CN104483715A - Method and device used for determining critical exhaust strength of tight sandstone gas reservoir exhaust source rocks - Google Patents

Abstract

The invention provides a method and a device used for determining critical exhaust strength of tight sandstone gas reservoir exhaust source rocks. The method comprises steps that, stratum data of a target interval of a tight sandstone gas reservoir research zone is acquired, stratum hydrostatic pressure, gas water interface tension force under the stratum condition, natural gas compression factors and capillary force are determined according to the acquired stratum data, gas bulging force under the force balance condition is calculated, and the critical exhaust strength is calculated according to the stratum temperature, effective hydrocarbon source rock thickness, hydrocarbon source rock porosity and natural gas substance amount of the acquired stratum data, and the natural gas compression factors and natural gas density acquired through calculation. The method solves a technical problem of difficulty in quantitatively predicting the critical exhaust strength of the tight sandstone gas reservoir exhaust source rocks in an oil gas basin in the prior art, improves exploration efficiency of tight sandstone gas and reduces risks in exploring tight sandstone gas reservoirs.

Description

Determine the method and apparatus of the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock

Technical field

The present invention relates to oil-gas exploration technical field, particularly a kind of method and apparatus determining the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock.

Background technology

DAMAGE OF TIGHT SAND GAS RESERVOIRS is a kind of important unconventional gas reservoir, and at present, the minable compact sandstone gas reserves of prior art are approximately 10.5 × 10 in the world ¹²~ 24 × 10 ¹²m ³, occupy first of Unconventional forage, there is very large resource potential.Tight Sandstone Reservoir Formation is machine-processed and Filling process is all very complicated, also the formation condition of a lot of scholar to DAMAGE OF TIGHT SAND GAS RESERVOIRS is had to be studied, such as: Berkenpas PG points out that the formation of DAMAGE OF TIGHT SAND GAS RESERVOIRS is not by the effect of buoyancy, but is subject to the control of hydrocarbon source rock internal pressure; Major impetus that to be rock gas fill to compact reservoir that Pang Xiongqi proposes gas tension, can by the minimum depth of burial of mechanical balance determination Gas reservoir, by the trap scope of material balance determination Gas reservoir; Jiang Fujie confirms by the method for physical simulation experiment the control action that gas tension is formed DAMAGE OF TIGHT SAND GAS RESERVOIRS, and there is critical condition; The distribution of Cai Xiyuan proposition Deep Tight Sandstone can be subject to the control in source rock development district; Zou Caineng proposes hydrocarbon source rock large area can enter the stage of ripeness in identical or close geochron, thus forms the hydrocarbon source rock extensively covering formula, and this is conducive to the formation of DAMAGE OF TIGHT SAND GAS RESERVOIRS.

These researchs have shown that gas tension is the power that DAMAGE OF TIGHT SAND GAS RESERVOIRS becomes to hide above, and the formation of distribution to DAMAGE OF TIGHT SAND GAS RESERVOIRS of Effective source rocks is most important.But, cannot determine that reaching which kind of condition rock gas just can enter compact reservoir according to the distribution of Effective source rocks, mainly cannot study from quantitative angle the critical condition that compact sandstone gas is formed, thus cause only concisely to determine according to result of study the standard and scope that form DAMAGE OF TIGHT SAND GAS RESERVOIRS available gas source rock exactly, make to go out the resource potential of DAMAGE OF TIGHT SAND GAS RESERVOIRS by Accurate Prediction.

Summary of the invention

Embodiments provide a kind of method determining the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock, to solve the technical matters of the critical venting intensity quantitative forecast difficulty of the exhaust source rock of DAMAGE OF TIGHT SAND GAS RESERVOIRS in petroliferous basin in prior art, the method comprises:

Obtain the formation data of objective interval in DAMAGE OF TIGHT SAND GAS RESERVOIRS study area, wherein, described formation data comprises: stratum water colunm height, formation temperature, reservoir pressure, compact reservoir pore throat radius, local water density, reservoir rock rock gas wetting angle, Effective source rocks thickness, hydrocarbon source rock factor of porosity and rock gas amount of substance;

According to described stratum water colunm height and local water density, determine stratum hydrostatic force;

According to described formation temperature and reservoir pressure, determine the gas-water interface tension force under corresponding formation condition and gas deviation factor;

According to described compact reservoir pore throat radius and reservoir rock rock gas wetting angle, and the gas-water interface tension force determined, calculate capillary force;

According to the stratum hydrostatic force determined and capillary force, calculate the gas tension under dynamic balance condition;

According to described formation temperature, reservoir pressure, rock gas amount of substance and the gas deviation factor determined, calculate the natural gas density under corresponding formation condition;

According to gas tension, gas deviation factor, natural gas density under described formation temperature, Effective source rocks thickness, hydrocarbon source rock factor of porosity, rock gas amount of substance and the dynamic balance condition that calculates, calculate the critical venting intensity of exhaust source rock.

In one embodiment, according to described stratum water colunm height and local water density, determine stratum hydrostatic force, comprising:

According to following formulae discovery stratum hydrostatic force:

P _w＝ρ _wgH

Wherein, P _wrepresent stratum hydrostatic force, g represents acceleration of gravity, and unit is kg/N, ρ _wrepresent local water density, unit is kg/m ³, H represents stratum water colunm height, and unit is m.

In one embodiment, according to described formation temperature and reservoir pressure, determine the gas-water interface tension force under corresponding formation condition and gas deviation factor, comprising:

According to the nomogram version of the methane gas-water interfacial tension under described formation temperature and formation condition corresponding to reservoir pressure, determine the gas-water interface tension force under corresponding formation condition;

According to described formation temperature and gas deviation factor plate corresponding to reservoir pressure, determine gas deviation factor.

