturing the test organisms and/or separating the test organisms on the basis of size may comprise the steps of introducing a fluid comprising at least a portion of the population of the test organisms into the first section of the first fluid vessel 210 and allowing at least a portion of the organisms to pass through the divider and into the second section of the first fluid vessel 210 .
  • the mesh size of the divider will be capable of passing through the first screen and into the second section of the first fluid vessel 210 .
  • Organisms having a size about greater than, alternatively, about equal to or greater than, the first mesh size will be retained within the first section of the first tub.
  • the divider may be configured such that only the unhatched eggs of the test organisms (e.g., a member of the genus Acartia ) will be capable of passing through the divider and into the second section of the first fluid vessel 210 .
  • culturing the test organisms and/or selecting the test organisms on the basis of size may further comprise allowing at least a portion of the test organisms, for example, within the fluid, in the second section 212 of the first fluid vessel 210 to flow out of the first fluid vessel 210 and into the fluid receptacle 230 .
  • the organisms within the second section 212 of the first fluid vessel 210 may be allowed to flow into the fluid receptacle 230 via the valve 215 and the flow conduit 216 .
  • an operator may allow the fluid and the organisms within the second section 212 of the first fluid vessel 210 to flow into the fluid receptacle 230 by providing a route of fluid communication via the valve 215 and the flow conduit 216 , for example, by opening the valve 215 .
  • the valve 215 With the valve 215 open, the fluid and the organisms within the second section 212 of the first fluid vessel 210 may flow therefrom and into the fluid receptacle 230 .
  • the first fluid vessel 210 is positioned at a height greater than the height of the fluid receptacle 230 , the fluid and organisms will readily flow, for example, by gravity, into the fluid receptacle 230 .
  • any fluid drained from the first fluid vessel 210 may be replaced with suitable, environmental fluid, as disclosed herein.
  • the fluid within the first fluid vessel 210 may be maintained at a suitable level.
  • the test organisms upon culturing the test organisms and/or separating the test organisms on the basis of size, for example, as by use of a TOCS system as disclosed herein, the test organisms may be present within a plurality of groups, approximately, on the basis of size. For example, in the embodiment of FIG. 2 , the test organisms may be present in two groups.
  • utilization of the TOCS system 2000 may allow the separation of the eggs (e.g., which are capable of passing through the divider 213 , into the second section 212 of the first fluid vessel 210 , and out of the first fluid vessel 210 into the fluid receptacle) from the adult and/or other life stages and/or sizes of the test organisms.
  • the eggs e.g., which are capable of passing through the divider 213 , into the second section 212 of the first fluid vessel 210 , and out of the first fluid vessel 210 into the fluid receptacle
  • a suitable number of test organisms of a given size range and/or life stage may be selected and/or prepared for testing.
  • the size and/or number of test organisms that will be suitable for a given test procedure may vary depending upon a variety of factors, such as, the number of trials to be performed, the duration of the trials, the type of wellbore fluid or wellbore fluid component to be assessed, the means by which the fluid is to be assessed (e.g., as will be discussed herein below) or the like.
  • the eggs may be selected and/or utilized for testing.
  • the eggs of the test organisms may be allowed to hatch and/or grow for a suitable time period following separation from the adult and/or other life stages of the test organisms.
  • the young test organisms may be allowed to hatch and grow for about 7 days, 10 day, 15 days, 20 days, 21 days, 24 days, 27 days, 30 days, or any other suitable time period, following separation and prior to testing.
  • all individuals subjected to testing may be of approximately the same age and/or life stage when subjected to testing.
  • test organisms not selected for usage in the trials may be returned to a suitable culturing environment (e.g., the TOCS system 2000 and/or utilized as brood stock for continued culturing of such test organisms, or the like.
  • a suitable culturing environment e.g., the TOCS system 2000 and/or utilized as brood stock for continued culturing of such test organisms, or the like.
  • the environment with the TOCS system 2000 e.g., within the first fluid vessel 210
  • maintaining such a suitable environment may include maintaining a suitable temperature (e.g., about 20° C.), maintaining the salinity of the environmental fluid within a suitable range (e.g., about 29-36% salinity), maintaining the oxygen saturation of the environmental fluid within a suitable range (e.g., via aeration), provision of food sources and/or nutrients, or combinations thereof.
  • a suitable temperature e.g., about 20° C.
  • a suitable range e.g., about 29-36% salinity
  • maintaining the oxygen saturation of the environmental fluid e.g., via aeration
  • the test organisms selected for usage in the trial(s) may be divided into a plurality of groups comprising a control group and one or more test groups.
  • the test organisms, for a given trial may be divided into a control group and one, two, three, four, five, or more test groups.
