CN104594888A - Oil layer identification method based on tight reservoir conductivity factor experiment - Google Patents
Oil layer identification method based on tight reservoir conductivity factor experiment Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 75
- 238000002474 experimental method Methods 0.000 title claims abstract description 64
- 239000011435 rock Substances 0.000 claims abstract description 118
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 51
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 48
- 238000005259 measurement Methods 0.000 claims abstract description 31
- 239000011148 porous material Substances 0.000 claims abstract description 28
- 238000005481 NMR spectroscopy Methods 0.000 claims abstract description 21
- 230000035699 permeability Effects 0.000 claims abstract description 15
- 238000004422 calculation algorithm Methods 0.000 claims abstract description 12
- 238000001228 spectrum Methods 0.000 claims abstract description 12
- 238000004458 analytical method Methods 0.000 claims abstract description 11
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical class O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims abstract description 5
- 238000005266 casting Methods 0.000 claims description 16
- 239000002734 clay mineral Substances 0.000 claims description 11
- 239000008398 formation water Substances 0.000 claims description 8
- 229920006395 saturated elastomer Polymers 0.000 claims description 8
- 238000013461 design Methods 0.000 claims description 6
- 150000003839 salts Chemical class 0.000 claims description 5
- 238000005553 drilling Methods 0.000 claims description 4
- 238000002441 X-ray diffraction Methods 0.000 abstract 1
- 239000007789 gas Substances 0.000 description 10
- 239000004927 clay Substances 0.000 description 6
- 238000010586 diagram Methods 0.000 description 4
- 238000011160 research Methods 0.000 description 4
- 239000004215 Carbon black (E152) Substances 0.000 description 3
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 239000012266 salt solution Substances 0.000 description 3
- 238000004364 calculation method Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- 230000000704 physical effect Effects 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- 230000011218 segmentation Effects 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 238000007405 data analysis Methods 0.000 description 1
- 238000009795 derivation Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000005684 electric field Effects 0.000 description 1
- 239000008187 granular material Substances 0.000 description 1
- 239000001307 helium Substances 0.000 description 1
- 229910052734 helium Inorganic materials 0.000 description 1
- SWQJXJOGLNCZEY-UHFFFAOYSA-N helium atom Chemical compound [He] SWQJXJOGLNCZEY-UHFFFAOYSA-N 0.000 description 1
- 125000001183 hydrocarbyl group Chemical group 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000011835 investigation Methods 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 230000005311 nuclear magnetism Effects 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 239000004575 stone Substances 0.000 description 1
- 230000001360 synchronised effect Effects 0.000 description 1
- 238000004457 water analysis Methods 0.000 description 1
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Abstract
The application provides an oil layer identification method based on tight reservoir conductivity factor experiments. The method comprises the following steps: s1: acquiring horizontal cores of different depths of a reservoir; s2: acquiring the porosity and permeability of the horizontal core, and calculating a quality index; s3: measuring the resistivity of the rock core and the resistivity of saturated brine to obtain formation factors; s4: performing nuclear magnetic resonance measurement to obtain a T2 spectrum, total porosity, effective porosity and irreducible water saturation; s5: performing X-ray diffraction and cast slice experiments; s6: according to the measurement and experiment results, establishing the correlation relationship between formation factors and the total porosity, effective porosity, pore throat size, distribution, connectivity and the like; s7: and determining an oil layer identification algorithm based on the established correlation relationship, and carrying out oil layer identification on the reservoir. By utilizing the embodiments of the application, the factors influencing the conductive capacity of the reservoir and the size of the factors can be analyzed according to experimental data of the tight reservoir, and the oil layer identification algorithm of the tight reservoir can be determined according to the analysis result.
Description
Technical field
The application belongs to petroleum exploration logging technical field, particularly relates to a kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment.
Background technology
The epoch that Petroleum Exploration in China enters " conventional gas and oil " develops simultaneously with " unconventionaloil pool ".The unconventionaloil pool being representative with fine and close oil gas becomes the Focal point and difficult point field of oil-gas exploration day by day.The conductive capability of correct understanding compact reservoir, research is set up to the oil-gas layer identification and the Reserve Estimation Method that are applicable to fine and close oil-gas reservoir, tool is of great significance.
