CN101498215B - Enhanced downhole fluid analysis - Google Patents
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- CN101498215B CN101498215B CN200810008636.5A CN200810008636A CN101498215B CN 101498215 B CN101498215 B CN 101498215B CN 200810008636 A CN200810008636 A CN 200810008636A CN 101498215 B CN101498215 B CN 101498215B
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Abstract
The operation, the analysis and the explanation of a chromatogram system can be obviously reinforced by coupling the chromatogram system with property measurement of one or a plurality of fluids. The property measurement of fluids provides fluid kinds, the existence of any pollutant, the estimation of hydrocarbon composition (C1, C2-C5 and C6+), the ratio of gas and oil, and the primary indication of color and/or fluorescent measurement. The other measurement used for the primary stage can include the measurement of density, viscosity and phase change. The measurement can be used for reinforcing the sampling regulation and the analysis regulation of GC in real time, and simultaneously improving the stability of chromatogram explanation.
Description
Technical field
The present invention relates to formation fluid (formation fluid) analysis, more specifically, relate to the system and method for the chromatography downhole fluid of enhancing, it utilizes the initial token of the character of described fluid, further analyze afterwards, such as wellbore fluid of described downhole fluid, processes fluid, formation fluid and drilling mud.
Background technology
Chromatography is the technology that is generally used for the hydrocarbon that characterizes underground generation in the equipment based on ground.It comprises for example hydrocarbon compound more than C36+ for long chain hydrocarbon compound, and high-resolution composition analysis is provided.These technology can be used for the composition model simulation of fluid in state equation adjustment and oil reservoirs subsequently, to promote or to provide plan and the design of oil reservoirs production strategy and the production equipment based on ground.
In the laboratory based on ground, typically, stratum (formation) hydrocarbon samples is flashed to ambient conditions, with gas and the liquid hydrocarbon phase of separate dissolved.Water by any liquid hydrocarbon (oil) that may be present in collection in mutually separates.The injection that not only oil-water mixes may be interfered quantitative hydrocarbon analysis, and contact with water and also may cause fixing degeneration fast mutually in chromatographic column.Standard analysis code, comprises post type and structure, temperature program(me), and flow rate of carrier gas and pressure, syringe and detector temperature, be used to characterize.Can be by the analysis of one or more chromatographic systems and code hydrocarbon phase cut for gases and liquids, so that resolution ratio and accuracy maximize.The canonical analysis time of this standardized technique is in the scope of a few minutes to one hour.
In order to obtain formation fluid, conventionally use the formation tester instrument with sampling probe, pump assembly and flow line.Typically, sampling probe contact stratum and pump are for fluid is drawn into flow line from stratum, and flow line may be containing the one or more sensor linkages (train) that are useful on local analysis.Subsequently, can or process in well or be collected in sample bottle for the further analysis based on ground fluid.Fluid can be multiphase mixture single-phase or water and gas/liquid hydrocarbon.Be drawn into initial fluid in instrument normally highly polluted by drilling well F.This filtrate can be (miscible with stratum hydrocarbon) of water-Ji's (with stratum hydrocarbon unmixing) or oil-base.By long-time continuous pumping, it is the representative of real formation fluid more that pollution decline and fluid become.
Pilkington (Pilkington) is at United States Patent (USP) 4,739, discloses a kind of method and apparatus that uses chromatographic system single-phase flow to be carried out to down-hole chromatogram in 654.In the technology of Pilkington, identify not by the highly polluted hydrocarbon samples of the F of oil base with resistivity sensor.But Pilkington is failed statement alternative sensor and is followed the tracks of the mud contamination thing of oil base as optical pickocff.In addition, Pilkington fails to point out the difference between formation water (or water base F) and oil.
If only use chromatographic analysis system in subsurface environment, sampling, by being blindly, does not have the knowledge of the priori of type of fluid, and described type of fluid is water, gas and/or liquid hydrocarbon or pollutant for example.The sampling of water and the injection in chromatographic system should be avoided, irrelevant because the pressure-volume-temperature (PVT) of itself and hydrocarbon characterizes.Contact water may cause the quick degeneration of the fixing phase of post and/or disturb quantitative hydrocarbon analysis.Blindly another problem of sampling is, in the time that hydrocarbon fluid is the mixture of gas phase and liquid phase, is difficult to these two phases all be sampled to obtain accurately in representational cut quantitatively.In order to maintain the integrality of analysis, would rather two-phase be sampled respectively and be obtained independently by single-phase injection their composition.