In one embodiment, according to described compact reservoir pore throat radius and reservoir rock rock gas wetting angle, and the gas-water interface tension force determined, calculate capillary force, comprising:

According to following formulae discovery capillary force:

$P_c=\frac{2\mathrm{\σ}\cos \mathrm{\θ}}{r}$

Wherein, P _crepresent capillary force, unit is that Pa, σ represent gas-water interface tension force, and unit is that N/m, θ represent reservoir rock rock gas wetting angle, and unit is °, and r represents compact reservoir pore throat radius, and unit is m.

In one embodiment, according to the stratum hydrostatic force determined and capillary force, calculate the gas tension under dynamic balance condition, comprising:

Gas tension according under following formulae discovery dynamic balance condition:

P _e＝P _c+P _w

Wherein, P _erepresent gas tension, P _crepresent capillary force, P _wrepresent stratum hydrostatic force.

In one embodiment, according to described formation temperature, reservoir pressure, rock gas amount of substance and the gas deviation factor determined, calculate the natural gas density under corresponding formation condition, comprising:

Natural gas density according under the formation condition that following formulae discovery is corresponding:

${\mathrm{\ρ}}_g=\frac{\mathrm{PM}}{\mathrm{ZRT}}$

Wherein, ρ _grepresent natural gas density, unit is kg/m ³, P represents reservoir pressure, and unit is that Mpa, M represent rock gas amount of substance, and unit is that kg/kmol, T represent formation temperature, and unit is that K, Z represent gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK).

In one embodiment, according to gas tension, gas deviation factor, natural gas density under described formation temperature, Effective source rocks thickness, hydrocarbon source rock factor of porosity, rock gas amount of substance and the dynamic balance condition that calculates, calculate the critical venting intensity of exhaust source rock, comprising:

Critical venting intensity according to following formulae discovery exhaust source rock:

$q_e=\frac{10M{h}_s\mathrm{\Φ}{P}_e}{Z{\mathrm{\ρ}}_g\mathrm{RT}}$

Wherein, q _erepresent the critical venting intensity of exhaust source rock, unit is m ³/ m ², M represents rock gas amount of substance, and unit is kg/mol, h _srepresent Effective source rocks thickness, unit is that m, Φ represent hydrocarbon source rock factor of porosity, P _erepresent the gas tension under dynamic balance condition, unit is Mpa, ρ _grepresent natural gas density, unit is kg/m ³, Z represents gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK), T represents formation temperature, and unit is K.

The embodiment of the present invention additionally provides a kind of device determining the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock, to solve the technical matters of the critical venting intensity quantitative forecast difficulty of the exhaust source rock of DAMAGE OF TIGHT SAND GAS RESERVOIRS in petroliferous basin in prior art, this device comprises:

Data acquisition module, for obtaining the formation data of objective interval in DAMAGE OF TIGHT SAND GAS RESERVOIRS study area, wherein, described formation data comprises: stratum water colunm height, formation temperature, reservoir pressure, compact reservoir pore throat radius, local water density, reservoir rock rock gas wetting angle, Effective source rocks thickness, hydrocarbon source rock factor of porosity and rock gas amount of substance;

Hydrostatic force determination module, for according to described stratum water colunm height and local water density, determines stratum hydrostatic force;

Interfacial tension and compressibility factor determination module, for according to described formation temperature and reservoir pressure, determine the gas-water interface tension force under corresponding formation condition and gas deviation factor;

Capillary force determination module, for according to described compact reservoir pore throat radius and reservoir rock rock gas wetting angle, and the gas-water interface tension force determined, calculate capillary force;

Gas tension determination module, for according to the stratum hydrostatic force determined and capillary force, calculates the gas tension under dynamic balance condition;

Natural gas density determination module, for according to described formation temperature, reservoir pressure, rock gas amount of substance and the gas deviation factor determined, calculates the natural gas density under corresponding formation condition;

Critical venting intensity determination module, for according to gas tension, gas deviation factor, the natural gas density under described formation temperature, Effective source rocks thickness, hydrocarbon source rock factor of porosity, rock gas amount of substance and the dynamic balance condition that calculates, calculate the critical venting intensity of exhaust source rock.

In one embodiment, described hydrostatic force determination module is specifically for according to following formulae discovery stratum hydrostatic force:

P _w＝ρ _wgH

Wherein, P _wrepresent stratum hydrostatic force, g represents acceleration of gravity, and unit is kg/N, ρ _wrepresent local water density, unit is kg/m ³, H represents stratum water colunm height, and unit is m.

In one embodiment, described interfacial tension and compressibility factor determination module comprise:

Interfacial tension determining unit, for the nomogram version according to the methane gas-water interfacial tension under described formation temperature and formation condition corresponding to reservoir pressure, determines the gas-water interface tension force under corresponding formation condition;

Compressibility factor determining unit, for according to described formation temperature and gas deviation factor plate corresponding to reservoir pressure, determines gas deviation factor.

In one embodiment, described capillary force determination module is specifically for according to following formulae discovery capillary force:

$P_c=\frac{2\mathrm{\σ}\cos \mathrm{\θ}}{r}$

Wherein, P _crepresent capillary force, unit is that Pa, σ represent gas-water interface tension force, and unit is that N/m, θ represent reservoir rock rock gas wetting angle, and unit is °, and r represents compact reservoir pore throat radius, and unit is m.

In one embodiment, described gas tension determination module is specifically for according to the gas tension under following formulae discovery dynamic balance condition:

P _e＝P _c+P _w

Wherein, P _erepresent gas tension, P _crepresent capillary force, P _wrepresent stratum hydrostatic force.