  • each of the plurality of test groups may be used to test varying concentrations of the wellbore servicing fluid and/or component, different components of a single wellbore servicing fluid, or the like.
  • the wellbore servicing fluid and/or component generally refers to a fluid (e.g., a composite fluid comprising multiple components) or one or more components thereof, which may be similar in composition, concentration, or combinations thereof, to a fluid as may be employed in the performance of a wellbore servicing operation, for example, a drilling fluid, a wellbore clean-out fluid, a completion and/or cementing fluid, an acidizing fluid, a perforating fluid, a fracturing or other stimulation fluid, a workover fluid, a shut-in or well-kill fluid, any other like, suitable fluid.
  • a fluid e.g., a composite fluid comprising multiple components
  • a fluid e.g., a composite fluid comprising multiple components
  • a fluid e.g., a composite fluid comprising multiple components
  • a fluid e.g., a composite fluid comprising multiple components
  • a fluid e.g., a composite fluid comprising multiple components
  • a fluid e.g.,
  • a plurality of test groups may be utilized to test the acceptability of a given servicing fluid and/or a given servicing fluid component at about 20%, 40%, 60%, 80%, 100%, and/or 120%, respectively, of the concentration at which that fluid and/or component may be employed.
  • a plurality of test groups may be utilized to test the acceptability of Component A, Component B, Component C, and Component D, etc., respectively, of a given servicing fluid.
  • each trial may be performed in multiple iterations, for example, to improve the accuracy and/or statistical significance of any such trials.
  • the trials, as disclosed herein may be performed in duplicate, triplicate, quadruplicate, etc.
  • the number of test organisms necessitated by such multiple trial iterations will increase, correspondingly.
  • each of the control group and the one or more test groups may be placed in separate, suitable test containers for the duration of the trials.
  • suitable test containers may be selected based upon factors including, but not limited to, the test organism that was selected, the size of the test organisms, the number of test organisms, the duration of the trial, the suitability of the environment provided by the test container for the test organisms, the amount of fluid and/or material to be tested, the like, and combinations thereof.
  • suitable test containers may include, but are not limited to, petri dishes, jars of various sizes and configurations, trays, tubs, barrels, and the like.
  • control group and the test group may be provided in a suitable environmental fluid.
  • the test group or groups of the test organisms may be subjected to the wellbore servicing fluid or a component thereof, for example, by introducing the wellbore servicing fluid and/or component into the environmental fluid.
  • the test groups may be subjected to the wellbore servicing fluid and/or wellbore servicing fluid component in varying concentrations and/or the test groups may be subjected to varying components thereof.
  • each of the one or more test groups may be placed in the environmental fluid, along with the servicing fluid and/or servicing fluid component in a specified concentration, within the test container for a suitable duration.
  • a suitable duration may be about 24 hours, alternatively, about 48 hours, alternatively, about 72 hours, alternatively, about 5 days, alternatively, about 7 days, alternatively, about 10 days, alternatively, about 12 days, alternatively, about 15 days, alternatively, about 28 days.
  • a suitable duration may be about 24 hours, alternatively, about 48 hours, alternatively, about 72 hours, alternatively, about 5 days, alternatively, about 7 days, alternatively, about 10 days, alternatively, about 12 days, alternatively, about 15 days, alternatively, about 28 days.
  • the environment within each of the test containers may be maintained as will be suitable for the selected test organism.
  • maintaining such a suitable environment may include maintaining a suitable temperature (e.g., about 20° C.), maintaining the salinity of the environmental fluid within a suitable range (e.g., about 29-36% salinity when utilizing Acartia, however salinity may varies with species, as will be appreciated by one of skill in the art upon viewing this disclosure), maintaining the oxygen saturation of the environmental fluid within a suitable range (e.g., via aeration), provision of food sources and/or nutrients, or combinations thereof.
  • a suitable temperature e.g., about 20° C.
  • a suitable range e.g., about 29-36% salinity when utilizing Acartia, however salinity may varies with species, as will be appreciated by one of skill in the art upon viewing this disclosure
  • maintaining the oxygen saturation of the environmental fluid within a suitable range e.g., via aeration
  • provision of food sources and/or nutrients or combinations
  • the acceptability of the wellbore servicing fluid and/or the wellbore servicing fluid component may be assessed upon completion of the trial (e.g., at the termination of the desired duration).
  • assessing the acceptability of the fluid and/or the fluid component may comprise assessing the health of the test organisms of the at least one test group and assessing the health of the test organisms of the control group.
  • assessing the health of the test organisms may comprise observing the survival rate associated with each group, observing the reproduction rate associated with each group, the rate of weight change associated with each group, observing various qualitative and/or quantitative characteristics associated with test organisms of each group, or combinations thereof.
