CN105804734B - A method of identifying thick oil reservoir using nuclear magnetic resonance log - Google Patents
A method of identifying thick oil reservoir using nuclear magnetic resonance log Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 76
- 238000005481 NMR spectroscopy Methods 0.000 title claims abstract description 40
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 69
- 239000012530 fluid Substances 0.000 claims abstract description 45
- 230000003595 spectral effect Effects 0.000 claims abstract description 29
- 230000005311 nuclear magnetism Effects 0.000 claims abstract description 24
- 238000001228 spectrum Methods 0.000 claims description 11
- 239000004744 fabric Substances 0.000 claims description 2
- 238000003672 processing method Methods 0.000 claims description 2
- 238000011156 evaluation Methods 0.000 abstract description 3
- 239000003921 oil Substances 0.000 description 25
- 238000002474 experimental method Methods 0.000 description 3
- 239000011148 porous material Substances 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 239000000295 fuel oil Substances 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 235000013399 edible fruits Nutrition 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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Abstract
The invention discloses a kind of methods identifying thick oil reservoir using nuclear magnetic resonance log, belong to fluid identification of reservoir field.Including：Well with nuclear magnetic resonance log data is handled to obtain standard T2Distribution profile；Reservoir nuclear-magnetism porosity is calculated, nuclear-magnetism T is utilized2It composes cutoff value method and calculates irreducible water saturation SBVI；Irreducible water saturation S is calculated using spectral coefficient methodSBVI；Finally calculate the fluid identification of reservoir factor；Fluid identification plate is established according to the fluid identification factor, to make accurate judgement to the fluid of reservoir.There are the irreducible water saturation calculated both when viscous crude, there are significant differences using reservoir by the present invention, are effectively identified to thick oil reservoir, realize in the region that viscous crude is distributed, utilize nuclear magnetic resonance T2The method for the irreducible water saturation difference that cutoff value and spectral coefficient method calculate, can realize and accurately and reliably be identified to thick oil reservoir, and effective Fluid Identification Method is provided for the thick oil reservoir exploration of current China's large area and reservoir evaluation.
Description
Technical field
Fluid identification of reservoir field in being explored the present invention relates to formation testing, more particularly to a kind of nuclear-magnetism of identification thick oil reservoir are total
It shakes logging method.
Background technology
The fluid identification of thick oil reservoir is one of the problem of well log interpretation evaluation, and nuclear magnetic resonance log is hydrogen in Study of Fluid
Natural content and occurrence status a kind of logging method, be the currently the only logging method that can evaluate crude oil physical property.
But viscous crude (viscosities il is confirmed for thick oil reservoir many experiments>50cP/50 DEG C) it is saturated to after rock sample, T2Spectrum is substantially
It is distributed in constraint liquid scope, when crude oil reaches certain viscosity, the T of viscous crude2Value is even also smaller than constraint fluid, at this time
Through being difficult to distinguish viscous crude and constraint fluid information, this is also the technology limit that a kind of nuclear magnetic resonance log at present identifies thick oil reservoir
System.
In terms of carrying out well logging recognition thick oil reservoir using nuclear magnetic resonance, forefathers are total from nuclear magnetic resonance experiment and practical nuclear-magnetism
Well logging aspect of shaking has done some research work, the refined equal T that viscous crude is found by nuclear magnetic resonance experiment of what ancestor2Spectral peak is with temperature
It increases to occur dividing and shows as multimodal feature, qualitative recognition thick oil reservoir is come with this；Bu Lingmei according to NMR logging data not
Same T2Distributional pattern, that is, T2The size of peak value qualitatively differentiates thick oil reservoir；Shao Weizhi etc. is summarized to be surveyed using nuclear magnetic resonance
The method of well identification thick oil reservoir by the classification of reservoir pore space be divided into micro--fine pore in-macrovoid compares water layer respectively
With oil reservoir standard T2Spectrum, poor spectrum signal and spectrum signal feature difference is moved to identify thick oil reservoir.
