CN106872507B - A kind of evaluation shale oil reservoir Absorb Water oil displacement efficiency and the method for displacement of reservoir oil time - Google Patents
A kind of evaluation shale oil reservoir Absorb Water oil displacement efficiency and the method for displacement of reservoir oil time Download PDFInfo
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Abstract
The invention discloses a kind of evaluation shale oil reservoir Absorb Water oil displacement efficiency and the methods of displacement of reservoir oil time, reach formation water salinity by the way that experiment simulated formation water is configured；Rock core is placed in fluorocarbon oil of the saturation without proton, surveys nuclear magnetic resonance T2Spectrum, statistics nuclear magnetic resonance T2The area that spectrum is surrounded with X-axis；Rock core is subjected to self-priming flood pot test, nuclear magnetic resonance T is surveyed after placing different time sections respectively2Spectrum, statistics nuclear magnetic resonance T2The area that spectrum is surrounded with X-axis；Rock core is placed to the nuclear magnetic resonance T that different time sections measure respectively2Spectrum is plotted on same figure, the T that will be obtained under the different self-priming water drive oil times2Spectrum determines T with X-axis surround the area reference area difference2Spectrum and X-axis surround the area increment rate R, if R is less than 5%, corresponding previous self-priming time is the best self-priming water drive oil time.This method evaluates the capillary imbibition water drive oil effect of shale oil using nuclear magnetic resonance technique, determines the best self-priming water drive oil time.
Description
Technical field
The present invention relates to oil and gas development experimental technique field, more particularly to a kind of evaluation shale oil reservoir self-priming water drive oil effect
Fruit and the method for determining the best self-priming water drive oil time.
Background technology
As conventional gas and oil resource is constantly reduced, unconventionaloil pool by people common concern, it has also become current grinds
Study carefully hot and difficult issue.Shale oil is as one of important unconventional petroleum resources, conventional because pore-size is based on nanoscale
The water drive oil mode of oil reservoir is not suitable for shale oil reservoir.At present mainly by horizontal well volume fracturing transformation generate crack come
Shale oil is developed, the problem is that crack provides the original in the nanoaperture that hypertonic channel often causes percolation ability very poor
Oil is difficult to be plucked out of.The nanoaperture of shale oil reservoir development is made full use of, carries out the evaluation of self-priming water drive oil, determine reasonably certainly
The time is inhaled for effective exploitation shale oil with important guiding value.In existing research, patent CN201310224584.6 is announced
Shale oil resource potential evaluation method in a kind of mud shale series of strata；Patent CN201510767641.4 discloses adding for shale oil
Work method；Patent CN201110124512.5 discloses a kind of method that shale gas and/or shale oil are exploited using heat power；Specially
Sharp CN201010539090.3 discloses a kind of method for processing shale oil；Patent CN201510044729.3 discloses a kind of mud page
The computation model of shale oil gas saturation；Patent CN201610029592.9 discloses a kind of shale oil gas High-quality Reservoir evaluation method
And parameter determination method；Patent CN201410571890.1 discloses the evaluation method of shale oil gas economical and effective interval；Patent
CN201310105272.3 discloses mud shale grease saturation degree method for accurate testing；Patent CN201310057719.4 is disclosed
A kind of oil shale petroleum resources in-situ retorting method；Patent CN201410598941.X discloses a kind of volume fracturing horizontal well and opens
The method for adopting shale oil；Patent CN201610151743.8 discloses shale oil Logging Evaluation Method；Patent
ZL201310145986.7 discloses the method that pore throat during a kind of quantitative assessment oil and gas secondary migration employs rule；Patent
ZL201410175123.9 discloses a kind of method that quantitative assessment water filling influences throat distribution；Patent
The method that ZL201410174667.3 discloses pore throat variation degree during a kind of quantitative assessment stress sensitive；Patent
ZL201410174888.0 discloses a kind of method that core flooding test effect is oozed in raising；The 2nd phase of volume 27 in 2007, mineral rock
Stone, Sun Laixi et al. has carried out fractured-cavernous carbonate reservoir self-priming using full petroliferous carbonate rock oil reservoir core sample and has driven
Oil experiment；The 3rd phase of volume 13 in 1992, petroleum journal, Qu Zhihao et al. using andesite photoetching replicate micro pore model into
Self-priming oil displacement experiment is gone；The 4th phase of volume 32 in 2002, Northwest University's journal (natural science edition), Qu Zhihao et al. passes through true
It is special to have studied Ansai, No. five stakes, Shanshan, the self-priming displacement of reservoir oil of 4 low permeability oil fields of Cole's health for the experiment of real sandstone micromodel
Sign.