In addition, importantly know the percentage of pollution, when the F that particularly contains mixable oil-base at sample, because the highly polluted character that sharply changes formation fluid, therefore the composition analysis of such sample is not worth.Acceptable level of pollution in formation fluid sample is: for the F of oil-base, approximately below 5%.In the case of the F of water-Ji, before analyzing, separate hydrocarbons is important.Therefore, advantageously only carry out fluid properties sign and chromatography during lower than acceptable level in level of pollution, adjust and the result of estimating of fluid character for state equation (EOS) obtaining.Although chromatography is generally used for estimating to pollute in ground experiment chamber, under conditions down-hole, be invalid by the long-time repeated sampling of chromatography to follow the tracks of pollution.This has not only increased the limited resources on downhole tool as the consumption of carrier gas, but also causes the decline of chromatographic performance.Most of posts readjust after certain frequency injection.If can adopt more effective method for polluting tracking, advantageously only use chromatography to be used for sample analysis.
Well typically runs through several stratum, and described stratum is filled with the fluid of the various kinds from dry gas to heavy oil.Therefore, downhole tool should preferably can be analyzed various fluids in single well logging running.In the case of there is no the priori of hydrocarbon samples kind, will have to adopt for example standard schedule, and not consider whether it is the dry gas that component mainly arrives C7, or component is until the dirty oil of C36 and Geng Gao.Therefore kind is adjusted and is optimized to improve resolution ratio and accuracy per sample.This may also cause unnecessary longer analysis time.Not only cause the higher cost relevant with drilling time at the high latency of analysis station, and increased the risk that instrument blocks in well.Also mean that the product of increasing consumption are as carrier gas longer analysis time, running stores are the important consideration in subsurface environment, because only there is limited supply.
One aspect of the present invention is for these defects in the prior art.
Summary of the invention
According to some aspects, the present invention relates to a kind of analytical system, this analytical system comprises the first platform and the second characterization platform, the instruction that the first platform is configured to receive at least a portion analyte and at least one character of this fluid is provided, the second characterization platform is configured to receive at least a portion formation fluid and comprises at least one chromatography linkage.Term used herein " chromatography linkage ", " analysis linkage " or " linkage " can comprise one or more sampler/syringes, one or more pillar and one or more detector, and their fluids are connected so that the relevant characterization from the eluent of described one or more pillars to be provided.In addition, for clear, term used herein " analyte " refers to the fluid sample of analyzing.According to the present invention, analyte can be single-phase or heterogeneous, and can comprise liquid hydrocarbon phase, water or gas hydrocarbon phase.
According to one or more aspects, the present invention relates to a kind of method that characterizes analyte.The method can comprise one or more following behaviors: at least one first character of determining analyte in the first characterization platform, at least one first character based on described at least in part, the composition of definite at least a portion analyte in the second characterization platform.
Brief description of the drawings
In accompanying drawing, Fig. 1 illustrates flow chart according to one or more embodiments of the present invention;
Fig. 2 is that the optical density of the various oil of demonstration is as the figure of the function of wavelength;
Fig. 3 is the figure that shows the absorption spectrum of oil samples and water sample;
Fig. 4 is the figure that shows the pollution prediction of oil samples, and described pollution prediction is used the fresh fluid analyser (Live Fluid Analyzer) on formation tester;
Fig. 5 is that diagram detects the heterogeneous figure that pumps assembly downstream, and described detection is used the composition fluid analyzer (Composition Fluid Analyzer) on formation tester; With
Fig. 6 is the figure showing from the downhole fluid analysis log of oil band, and described analysis is used the composition fluid analyzer on formation tester.