In one embodiment, described natural gas density determination module is specifically for according to the natural gas density under formation condition corresponding to following formulae discovery:

${\mathrm{\ρ}}_g=\frac{\mathrm{PM}}{\mathrm{ZRT}}$

Wherein, ρ _grepresent natural gas density, unit is kg/m ³, P represents reservoir pressure, and unit is that Mpa, M represent rock gas amount of substance, and unit is that kg/kmol, T represent formation temperature, and unit is that K, Z represent gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK).

In one embodiment, described critical venting intensity determination module is specifically for the critical venting intensity according to following formulae discovery exhaust source rock:

$q_e=\frac{10M{h}_s\mathrm{\Φ}{P}_e}{Z{\mathrm{\ρ}}_g\mathrm{RT}}$

Wherein, q _erepresent the critical venting intensity of exhaust source rock, unit is m ³/ m ², M represents rock gas amount of substance, and unit is kg/mol, h _srepresent Effective source rocks thickness, unit is that m, Φ represent hydrocarbon source rock factor of porosity, P _erepresent the gas tension under dynamic balance condition, unit is Mpa, ρ _grepresent natural gas density, unit is kg/m ³, Z represents gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK), T represents formation temperature, and unit is K.

In embodiments of the present invention, provide the defining method of the critical venting intensity of a kind of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock, establish DAMAGE OF TIGHT SAND GAS RESERVOIRS effective air feed source rock critical row's hydrocarbon quantification of intensities computation model, simultaneously can go out the size of the critical venting intensity of the effective air feed of DAMAGE OF TIGHT SAND GAS RESERVOIRS in basin source rock by Accurate Prediction, thus solve the technical matters of the critical venting intensity quantitative forecast difficulty of the exhaust source rock of DAMAGE OF TIGHT SAND GAS RESERVOIRS in petroliferous basin in prior art, reach the exploration efficiency improving compact sandstone gas, reduce the technique effect of the exploration risk of DAMAGE OF TIGHT SAND GAS RESERVOIRS.

Accompanying drawing explanation

Accompanying drawing described herein is used to provide a further understanding of the present invention, forms a application's part, does not form limitation of the invention.In the accompanying drawings:

Fig. 1 is the process flow diagram of the method for the critical venting intensity of the determination DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock of the embodiment of the present invention;

Fig. 2 is Kuche Depression of Talimu Basin Jurassic In Eastern tight sand effective air feed source rock critical row's hydrocarbon intensity distributions of the embodiment of the present invention and effective air feed source rock scope schematic diagram;

Fig. 3 is the structured flowchart of the device of the critical venting intensity of the determination DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock of the embodiment of the present invention.

Embodiment

Inventor considers that the rock gas that can utilize and generate in hydrocarbon source rock fills the dynamic balance condition of process to compact reservoir pore throat: when the rock gas generated in hydrocarbon source rock reaches some, the gas tension produced enough overcomes capillary force and overlying water column pressure, set up the method determining the critical venting intensity of available gas source rock, thus determine different depth of burial, formation temperature, the critical venting intensity that rock gas under pressure condition fills to compact reservoir, to solve the difficult problem whether DAMAGE OF TIGHT SAND GAS RESERVOIRS gas source rock possesses the quantitative evaluation of air feed validity, for prediction tight gas reservoir available gas source rock critical row hydrocarbon intensity provides a kind of accurately feasible method, and then the total amount of air feed in compact reservoir can be judged, and provide reference for Mineral Resources Potential Prediction, improve compact sandstone gas exploration efficiency, reduce the exploration risk of DAMAGE OF TIGHT SAND GAS RESERVOIRS, there is applicability widely.

Specifically, provide a kind of method determining the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock in this example, as shown in Figure 1, comprise the following steps:

Step 101: the formation data obtaining objective interval in DAMAGE OF TIGHT SAND GAS RESERVOIRS study area, wherein, described formation data comprises: stratum water colunm height, formation temperature, reservoir pressure, compact reservoir pore throat radius, local water density, reservoir rock rock gas wetting angle, Effective source rocks thickness, hydrocarbon source rock factor of porosity and rock gas amount of substance;

Step 102: according to described stratum water colunm height and local water density, determine stratum hydrostatic force;

Step 103: according to described formation temperature and reservoir pressure, determines the gas-water interface tension force under corresponding formation condition and gas deviation factor;

Step 104: according to described compact reservoir pore throat radius and reservoir rock rock gas wetting angle, and the gas-water interface tension force determined, calculate capillary force;

Step 105: according to the stratum hydrostatic force determined and capillary force, calculate the gas tension under dynamic balance condition;

Step 106: according to described formation temperature, reservoir pressure, rock gas amount of substance and the gas deviation factor determined, calculates the natural gas density under corresponding formation condition;

Step 107: according to gas tension, gas deviation factor, natural gas density under described formation temperature, Effective source rocks thickness, hydrocarbon source rock factor of porosity, rock gas amount of substance and the dynamic balance condition that calculates, calculates the critical venting intensity of exhaust source rock.

In this example, provide the defining method of the critical venting intensity of a kind of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock, establish DAMAGE OF TIGHT SAND GAS RESERVOIRS effective air feed source rock critical row's hydrocarbon quantification of intensities computation model, simultaneously can go out the size of the critical venting intensity of the effective air feed of DAMAGE OF TIGHT SAND GAS RESERVOIRS in basin source rock by Accurate Prediction, thus solve the problem of the critical venting intensity quantitative forecast difficulty of the exhaust source rock of DAMAGE OF TIGHT SAND GAS RESERVOIRS in petroliferous basin in prior art, improve the exploration efficiency of compact sandstone gas, reduce the exploration risk of DAMAGE OF TIGHT SAND GAS RESERVOIRS.