The conductive capability of rock is usually relevant to the lithology, physical property, oil-gas possibility etc. of rock, can according to the conductive capability identification oil reservoir of rock, calculating hydrocarbon saturation etc.Because fine and close oil-gas exploration was just just risen in recent years, people for the experimental technique of electric conduction of rock ability, the level of understanding and further oil layer recognition technology also mainly rest on the conventional reservoir stage, lack be applicable to compact reservoir electric conduction of rock capacity experimental, analysis and further Identification Method of Oil.Be seen in diplomatic research report for this problem in prior art also very few, not having can for the experience using for reference reference.The existence of this bottleneck problem, well logging study personnel are known little about it for problems such as " what similarities and differences compact reservoir and conventional reservoir have on earth in electric conduction of rock ability ", Just because of this, how rock core sampled at the scene, need to carry out which supporting petrophysics experiment, how to carry out follow-up comprehensive analysis of experimental data, affect the key factor of compact reservoir conductive capability power comprise which etc. a series of content all urgently research and solve, the investigation and application of restriction compact reservoir hydrocarbon bearing distinguishing and oily method for quantitatively evaluating.
Summary of the invention
The application's object is to provide a kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment, based on affecting the factor of compact reservoir conductive capability on the interpretation of reservoir-level rock core and determining and affecting size, the Identification Method of Oil of compact reservoir can be set up.
A kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment that the application provides is achieved in that
Based on an Identification Method of Oil for compact reservoir conduction Factor Experiment, described method comprises:
S1: the horizontal rock core obtaining reservoir different depth;
S2: measure the porosity and permeability obtaining described horizontal rock core, and measure according to described the qualitative index that the porosity and permeability obtained calculates described reservoir;
S3: measure and obtain the rock core resistivity of described horizontal rock core under saturated brine condition and described saturated salt resistivity of water, using the ratio of described rock core resistivity and described saturated resistivity of water as the formation factor of described reservoir;
S4: Nuclear Magnetic Resonance Measurement is carried out to described horizontal rock core and obtains the nuclear magnetic resonance T 2 spectrum of described horizontal rock core, total porosity, effecive porosity and irreducible water saturation;
S5: X diffraction and casting body flake experiment are carried out to described horizontal rock core, obtains the information of clay mineral type contained by described horizontal rock core and content, Pore throat size and distribution and connectedness;
S6: according to the measurement described in S1 ~ S5 and experimental result, analyzes and sets up described formation factor and the correlative relationship comprising described total porosity, effecive porosity, irreducible water saturation, qualitative index, clay mineral type and content, Pore throat size and distribution and connectedness;
S7: based on the correlative relationship determination oil layer recognition algorithm of described foundation, according to described oil layer recognition algorithm, oil layer recognition is carried out to described reservoir.
In preferred embodiment, the described correlative relationship determination oil layer recognition algorithm based on described foundation, comprising:
The oil layer recognition plate that to set up with the ratio of formation resistivity characteristic value and formation water resistivity, stratum total porosity be coordinate, adopts following formula to calculate the boundary equation distinguishing oil, water:
In above formula, φ
tfor the total porosity (%) on stratum, C is the empirical being applicable to reservoir place survey area, F is the formation factor of experimentally data acquisition and the relation function formula of total porosity, A and B be experimentally data determine what meet described formation factor and total porosity distribution relation take total porosity as total porosity coefficient and the index of the truth of a matter.
A kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment that the application provides, based on the experiment analysis results of the horizontal rock core of reservoir different depth, represent that the conductive capability on stratum sets up the relation between formation factor and multiple factor affecting stratum conductive capability with formation factor, factor and the size thereof of reservoir conductive capability is affected according to actual survey area compact reservoir analysis of experimental data, and further according to the oil layer recognition algorithm of analysis result determination compact reservoir, identify the oil reservoir of described compact reservoir.
Accompanying drawing explanation
In order to be illustrated more clearly in the embodiment of the present application or technical scheme of the prior art, be briefly described to the accompanying drawing used required in embodiment or description of the prior art below, apparently, the accompanying drawing that the following describes is only some embodiments recorded in the application, for those of ordinary skill in the art, under the prerequisite not paying creative work, other accompanying drawing can also be obtained according to these accompanying drawings.