Invention content
In order to solve the problems, such as that conventional nuclear magnetic resonance log can not be utilized to identify that thick oil reservoir, the present invention provide one in the prior art
Kind utilizes T2The method that cutoff value and spectral coefficient method calculate reservoir irreducible water saturation to identify thick oil reservoir.This method can
Viscous crude signal is avoided in realization and to fetter fluid signal Chong Die and lead to the unfavorable factor of viscous crude signal None- identified.Pass through two kinds of sides
Method calculate irreducible water saturation the difference of water layer and heavy oil tested layer come quickly, accurately identify thick oil reservoir.
The purpose of the present invention is what is realized by following technical proposals.
A method of it identifying thick oil reservoir using nuclear magnetic resonance log, includes the following steps：
Step (1) handles the well with nuclear magnetic resonance log data to obtain standard T2Distribution profile；
Step (2) calculates the nuclear-magnetism porosity of reservoirAnd utilize nuclear-magnetism T2Cutoff value method is composed with spectral coefficient method to distinguish
Calculate the T of reservoir2Compose cutoff value method irreducible water saturation SBVIWith spectral coefficient method irreducible water saturation SSBVI；
Step (3) utilizes the reservoir nuclear-magnetism porosity required by step (2)And T2It composes cutoff value method and fetters water saturation
Spend SBVIWith spectral coefficient method irreducible water saturation SSBVI, calculate fluid identification of reservoir factor k；
Step (4), with the irreducible water saturation S of spectral coefficient methodSBVIFor abscissa, fluid identification of reservoir factor k is vertical sits
Mark establishes fluid identification plate, respectively obtains fluid oil reservoir, water layer and dried layer region；
Step (5), for the new well of properties of fluid in bearing stratum to be identified, the spectral coefficient calculated according to step (2), step (3)
Method irreducible water saturation SSBVIWith fluid identification factor k, then the result of calculation of purpose of horizon is projected on cross plot, to thick
The fluid of oily reservoir makes identification.
Further, when carrying out step (1) operation, inversion procedure need to be carried out to the well with Nuclear Magnetic Resonance Logging and obtained
Standard T2Spectrum, processing method are calculated according to DPP and LEAD3.0 log interpretation softwares.
Further, in step (2), preceding 5 echo-signals calculate storage in the echo measured nuclear-magnetism using DPP softwares
The nuclear-magnetism porosity of layer
Further, in step (2), T is utilized2Cutoff value method calculates irreducible water saturation SBVI, it is calculated by the following formula
It obtains：
In formula, SBVIFor nuclear-magnetism T2The irreducible water saturation of cutoff value method；T2minFor nuclear magnetic resonance standard T2The minimum of distribution
Time value；T2maxFor nuclear magnetic resonance standard T2The maximum time value of distribution；T2cutoffIt is T2Cutoff value；φiFor nuclear magnetic resonance standard
T2Each T in distribution2Amplitude corresponding to time.
Further, in step (2), irreducible water saturation S is calculated using spectral coefficient methodSBVI, it is calculated by the following formula
It obtains：
In formula, SSBVIFor the irreducible water saturation of spectral coefficient method；WiFor nuclear magnetic resonance standard T2T in distribution2iComponent irreducible water
Corresponding weight coefficient；I=1,2 ..., n；T2iIt is T related with i-th of component2Relaxation time；M, b are undetermined coefficients, with
Pore geometry and Free water water-column are related；N is the number of component；φiFor T2T in distribution2iCorresponding to component
Amplitude.
Further, it in step (3), calculates fluid identification of reservoir factor k and is calculated by the following formula to obtain：
In formula,By the reservoir nuclear-magnetism porosity calculated in step (2), unit is decimal；SBVIFor in step (2)
Utilize nuclear-magnetism T2Cutoff value method irreducible water saturation, unit are percentage；SSBVIFor what is calculated using spectral coefficient method in step (2)
Spectral coefficient method irreducible water saturation, unit are percentage.