During concrete enforcement, in above-mentioned steps 102, can according to following formulae discovery stratum hydrostatic force:

P _w＝ρ _wgH

Wherein, P _wrepresent stratum hydrostatic force, g represents acceleration of gravity, and unit is kg/N, ρ _wrepresent local water density, unit is kg/m ³, H represents stratum water colunm height, and unit is m.

During concrete enforcement, in above-mentioned steps 103, can according to the nomogram version of the methane gas-water interfacial tension under formation temperature and formation condition corresponding to reservoir pressure, determine the gas-water interface tension force under corresponding formation condition, according to formation temperature and gas deviation factor plate corresponding to reservoir pressure, determine gas deviation factor.

During concrete enforcement, in above-mentioned steps 104, can according to following formulae discovery capillary force:

$P_c=\frac{2\mathrm{\σ}\cos \mathrm{\θ}}{r}$

Wherein, P _crepresent capillary force, unit is that Pa, σ represent gas-water interface tension force, and unit is that N/m, θ represent reservoir rock rock gas wetting angle, and unit is °, and r represents compact reservoir pore throat radius, and unit is m.

During concrete enforcement, in above-mentioned steps 105, can according to the gas tension under following formulae discovery dynamic balance condition:

P _e＝P _c+P _w

Wherein, P _erepresent gas tension, P _crepresent capillary force, P _wrepresent stratum hydrostatic force.

During concrete enforcement, in above-mentioned steps 106, can according to the natural gas density under formation condition corresponding to following formulae discovery:

${\mathrm{\ρ}}_g=\frac{\mathrm{PM}}{\mathrm{ZRT}}$

Wherein, ρ _grepresent natural gas density, unit is kg/m ³, P represents reservoir pressure, and unit is that Mpa, M represent rock gas amount of substance, and unit is that kg/kmol, T represent formation temperature, and unit is that K, Z represent gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK).

After according to the above-mentioned gas tension, gas deviation factor and the natural gas density that calculate under dynamic balance condition, the critical venting intensity of source rock can be vented according to following formulae discovery:

$q_e=\frac{10M{h}_s\mathrm{\Φ}{P}_e}{Z{\mathrm{\ρ}}_g\mathrm{RT}}$

Wherein, q _erepresent the critical venting intensity of exhaust source rock, unit is m ³/ m ², M represents rock gas amount of substance, and unit is kg/mol, h _srepresent Effective source rocks thickness, unit is that m, Φ represent hydrocarbon source rock factor of porosity, P _erepresent the gas tension under dynamic balance condition, unit is Mpa, ρ _grepresent natural gas density, unit is kg/m ³, Z represents gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK), T represents formation temperature, and unit is K.

The above-mentioned method determining the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock of instructions is carried out below in conjunction with a specific embodiment, but it should be noted that, this specific embodiment is only to better the present invention is described, does not form inappropriate limitation of the present invention.

In this example, with the Type of Fractures In The Jurassic Tight Sandstone of Kuche Depression of Talimu Basin eastern region for the method for objective for implementation to the above-mentioned critical venting intensity of determination DAMAGE OF TIGHT SAND GAS RESERVOIRS available gas source rock is specifically described, storehouse car down warping region is positioned at North Tarim Basin, overall in NEE to wire spread, the long 450km of thing, wide 50 ~ the 80km in north and south, contour area 2.7 × 104km2, cenozoic strata in major developmental, disappearance upper Cretaceous series, has: the Triassic system, Jurassic systerm, Lower Cretaceous Series, Paleogene System, Neogene System and Quaternary system etc. from bottom to top.East part of the Kuqa depression DAMAGE OF TIGHT SAND GAS RESERVOIRS is mainly distributed in upper Triassic series and low￣middle Jurassic stratum, wherein, charge-coupled and the positive rosy clouds group of Ah is as main reservoir, and upper Triassic series tower Ritchie gram group and Mount Huang street group and the positive rosy clouds group of Lower Jurassic Series, Kezilenur Forma-tion are distribution of source rock layer positions.Hydrocarbon source rock lithology is formed with lacustrine mud, shale, resinous shale and limnetic facies high-carbon mud stone, coal petrography, and organic matter type is based on III type, and abundance of organic matter is high, and raw hydrocarbon potentiality are large.Reservoir rocks type is all based on rock-fragment sandstone, and the charge-coupled relative thickness of Ah is comparatively large, and distribution is stable, and positive rosy clouds group thinner thickness is sand-mud interbed, and compact sandstone gas resource potential enriches.

In this example, determine the method for the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS effective air feed source rock, comprise the following steps:

Step 1: by collecting existing formation temperature, pressure data at present, local water density data, hydrocarbon source rock thickness transitivity data and reservoir rock thin-section analysis data, and rock gas amount of substance data, obtain stratum water column height H data 7 altogether, formation temperature T data 7, reservoir pressure number P data 7, compact reservoir pore throat radius r data 20, local water density p _wdata 1, reservoir rock rock gas wetting angle data 1, Effective source rocks thickness h _sdata 7, hydrocarbon source rock factor of porosity Φ data 7, rock gas amount of substance M data 1.

Further, can also to H, T, P, r, the ρ collected _w, θ, h _s, Φ, M analyze, and to determine available data, thus improves the accuracy analyzed.Such as, compact reservoir pore throat radius r data 20 are obtained altogether in certain gatherer process, by to data analysis, finally determine that in these 20 data, data available is 7, what is called determines 7 data availables from 20 data, although this mainly considers that the data obtained are many, some data possible error is larger etc., just cannot as data available.