Fig. 1 is the method flow schematic diagram of a kind of embodiment of a kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment of the application;
Fig. 2 is the casting body flake measurement result schematic diagram of an embodiment in method described in the application;
Fig. 3 is the formation factor of an embodiment and the graph of a relation of total porosity in method described in the application;
Fig. 4 is the formation factor of an embodiment and the graph of a relation of effecive porosity in method described in the application;
Fig. 5 is the formation factor of an embodiment in method described in the application and the graph of a relation of reservoir qualitative index;
Fig. 6 is the formation factor of an embodiment and the graph of a relation of irreducible water saturation in method described in the application;
Fig. 7 is the nuclear magnetic resonance T 2 spectrum figure of the close sample of total porosity of an embodiment in method described in the application;
Fig. 8 is the casting body flake measurement result figure of the close sample of total porosity of an embodiment in method described in the application;
Fig. 9 is the new plate of oil layer recognition of an embodiment in method described in the application;
Figure 10 is traditional oil layer recognition plate of an embodiment in method described in the application.
Detailed description of the invention
Technical scheme in the application is understood better in order to make those skilled in the art person, below in conjunction with the accompanying drawing in the embodiment of the present application, technical scheme in the embodiment of the present application is clearly and completely described, obviously, described embodiment is only some embodiments of the present application, instead of whole embodiments.Based on the embodiment in the application, those of ordinary skill in the art are not making the every other embodiment obtained under creative work prerequisite, all should belong to the scope of the application's protection.
In reservoir, the conductive capability of rock typically refers to the ability of rock conductive electric current in the electric field, by resistivity or electrical conductivity or can weigh according to the formation factor value that resistivity obtains.The conductive capability of rock is usually relevant to the lithology, physical property, oil-gas possibility etc. of rock, can according to the conductive capability identification oil reservoir of rock, calculating hydrocarbon saturation etc.Affect a lot of because have of reservoir conductive capability, the application provides a kind of experimental technique based on analyzing influence reservoir-level rock core conductive capability factor to analyze and research affects the factor of reservoir conduction, and then sets up suitable Identification Method of Oil according to actual experiment result.
Fig. 1 is the method flow diagram of a kind of Identification Method of Oil embodiment based on compact reservoir conduction Factor Experiment that the application provides.As shown in Figure 1, described a kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment can comprise:
S1: the horizontal rock core obtaining reservoir different depth.
In the present embodiment, can require rationally to arrange to choose the depth interval of described horizontal rock core and the size of described horizontal rock core according to exploration demand and experimental precision.Usually, for ensureing the certainty of measurement of follow-up X diffraction and casting body flake experiment, the horizontal rock core weight of described acquisition needs to reach certain requirement.Meanwhile, in order to synchronous experiment, accelerate experiment progress, coordinate relevant experiments supporting, reducing the error that same level rock core brings because participating in different experiments, certain designing requirement can be had to the horizontal rock core drilled through.A kind of trephination obtaining described horizontal rock core can be provided in the present embodiment, specifically can comprise:
S101: drill through the little rock core that two block lengths are L, diameter is R in the horizontal direction at same depth of reservoirs point D1 place;
S102: by two blocks of little rock cores drilling through at described D1 place wherein one piece of cutting be two pieces, ensure that wherein a block length is 5 centimetres, diameter is 2.5 centimetres;
S103: the two blocks of little rock cores drilling through reservoir different depth point Dn place according to the method for S101, S102, and by two little rock cores at described Dn place wherein one piece be divided into two pieces, ensure that wherein a block length is 5 centimetres, diameter is 2.5 centimetres.
In preferred embodiment, described in the span of the length L of two blocks of little rock cores at different depth point Dn place that drills through can be 8 centimetres≤L≤10 centimetre.Concrete drill through processing procedure and can comprise:
Near same depth point D1, drill through two block length 8-10cm in the horizontal direction, little rock core A1 and B1 that diameter is 2.5cm.To wherein cut in half along circular cross-section direction by one piece little rock core A1, ensure that wherein a little block length is 5cm, diameter is 2.5cm, is designated as A1
1, remain one piece and be designated as A1
2.In like manner, near the D2 of depth point, drill through little rock core A2 and B2 that two pieces of diameters are 2.5cm, length 8-10cm in the horizontal direction, A2 is cut in half along circular cross-section direction, is designated as A2 respectively
1and A2
2, ensure A2
1length be 5cm, diameter is 2.5cm.The rest may be inferred, drills through little rock core An and Bn that two pieces of diameters are 2.5cm, length is 8-10cm in the horizontal direction, carry out cutting processing, break it into two, be designated as An respectively to An by preceding method near the Dn of depth point
1and An
2, wherein An
1length be about 5cm, diameter is 2.5cm.
