CN110485977A - The logging method of quick predict shale gas-bearing formation formation fracture pressure gradient - Google Patents
The logging method of quick predict shale gas-bearing formation formation fracture pressure gradient Download PDFInfo
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- CN110485977A CN110485977A CN201910753001.6A CN201910753001A CN110485977A CN 110485977 A CN110485977 A CN 110485977A CN 201910753001 A CN201910753001 A CN 201910753001A CN 110485977 A CN110485977 A CN 110485977A
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- shale gas
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- bearing formation
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Abstract
The present invention relates to a kind of logging methods of quick predict shale gas-bearing formation formation fracture pressure gradient, well to be predicted is segmented, obtain every section of well shale gas-bearing formation to be predicted of well logging shear wave slowness and well logging compressional wave time difference, and seek its arithmetic mean of instantaneous value, obtain every section of well shale gas-bearing formation of compensation density to be predicted, depth is consistent with well logging shear wave slowness and well logging compressional wave time difference, obtain the formation pore fluid barometric gradient of each interval of well shale gas-bearing formation to be predicted, obtain regional stratum water density statistical value, determine the segment data of shale gas horizontal well horizontal segment, according to model FRAC=(Kw-DTC/DTS) × (DEN+FPG), the shale gas-bearing formation formation fracture pressure gradient of piecewise prediction well to be predicted, export prediction result.The present invention has applied 40 mouthfuls of wells, and for the mean error of the shale gas-bearing formation formation fracture pressure gradient of prediction less than 20%, speed is fast, at low cost.
Description
Technical field
Technical field according to the present invention is shale gas exploration and development, and in particular to a kind of quick predict shale gas-bearing formation
The logging method of formation fracture pressure gradient.
Background technique
Exploitation shale gas-bearing formation needs the drilling well of carrying out horizontal well and staged fracturing, and pressure break just needs to grasp shale gas before construction
Layer formation fracture pressure, and drilling well with high safety, optimization drilling well etc. be also required to live quick predict stratum to be drilled stratum it is broken
Split pressure, in general, surveying well logging is mostly " barometric gradient " to characterize shale gas-bearing formation pressure characteristic.Shale gas-bearing formation formation fracture pressure is
The product of its vertical depth and formation fracture pressure gradient.
CN106324680A provides a kind of formation fracture pressure prediction method, this method comprises: passing through individual well in work area
Crosshole seismic obtain individual well at stratum shear wave curve；According to the elastic parameter on stratum at shear wave curve acquisition individual well；It obtains
The overburden pressure on stratum, formation pore pressure and tensile strength of rock at individual well；It is obtained at individual well by pressure break microseism
The tectonic stress coefficient on stratum；According to tectonic stress coefficient, overburden pressure, formation pore pressure and tensile strength of rock,
Obtain the formation fracture pressure on stratum at individual well；Using the elastic parameter on stratum at individual well as constraint condition, prestack is carried out to work area
Elastic parameter inversion obtains the elastic parameter in work area；It is fitted the formation fracture pressure on stratum and the elastic parameter in work area at individual well,
Obtain the formation fracture pressure in work area.
CN103912269A discloses a kind of shale gas reservoir formation fracture pressure gradient and determines that method, core are according to formula
FRAC=FPG+POIS/ (1-POIS) × (Ρb-Sg× FPG) shale reservoir formation fracture pressure gradient FRAC is calculated, it needs to obtain
Target interval Rock Poisson Ratio Using POIS is taken, and needs to obtain gas saturation Sg etc. by well logging or well-log information, though it is solved
Conventional method computational accuracy not high problem, but method is relative complex.
CN108708715A discloses the survey logging method of quick predict shale gas-bearing formation formation fracture pressure gradient, obtains institute
State the lithology and density logging ρ b data of well shale gas-bearing formation, measurement unit g/cm3；The well logging of the well shale gas-bearing formation is obtained with brill stratum
Pore fluid pressure gradient FPG data, measurement unit are MPa/100m or MPa/hm；Predict that the shale gas-bearing formation stratum of the well is broken
Split pressure gradient FRAC, measurement unit are MPa/100m or MPa/hm, and prediction model is FRAC=(ρ b+FPG)/2；Output prediction
As a result.
Summary of the invention
The purpose of the present invention is be directed to above-mentioned status, it is desirable to provide one kind is quick, simple and easy to do, adaptation range is relatively wide
Quick predict shale gas-bearing formation formation fracture pressure gradient logging method.