  • assessing the acceptability of the fluid and/or the fluid component may further comprise comparing the control group with the test groups.
  • the control group and the test groups may be compared to determine whether any statistically significant difference, in any one or more of the observed characteristics, qualities, or quantities, may be due to the presence of the wellbore servicing fluid or any component thereof at any of the tested concentrations.
  • various statistical methods may be employed to determine the significance of any apparent or unapparent difference between the control group and any one or more of the test groups.
  • the wellbore servicing fluid and/or a component thereof may be deemed acceptable where no statistically significant difference exists between the control group and one or more of the test groups, depending upon the test group.
  • a wellbore servicing fluid and/or component may be deemed acceptable for use at some concentrations and unacceptable at other concentrations.
  • the wellbore servicing fluid and/or a component thereof may be deemed acceptable where the differences between the control group and one or more of the test groups are not detrimental to the test organisms (e.g., where the wellbore servicing fluid and/or component has a beneficial effect on the test organisms).
  • assessing the acceptability of the fluid and/or the fluid component may comprise determining a median lethal concentration (an LC50), a median effective concentration (an EC50), a median inhibitory concentration (an IC50), a no observed effect concentration (NOEC), a lowest observed effect concentration (a LOEC), or combinations thereof.
  • an LC50 median lethal concentration
  • an EC50 median effective concentration
  • an IC50 median inhibitory concentration
  • NOEC no observed effect concentration
  • a LOEC lowest observed effect concentration
  • the term “LC50” may refer to the concentration of a test substance where 50% of the organisms die; the term “EC50” may refer to the concentration of a test substance where 50% of the organisms show a significant given effect (e.g., if a skin test, where half the organisms show the expected rash or response); the term “IC50” may refer to the concentration of a test substance where 50% of the organisms given response is inhibited (e.g., where production stops); the term “NOEC” may refer to the highest concentration where no significant effect is observed; and the term “LOEC” may refer to the lowest concentration where some significant effect is observed.
  • the wellbore servicing fluid or component may be made available for usage.
  • a provider or manufacturer may package the fluid and/or fluid component for distribution and usage by an end user.
  • Such a provider or manufacturer may provide instructions, information, and/or recommendations (e.g., on, within, or included with the product) for the safe and proper usage of the fluid or fluid component.
  • instructions, information, or recommendations may include safe and effective concentrations for usage, geographical or other usage restrictions, proposed risk avoidance measures, proposed clean-up procedures, safety and/or environmental impact ratings, or the like.
  • the wellbore servicing fluid may be utilized in a wellbore servicing operation.
  • the wellbore servicing operation may comprise a drilling operation, a wellbore clean-out operation, a completion and/or cementing operation, an acidizing operation, a perforating operation, a fracturing or other stimulation operation, a workover operation, a shut-in or well-kill operation, any other like, suitable operation, as will be recognized by one of skill in the art viewing this disclosure, or combinations thereof.
  • the wellbore servicing fluid may be prepared at the site of such a servicing operation (e.g., at the wellhead).
  • the wellbore servicing fluid and/or component may be mixed (e.g., via the operation of one or more blenders) one or more additional component in suitable amounts to yield a servicing fluid of a desired character.
  • the wellbore servicing fluid or component may be prepared off-site and transported to the work site.
  • the prepared wellbore servicing fluid may be conveyed into the wellbore and/or into the subterranean formation.
  • the prepared fluid present at the work site may be conveyed via the operation of one or more pumps, compressors, or the like, through flowlines (e.g., manifolds, tubing, etc.) into the wellbore.
  • the wellbore servicing fluid may be conveyed at a suitable rate and/or pressure, as may depend upon the particular servicing operation being performed.
  • the wellbore servicing fluid may be circulated through the wellbore, introduced into the formation (e.g., a fracture or perforation within the formation), or to a predetermined depth within the wellbore.
  • the wellbore servicing operation may be directed to a wellbore penetrating a subterranean formation beneath dry land, alternatively, to a subterranean formation beneath a body of water.
  • the exemplary chemicals, fluids, and/or additives disclosed herein may directly or indirectly affect one or more components or pieces of equipment associated with the preparation, delivery, recapture, recycling, reuse, and/or disposal of the disclosed chemicals, fluids, and/or additives.
  • the disclosed chemicals, fluids, and/or additives may directly or indirectly affect one or more mixers, related mixing equipment, mud pits, storage facilities or units, fluid separators, heat exchangers, sensors, gauges, pumps, compressors, and the like used generate, store, monitor, regulate, and/or recondition the exemplary chemicals, fluids, and/or additives.