S2: measure the porosity and permeability obtaining described horizontal rock core, and measure according to described the qualitative index that the porosity and permeability obtained calculates described reservoir.
In application example as escribed above, can to the horizontal rock core A1 obtained by the first step
1, A2
1..., An
1carry out porosity and permeability measurement.Porosity measurement can adopt helium injection method, and specific operation process can with reference to industry standard SY/T5336-2006, and permeability survey can adopt rock core plunger drop of pressure method, and concrete operating process can with reference to industry standard SY/T 5336-2006.The design formulas of the qualitative index RQI of reservoir is as follows:
In above formula, k is permeability, and unit is 10
-3μm
2, φ is degree of porosity, and adopt fractional representation mode, the unit of the qualitative index RQI of reservoir is 0.0314 μm.Reservoir qualitative index and average throat radius have good positive correlation, are to evaluate the important indicator that RESERVOIR PORE STRUCTURE is good and bad, analyze reservoir conductive capability.
S3: measure and obtain the rock core resistivity of described horizontal rock core under saturated brine condition and described saturated salt resistivity of water, using the ratio of described rock core resistivity and described saturated resistivity of water as the formation factor of described reservoir.
Can to described horizontal rock core A1
1, A2
1..., An
1carry out the resistivity measurement under saturated brine condition.According to type and the salinity of the formation water of described rock core place target zone, configuration salt solution, carries out resistivity measurement to the salt solution prepared, then by described rock core A1
1, A2
1..., An
1immerse carry out in the salt solution that configures saturated after measure its resistivity, measuring method can with reference to industry standard SYT5385-2007.According to measuring the rock core resistivity that obtains, calculating the ratio of itself and salt resistivity of water, obtaining formation factor.
S4: Nuclear Magnetic Resonance Measurement is carried out to described horizontal rock core and obtains the nuclear magnetic resonance T 2 spectrum of described horizontal rock core, total porosity, effecive porosity and irreducible water saturation.
To described horizontal rock core A1
1, A2
1..., An
1carry out Nuclear Magnetic Resonance Measurement.Nuclear magnetic resonance measuring method can with reference to industry standard SY/T6490-2007.By measuring rock core nuclear magnetic resonance T 2 spectrum, total porosity, effecive porosity and irreducible water saturation when obtaining saturation water.Immobile water all containing some in any oil and gas reservoir, i.e. " irreducible water " or " residual water " of usual indication.Irreducible water mainly contains the hollow billet backwater etc. in the film backwater on water-wet rock stone granulate surface and fine hollow billet duct, and corresponding saturation ratio is called irreducible water saturation.The conductive capability of described irreducible water saturation on rock core has very important impact, therefore, is obtained outside T2 spectrum, degree of porosity, also need this parameter of irreducible water saturation obtaining described horizontal rock core in the present embodiment by Nuclear Magnetic Resonance Measurement.
In the mode of another kind of embodiment, the horizontal rock core quantity of described acquisition is more, described method can also comprise classifies to described horizontal rock core according to the pore structure of rock core, and rock core pore structure is divided into four classes by concrete " the three hole component percentages methods " sorting technique described in (ZL201010218652.4) that such as can adopt.Simultaneous observation can be carried out by the horizontal rock core close to pore structure like this, improve conventional efficient.
S5: X diffraction and casting body flake experiment are carried out to described horizontal rock core, obtains the information of clay mineral type contained by described horizontal rock core and content, Pore throat size and distribution and connectedness.
X diffraction and casting body flake experiment can be carried out to the horizontal rock core after above-mentioned measurement and experiment in the present embodiment, obtain the information of clay mineral type contained by described horizontal rock core and content, Pore throat size and distribution and connectedness.According to two blocks of little rock cores of level of aforementioned acquisition, for reducing the horizontal rock core of experiments of measuring to the impact of subsequent experimental, saving time, ensureing the reliability of experimental result, preferred embodiment, can to the level obtained by S1 little rock core A1
2+ B1, A2
2+ B2, A3
2+ B3 ..., An
2+ Bn carries out X diffraction and casting body flake experiment.What X diffraction experiment method was concrete can with reference to industry standard SY/T5163-2010.