The implementation of the object of the invention is the logging method of quick predict shale gas-bearing formation formation fracture pressure gradient, tool
Steps are as follows for body:
1) well to be predicted is segmented, segment data source provides for Party A；
2) well shale gas-bearing formation well-log information to be predicted is obtained；
Each section of well shale gas-bearing formation to be predicted of well logging shear wave slowness DTS data and well logging compressional wave time difference DTC data are obtained,
And seek its arithmetic mean of instantaneous value；
The well logging shear wave slowness DTS, well logging compressional wave time difference DTC measurement unit are μ s/m；
3) each section of well shale gas-bearing formation of compensation density DEN data to be predicted, depth and well logging shear wave slowness DTS number are obtained
According to well logging compressional wave time difference DTC data, and seek its arithmetic mean of instantaneous value；
The depth and well logging shear wave slowness DTS, depth and well logging compressional wave time difference DTC measurement unit are g/cm3；
4) each section of well shale gas-bearing formation of formation pore fluid barometric gradient FPG data to be predicted are obtained；
The formation pore fluid barometric gradient FPG measurement unit is MPa/100m；
5) regional stratum water density statistical value Kw data are obtained；
The regional stratum water density statistical value Kw is dimensionless；
6) the shale gas-bearing formation formation fracture pressure gradient FRAC of piecewise prediction well to be predicted；
(1) segment data of shale gas horizontal well horizontal segment is determined as required；
(2) according to model FRAC=(Kw-DTC/DTS) × (DEN+FPG), the shale gas-bearing formation of piecewise prediction well to be predicted is every
One section of formation fracture pressure gradient FRAC；
The shale gas-bearing formation formation fracture pressure gradient FRAC measurement unit is MPa/100m；
7) prediction result of each section of shale gas-bearing formation of formation fracture pressure gradient FRAC of well to be predicted is exported.
The present invention be the shale gas-bearing formation based on acquisition well logging shear wave slowness DTS data, well logging compressional wave time difference DTC data,
Compensation density DEN data, formation pore fluid barometric gradient FPG data and regional stratum water density statistical value Kw data, quickly
Predict shale gas-bearing formation formation fracture pressure gradient FRAC.
The present invention is that the practical experience through the applicant's many years is summarized, and obtained method is verified by field application,
The present invention applies 40 mouthfuls of wells in the multiple shale gas fields in the Sichuan Basin, compared with the result that other methods obtain, the shale of prediction
For the mean error of gas-bearing formation formation fracture pressure gradient less than 20%, speed is fast, at low cost, is able to satisfy well logging quick predict shale gas
The need of work of layer formation fracture pressure gradient can provide weight for shale gas-bearing formation fracturing reform and safety drilling, optimization drilling well
Want operation foundation.
Detailed description of the invention
Fig. 1 is workflow block diagram of the present invention.
Specific embodiment
The present invention is described in detail with reference to the accompanying drawings.
Referring to Fig.1, specific steps of the invention are as follows:
1) well to be predicted is segmented, segment data source provides for Party A.
2) well shale gas-bearing formation well-log information to be predicted is obtained；
Each section of well shale gas-bearing formation to be predicted of well logging shear wave slowness DTS data and well logging compressional wave time difference DTC data are obtained,
And seek its arithmetic mean of instantaneous value；
The well logging shear wave slowness DTS, well logging compressional wave time difference DTC measurement unit are μ s/m.
3) each section of well shale gas-bearing formation of compensation density DEN data to be predicted, depth and well logging shear wave slowness DTS number are obtained
According to well logging compressional wave time difference DTC data, and seek its arithmetic mean of instantaneous value；
The depth and well logging shear wave slowness DTS, depth and well logging compressional wave time difference DTC measurement unit are g/cm3。
4) each section of well shale gas-bearing formation of formation pore fluid barometric gradient FPG data to be predicted are obtained；
The formation pore fluid barometric gradient FPG measurement unit is MPa/100m.
5) regional stratum water density statistical value Kw data are obtained；
The regional stratum water density statistical value Kw is dimensionless.
6) the shale gas-bearing formation formation fracture pressure gradient FRAC of piecewise prediction well to be predicted；
(1) segment data of shale gas horizontal well horizontal segment is determined as required；
(2) according to model FRAC=(Kw-DTC/DTS) × (DEN+FPG), the shale gas-bearing formation of piecewise prediction well to be predicted is every
One section of formation fracture pressure gradient FRAC；
The shale gas-bearing formation formation fracture pressure gradient FRAC measurement unit is MPa/100m.
7) prediction result of each section of shale gas-bearing formation of formation fracture pressure gradient FRAC of well to be predicted is exported.
The present invention applies more than 40 mouth wells in southern Sichuan Fuling, Sichuan Basin shale gas field, the knot obtained with other methods
Fruit is compared, and for the mean error of the shale gas-bearing formation formation fracture pressure gradient of prediction less than 20%, speed is fast, at low cost.
The present invention is described in detail with specific embodiment below.
Example: FL shale gas field P block A well, well type is horizontal well.A well is divided into according to the segment data that Party A provides
13 sections.
By dipole acoustic log data, the well logging shear wave slowness DTS arithmetic mean of instantaneous value for obtaining pressure break paragraph 1 is 381 μ s/m,
Well logging compressional wave time difference DTC arithmetic mean of instantaneous value is 211 μ s/m；The 2nd section of pressure break of well logging shear wave slowness DTS arithmetic mean of instantaneous value is 375 μ
S/m, well logging compressional wave time difference DTC arithmetic mean of instantaneous value are 207 μ s/m；And so on, the 3rd section of pressure break is arrived the 13rd section of well logging shear wave of pressure break
See Table 1 for details for time difference DTS and well logging compressional wave time difference DTC arithmetic average.