Detailed description of the invention
The invention provides down-hole, on the spot, formation fluid characterize system and technology.System and technology that aspects more of the present invention provide the chromatogram that promotes formation fluid to characterize.Promote the sign of this formation fluid in subsurface environment to comprise: at least one of initial layer fluid definitely or multiple character, as optical signature, type of fluid, fluid density, fluid color, fluid fluorescence GOR rate and low resolution composition.Therefore, aspects more of the present invention relate to characterization system and technology graduate or stage by stage, and wherein the first analytical procedure or platform can be utilized to characterize the characteristic of formation fluid together with one or more more analysis platforms.The first characterization platform can comprise nondestructive platform, comprises, for example, measures the technology of the intrinsic property of analyzed fluid.Fluid can be formation fluid, and intrinsic property can be at least one fluid properties of formation fluid component.Those skilled in the art will appreciate that multiple alternative fluid can be used for implementing the present invention.In addition, for illustration purpose, the present invention will be described for the fluid running in subsurface environment, and this fluid is called " formation fluid " in this article.Such explanation is not intended to limit scope, because as understood by those skilled in the art, the present invention can implement on multiple alternative fluid.First or initial token function can promote or the sign of layer fluid post, or at least promote or the sign of the part in layer fluid post.But, if, for example in bypass mechanism, carrying out the first platform sign, first platform that also can utilize the destructiveness of carrying out sample segment to characterize provides initial token.
More features of the present invention relate to downhole analysis, and described downhole analysis comprises fast and effective sign, realizes required chromatographic isolation simultaneously.For example, the present invention can allow the chromatographic isolation code of the knowledge-chosen the best based on type of fluid.But, in the case of the priori that there is no fluid, will use single code to guarantee suitable sign.The code that this may unnecessarily extend analytical cycle or need unnecessary complexity.For example, if sample mainly comprises dry gas, will adopt unnecessary long analysis time and temperature heating oblique line to rise to reach the high column temperature of the main component using non-existent more high carbon atom number as target.This also may cause system carry out next analyze before longer cool time.
In order to use the gas-chromatography output of adjusting for EOS, in sample fluid, the quality of all components or molar fraction should be known.In the laboratory based on ground, in the chromatogram quantification of molar fraction or mass fraction need to be present in sample but not component in chromatogram output describe.This may be because: (i) they are crossed to be adsorbed on doughtily and fixing go up mutually, and in analysis time wash-out never, (ii) never in sampler/syringe, evaporate because of the low volatility under the temperature and pressure condition adopting, the part of the sample plug (sample plug) of therefore not evaporating is expelled in pillar, or (iii) they are recoiled, thereby do not pass through detector.In the analysis based on ground, by using interior mark (with the ratio accurately measured and the particular components of sample mix), as in the method described in ASTMD5307-97 and D5442-93, these components are described conventionally.But mark and hydrocarbon samples may be complicated in very accurately mixing in the gas-chromatography instrument of down-hole.
Aspects more of the present invention can comprise downhole tool or system, and it comprises one or more initial token systems, subsystem or parts, and they provide initial value and the characteristic of fluid.The present invention is advantageously integrated chromatographic system and technology and other sensor and/or code, as based on those of optical technology, resistivity, NMR, and/or provide the measured value of intrinsic property, as density and/or viscosity.
Fig. 1 has exemplarily illustrated one embodiment of the invention.The subsystem of optics-Ji can be determined the existence of any water in analyte or gas or liquid (oil) hydrocarbon phase at first.Therefore, the existence of water, oil and/or gas or do not exist, can be in the first sign step 112 initial token.In some cases, more embodiment can provide at least the estimation for the ratio of oil (GOR) about any dissolved gas of analyte.Some more aspects can comprise at least a portion of analyte or the color of component and Fluorescent Characterization, and described analyte can be further used in one or more sign linkages subsequently or that follow.For example, can determine color and/or the fluorescence of liquid hydrocarbon phase, and initial or the first character of determining can provide the qualitative estimation of the characteristic of for example light or heavy-hydrocarbon oil of oil.Can by as seen to the absorption spectrum of near infrared region for the composition analysis that carries out low resolution for example, C1, C2-C5 or C6+, and the mud contamination of any oil base, as with described in Publication about Document: Andrews etc., " use quantitatively (the QuantifyingContamination Using Color of Crude and Condensate) of pollution of the color of crude oil and condensate ", oil field comment (OilfieldReview), autumn calendar year 2001, 24-43 page, with Betancourt etc., " analyze the hydrocarbon (Analyzing Hyrdocarbons in the Borehole) in boring ", oil field comment (Oilfield Review), autumn in 2003, 54-61 page, they have described these optical measurement in further detail.If suitable, can evaluate more sign in step 122.That if sample is considered to pollute or be considered to mainly be formed by undesirable component, no longer consider further to characterize, and be recoverable to another sample, 122, no.In addition, if initial or the first characterization result is uncertain, fuzzy and/or invalid aspect other, be recoverable to another sample.For illustration purpose, this is illustrated in step 106, but, those skilled in the art will recognize that, the withdrawal of another sample can occur in multiple alternative platform, is included in step 112 or 122.For example, if the analyte of regaining is mainly made up of non--hydrocarbon component, can abandons sample, and will further not characterize.If effectively sample value obtains further and evaluates, 122, be, in one or more second characterizes steps 142, sample is transferred to second or analysis subsequently in.In some cases, can be at least partly based on the first characterization result, determine that second characterizes one or more optional steps of one or more parameters of step 132, for example, in one or more chromatogram linkages.Combination the first and second results 152 that can selection operation can comprise are in addition explained to provide about the enhancing of analyte quality, feature and/or characteristic.