One piece remaining after choosing the segmentation of described little rock core in the present embodiment to merge with the little rock core of another block together with carry out X diffraction and casting body flake is tested, it is the quality in order to increase experiment rock core, meet requirement of experiment, particularly ensure the clay combining by X diffraction experiment, to understand clay type and the content of this depth point, the precision of experiment measuring can be improved.
Casting body flake experiment synchronously can be carried out with X diffraction experiment, and specific experiment operating process can with reference to industry standard SY/T5913-2004.
S6: according to the measurement described in S1 ~ S5 and experimental result, analyzes and sets up described formation factor and the correlative relationship comprising described total porosity, effecive porosity, irreducible water saturation, qualitative index, clay mineral type and content, Pore throat size and distribution and connectedness.
Concrete described formation factor and the correlative relationship of total porosity, effecive porosity etc. can adopt the graph of a relation making formation factor and the influence factor such as total porosity, effecive porosity respectively.The coordinate system of described formation factor and other influences factor can be set up respectively, in described coordinate system, embody above-mentioned measurement and experimental result data, thus more vivid, present and help to analyze the relation that formation factor and other influences affect intuitively.
From the first inertial concerns of the formation factor of described foundation and total porosity, effecive porosity, irreducible water saturation, qualitative index, clay mineral type and content, Pore throat size and distribution and connectedness etc., the factor of analyzing influence survey area compact reservoir rock core conductive capability and affect size etc., can sum up law characteristic or the inner link of survey area different depth or same degree of depth conductive capability further, the described law characteristic that can draw based on analysis or inner link set up corresponding design formulas.
In another kind of embodiment, when analyzing the correlative relationship of formation factor and other influences factor, the horizontal rock core group only can choosing total porosity close is analyzed.Such as can choose the horizontal core sample data analysis of total porosity relative error in 10% scope, therefore, in another kind of embodiment, the described correlative relationship set up according to the measurement described in S1 ~ S5 and experimental result comprises sets up described correlative relationship according to the experimental data of the horizontal rock core of described total porosity within the scope of preset error.
S7: based on the correlative relationship determination oil layer recognition algorithm of described foundation, according to described oil layer recognition algorithm, oil layer recognition is carried out to described reservoir.
Analysis obtain survey area formation factor and described comprise the correlative relationship of described total porosity, effecive porosity, irreducible water saturation, qualitative index, clay mineral type and content, Pore throat size and distribution and connectedness after, the recognizer of this region oil reservoir can be determined, according to described oil layer recognition algorithm identification oil reservoir based on the correlative relationship of described foundation.Described correlative relationship can comprise based at least one in the design formulas realizing summing up, setting up to above-mentioned steps, parameter value scope, parameter value.
A kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment of the application, provide and a set ofly how to carry out the compact reservoir conduction method step of Factor Experiment and the treatment and analysis method to data, determine to affect the key factor of compact reservoir conductive capability according to the experimental result of survey area on the spot and affect size, determining the recognition methods of oil reservoir further.Based on the Identification Method of Oil that the application's actual experiment result data is determined, can identify oil reservoir more accurately, for underground oil and gas exploitation and qualitative assessment are laid a good foundation.
It should be noted that, a kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment described in the application goes for conduction experiment and the oil layer recognition of the horizontal rock core of compact reservoir, although also may be used for conventional oil reservoir and other are not mentioned but still be suitable for the reservoir area of the application's method.
Here is the application example utilizing a kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment described in the application, and the implementation process of the application's method can be described clearly, intuitively.
Drill through horizontal rock core at survey area different depth, same depth point place drills through two blocks of little rock cores of level, forms one group.Drill through altogether 16 groups of rock cores, be designated as A1, B1 respectively, A2, B2 ..., A16, B16.The diameter of the horizontal rock core of each block is 2.5cm, and length is 10cm.Respectively to A1, A2, A3 ..., A16 cuts, and cut surface is parallel with plunger sample bottom surface, and the position of cut point should ensure that a wherein block length of cutting in rear two blocks of rock cores is 5cm, and the rock core meeting this condition after cutting is designated as A1 respectively
1, A2
1..., A16
1, residue rock core is designated as A1 respectively
2, A2
2..., A16
2.
To A1
1, A2
1..., A16
1carry out porosity and permeability measurement, calculate the qualitative index of reservoir.
The qualitative index result of calculation of degree of porosity, permeability survey result and reservoir is in table 1.