By litho-density log data, the arithmetic mean of instantaneous value of the compensation density DEN of pressure break paragraph 1 is 2.51g/cm3；Pressure break
The arithmetic mean of instantaneous value of 2nd section of compensation density DEN is 2.52g/cm3；And so on, the 3rd section of pressure break to the 13rd section of pressure break compensation
See Table 1 for details for the arithmetic mean of instantaneous value of density DEN.
By with boring pressing inspection result data acquisition formation pore fluid barometric gradient FPG data, the stratum of pressure break paragraph 1
Pore fluid pressure gradient FPG is 1.45MPa/100m；The 2nd section of pressure break of formation pore fluid barometric gradient FPG is
1.45MPa/100m, and so on, the 3rd section of pressure break to the 13rd section of formation pore fluid barometric gradient FPG of pressure break see Table 1 for details.
Obtaining well area water flooding Statistics of Density value Kw to be predicted is 1.07.
According to prediction model FRAC=(Kw-DTC/DTS) (× DEN+FPG), segmentation calculates each section of shale gas-bearing formation of ground
Layer fracture pressure gradient, the formation pore fluid barometric gradient FRAC that pressure break paragraph 1 is calculated is 2.06MPa/100m；It calculates
The formation pore fluid barometric gradient FRAC for obtaining the 2nd section of pressure break is 2.06MPa/100m；And so on, the 3rd section of pressure break to pressure
Splitting the 13rd section of formation pore fluid barometric gradient FRAC, see Table 1 for details.
Well to be predicted is exported in the prediction knot of the formation fracture pressure gradient FRAC=2.06MPa/100m of pressure break paragraph 1
Fruit；Well to be predicted is exported in the prediction result of the 2nd section of pressure break of formation fracture pressure gradient FRAC=2.06MPa/100m；With this
Analogize, see Table 1 for details for the prediction result of the 3rd section of pressure break to the 13rd section of pressure break of formation fracture pressure gradient FRAC.
As seen from Table 1, A well pressure break is in pressure break paragraph 1, the formation fracture pressure provided by site operation fracturing engineering
76.42MPa is calculated, and the formation fracture pressure gradient of the depth is 2.13MPa/100m, is calculated by the present invention, the stratum of the depth
Fracture pressure gradient is 2.06MPa/100m, relative error 3.29%.
A well pressure break is calculated at the 2nd section of pressure break by the formation fracture pressure 87.43MPa that site operation fracturing engineering provides,
The formation fracture pressure gradient of the depth is 2.43MPa/100m, is calculated by the present invention, the formation fracture pressure gradient of the depth
For 2.06MPa/100m, relative error 15.23%；It is the 3rd section of pressure break to the 13rd section of pressure break of formation fracture pressure gradient, opposite
See Table 1 for details for error.
From the fracturing engineering of table 1, practice have shown that, calculation method of the present invention is reliable.
Table 1
Claims (1)
1. the logging method of quick predict shale gas-bearing formation formation fracture pressure gradient, it is characterised in that: specific step is as follows:
1) well to be predicted is segmented, segment data source provides for Party A；
2) well shale gas-bearing formation well-log information to be predicted is obtained；
Each section of well shale gas-bearing formation to be predicted of well logging shear wave slowness DTS data and well logging compressional wave time difference DTC data are obtained, and are asked
Take its arithmetic mean of instantaneous value；
The well logging shear wave slowness DTS, well logging compressional wave time difference DTC measurement unit are μ s/m；
3) obtain each section of well shale gas-bearing formation of compensation density DEN data to be predicted, depth and well logging shear wave slowness DTS data and
Well logging compressional wave time difference DTC data, and seek its arithmetic mean of instantaneous value；
The depth and well logging shear wave slowness DTS, depth and well logging compressional wave time difference DTC measurement unit are g/cm3；
4) each section of well shale gas-bearing formation of formation pore fluid barometric gradient FPG data to be predicted are obtained；
The formation pore fluid barometric gradient FPG measurement unit is MPa/100m；
5) regional stratum water density statistical value Kw data are obtained；
The regional stratum water density statistical value Kw is dimensionless；
6) the shale gas-bearing formation formation fracture pressure gradient FRAC of piecewise prediction well to be predicted；
(1) segment data of shale gas horizontal well horizontal segment is determined as required；
(2) according to model FRAC=(Kw-DTC/DTS) × (DEN+FPG), each section of the shale gas-bearing formation of piecewise prediction well to be predicted
Formation fracture pressure gradient FRAC；
The shale gas-bearing formation formation fracture pressure gradient FRAC measurement unit is MPa/100m；
7) prediction result of each section of shale gas-bearing formation of formation fracture pressure gradient FRAC of well to be predicted is exported.
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