Step 2: according to the stratum water column height H collected in step 1 and local water density p _wdata calculate stratum hydrostatic force P _w, concrete, can according to following formulae discovery hydrostatic force P _w:

P _w＝ρ _wgH

Wherein, ρ _wrepresent local water density, unit is kg/m ³, g represents acceleration of gravity, constant, and 9.8N/kg, H represent stratum water colunm height, and unit is m.

According to the local water density p to gained _wdata and height above sea level depth H data, in conjunction with hydrostatic force computing formula, can obtain the value of hydrostatic force under different depth, concrete numerical value is as shown in table 1, and table 1 is east part of the Kuqa depression hydrostatic force tables of data:

Table 1

Step 3: according to the formation temperature T collected in step 1 and pressure P data, determine gas-water interface tension force σ under formation condition, concrete, under formation condition, gas-water interface tension force σ can be temperature T, the pressure P data according to stratum, and under corresponding formation condition, the nomogram version of methane gas-water table tension force obtains;

According to temperature T, the pressure P data on collected east part of the Kuqa depression stratum, under corresponding formation condition the promise of methane gas-water table tension force not plate obtain the gas-water interface tension force σ under Different Strata condition as shown in table 2:

Table 2

Step 4: according to the compact reservoir pore throat radius r collected in step 1 and reservoir rock rock gas wetting angle θ data, and the gas-water interface tension force σ determined in step 3, calculate capillary force P _c, concrete, can according to following formulae discovery capillary force P _c:

$P_c=\frac{2\mathrm{\σ}\cos \mathrm{\θ}}{r}$

Wherein, P _crepresent capillary force, unit is that Pa, σ represent gas-water interface tension force, and unit is that N/m, θ represent moisten contact angle, and unit is °, and r represents reservoir pore throat radius, and unit is m.

According to collected reservoir pore throat radius r data, reservoir rock rock gas wetting angle data, gas-water interface tension data under the formation condition determined in integrating step 300, determine capillary force Pc numerical value as shown in table 3 according to capillary force computing formula:

Table 3

Step 5: according to the hydrostatic force P determined in step 2 _w, and the capillary force P determined in step 4 _c, gas tension P under computing power equilibrium condition _e, concrete, can according to gas tension P under following formulae discovery dynamic balance condition _e:

P _e＝P _c+P _w

According to the hydrostatic force P calculated _wdata and capillary force data, according to gas tension P under dynamic balance condition _ecomputing formula can obtain gas expansion force data as shown in table 4:.

Table 4

Step 6: according to the formation temperature T collected in step 1 and pressure P data, determine gas deviation factor Z, wherein, gas deviation factor Z can be according to formation temperature T, pressure P data, corresponding gas deviation factor plate obtains.For Kuche Depression of Talimu Basin Jurassic In Eastern DAMAGE OF TIGHT SAND GAS RESERVOIRS, according to obtained formation temperature T, pressure P data, corresponding gas deviation factor plate reads and obtains gas deviation factor Z data as shown in table 5:

Table 5

Step 7: according to the formation temperature T collected in step 1, pressure P and rock gas amount of substance M data, and the gas deviation factor Z determined in step 6, calculate natural gas density ρ under formation condition _g, natural gas density ρ under formation condition can be obtained according to following formulae discovery _g:

${\mathrm{\ρ}}_g=\frac{\mathrm{PM}}{\mathrm{ZRT}}$

Wherein, ρ _grepresent natural gas density, unit is kg/m ³, P represents pressure residing for rock gas, and unit is that Mpa, M represent natural gas molecule amount, and unit is that kg/mol, T represent stratum absolute temperature, and unit is that K, Z represent gas deviation factor, and R represents universal gas constant, and general value is 0.008314Mpam ³/ (kmolK).

For Kuche Depression of Talimu Basin Jurassic In Eastern DAMAGE OF TIGHT SAND GAS RESERVOIRS, according to collected formation temperature, pressure data and natural gas molecule amount data, in conjunction with the gas deviation factor Z data obtained, according to natural gas density computing formula under formation condition, calculate the natural gas density ρ under Different Strata condition as shown in table 6 _g:

Table 6

Step 8: according to formation temperature T, the Effective source rocks thickness h collected in step 1 _s, gas tension P under the dynamic balance condition determined of factor of porosity Ф and rock gas amount of substance M data, step 5 _e, natural gas density ρ under the formation condition determined of the gas deviation factor Z that determines of step 6 and step 7 _g, calculate the critical venting intensity q of exhaust source rock _e, concrete, can according to the critical venting intensity q of following formulae discovery air feed source rock _e:

$q_e=\frac{10M{h}_s\mathrm{\Φ}{P}_e}{Z{\mathrm{\ρ}}_g\mathrm{RT}}$

Wherein, q _erepresent hydrocarbon source rock venting intensity, unit is m ³/ m ², M represents rock gas molal weight, and unit is kg/mol, h _srepresent the thickness of hydrocarbon source rock, unit is the factor of porosity that m, Φ represent hydrocarbon source rock, zero dimension, P _erepresent the gas tension under dynamic balance condition, unit is Mpa, ρ _grepresent natural gas density, unit is kg/m ³, Z represents gas deviation factor, and R represents universal gas constant, and general value is 0.008314Mpam ³/ (kmolK), T represents stratum absolute temperature, and unit is K.

For Kuche Depression of Talimu Basin Jurassic In Eastern DAMAGE OF TIGHT SAND GAS RESERVOIRS, according to the thickness h of the formation temperature T data obtained, rock gas amount of substance M data, hydrocarbon source rock _sdata and hydrocarbon source rock factor of porosity Ф data, in conjunction with gas tension P under the dynamic balance condition calculated _edata, natural gas density ρ _gthe compressibility factor Z of data and rock gas, calculates the critical venting intensity value of air feed source rock as shown in table 7 according to venting intensity computing formula:

Table 7

Can determine that critical venting intensity is 14.1 × 108m according to the numerical value in table 7 ³/ km ², thus the distribution range of the effective air feed source rock of Jurassic systerm Sandstone Gas Reservoir shown in Fig. 2 can be defined, thus provide good geologic condition for forming large-scale tight gas reservoir.