Table 1 physical parameter measurement and calculation result
According to the formation water analysis of data on stratum, rock core place, configuration salinity be the equivalent N aCl solution of 12000ppm as practice ground layer water, its resistivity R when 25 degrees Celsius
wbe 0.435 ohm meter, the core resistivity measuring result Ro after saturated this kind of solution of horizontal rock core and with salt resistivity of water R
wratio (formation factor F) as shown in table 2.
Table 2 rock electrical measurements
To the horizontal rock core A1 of segmentation
1, A2
1..., A16
1carry out Nuclear Magnetic Resonance Measurement, obtain nuclear magnetic resonance T 2 spectrum, nuclear-magnetism total porosity, effecive porosity and Pore structure during saturation water.Nuclear magnetic resonance measuring method is with reference to industry standard SY/T6490-2007.By measuring rock core nuclear magnetic resonance T 2 spectrum when obtaining saturation water, the total porosity of nuclear magnetic resonance, effecive porosity and irreducible water saturation.Total porosity, effecive porosity and irreducible water saturation result are as shown in table 3.
Table 3 Nuclear Magnetic Resonance Measurement result
| Sample number into spectrum | Total porosity (%) | Effecive porosity (%) | Irreducible water saturation (%) |
| 1 | 15.00 | 15.00 | 9.18 |
| 2 | 17.10 | 17.03 | 13.09 |
| 3 | 16.20 | 16.22 | 11.36 |
| 4 | 16.60 | 16.60 | 10.53 |
| 5 | 20.50 | 20.06 | 34.88 |
| 6 | 14.90 | 14.75 | 18.20 |
| 7 | 20.10 | 19.65 | 38.57 |
| 8 | 19.30 | 18.63 | 37.55 |
| 9 | 16.30 | 15.00 | 44.75 |
| 10 | 12.90 | 12.08 | 45.76 |
| 11 | 16.60 | 15.50 | 42.92 |
| 12 | 13.60 | 12.89 | 46.04 |
| 13 | 14.60 | 11.41 | 50.55 |
| 14 | 14.20 | 11.67 | 53.16 |
| 15 | 7.40 | 5.27 | 44.89 |
| 16 | 6.10 | 8.92 | 59.17 |
To A1
2+ B1, A2
2+ B2, A3
2+ B3 ..., A16
2+ B16 carries out X diffraction and casting body flake experiment.
The main purpose of X diffraction experiment understands rock clay mineral component type and content, and measurement result is as shown in table 4.Casting body flake measurement result schematic diagram as shown in Figure 2.In Fig. 2, white portion represents hole and venturi, and black part represents rock matrix.
Table 4 X diffraction measurements
Experimentally result, make the graph of a relation of formation factor and total porosity, effecive porosity, reservoir qualitative index and irreducible water saturation respectively, design formulas shown in figure is that experimentally result data calculates the formula formulated, and can certainly arrange other design formulas or empirical formula according to demand.Result is as shown in Fig. 3, Fig. 4, Fig. 5 and Fig. 6, Fig. 3 is the formation factor of an embodiment in method described in the application and the graph of a relation (abscissa is logarithmic scale) of total porosity, Fig. 4 is the formation factor of an embodiment and the graph of a relation of effecive porosity in method described in the application, Fig. 5 is the formation factor of an embodiment in method described in the application and the graph of a relation of reservoir qualitative index, and Fig. 6 is the formation factor of an embodiment and the graph of a relation of irreducible water saturation in method described in the application.Formula in Fig. 3, Fig. 4 is the functional expression meeting the overall mathematical relationship of experimental data of experimentally data derivation, simulation, in different survey area, different experiments, its formula can not be identical, even there is very large difference, this is also that the application can set up with experimental data the reliability and validity place that identify oil reservoir method.
In the present embodiment can by Sample selection close for total porosity out, fully utilize the supporting petrophysics experiment result of these samples, analyze the internal relation of formation factor and irreducible water saturation, clay content, Pore throat size and distribution, pore throat connectedness etc.