In some embodiments of the present invention, can utilize by the color harmony intensity of the light of sample transmission or reflection and distinguish the different oil forming.Can use the light of absorption or optical density (OD) that the sign of component is provided, OD can be the ratio of incident light and transmitted light, and fluid is darker, and OD is higher.For example, light hydrocarbon is light colourless and that do not absorb visible spectrum typically, and condensate can be clarification or slightly with micro-red-brown color, because they absorb blue light, and the heavy crude with complicated molecule typically is burgundy, because be all absorbed at the light of whole visible spectrum.Therefore, in some embodiments of the present invention, the first characterization platform comprises measures the initial token of optical density with sampling.In some cases, the feature of considering can be the existence of one or more fluid-phases.Can also be by the instrument of optical system base as the fresh fluid analyser (LFA of shura Mu Baige (Schlumberger)
tM) and composition fluid analyzer or CFA
tMfor detection of single-phase and multiphase flow, and further provide about suitable sampling condition or whether should further analyze the instruction of the sample of withdrawal.In the more embodiment of the present invention, the system of optics base and measure the resistivity of for example fluid or electrical conductivity those and utilize those of nuclear magnetic resonance (NMR) also can be in the first characterization platform.
The particularly advantageous embodiment of the present invention can adopt the spectral measurement of sample that initial characteristics or multiple initial characteristics are provided.In the situation that some are special, can catch the spectral signal from sample, and the special constituent of spectrum, for example, and at the light of selective wavelength, the instruction of the required and/or undesirable component in can sampling or do not exist.Fig. 2 and 3 is (based on Andrew (Andrews) etc., " use quantitatively (the QuantifyingContamination Using Color of Crude and Condensate) of pollution of the color of crude oil and condensate ", comment in oil field, autumn calendar year 2001, contained data in 24-43 page), exemplarily show the graph of a relation between optical density and light wavelength.As shown in Figure 3, water typically absorbs the light of near-infrared wavelength, i.e. the light of approximately 1445 and 1930 nanometers.Therefore, can adopt optical technology, by catching/observe the response of sample or characteristic properties to provide one or more targets to consider existing and/or non-existent instruction of things, determine the existence of water in sample.
In one embodiment of the invention, optical system can comprise at least one light source as light emitting diode, and described light emitting diode (LED) light is typically coupled at least one refractometer by window, and described window can be sapphire window.Window is set to typically against accommodating the flow line of the fluid being characterized or becoming its a part of sapphire window.Refractometer utilizes the reverberation of window quantitatively to identify the fluid-phase in oil pipeline.In the angle of incidence of selecting, the reflectance factor of reflectance factor when gas contacts with window during much larger than oil or water contact window.In more embodiment, optical system can further comprise the detector module of the Absorption Characteristics of secondary light source and definite fluid.One or more wideband light sources can pass through fluid by the transmission of wide spectral light as high temperature halogen tungsten filament lamp.The distribution of measuring transmitted light in whole visible and near infrared spectrum.Can use multiple passages selectively to determine, observe or quantize the light of multiple wave-length coverages of spectrum.From the sign of the relative quantity of respective components in the measurement sampling of each passage.