The quantitative defining method of the effective air feed of the DAMAGE OF TIGHT SAND GAS RESERVOIRS in this example source rock critical row hydrocarbon intensity, a difficult problem for effective air feed source rock distribution range quantitative forecast of DAMAGE OF TIGHT SAND GAS RESERVOIRS in petroliferous basin can be solved, establish DAMAGE OF TIGHT SAND GAS RESERVOIRS effective air feed source rock critical row's hydrocarbon quantification of intensities computation model, simultaneously can also go out the size of the critical venting intensity of the effective air feed of DAMAGE OF TIGHT SAND GAS RESERVOIRS in basin source rock by Accurate Prediction, and be effectively vented the distribution range of source rock, improve the exploration efficiency of compact sandstone gas, reduce the exploration risk of DAMAGE OF TIGHT SAND GAS RESERVOIRS, there is applicability widely.

Based on same inventive concept, additionally provide a kind of device determining the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock in the embodiment of the present invention, as described in the following examples.Owing to determining principle that the device of critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock deals with problems and to determine that DAMAGE OF TIGHT SAND GAS RESERVOIRS is vented the method for the critical venting intensity of source rock similar, therefore determine that the enforcement of the device of the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock see determining that DAMAGE OF TIGHT SAND GAS RESERVOIRS is vented the enforcement of the method for the critical venting intensity of source rock, can repeat part and repeating no more.Following used, term " unit " or " module " can realize the software of predetermined function and/or the combination of hardware.Although the device described by following examples preferably realizes with software, hardware, or the realization of the combination of software and hardware also may and conceived.Fig. 3 is a kind of structured flowchart of the device of the critical venting intensity of the determination DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock of the embodiment of the present invention, as shown in Figure 3, comprise: data acquisition module 301, hydrostatic force determination module 302, interfacial tension and compressibility factor determination module 303, capillary force determination module 304, gas tension determination module 305, natural gas density determination module 306 and critical venting intensity determination module 307, be described this structure below.

Data acquisition module 301, for obtaining the formation data of objective interval in DAMAGE OF TIGHT SAND GAS RESERVOIRS study area, wherein, described formation data comprises: stratum water colunm height, formation temperature, reservoir pressure, compact reservoir pore throat radius, local water density, reservoir rock rock gas wetting angle, Effective source rocks thickness, hydrocarbon source rock factor of porosity and rock gas amount of substance;

Hydrostatic force determination module 302, for according to described stratum water colunm height and local water density, determines stratum hydrostatic force;

Interfacial tension and compressibility factor determination module 303, for according to described formation temperature and reservoir pressure, determine the gas-water interface tension force under corresponding formation condition and gas deviation factor;

Capillary force determination module 304, for according to described compact reservoir pore throat radius and reservoir rock rock gas wetting angle, and the gas-water interface tension force determined, calculate capillary force;

Gas tension determination module 305, for according to the stratum hydrostatic force determined and capillary force, calculates the gas tension under dynamic balance condition;

Natural gas density determination module 306, for according to described formation temperature, reservoir pressure, rock gas amount of substance and the gas deviation factor determined, calculates the natural gas density under corresponding formation condition;

Critical venting intensity determination module 307, for according to gas tension, gas deviation factor, the natural gas density under described formation temperature, Effective source rocks thickness, hydrocarbon source rock factor of porosity, rock gas amount of substance and the dynamic balance condition that calculates, calculate the critical venting intensity of exhaust source rock.

In one embodiment, hydrostatic force determination module 302 is specifically for according to following formulae discovery stratum hydrostatic force:

P _w＝ρ _wgH

Wherein, P _wrepresent stratum hydrostatic force, g represents acceleration of gravity, and unit is kg/N, ρ _wrepresent local water density, unit is kg/m ³, H represents stratum water colunm height, and unit is m.

In one embodiment, interfacial tension and compressibility factor determination module 303 comprise: interfacial tension determining unit, for the nomogram version according to the methane gas-water interfacial tension under described formation temperature and formation condition corresponding to reservoir pressure, determine the gas-water interface tension force under corresponding formation condition; Compressibility factor determining unit, for according to described formation temperature and gas deviation factor plate corresponding to reservoir pressure, determines gas deviation factor.

In one embodiment, capillary force determination module 304 is specifically for according to following formulae discovery capillary force:

$P_c=\frac{2\mathrm{\σ}\cos \mathrm{\θ}}{r}$

Wherein, P _crepresent capillary force, unit is that Pa, σ represent gas-water interface tension force, and unit is that N/m, θ represent reservoir rock rock gas wetting angle, and unit is °, and r represents compact reservoir pore throat radius, and unit is m.

In one embodiment, gas tension determination module 305 is specifically for according to the gas tension under following formulae discovery dynamic balance condition:

P _e＝P _c+P _w

Wherein, P _erepresent gas tension, P _crepresent capillary force, P _wrepresent stratum hydrostatic force.

In one embodiment, natural gas density determination module 306 is specifically for according to the natural gas density under formation condition corresponding to following formulae discovery:

${\mathrm{\ρ}}_g=\frac{\mathrm{PM}}{\mathrm{ZRT}}$

Wherein, ρ _grepresent natural gas density, unit is kg/m ³, P represents reservoir pressure, and unit is that Mpa, M represent rock gas amount of substance, and unit is that kg/kmol, T represent formation temperature, and unit is that K, Z represent gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK).