The experiments supporting measurement result meeting the sample of degree of porosity similar conditions is as shown in table 5.Table 5 illustrates, the sample that degree of porosity is close, and irreducible water saturation difference is obvious, and formation factor is close.The nuclear magnetic resonance T 2 spectrum of these samples and casting body flake feature are as shown in Figure 7, Figure 8, the casting body flake measurement result figure of Fig. 7 to be the nuclear magnetic resonance T 2 spectrum figure of the close sample of total porosity of an embodiment in method described in the application, Fig. 8 be close sample of degree of porosity of an embodiment in method described in the application.These two figure show, the sample that these degree of porosity are close, permeability contrast is obvious, formation factor is close, pore structure difference is fairly obvious, in pore system, one class is based on large scale hole (No. 2 samples), and a class is based on small size hole (No. 9 and No. 11 samples).Can also see from casting body flake, although the pore throat size of this two classes sample exists notable difference, the connectedness of pore throat is all very good.The clay mineral type of these samples and content are as shown in X diffraction patterns in table 4, and table 4 can illustrate, the clay content of these samples is all relatively less (absolute content is less than 3%), can ignore the impact of electric conduction of rock ability.
The experiments supporting result of the close sample of table 5 degree of porosity
Comprehensive analysis Fig. 2 ~ Fig. 8, table 1 ~ table 5, can be summarized as follows the conductive capability of rock when 100% is moisture involved in this example:
(1) there is the strongest correlation (power function relationship) between formation factor and total porosity, also have certain correlation (logarithmic function relation) with effecive porosity, but correlation is not as the former; Obvious correlation is not had between the qualitative index of formation factor and reservoir and irreducible water saturation;
(2), under the condition that total porosity is close, the tight rock sample that irreducible water saturation is high, permeability is low, pore structure is poor can have close conductive capability by low with irreducible water saturation, that permeability is high, pore structure is good sample; X diffraction patterns shows, clay type and the content of these samples are close, also close on the impact of electric conduction of rock ability, and because clay content is less, therefore it is also more weak on the impact of electric conduction of rock ability;
(3) nuclear magnetic resonance and casting body flake result show, although these sample pore throat size differences are obvious, but pore throat is all interspersed in netted, better connective, for the transport of conductive ion all provides good channel condition, this is that core sample total porosity is close, RESERVOIR PORE STRUCTURE difference obviously but the close key reason of formation factor.
In the present embodiment, with the ratio of formation resistivity characteristic value and formation water resistivity for ordinate, with stratum total porosity for abscissa (linear graduation), oil-water layer identification plate is set up, as shown in Figure 9.Formation resistivity characteristic value and formation water resistivity can be the formation resistivity and formation water resistivity that obtain according to the well-log information gathered.
Above-mentioned experimental result shows, formation factor (rock complete moisture time formation resistivity and the ratio of formation water resistivity) with total porosity, there is best functional relation, in the survey area of this experiment, as long as total porosity is close, the rock core that bound water content is high can have identical conductive capability with the rock core of low bound water content, so in identification plate, we are with formation factor F and total porosity φ
tfunctional relation (formula in Fig. 3) based on, be multiplied by suitable constant, just can be set up the boundary line equation effectively can distinguishing oil, water layer, when data point is positioned on boundary line, reservoir is considered as oil reservoir, and then realizes identification and the division of oil reservoir.Described boundary line equation form is as follows:
In equation, φ
tfor the total porosity (%) on stratum, C is the empirical being applicable to survey area, through too much regional many experiments in the application, the span that C is suitable for is 1.9 ~ 6.3, in this example, value is 2.8, F is the formation factor of experimentally data acquisition and the relation function formula of total porosity, A and B be experimentally data determine what meet described formation factor and total porosity distribution relation (such as Fig. 3) take total porosity as total porosity coefficient and the index of the truth of a matter, such as the present embodiment coefficient A meeting Fig. 3 formation factor and total pore space relation that experimentally data obtain is 603.72, index B is-1.1382.In Fig. 9, dotted line is oil, the water layer boundary line in this example.
And if adopt traditional recognition methods, namely set up the figure that crosses of formation resistivity and interval transit time to identify oil reservoir, then poor effect, as shown in Figure 10, oil reservoir and water layer mix, and are difficult to effective identification.
Each embodiment in this manual adopts the mode of going forward one by one to describe, between each embodiment identical similar part mutually see, what each embodiment stressed is the difference with other embodiments.
A kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment described in the application goes for conduction experiment and the oil layer recognition of the horizontal rock core of compact reservoir, although also may be used for conventional oil reservoir and other are not mentioned but still be suitable for the reservoir area of the application's method.The identical object of the application can be realized for relating in the application but all should belong in the application's scope required for protection without the need to the amendment of creationary experiment condition, change and distortion etc.