In addition, can distinguish fume as mud solid, because the existence of this pollutant typically confirms as the noise in OD measurement.For example, Fig. 4 has shown and can be used in optical means following the tracks of the figure from the pollutant in the formation fluid of mud (OBM) filtrate of oil-base.Can be used in real time fresh fluid analyser or LFA available from shura Mu Baige
tM, it is substantially described in oil field comment (Oilfield Review), 24-43 page, autumn calendar year 2001 by Andrew etc.OBM filtrate is colourless and there is no the methane dissolving.Along with continuous sucking and pollutant decline in the fluid of sampling, the mark of the formation fluid in sample increases.This increase by the optical density in color and methane wavelength channel is confirmed, and described optical density increases and stablizes along with polluting stable.In the sample instance shown in this figure, Color Channel data prediction approximately 4.9% pollutes, and methane passage predicts that approximately 6.2% pollutes.Average 5.5% is consistent with 4.3% pollution of the GC Analysis deterrmination by vitro collection sample.
Fig. 5 (examines spy (Betancourt) etc. based on beta, the data that comprise in SPE 87011, the meeting of SPE Asia-Pacific, Malaysia Kuala Lumpur, in March, 2004)) show, can carry out optical measurement with the composition fluid analyzer that pumps assembly downstream that is arranged in formation tester instrument.Pump assembly and cause the Gravity Separation of gas, oil and water.When the optical signalling that comes autofluorescence and absorptiometry is flowed through optical pickocff in flow line at oil-water-gas slug (slug), draw their aspect graph.This preceding first be characterized in avoid water sampling and select for use chromatogram linkage second analyze representative single phase and gaseous sample be potential important.
Therefore,, aspect more of the present invention, the efficiency of down-hole chromatographic system and technology can be enhanced or be improved by the Real-Time Evaluation of being convenient to when sampling.For example, first of optics base the sign subsystem can guarantee only in the time there is no water, to carry out gas-chromatography (GC) analysis.In the hydrocarbon-current of many mixing, pump assembly serves as downhole separator and produces the slug of water and hydrocarbon.Use the first characterization tool can in sampling, use as instructing, to catch hydrocarbon slug.This is by the measurement of guaranteeing to be correlated with and prevent the infringement of the pillar to water sensitive.Similarly separation can occur in the time there is oil/gas stream.Therefore, for example, the first system of optics-Ji can be used for instructing sample time to regain oil samples, then in next running, regains gaseous sample.
Chromatogram linkage of the present invention typically comprises one or more sampler/syringes, one or more pillars, and one or more detector, and their fluids are connected so that the relevant characterization from the eluent of one or more pillars to be provided.Typically, detector can be for example flame ionization detector or thermal conductivity detector (TCD), and pillar accommodates fixing phase, for example, one or more components of analyte is shown to gel or other suitable material of affinity.
In one or more preferred embodiments, the system of optics-Ji can promote to determine the best GC sampling period fast and/or continuously based on pollution.For example, typically, only enough low at pollutant, sample analysis has the used time just to regain sample.Pollute although GC can be used for following the tracks of, preferably reduce the quantity that GC analyzes, typically spend because GC analyzes the time that ratio is as longer in the analytical technology of optics-Ji.On the contrary, first of optics-Ji analyzes and can monitor continuously pollution, and pollutes when enough low thinking, the GC of for example sample analyzes when suitable, triggers other sign.Avoid or reduce and pollute the dependence that the chromatogram of following the tracks of characterizes, can minimizing instrument spending in the time at fluid sampling station, because GC analyzes typically cost than longer time of optical analysis on the spot in well.This has reduced the risk that instrument blocks.Before chromatogram characterizes, selectively sample or the other benefit of water pollution classification is, can reduce the consumption of carrier phase.Therefore, in some embodiments, can utilize less holonomic system, because reduced the operation requirements that carries out quantitatively similar and/or qualitative analysis.In addition, the degeneration of post is minimized, and makes can carry out the representative sample analysis of more heterogeneous pass before pillar need to readjust.
Methane and carbon dioxide often can co-elute.Optical characterisation methane component molar fraction allows to determine by the following method the relative quantity of carbon dioxide, for example, is carried out the methane contribution of compensated measurement by the combination methane and carbon dioxide of the measurement of determining by chromatography.Therefore, embodiments more of the present invention can be avoided chromatographic process, and these chromatographic processes, typically for separating of methane and carbon dioxide, are the methods typically with longer analysis time.Therefore, aspects more of the present invention belong to the combination of chromatography and optical analysis system with better quantitatively and explain.Adopt CFA
tMoptical analysis provide C1, C2-C5 and C6+, and these outputs can be used for check with GC measure uniformity.If there is marked difference, detects in real time it and allow the chance of duplicate measurements.