In one embodiment, critical venting intensity determination module 307 is specifically for the critical venting intensity according to following formulae discovery exhaust source rock:

$q_e=\frac{10M{h}_s\mathrm{\Φ}{P}_e}{Z{\mathrm{\ρ}}_g\mathrm{RT}}$

Wherein, q _erepresent the critical venting intensity of exhaust source rock, unit is m ³/ m ², M represents rock gas amount of substance, and unit is kg/mol, h _srepresent Effective source rocks thickness, unit is that m, Φ represent hydrocarbon source rock factor of porosity, P _erepresent the gas tension under dynamic balance condition, unit is Mpa, ρ _grepresent natural gas density, unit is kg/m ³, Z represents gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK), T represents formation temperature, and unit is K.

In another embodiment, additionally provide a kind of software, this software is for performing the technical scheme described in above-described embodiment and preferred implementation.

In another embodiment, additionally provide a kind of storage medium, store above-mentioned software in this storage medium, this storage medium includes but not limited to: CD, floppy disk, hard disk, scratch pad memory etc.

From above description, can find out, the embodiment of the present invention achieves following technique effect: the defining method providing the critical venting intensity of a kind of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock, establish DAMAGE OF TIGHT SAND GAS RESERVOIRS effective air feed source rock critical row's hydrocarbon quantification of intensities computation model, simultaneously can go out the size of the critical venting intensity of the effective air feed of DAMAGE OF TIGHT SAND GAS RESERVOIRS in basin source rock by Accurate Prediction, thus solve the problem of the critical venting intensity quantitative forecast difficulty of the exhaust source rock of DAMAGE OF TIGHT SAND GAS RESERVOIRS in petroliferous basin in prior art, improve the exploration efficiency of compact sandstone gas, reduce the exploration risk of DAMAGE OF TIGHT SAND GAS RESERVOIRS.

Obviously, those skilled in the art should be understood that, each module of the above-mentioned embodiment of the present invention or each step can realize with general calculation element, they can concentrate on single calculation element, or be distributed on network that multiple calculation element forms, alternatively, they can realize with the executable program code of calculation element, thus, they can be stored and be performed by calculation element in the storage device, and in some cases, step shown or described by can performing with the order be different from herein, or they are made into each integrated circuit modules respectively, or the multiple module in them or step are made into single integrated circuit module to realize.Like this, the embodiment of the present invention is not restricted to any specific hardware and software combination.

The foregoing is only the preferred embodiments of the present invention, be not limited to the present invention, for a person skilled in the art, the embodiment of the present invention can have various modifications and variations.Within the spirit and principles in the present invention all, any amendment done, equivalent replacement, improvement etc., all should be included within protection scope of the present invention.

Claims (14)

1. determine a method for the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock, it is characterized in that, comprising:

Obtain the formation data of objective interval in DAMAGE OF TIGHT SAND GAS RESERVOIRS study area, wherein, described formation data comprises: stratum water colunm height, formation temperature, reservoir pressure, compact reservoir pore throat radius, local water density, reservoir rock rock gas wetting angle, Effective source rocks thickness, hydrocarbon source rock factor of porosity and rock gas amount of substance;

According to described stratum water colunm height and local water density, determine stratum hydrostatic force;

According to described formation temperature and reservoir pressure, determine the gas-water interface tension force under corresponding formation condition and gas deviation factor;

According to described compact reservoir pore throat radius and reservoir rock rock gas wetting angle, and the gas-water interface tension force determined, calculate capillary force;

According to the stratum hydrostatic force determined and capillary force, calculate the gas tension under dynamic balance condition;

According to described formation temperature, reservoir pressure, rock gas amount of substance and the gas deviation factor determined, calculate the natural gas density under corresponding formation condition;

According to gas tension, gas deviation factor, natural gas density under described formation temperature, Effective source rocks thickness, hydrocarbon source rock factor of porosity, rock gas amount of substance and the dynamic balance condition that calculates, calculate the critical venting intensity of exhaust source rock.

2. the method for claim 1, is characterized in that, according to described stratum water colunm height and local water density, determines stratum hydrostatic force, comprising:

According to following formulae discovery stratum hydrostatic force:

P _w＝ρ _wgH

Wherein, P _wrepresent stratum hydrostatic force, g represents acceleration of gravity, and unit is kg/N, ρ _wrepresent local water density, unit is kg/m ³, H represents stratum water colunm height, and unit is m.

3. the method for claim 1, is characterized in that, according to described formation temperature and reservoir pressure, determines the gas-water interface tension force under corresponding formation condition and gas deviation factor, comprising:

According to the nomogram version of the methane gas-water interfacial tension under described formation temperature and formation condition corresponding to reservoir pressure, determine the gas-water interface tension force under corresponding formation condition;

According to described formation temperature and gas deviation factor plate corresponding to reservoir pressure, determine gas deviation factor.

4. the method for claim 1, is characterized in that, according to described compact reservoir pore throat radius and reservoir rock rock gas wetting angle, and the gas-water interface tension force determined, calculate capillary force, comprising:

According to following formulae discovery capillary force:

$P_c=\frac{2\mathrm{\σ}\cos \mathrm{\θ}}{r}$

Wherein, P _crepresent capillary force, unit is that Pa, σ represent gas-water interface tension force, and unit is that N/m, θ represent reservoir rock rock gas wetting angle, and unit is °, and r represents compact reservoir pore throat radius, and unit is m.