Above-mentioned main problem is：(1) the existing research for shale oil is mainly shown as shale oil resource and page
All kinds of evaluation methods of shale oil reservoir, the fracturing reform method of shale oil, shale oil parameter computation model, shale oil exploitation
Or processing method, and this development scheme of self-priming water drive shale oil and the determining method of best self-priming time have not been reported；(2)
Although the existing self-priming flooding method for LOW PERMEABILITY RESERVOIR and carbonate reservoir, the experimental model used, laboratory facilities and comment
Valency method is different from the present invention, and research object is widely different with the present invention, and existing method is caused not to be suitable for this hair
Bright research object；(3) the present inventor early period using nuclear magnetic resonance technique for oil gas it is secondary into hide, waterflooding extraction process should
Power is sensitive, pore throat variation and in ooze the raising recovery ratio effect of rock core and evaluated, but evaluation object, evaluation procedure, to solve
Main problem certainly and the main purpose reached differ greatly with the present invention.
Invention content
To solve drawbacks described above in the prior art, the purpose of the present invention is to provide a kind of evaluation shale oil reservoirs
Absorb Water oil displacement efficiency and the method for determining the best self-priming water drive oil time, this method is by experiment, using nuclear magnetic resonance technique,
It improves to evaluate the capillary imbibition water drive oil effect of shale oil, and determine best self-priming based on experiment flow and experimental method
The water drive oil time, for shale oil to be instructed to develop.
The present invention is realized by following technical proposals.
A kind of evaluation shale oil reservoir Absorb Water oil displacement efficiency and the method for displacement of reservoir oil time, which is characterized in that including following
Step：
Step 1: configuration experiment simulated formation water, reaches formation water salinity；
Step 2: rock core is placed in high pressure saturation device, its saturation is made to be free of the fluorocarbon oil of proton, survey nuclear magnetic resonance T2
Spectrum, statistics nuclear magnetic resonance T2The area that spectrum is surrounded with X-axis；
Step 3: rock core is placed in the core holding unit in insulating box, mould is persistently injected in rock core both ends with extremely low speed
Intend water flooding and carry out self-priming flood pot test, change temperature and ring pressure, self-priming water drive oil survey nuclear magnetic resonance T after 24 hours2Spectrum, system
Count nuclear magnetic resonance T2The area that spectrum is surrounded with X-axis；
Step 4: repeating step 3, rock core difference self-priming water drive oil 48 hours, 72 hours, 96 hours is surveyed nuclear-magnetism and is total to respectively
Shake T2Spectrum, statistics nuclear magnetic resonance T2The area that spectrum is surrounded with X-axis；
Step 5: the nuclear magnetic resonance T that step 2 is measured2Spectrum and Step 3: four rock cores distinguish self-priming water drive oil it is different when
Between the nuclear magnetic resonance T that measures of section2Spectrum is plotted on same figure, the T under the conditions of comparative analysis difference self-priming time2Spectrum variation；
Step 6: the T that will be obtained under the different self-priming water drive oil times2Spectrum and X-axis surround the area and the preceding T once obtained2Spectrum
It is compared with X-axis surround the area, reference area difference；
Step 7: according to area difference DELTA S, T is determined2Spectrum and X-axis surround the area increment rate R obtain shale oil reservoir certainly
It absorbs water the displacement of reservoir oil time, if R is less than 5%, then it is assumed that corresponding previous self-priming time is the best self-priming water drive oil time.