  • the disclosed chemicals, fluids, and/or additives may also directly or indirectly affect any transport or delivery equipment used to convey the chemicals, fluids, and/or additives to a well site or downhole such as, for example, any transport vessels, conduits, pipelines, trucks, tubulars, and/or pipes used to fluidically move the chemicals, fluids, and/or additives from one location to another, any pumps, compressors, or motors (e.g., topside or downhole) used to drive the chemicals, fluids, and/or additives into motion, any valves or related joints used to regulate the pressure or flow rate of the chemicals, fluids, and/or additives, and any sensors (i.e., pressure and temperature), gauges, and/or combinations thereof, and the like.
  • any transport or delivery equipment used to convey the chemicals, fluids, and/or additives to a well site or downhole
  • any transport vessels, conduits, pipelines, trucks, tubulars, and/or pipes used to fluidically move the chemicals, fluids, and/or additives from one location
  • the disclosed chemicals, fluids, and/or additives may also directly or indirectly affect the various downhole equipment and tools that may come into contact with the chemicals/fluids such as, but not limited to, drill string, coiled tubing, drill pipe, drill collars, mud motors, downhole motors and/or pumps, floats, MWD/LWD tools and related telemetry equipment, drill bits (including roller cone, PDC, natural diamond, hole openers, reamers, and coring bits), sensors or distributed sensors, downhole heat exchangers, valves and corresponding actuation devices, tool seals, packers and other wellbore isolation devices or components, and the like.
  • drill string including roller cone, PDC, natural diamond, hole openers, reamers, and coring bits
  • sensors or distributed sensors including roller cone, PDC, natural diamond, hole openers, reamers, and coring bits
  • downhole heat exchangers valves and corresponding actuation devices
  • tool seals packers and other wellbore isolation devices or components, and the like.
  • Embodiment 1 A method of assessing a wellbore servicing fluid or a component thereof comprising:
  • Embodiment 2 The method of embodiment 1, wherein the predetermined duration is from about 18 days to about 24 days.
  • Embodiment 3 The method of one of embodiments 1 through 2, wherein the predetermined duration is about 21 days.
  • Embodiment 4 The method of one of embodiments 1 through 3, wherein the divider comprises a mesh having openings of from about 80 microns to about 100 microns.
  • Embodiment 5 The method of one of embodiments 1 through 4, wherein the divider comprises a mesh having openings of about 90 microns.
  • Embodiment 6 The method of one of embodiments 1 through 5, wherein the first fluid vessel is configured to fluidly drain via common point.
  • Embodiment 7 The method of one of embodiments 1 through 6, wherein the first fluid vessel is configured as an inverted cone.
  • Embodiment 8 The method of one of embodiments 1 through 6, wherein the first fluid vessel is configured as an inverted pyramid.
  • Embodiment 9 The method of one of embodiments 1 through 8, wherein the first tub is positioned at a height greater than the height at which the fluid receptacle is positioned.
  • Embodiment 10 The method of one of embodiments 1 through 9, wherein the first fluid vessel further comprises a valve and a flow conduit in fluid communication with the fluid receptacle, wherein the portion of the organisms of less than the first size are allowed to flow out of the first fluid vessel and into the fluid receptacle via the valve and the flow conduit.
  • Embodiment 11 The method of one of embodiments 1 through 10, wherein the divider is oriented substantially horizontally.
  • Embodiment 12 The method of one of embodiments 1 through 11, wherein the first section is at least partially above the second section.
  • Embodiment 13 The method of one of embodiments 1 through 12, wherein the test organisms are introduced within an aquatic solution.
  • Embodiment 14 The method of embodiment 13, wherein the aqueous solution comprises a salinity of about 29-36%.
  • Embodiment 15 The method of one of embodiments 1 through 14, wherein the at least one test group comprises at least two test groups, wherein, in each of the at least two test groups, the test organisms are subjected to the wellbore servicing fluid or component thereof at varying concentrations.
  • Embodiment 16 The method of one of embodiments 1 through 15, wherein the at least one test group comprises at least two test groups, wherein, in each of the at least two test groups, the test organisms are subjected to a different component of the wellbore servicing fluid.
  • Embodiment 17 The method of one of embodiments 1 through 16, wherein the test organism comprises a member of the genus Acartia.
  • Embodiment 18 The method of one of embodiments 1 through 17, wherein the at least a portion of the organisms of the size less than the first size comprise eggs of the test organisms.
  • Embodiment 19 The method of one of embodiments 1 through 18, wherein an adult life stage of the test organism is not capable of passing through the divider.
  • Embodiment 20 The method of one of embodiments 1 through 19, wherein the wellbore servicing fluid or a component thereof comprises a drilling fluid, a perforating fluid, a fracturing fluid, an acidizing fluid, a cementitious composition, or a component thereof.
  • R Rl+k*(Ru ⁇ Rl)
  • k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, . . . , 50 percent, 51 percent, 52 percent, . . . , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent.
  • any numerical range defined by two R numbers as defined in the above is also specifically disclosed.