Although depict the application by embodiment, those of ordinary skill in the art know, the application has many distortion and change and do not depart from the spirit of the application, and the claim appended by wishing comprises these distortion and change and do not depart from the spirit of the application.
Claims (9)
1., based on an Identification Method of Oil for compact reservoir conduction Factor Experiment, it is characterized in that, described method comprises:
S1: the horizontal rock core obtaining reservoir different depth;
S2: measure the porosity and permeability obtaining described horizontal rock core, and measure according to described the qualitative index that the porosity and permeability obtained calculates described reservoir;
S3: measure and obtain the rock core resistivity of described horizontal rock core under saturated brine condition and described saturated salt resistivity of water, using the ratio of described rock core resistivity and described saturated resistivity of water as the formation factor of described reservoir;
S4: Nuclear Magnetic Resonance Measurement is carried out to described horizontal rock core and obtains the nuclear magnetic resonance T 2 spectrum of described horizontal rock core, total porosity, effecive porosity and irreducible water saturation;
S5: X diffraction and casting body flake experiment are carried out to described horizontal rock core, obtains the information of clay mineral type contained by described horizontal rock core and content, Pore throat size and distribution and connectedness;
S6: according to the measurement described in S1 ~ S5 and experimental result, analyzes and sets up described formation factor and the correlative relationship comprising described total porosity, effecive porosity, irreducible water saturation, qualitative index, clay mineral type and content, Pore throat size and distribution and connectedness;
S7: based on the correlative relationship determination oil layer recognition algorithm of described foundation, according to described oil layer recognition algorithm, oil layer recognition is carried out to described reservoir.
2. as claimed in claim 1 a kind of based on compact reservoir conduction Factor Experiment Identification Method of Oil, it is characterized in that, the horizontal rock core of described acquisition reservoir different depth comprises:
S101: drill through the little rock core that two block lengths are L, diameter is R in the horizontal direction at same depth of reservoirs point D1 place;
S102: by two blocks of little rock cores drilling through at described D1 place wherein one piece of cutting be two pieces, ensure that wherein a block length is 5 centimetres, diameter is 2.5 centimetres;
S103: the two blocks of little rock cores drilling through reservoir different depth point Dn place according to the method for S101, S102, and by two little rock cores at described Dn place wherein one piece be divided into two pieces, ensure that wherein a block length is 5 centimetres, diameter is 2.5 centimetres.
3. a kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment as claimed in claim 2, is characterized in that, described in the span of the length L of the two blocks of little rock cores in different depth point Dn place that drills through be:
8 centimetres≤L≤10 centimetre.
4. a kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment as claimed in claim 1, it is characterized in that, the described correlative relationship set up according to the measurement described in S1 ~ S5 and experimental result comprises:
Experimental data according to the horizontal rock core of described total porosity within the scope of preset error sets up described correlative relationship.
5. a kind of Identification Method of Oil based on compact reservoir conduction Factor Experiment as claimed in claim 1, is characterized in that, described analysis the correlative relationship set up comprises at least one in the design formulas of foundation, parameter value scope, parameter value.
6. as claimed in claim 1 a kind of based on compact reservoir conduction Factor Experiment Identification Method of Oil, it is characterized in that, the described correlative relationship determination oil layer recognition algorithm based on described foundation, comprising:
The oil layer recognition plate that to set up with the ratio of formation resistivity characteristic value and formation water resistivity, stratum total porosity be coordinate, adopts following formula to calculate the boundary equation distinguishing oil, water:
In above formula, φ
tfor the total porosity (%) on stratum, C is the empirical being applicable to reservoir place survey area, F is the formation factor of experimentally data acquisition and the relation function formula of total porosity, A and B be experimentally data determine what meet described formation factor and total porosity distribution relation take total porosity as total porosity coefficient and the index of the truth of a matter.
7. as claimed in claim 6 a kind of based on compact reservoir conduction Factor Experiment Identification Method of Oil, it is characterized in that, the span of described empirical C is: 1.9≤C≤6.3.
8. as claimed in claim 6 a kind of based on compact reservoir conduction Factor Experiment Identification Method of Oil, it is characterized in that, the value of described empirical C is 2.8.
9. as claimed in claim 1 a kind of based on compact reservoir conduction Factor Experiment Identification Method of Oil, it is characterized in that, described method also comprises:
According to rock core pore structure, described horizontal rock core is classified.
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