Further, in the step 1, reach formation water salinity for 25000mg/L.
Further, in the step 3, self-priming flood pot test is：Core holding unit rock core being placed in insulating box
Interior, rock core both ends persistently inject simulated formation water with the extremely low speed of 0.01ml/min and carry out self-priming flood pot test, are set in
At a temperature of 10~70 DEG C, the rock core self-priming water drive oil time is more than 24 hours, and ring pressure is between 0.1MPa~25MPa.
Further, in the step 6, according to formula (1) reference area difference：
Δ S=Si+1-Si (1)
In formula：Δ S is the T that i+1 time is obtained with ith2Spectrum and X-axis surround the area difference；
SiThe T obtained for ith2Spectrum and X-axis surround the area；
Si+1The T obtained for i+1 time2Spectrum and X-axis surround the area.
Further, in the step 7, T is determined according to the following formula2Spectrum and X-axis surround the area increment rate R：
In formula, R T2Spectrum and X-axis surround the area increment rate.
Compared with prior art, the present invention has the following advantages：
(1) for shale oil nanoaperture development degree height, conventional flat well body, which overstocks cleft hand section and is difficult to effective exploitation, to be received
In metre hole gap the characteristics of crude oil, based on the basic principle of capillary imbibition effect, novelty proposes to utilize capillary imbibition water drive
The thought of oil, and propose the method for determining best self-priming time, in order to which Absorb Water oil displacement efficiency under normal temperature and pressure is overcome to be difficult to instead
The shortcomings that reflecting reservoir condition gradually changes temperature and ring pressure in experimentation, comes during evaluation time, temperature, pressure change
Absorb Water oil displacement efficiency, and determine the best self-priming water drive oil time, to realize the effective exploitation of shale oil nanoaperture crude oil.
(2) it is difficult to realize quantitative assessment for traditional self-priming oil displacement experiment method, can not reflect self-priming in different aperture
The shortcomings that water drive oil effect, using nuclear magnetic resonance technique, is improved by experimental method, and foring can quantitative assessment difference self-priming
Time oil displacement efficiency, and the method that can intuitively compare different aperture self-priming water drive oil feature difference.
Description of the drawings
Fig. 1 Absorb Water oil displacement process schematic diagrames；
Fig. 2 is the nuclear magnetic resonance T of the different self-priming water drive oil times of embodiment 12Spectrogram；
Fig. 3 is the nuclear magnetic resonance T of the different self-priming water drive oil times of embodiment 22Spectrogram.
Specific embodiment
The invention will be described in further detail with reference to the accompanying drawings and examples, but is not intended as doing any limit to invention
The foundation of system.
Certain oil field sample combination attached drawing is chosen below to be described in detail the present invention.