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  • Chemical & Material Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Apparatus Associated With Microorganisms And Enzymes (AREA)
  • Measuring Or Testing Involving Enzymes Or Micro-Organisms (AREA)
  • Farming Of Fish And Shellfish (AREA)
US13/526,049 2012-06-18 2012-06-18 System and Method of Assessing a Wellbore Servicing Fluid or a Component Thereof Abandoned US20130333877A1 (en)

Priority Applications (8)

Application Number Priority Date Filing Date Title
US13/526,049 US20130333877A1 (en) 2012-06-18 2012-06-18 System and Method of Assessing a Wellbore Servicing Fluid or a Component Thereof
PCT/US2013/043933 WO2013191883A2 (fr) 2012-06-18 2013-06-03 Système et procédé d'évaluation d'un fluide de service de puits de forage ou d'un composant de celui-ci
BR112014031128A BR112014031128A2 (pt) 2012-06-18 2013-06-03 método para avaliar um fluido de serviço de furo de poço ou um componente do mesmo
EP13728305.7A EP2831266A2 (fr) 2012-06-18 2013-06-03 Système et procédé pour l'évaluation de la toxicité d'un fluide de service de puits de forage ou d'un composant de celui-ci
AU2013277594A AU2013277594B2 (en) 2012-06-18 2013-06-03 System and method of assessing the toxicity of a wellbore servicing fluid or a component thereof
CA2877106A CA2877106C (fr) 2012-06-18 2013-06-03 Systeme et procede d'evaluation d'un fluide de service de puits de forage ou d'un composant de celui-ci
EA201492171A EA201492171A1 (ru) 2012-06-18 2013-06-03 Система и способ оценки жидкости для технического обслуживания ствола скважины или ее компонента
MX2014014440A MX358634B (es) 2012-06-18 2013-06-03 Sistema y metodo para evaluar la toxicidad de un fluido para dar mantenimiento a sondeos o un componente del mismo.