A feature more of the present invention can belong to utilizes first fluid property information to improve or even optimization chromatography.For example, characterization system or instrument can comprise the rules of analysis of one or more storages, and it for example comprises, temperature program(me), flow rate of carrier gas, and/or pressure time table.According to the kind of hydrocarbon, for example dry gas, light oil, heavy oil etc., can use various codes, and typically real-time selection the best and/or preferred rules of analysis, to improve resolution ratio and rapid analysis be provided.
In some embodiments of the present invention, can under conditions down-hole, determine density and/or the viscosity of analyte, for example, use vibrating sensor, as those disclosed in WO2002077613 and WO2006094694, so that initial token to be provided.Can obtain about hydrocarbon kind, light or qualitative information heavily by viscosity information.Can carry out to quantize more cursorily chromatogram with density information.
As explained before this, because the incomplete gasification in sample/injecting unit or in fixing strong absorption of going up mutually etc., not all sample component all can be eluted in chromatogram.Mark in current laboratory method is used, described at ASTM D5307-97 and D5442-93, with the quality of determining that it loses in chromatogram.This mark is called additional mark, and with together with the quality information of all other components, can provide total fluid composition.Then, this Information Availability is in the relation adopting between EOS estimated pressure, volume and temperature.Typically, use the fluid properties of accurate and detailed composition and measurement as bubble point, dew point, with the phase blend of other component, compressibility, density etc., adjust state equation characteristic constant (referring to, A Mode (Ahmed) etc., SPE 15673).Under conditions down-hole, be difficult to adopt interior mark and fluid sample to prepare quantitative mixture.Conventionally,, by using for example accurate sample loop, will allow chromatogram sampler at down-hole pressure and temperature, to extract the fluid of precise volumes.Nearest publication, as WO2002077613 and WO2006094694, discloses the vibrating device of high-acruracy survey density under conditions down-hole.Use density and the volume measured, can calculate the gross mass for the sample of chromatography.In chromatogram, the peak area of the component of wash-out can be used for obtaining the quality of every kind of elution fraction.Difference between total eluted mass and input quality is missing mass.This makes the mass fraction of the component that can determine wash-out and total composition of additional mark and fluid, then can be as the input message of EOS model.
The fluid sensor for underground survey that system of the present invention and technology expectation utilization are other, for example, as at (Lo etc., SPE 77264, SPE periodical (SPE Journal), in March, 2002,24-34 page) in disclosed NMR, for measuring hydrocarbon fluid viscosity and GOR rate.Can between water and hydrocarbon fluid, distinguish with resistivity sensor.Measure fluid phase change character as bubble point, dew point, there is (appearance) temperature in wax, other sensor of asphalitine initiation pressure (asphaltene onset pressure) also can provide the information that can be combined with downhole gas analysis of hplc, thereby further promote down-hole EOS to adjust, and allow the real-time consistency of all measuring transducers to confirm.
Fig. 6 has shown that, from the down-hole pressure of oil well and fluid analysis log, described analysis is used the composition fluid analyzer on formation tester.These fluid analysis logs are based on from Fujisawa etc., the data of SPE 89704, SPE ATCE, Houston, Texas, in September, 2004).Pressure detection well curve has clearly illustrated the existence of the gas in stratum, oil and water band.The large composition that has shown hydrocarbon at the fluid log of 5 sample houses changes, as visible in C1, C2-C5 and C6+ mark and the GOR that represents with m3/m3 on right side.This variation is confirmed by laboratory measurement subsequently.The fluid of standing above (xx68.2m) with high GOR is interpreted as in pneumatic jack region, and is the retrograde gas condensate with the C6+ of light colour and approximately 34 % by weight.Station (xy06.3m) is below confirmed as containing the more heavier dirty oil of polyaromatic compound and approximately 72 % by weight C6+.Therefore,, if carry out chromatography in this well, same system must be analyzed at the gaseous sample of the shallow degree of depth of about xx68.2m and at the heavier dirty oil of the degree of depth of about xy06.3m simultaneously.Typical chromatogram code starts from low temperature so that enough resolution ratio to be provided in lighter component, then makes temperature oblique line increase with the heavier component of wash-out.Can adopt and regulate circulation (conditioning cycle) and/or recoil that analysis is carried through to the end, to remove the not component of wash-out.The oil phase ratio heavier with point analysis of variance, the chromatographic isolation of gaseous sample and analysis can be in the shorter times and with lower maximum temperature realization, with wash-out all components.Rise by temperature oblique line higher for heavier oily maximum temperature, will mean that equally the cool time before the analysis starting is subsequently longer.Also may there is larger missing mass by heavier oil, and require readjusting circulation and/or recoiling to remove the component of any not wash-out from pillar after analysis.Existing knowledge from optical analysis contributes to optimize chromatogram code, if make to have the priori about hydrocarbon kind, can use code more fast for gaseous sample.Same attention, this priori will avoid chromatography to stand in water band.