Further, in the step (4), it is complete with the nuclear magnetic signal of viscous crude and irreducible water to establish fluid identification plate
Overlapping and the two calculate the difference of the physical model and computation model of irreducible water saturation so that when there are when viscous crude two for reservoir
There are significant differences for the irreducible water saturation that person calculates, and are effectively identified to thick oil reservoir using this species diversity.
Technical solution provided in an embodiment of the present invention develops viscous crude to region and has the well point of NMR logging data
It Cai Yong not T2Cutoff value method and spectral coefficient method calculate the irreducible water saturation of reservoir, since the nuclear magnetic signal of viscous crude and irreducible water is complete
Full weight is folded and the difference of the physical model and computation model of the two calculating irreducible water saturation so that when there are when viscous crude for reservoir
There are significant differences for the irreducible water saturation that the two calculates, and are effectively identified to thick oil reservoir using this species diversity.The party
Method, which realizes, utilizes T2Cutoff value method and spectral coefficient method calculate reservoir irreducible water saturation water layer and heavy oil tested layer difference, quickly
Differentiate thick oil reservoir；The problem of avoiding because the viscous crude relaxation time is too short, leading to conventional nuclear magnetic resonance log None- identified；Energy
Enough realize accurately and reliably identifies thick oil reservoir, is provided for the petroleum reservoir exploration of current China's large area and reservoir evaluation
Effective viscous crude Fluid Identification Method.
Description of the drawings
To describe the technical solutions in the embodiments of the present invention more clearly, make required in being described below to embodiment
Attached drawing is briefly described, it should be apparent that, drawings in the following description are only some embodiments of the invention, for
For those of ordinary skill in the art, without creative efforts, other are can also be obtained according to these attached drawings
Attached drawing.
Fig. 1 is the method flow diagram of identification thick oil reservoir provided in an embodiment of the present invention；
Fig. 2 is the fluid identification plate that the embodiment of the present invention is established；
Fig. 3 is the new well fluids identification application effect figure of a bite provided in an embodiment of the present invention.
Specific implementation mode
To make the object, technical solutions and advantages of the present invention clearer, below in conjunction with attached drawing to embodiment party of the present invention
Formula is described in further detail.
Shown in Fig. 1, the present invention is given using the method for nuclear magnetic resonance log identification thick oil reservoir, is included the following steps：
Step (1) handles the well with nuclear magnetic resonance log data to obtain standard T2Distribution profile；
Step (2) calculates the nuclear-magnetism porosity of reservoirAnd utilize nuclear-magnetism T2Compose cutoff value method and spectral coefficient method point
Not Ji Suan reservoir T2Compose cutoff value method irreducible water saturation SBVIWith spectral coefficient method irreducible water saturation SSBVI；
Step (3) utilizes the reservoir nuclear-magnetism porosity required by step (2)And T2It composes cutoff value method and fetters water saturation
Spend SBVIWith spectral coefficient method irreducible water saturation SSBVI, calculate fluid identification of reservoir factor k；
Step (4), with the irreducible water saturation S of spectral coefficient methodSBVIFor abscissa, fluid identification of reservoir factor k is vertical sits
Mark establishes fluid identification plate, respectively obtains fluid oil reservoir, water layer and dried layer region；
Step (5) calculates its spectral coefficient for the new well of properties of fluid in bearing stratum to be identified according to step (2), step (3)
Method irreducible water saturation SSBVIWith fluid identification factor k, then the result of calculation of purpose of horizon is projected on cross plot, to thick
The fluid of oily reservoir makes identification.
The present invention chooses certain fault block of North China Oilfield Lixian Slope development thick oil reservoir as embodiment.Specifically according to as follows
Step is implemented.