Embodiment 1
It is a kind of evaluate shale oil reservoir Absorb Water oil displacement efficiency and determine the best self-priming water drive oil time method include with
Lower step：
Step 1: configuration experiment simulated formation water, reaches formation water salinity for 25000mg/L；
Step 2: rock core is placed in high pressure saturation device, its saturation is made to be free of the fluorocarbon oil of proton, survey nuclear magnetic resonance T2
Spectrum, statistics nuclear magnetic resonance T2Spectrum is 764.71 with the area that X-axis is surrounded；
Step 3: rock core is placed in the core holding unit in insulating box, rock core both ends are with the extremely low speed of 0.01ml/min
Persistently injection simulated formation water carries out self-priming flood pot test to degree, and experimental temperature is 40 DEG C, and ring is pressed as 5MPa, self-priming water drive oil 24
Nuclear magnetic resonance T is surveyed after hour2Spectrum, statistics nuclear magnetic resonance T2Spectrum is 913.32 with the area that X-axis is surrounded；
Step 4: repeating step 3, rock core difference self-priming water drive oil 48 hours, 72 hours, 96 hours, self-priming water drive oil is not
After the period, nuclear magnetic resonance T is surveyed after each2Spectrum, statistics nuclear magnetic resonance T2Composing the area surrounded with X-axis is respectively
936.53、946.03、949.95；
Step 5: by nuclear magnetic resonance T2Spectrum is plotted on same figure, and as shown in Figure 2, comparison finds self-priming water drive oil 24
The T of hour2Compose that amplitude of variation is maximum, self-priming water drive oil 48 hours, 72 hours, the T of 96 hours2Amplitude of variation is composed to reduce；
Step 6: the T that will be obtained under the different self-priming water drive oil times2Spectrum and X-axis surround the area and the preceding T once obtained2Spectrum
It is compared with X-axis surround the area, according to formula (1), reference area difference is respectively 148.61,23.21,9.5,3.92；
Δ S=Si+1-Si (1)
Step 7: according to Δ S, R is determined according to formula (2), it is known that self-priming water drive oil 24 hours, 48 hours, 72 hours, it is 96 small
When R be respectively 19.43%, 2.54%, 1.01%, 0.41%, thereby determine that the best self-priming water drive oil time be 24 hours.
Embodiment 2
It is a kind of evaluate shale oil reservoir Absorb Water oil displacement efficiency and determine the best self-priming water drive oil time method include with
Lower step：
Step 1: configuration experiment simulated formation water, reaches formation water salinity for 25000mg/L；
Step 2: rock core is placed in high pressure saturation device, its saturation is made to be free of the fluorocarbon oil of proton, survey nuclear magnetic resonance T2
Spectrum, statistics nuclear magnetic resonance T2Spectrum is 370.15 with the area that X-axis is surrounded；
Step 3: rock core is placed in the core holding unit in insulating box, rock core both ends are with the extremely low speed of 0.01ml/min
Persistently injection simulated formation water carries out self-priming flood pot test to degree, and experimental temperature is 10 DEG C, and ring is pressed as 25MPa, self-priming water drive oil
Nuclear magnetic resonance T is surveyed after 24 hours2Spectrum, statistics nuclear magnetic resonance T2Spectrum is 434.56 with the area that X-axis is surrounded；
Step 4: repeating step 3, rock core difference self-priming water drive oil 48 hours, 72 hours, 96 hours, self-priming water drive oil is not
After the period, nuclear magnetic resonance T is surveyed after each2Spectrum, statistics nuclear magnetic resonance T2Composing the area surrounded with X-axis is respectively
449.33、463.16、474.94；
Step 5: by nuclear magnetic resonance T2Spectrum is plotted on same figure, as shown in Figure 3, the existing self-priming water drive oil of comparison distribution
The T of 24 hours2Compose that amplitude of variation is maximum, self-priming water drive oil 48 hours, 72 hours, the T of 96 hours2Amplitude of variation is composed to reduce；
Step 6: the T that will be obtained under the different self-priming water drive oil times2Spectrum and X-axis surround the area and the preceding T once obtained2Spectrum
It is compared with X-axis surround the area, according to formula (1), reference area difference is respectively 64.41,14.77,13.83,11.78.
Δ S=Si+1-Si (1)
Step 7: according to Δ S, R is determined according to formula (2), it is known that self-priming water drive oil 24 hours, 48 hours, 72 hours, it is 96 small
When R be respectively 17.40%, 3.40%, 3.08%, 2.54%, thereby determine that the best self-priming water drive oil time be 24 hours.