Although described illustrative embodiments more of the present invention, should it is evident that for those skilled in the art, above-mentioned is only illustrative and nonrestrictive, only presents by way of example.Multiple change and other embodiment all in those of ordinary skill in the art's scope, and are thought and are fallen within the scope of the present invention.Particularly, although the many examples that present relate to the specific combination of method behavior or factor of system, should be appreciated that these behaviors and these key elements can otherwise combine to realize identical object herein.
It will be appreciated by those skilled in the art that parameter described herein and structure are exemplary, actual parameter and/or structure will depend on the concrete application that uses system of the present invention and technology.Those skilled in the art it is also recognized that or can determine, only use normal experiment, are equivalent to particular embodiments of the present invention.Therefore, should be appreciated that embodiment described herein only presents by example, and in the scope of appended claim book and equivalent thereof; The present invention can implement in the mode beyond specifically described mode.
And, it should also be understood that, the present invention relates to each feature described herein, system, subsystem or technology, if with such feature, system, subsystem and technology be not mutually inharmonious, any combination of two above features described herein, system, subsystem or technology, and any combination of more than two feature, system, subsystem and/or method, in the scope of the invention that is considered to embody in as claims.In addition be only associated with an embodiment, and behavior, the factors and characteristics discussed are not intended to get rid of from the similar role of other embodiment.
Term used herein " multiple " refers to plural entry or component.Term " comprises ", " comprising ", " with ", " having ", " containing " and " relating to ", be no matter in printed instructions or in claims etc., be all open term, that is, represent " including but not limited to ".Therefore, the use of this term means and comprises listed thereafter entry, and equivalent, and other entry.About claims, only have transition phrase " by ... composition " and " substantially by ... composition " be respectively just seal or semi-enclosed transition phrase.Order term is if the use in claims such as " first ", " second ", " the 3rd " is to change key element required for protection; not by self meaning that any priority, superiority or a claimed key element exceed another order or the chronological order that carries out the behavior of method; but only as the mark of distinguishing the claimed key element with a certain title and another key element with same names (but using order term), to distinguish key element required for protection.
Claims (19)
1. an analytical system, it comprises:
The first characterization platform, this platform is configured to the instruction of at least one character that receives analyte and this analyte is provided, wherein at least one character based on indicated and described analyte is defined as is effective analyte sample; With
The second characterization platform, this platform is configured to receive at least a portion analyte of described effective analyte sample and comprises at least one chromatography linkage.
2. analytical system claimed in claim 1, the first and second wherein said characterization platform are contained in shell.
3. analytical system claimed in claim 1, it also comprises controller, and this controller is operatively connected, and is sent to described the second characterization platform to receive from the signal of described the first characterization platform and by least one control signal.
4. analytical system claimed in claim 1, the first wherein said characterization platform comprises the detector based on optics, this detector is arranged to provide at least one the instruction in the fluid composition of type of fluid, pollutant level and at least a portion analyte.
5. the analytical system of claim 1, the first wherein said characterization platform comprises density sensor, this density sensor is arranged to provide at least one the instruction in the density of at least a portion analyte.
6. analytical system claimed in claim 1, wherein said analyte is formation fluid.
7. analytical system claimed in claim 6, wherein said formation fluid is heterogeneous fluid.
8. analytical system claimed in claim 7, wherein said formation fluid contains water.
9. analytical system claimed in claim 7, wherein said formation fluid contains gas hydrocarbon phase.
10. analytical system claimed in claim 7, wherein said formation fluid contains liquid hydrocarbon phase.