Step (1) there is the well of nuclear magnetic resonance log data to be handled to obtain standard T this area2Distribution profile, the area
Nuclear magnetic resonance log data are measured by Halliburton's p-type nuclear magnetic resonance log instrument and middle oil well logging MRT nuclear magnetic resonance log instruments, to echo
String carries out inversion procedure and seeks T2Time spectrum is respectively adopted DPP and is handled with LEAD3.0 log interpretation softwares.
Step (2), preceding 5 echo-signals calculate reservoir porosity in the echo measured nuclear-magnetism using DPP softwaresTo the standard T of acquisition2Spectrum applies T2Cutoff value method calculates irreducible water saturation, is specifically calculated according to following formula：
Wherein, SBVIFor nuclear-magnetism T2The irreducible water saturation of cutoff value method, T2minFor nuclear magnetic resonance standard T2When distribution is minimum
Between be worth, 0.3ms；T2maxFor nuclear magnetic resonance standard T2It is distributed maximum time value, 3000ms；T2cutOff is T2Cutoff value, 23ms；φi
For nuclear magnetic resonance standard T2T in distribution2iAmplitude corresponding to component.
To the standard T of acquisition2It composes spectrum of use Y-factor method Y and calculates irreducible water saturation, specifically counted according to following formula
It calculates：
Wherein, SSBVIFor the irreducible water saturation of spectral coefficient method, Wi(i=1,2 ..., 200) be nuclear magnetic resonance standard T2Point
T in cloth2iProportionality coefficient corresponding to component irreducible water, T2, iIt is T related with i-th of component2Relaxation time, m take 0.0618, b
It is that the number of component takes 200, φ to take 1, niFor T2T in distribution2iAmplitude corresponding to component.
In step (3), utilize what is calculated in step (2)SBVIAnd SSBVI, calculate fluid identification of reservoir factor k and pass through
Following formula is calculated：
Step (4), with SSBVIFor abscissa, k is that ordinate makes fluid identification plate, as shown in Figure 2.
Step (5) carries out fluid identification to the new well of area's a bite, as shown in figure 3, third road is standard T2Spectrum, the 4th
For the irreducible water saturation that two methods calculate, wherein SBVIFor T2The irreducible water saturation that cutoff value calculates, SSBVIFor spectral coefficient
The irreducible water saturation of calculating, the fluid identification factor k=2.6, S that No. 35 floor calculateSBVI=46% reservoir is reservoir characteristics,
No. 39 layer fluid recognition factors k=-1.3, SSBVI=34% layer is water layer feature, is confirmed through formation testing.
When reservoir development viscous crude, its nuclear magnetic signal limits nuclear magnetic resonance log to thick often with irreducible water signal overlap
Effective identification of oily reservoir, it can be seen that calculating reservoir irreducible water saturation model using two kinds calculates knot from the embodiment
The difference of fruit can effectively identify thick oil reservoir, i.e., it is small to show as difference in both water layers result of calculation, and is developed in viscous crude
Reservoir show as apparent difference.
The embodiments of the present invention are for illustration only, can not represent the quality of embodiment.
It is provided for the embodiments of the invention technical solution above to be described in detail, specific case used herein
The principle and embodiment of the embodiment of the present invention are expounded, the explanation of above example is only applicable to help to understand this
The principle of inventive embodiments；Meanwhile for those of ordinary skill in the art, embodiment according to the present invention, in specific embodiment party
There will be changes in formula and application range, in conclusion the content of the present specification should not be construed as limiting the invention.