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US13/526,049 US20130333877A1 (en) 2012-06-18 2012-06-18 System and Method of Assessing a Wellbore Servicing Fluid or a Component Thereof

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EP (1) EP2831266A2 (fr)
AU (1) AU2013277594B2 (fr)
BR (1) BR112014031128A2 (fr)
CA (1) CA2877106C (fr)
EA (1) EA201492171A1 (fr)
MX (1) MX358634B (fr)
WO (1) WO2013191883A2 (fr)

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2091023A (en) * 1937-04-14 1937-08-24 Roy L Arterbury Well boring apparatus
US5627143A (en) * 1993-09-01 1997-05-06 Dowell Schlumberger Incorporated Wellbore fluid

Family Cites Families (1)

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Publication number Priority date Publication date Assignee Title
CA2065716A1 (fr) * 1991-04-29 1992-10-30 Amikam Horowitz Test de biotoxite pour produits chimiques

Patent Citations (2)

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Publication number Priority date Publication date Assignee Title
US2091023A (en) * 1937-04-14 1937-08-24 Roy L Arterbury Well boring apparatus
US5627143A (en) * 1993-09-01 1997-05-06 Dowell Schlumberger Incorporated Wellbore fluid

Non-Patent Citations (3)

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Title
Medina et al. Static-renewal culture of Acartia tonsa (copepoda: calanoida) for ecotoxicological testing. Aquaculture. 2004;229:203-213. *
Mesh. Screening, stainless steel wire mesh, nylon, polyester, polypropylene mesh. www.tedpella.com. 2010;1-3. *
Rose et al. Development of an acute toxicity test with the marine copepod Acartia sinjiensis. Australasian Journal of Ecotoxicology. 2006;12:73-81. *

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BR112014031128A2 (pt) 2017-06-27
MX358634B (es) 2018-08-29
MX2014014440A (es) 2015-02-04
CA2877106A1 (fr) 2013-12-27
CA2877106C (fr) 2018-03-06
AU2013277594B2 (en) 2017-06-15
WO2013191883A2 (fr) 2013-12-27
AU2013277594A1 (en) 2015-01-22
WO2013191883A3 (fr) 2014-06-05
EP2831266A2 (fr) 2015-02-04
EA201492171A1 (ru) 2015-05-29

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