11. 1 kinds characterize the method for analyte, and the method comprises one or more following behaviors:
In the first characterization platform, provide analyte, so that the instruction of at least one the first character of described analyte to be provided, wherein at least one first character based on indicated and described analyte is defined as is effective analyte sample; With
At least one first character based on described at least in part, the composition of at least a portion analyte of definite described effective analyte sample in the second characterization platform.
Method described in 12. claims 11, the method is also included in the behavior of determining the hydrocarbon content of at least a portion analyte in described the first characterization platform.
Method described in 13. claims 12, the method also comprises that at least part of hydrocarbon content based on measuring is transferred to control signal the behavior of described the second characterization platform.
Method described in 14. claims 11, the wherein said behavior of determining the composition of at least a portion analyte in the second characterization platform comprises the behavior of the component of the analyte described in chromatographic isolation.
Method described in 15. claims 14, the method also comprises the behavior of the component of the analyte that detects chromatographic isolation.
Method described in 16. claims 14, the wherein said behavior of the composition of at least a portion analyte of determining in the second characterization platform also comprises the behavior of the chromatogram that produces the composition component that represents analyte.
Method described in 17. claims 16, the method also comprises the behavior that described chromatogram is transferred to remote equipment by well.
Method described in 18. claims 11, the method also comprises the measurement parameter based on from described the first characterization platform at least partly, the behavior that produces the first set operational factor of described the second characterization platform.
Method described in 19. claims 11, wherein said analyte is formation fluid.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN200810008636.5A CN101498215B (en) | 2008-02-01 | 2008-02-01 | Enhanced downhole fluid analysis |
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| CN102052076B (en) * | 2009-10-30 | 2014-04-02 | 中国石油化工股份有限公司 | System for monitoring components of shaft fluid of H2S/CO2-containing gas field and analysis method thereof |
| CN105301150B (en) * | 2015-12-09 | 2017-03-08 | 中国地质科学院水文地质环境地质研究所 | Volatile organic contaminant field enriching apparatus in a kind of subsoil water |
| CN109386282B (en) * | 2017-08-09 | 2022-02-15 | 中国石油化工股份有限公司 | Identification method for drilling oil layer under mixed oil drilling fluid condition |
| CN110056348B (en) * | 2019-04-25 | 2021-05-11 | 中国海洋石油集团有限公司 | Method and system for determining formation fluid composition and properties |
| CN113640178A (en) * | 2021-08-10 | 2021-11-12 | 中海油田服务股份有限公司 | Stratum water type identification method, pollution rate determination method and computing equipment |
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| WO2002057595A1 (en) * | 2001-01-18 | 2002-07-25 | Shell Internationale Research Maatschappij B.V. | Measuring the in situ static formation temperature |
| CN1664575A (en) * | 2005-03-14 | 2005-09-07 | 辽河石油勘探局 | Method for monitoring petroleum reservoir performance by using biomarkers |
| DE102006019813A1 (en) * | 2005-04-29 | 2006-11-02 | Schlumberger Technology B.V. | Fluid analysis assembly for down hole tool, has sensors that communicate with formation fluid to sense one parameter of formation fluid while pressure of formation fluid changes in continuous manner |
| CN1896459A (en) * | 2005-01-11 | 2007-01-17 | 施蓝姆伯格海外股份有限公司 | System and methods of deriving differential fluid properties of downhole fluids |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2002057595A1 (en) * | 2001-01-18 | 2002-07-25 | Shell Internationale Research Maatschappij B.V. | Measuring the in situ static formation temperature |
| CN1896459A (en) * | 2005-01-11 | 2007-01-17 | 施蓝姆伯格海外股份有限公司 | System and methods of deriving differential fluid properties of downhole fluids |
| CN1896458A (en) * | 2005-01-11 | 2007-01-17 | 施蓝姆伯格海外股份有限公司 | System and methods of deriving fluid properties of downhole fluids and uncertainty thereof |
| CN1664575A (en) * | 2005-03-14 | 2005-09-07 | 辽河石油勘探局 | Method for monitoring petroleum reservoir performance by using biomarkers |
| DE102006019813A1 (en) * | 2005-04-29 | 2006-11-02 | Schlumberger Technology B.V. | Fluid analysis assembly for down hole tool, has sensors that communicate with formation fluid to sense one parameter of formation fluid while pressure of formation fluid changes in continuous manner |
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