Embodiment 3
Step 1: configuration experiment simulated formation water, reaches formation water salinity for 25000mg/L；
Step 2: rock core is placed in high pressure saturation device, its saturation is made to be free of the fluorocarbon oil of proton, survey nuclear magnetic resonance T2
Spectrum, statistics nuclear magnetic resonance T2Spectrum is 365.64 with the area that X-axis is surrounded；
Step 3: rock core is placed in the core holding unit in insulating box, rock core both ends are with the extremely low speed of 0.01ml/min
Persistently injection simulated formation water carries out self-priming flood pot test to degree, and experimental temperature is 70 DEG C, and ring power is 0.1Mpa, self-priming water drive oil
Nuclear magnetic resonance T is surveyed after 24 hours2Spectrum, statistics nuclear magnetic resonance T2Spectrum is 453.22 with the area that X-axis is surrounded；
Step 4: repeating step 3, rock core difference self-priming water drive oil 48 hours, 72 hours, 96 hours, self-priming water drive oil is not
After the period, nuclear magnetic resonance T is surveyed after each2Spectrum, statistics nuclear magnetic resonance T2Composing the area surrounded with X-axis is respectively
485.23、502.86、510.65；
Step 5: by nuclear magnetic resonance T2Spectrum is plotted on same figure, as shown in Figure 3, the existing self-priming water drive oil of comparison distribution
The T of 24 hours2Compose that amplitude of variation is maximum, self-priming water drive oil 48 hours, 72 hours, the T of 96 hours2Amplitude of variation is composed to reduce；
Step 6: the T that will be obtained under the different self-priming water drive oil times2Spectrum and X-axis surround the area and the preceding T once obtained2Spectrum
It is compared with X-axis surround the area, according to formula (1), reference area difference is respectively 87.58,32.01,17.63,7.79.
Δ S=Si+1-Si (1)
Step 7: according to Δ S, R is determined according to formula (2), it is known that self-priming water drive oil 24 hours, 48 hours, 72 hours, it is 96 small
When R be respectively 23.95%, 7.06%, 3.63%, 1.55%, thereby determine that the best self-priming water drive oil time be 48 hours.
The principle explanation of experimental method
Shale oil nanoaperture is developed, and horizontal well volume fracturing is current main development scheme, is produced by volume fracturing
Crack is given birth to link up pore network, the hypertonic channel of crude oil flow is provided.But the crack quantity that volume fracturing generates is limited
, all nanoapertures can not be linked up, for the nanoaperture do not linked up by crack, how to realize that crude oil development just seems
It is particularly important.From the angle of reservoir physics, for hydrophilic porous medium, capillary force is the power of the displacement of reservoir oil, and hole
Radius is smaller, and capillary force is bigger.Based on this thought, the nanoaperture of shale oil is developed, capillary imbibition aquatic products
Raw displacement power is big, crude oil that can be in effective displacement nanoaperture, and then realizes the effective exploitation of shale oil.In order to compare
The influence of reservoir temperature and pressure to Absorb Water oil displacement efficiency, tests and is carried out in insulating box, changes rock core folder in experimentation
Holder ring pressure.
Rock core is placed in the core holding unit in insulating box by this method, by set extremely low speed, certain temperature and
Ring pressure holding, which continues, injects the development self-priming flood pot test of simulated formation water, and the injection rate of simulated formation water is extremely low in experimentation,
The rock core for being equivalent to saturation fluorocarbon oil is immersed in simulated formation water, effectively simulates self-priming flood pot test process.During experiment, mould
Displacement crude oil (Fig. 1) in tiny hole can be entered under the effect of the self-priming of capillary force by intending water flooding, as self-priming time increases,
The crude oil amount of displacement can also change therewith, so as to achieve the purpose that carry out shale oil exploitation using capillary imbibition principle.
And in-place oil is replaced to be free of the fluorocarbon oil of proton in experimentation, the nuclear magnetic resonance T measured2Spectrum signal is main
The variation of simulated formation water in rock core is reflected, according to nuclear magnetic resonance T in displacement process2The size that spectrum is surrounded with X-axis, can
To reflect the water entered in nanoaperture, also reflect by the crude oil amount of displacement, can be determined most preferably according to the variation of area
The self-priming water drive oil time.