Claims (6)
1. a kind of method identifying thick oil reservoir using nuclear magnetic resonance log, which is characterized in that include the following steps：
Step (1) handles the well with nuclear magnetic resonance log data to obtain standard T2Distribution profile；
Step (2) calculates the nuclear-magnetism porosity of reservoirAnd utilize nuclear-magnetism T2Spectrum cutoff value method is calculated separately with spectral coefficient method
The T of reservoir2Compose cutoff value method irreducible water saturation SBVIWith spectral coefficient method irreducible water saturation SSBVI；
Step (3) utilizes the reservoir nuclear-magnetism porosity required by step (2)And T2Compose cutoff value method irreducible water saturation SBVI
With spectral coefficient method irreducible water saturation SSBVI, calculate fluid identification of reservoir factor k；
Step (4), with the irreducible water saturation S of spectral coefficient methodSBVIFor abscissa, fluid identification of reservoir factor k establishes for ordinate
Fluid identification plate respectively obtains fluid oil reservoir, water layer and dried layer region；
Step (5), for the new well of properties of fluid in bearing stratum to be identified, the spectral coefficient method beam calculated according to step (2), step (3)
Tie up water saturation SSBVIWith fluid identification factor k, then the result of calculation of purpose of horizon is projected on cross plot, viscous crude is stored up
The fluid of layer makes identification；
In the step (3), calculates fluid identification of reservoir factor k and be calculated by the following formula to obtain：
In formula,For reservoir nuclear-magnetism porosity, unit is decimal；SBVIFor T2Cutoff value method irreducible water saturation, unit hundred
Score；SSBVIFor spectral coefficient method irreducible water saturation, unit is percentage.
2. the method as described in claim 1, which is characterized in that in the step (1), to the well with nuclear magnetic resonance log data into
Row inversion procedure obtains standard T2Spectrum, processing method are calculated according to DPP and LEAD3.0 log interpretation softwares.
3. the method as described in claim 1, which is characterized in that in the step (2), measured nuclear-magnetism using DPP softwares
Preceding 5 echo-signals calculate the nuclear-magnetism porosity of reservoir in echo
4. the method as described in claim 1, which is characterized in that in the step (2), utilize T2Cutoff value method calculates irreducible water
Saturation degree SBVI, it is calculated by the following formula to obtain：
In formula, SBVIFor nuclear-magnetism T2The irreducible water saturation of cutoff value method；T2minFor nuclear magnetic resonance standard T2The minimum time of distribution
Value；T2maxFor nuclear magnetic resonance standard T2The maximum time value of distribution；T2cutoffIt is T2Cutoff value；φiFor nuclear magnetic resonance standard T2Point
Each T in cloth2Amplitude corresponding to time.
5. the method as described in claim 1, which is characterized in that in the step (2), it is full to calculate irreducible water using spectral coefficient method
With degree SSBVI, it is calculated by the following formula to obtain：
In formula, SSBVIFor the irreducible water saturation of spectral coefficient method；WiFor nuclear magnetic resonance standard T2T in distribution2iComponent irreducible water institute is right
The weight coefficient answered；I=1,2 ..., n；T2iIt is T related with i-th of component2Relaxation time；M, b are undetermined coefficients, with hole
Geometry and Free water water-column are related；N is the number of component；φiFor T2T in distribution2iAmplitude corresponding to component.
6. the method as described in claim 1, which is characterized in that in the step (4), it is with viscous crude to establish fluid identification plate
With the nuclear magnetic signal of irreducible water is completely overlapped and the two calculate irreducible water saturation physical model and computation model difference,
So that when there are significant differences there are the irreducible water saturation calculated both when viscous crude for reservoir, using this species diversity to thick oil reservoir
Effectively identified.
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| CN106050225B (en) * | 2016-06-06 | 2019-03-12 | 中国石油天然气集团公司 | A kind of nuclear magnetic resonance log T2 composes the determination method of 100% pure water spectrum |
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| CN106837318B (en) * | 2016-12-23 | 2020-01-07 | 中国石油天然气股份有限公司 | Method and device for obtaining rock stratum thick oil content |
| CN107656315B (en) * | 2017-08-23 | 2019-09-06 | 中国石油天然气股份有限公司 | Method and device for determining reservoir fluid factor |
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