The above content is a further detailed description of the present invention in conjunction with specific preferred embodiments, it is impossible to assert
The specific embodiment of the present invention is only limitted to this, for those of ordinary skill in the art to which the present invention belongs, is not taking off
Under the premise of from present inventive concept, several simple deduction or replace can also be made, should all be considered as belonging to the present invention by institute
Claims of submission determine scope of patent protection.
Claims (4)
1. a kind of evaluation shale oil reservoir Absorb Water oil displacement efficiency and the method for displacement of reservoir oil time, which is characterized in that including following steps
Suddenly：
Step 1: configuration experiment simulated formation water, reaches formation water salinity；
Step 2: rock core is placed in high pressure saturation device, its saturation is made to be free of the fluorocarbon oil of proton, survey nuclear magnetic resonance T2Spectrum, statistics
Nuclear magnetic resonance T2The area that spectrum is surrounded with X-axis；
Step 3: rock core is placed in the core holding unit in insulating box, simulation ground is persistently injected at rock core both ends with extremely low speed
Layer water carries out self-priming flood pot test, changes temperature and ring pressure, self-priming water drive oil survey nuclear magnetic resonance T after 24 hours2Spectrum counts core
Magnetic resonance T2The area that spectrum is surrounded with X-axis；
Specially：
Rock core is placed in the core holding unit in insulating box, mould is persistently injected in rock core both ends with the extremely low speed of 0.01ml/min
To intend water flooding and carry out self-priming flood pot test, be set at a temperature of 10~70 DEG C, the rock core self-priming water drive oil time is more than 24 hours,
Ring power is between 0.1MPa~25MPa；
Step 4: repeating step 3, self-priming water drive oil 48 hours, 72 hours, 96 hours surveys self-priming water drive oil different time respectively
Rock core nuclear magnetic resonance T after section2Spectrum, statistics nuclear magnetic resonance T2The area that spectrum is surrounded with X-axis；
Step 5: the nuclear magnetic resonance T that step 2 is measured2Spectrum and Step 3: four rock cores difference self-priming water drive oil different time sections survey
The nuclear magnetic resonance T obtained2Spectrum is plotted on same figure, the T under the conditions of comparative analysis difference self-priming time2Spectrum variation；
Step 6: the T that will be obtained under the different self-priming water drive oil times2Spectrum and X-axis surround the area and the preceding T once obtained2Spectrum and X
Axis surround the area is compared, reference area difference；
Step 7: according to area difference DELTA S, T is determined2Spectrum and X-axis surround the area increment rate R, obtain shale oil reservoir self-priming water drive
The oily time, if R is less than 5%, then it is assumed that corresponding previous self-priming time is the best self-priming water drive oil time.
2. evaluation shale oil reservoir Absorb Water oil displacement efficiency according to claim 1 and the method for displacement of reservoir oil time, feature
It is, in the step 1, reaches formation water salinity for 25000mg/L.
3. evaluation shale oil reservoir Absorb Water oil displacement efficiency according to claim 1 and the method for displacement of reservoir oil time, feature
It is, in the step 6, according to formula (1) reference area difference：
Δ S=Si+1-Si (1)
In formula：Δ S is the T that i+1 time is obtained with ith2Spectrum and X-axis surround the area difference；
SiThe T obtained for ith2Spectrum and X-axis surround the area；
Si+1The T obtained for i+1 time2Spectrum and X-axis surround the area.
4. evaluation shale oil reservoir Absorb Water oil displacement efficiency according to claim 3 and the method for displacement of reservoir oil time, feature
It is, in the step 7, determines T according to the following formula2Spectrum and X-axis surround the area increment rate R：
In formula, R T2Spectrum and X-axis surround the area increment rate.
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