5. the method for claim 1, is characterized in that, according to the stratum hydrostatic force determined and capillary force, calculates the gas tension under dynamic balance condition, comprising:

Gas tension according under following formulae discovery dynamic balance condition:

P _e＝P _c+P _w

Wherein, P _erepresent gas tension, P _crepresent capillary force, P _wrepresent stratum hydrostatic force.

6. the method for claim 1, is characterized in that, according to described formation temperature, reservoir pressure, rock gas amount of substance and the gas deviation factor determined, calculates the natural gas density under corresponding formation condition, comprising:

Natural gas density according under the formation condition that following formulae discovery is corresponding:

${\mathrm{\ρ}}_g=\frac{\mathrm{PM}}{\mathrm{ZRT}}$

Wherein, ρ _grepresent natural gas density, unit is kg/m ³, P represents reservoir pressure, and unit is that Mpa, M represent rock gas amount of substance, and unit is that kg/kmol, T represent formation temperature, and unit is that K, Z represent gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK).

7. the method according to any one of claim 1 to 6, it is characterized in that, according to gas tension, gas deviation factor, natural gas density under described formation temperature, Effective source rocks thickness, hydrocarbon source rock factor of porosity, rock gas amount of substance and the dynamic balance condition that calculates, calculate the critical venting intensity of exhaust source rock, comprising:

Critical venting intensity according to following formulae discovery exhaust source rock:

$q_e=\frac{10M{h}_s\mathrm{\Φ}{P}_e}{Z{\mathrm{\ρ}}_g\mathrm{RT}}$

Wherein, q _erepresent the critical venting intensity of exhaust source rock, unit is m ³/ m ², M represents rock gas amount of substance, and unit is kg/mol, h _srepresent Effective source rocks thickness, unit is that m, Φ represent hydrocarbon source rock factor of porosity, P _erepresent the gas tension under dynamic balance condition, unit is Mpa, ρ _grepresent natural gas density, unit is kg/m ³, Z represents gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK), T represents formation temperature, and unit is K.

8. determine a device for the critical venting intensity of DAMAGE OF TIGHT SAND GAS RESERVOIRS exhaust source rock, it is characterized in that, comprising:

Data acquisition module, for obtaining the formation data of objective interval in DAMAGE OF TIGHT SAND GAS RESERVOIRS study area, wherein, described formation data comprises: stratum water colunm height, formation temperature, reservoir pressure, compact reservoir pore throat radius, local water density, reservoir rock rock gas wetting angle, Effective source rocks thickness, hydrocarbon source rock factor of porosity and rock gas amount of substance;

Hydrostatic force determination module, for according to described stratum water colunm height and local water density, determines stratum hydrostatic force;

Interfacial tension and compressibility factor determination module, for according to described formation temperature and reservoir pressure, determine the gas-water interface tension force under corresponding formation condition and gas deviation factor;

Capillary force determination module, for according to described compact reservoir pore throat radius and reservoir rock rock gas wetting angle, and the gas-water interface tension force determined, calculate capillary force;

Gas tension determination module, for according to the stratum hydrostatic force determined and capillary force, calculates the gas tension under dynamic balance condition;

Natural gas density determination module, for according to described formation temperature, reservoir pressure, rock gas amount of substance and the gas deviation factor determined, calculates the natural gas density under corresponding formation condition;

Critical venting intensity determination module, for according to gas tension, gas deviation factor, the natural gas density under described formation temperature, Effective source rocks thickness, hydrocarbon source rock factor of porosity, rock gas amount of substance and the dynamic balance condition that calculates, calculate the critical venting intensity of exhaust source rock.

9. device as claimed in claim 8, is characterized in that, described hydrostatic force determination module is specifically for according to following formulae discovery stratum hydrostatic force:

P _w＝ρ _wgH

Wherein, P _wrepresent stratum hydrostatic force, g represents acceleration of gravity, and unit is kg/N, ρ _wrepresent local water density, unit is kg/m ³, H represents stratum water colunm height, and unit is m.

10. device as claimed in claim 8, it is characterized in that, described interfacial tension and compressibility factor determination module comprise:

Interfacial tension determining unit, for the nomogram version according to the methane gas-water interfacial tension under described formation temperature and formation condition corresponding to reservoir pressure, determines the gas-water interface tension force under corresponding formation condition;

Compressibility factor determining unit, for according to described formation temperature and gas deviation factor plate corresponding to reservoir pressure, determines gas deviation factor.

11. devices as claimed in claim 8, is characterized in that, described capillary force determination module is specifically for according to following formulae discovery capillary force:

$P_c=\frac{2\mathrm{\σ}\cos \mathrm{\θ}}{r}$

Wherein, P _crepresent capillary force, unit is that Pa, σ represent gas-water interface tension force, and unit is that N/m, θ represent reservoir rock rock gas wetting angle, and unit is °, and r represents compact reservoir pore throat radius, and unit is m.

12. devices as claimed in claim 8, is characterized in that, described gas tension determination module is specifically for according to the gas tension under following formulae discovery dynamic balance condition:

P _e＝P _c+P _w

Wherein, P _erepresent gas tension, P _crepresent capillary force, P _wrepresent stratum hydrostatic force.

13. devices as claimed in claim 8, is characterized in that, described natural gas density determination module is specifically for according to the natural gas density under formation condition corresponding to following formulae discovery:

${\mathrm{\ρ}}_g=\frac{\mathrm{PM}}{\mathrm{ZRT}}$

Wherein, ρ _grepresent natural gas density, unit is kg/m ³, P represents reservoir pressure, and unit is that Mpa, M represent rock gas amount of substance, and unit is that kg/kmol, T represent formation temperature, and unit is that K, Z represent gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK).

14. devices according to any one of claim 8 to 13, is characterized in that, described critical venting intensity determination module is specifically for the critical venting intensity according to following formulae discovery exhaust source rock:

$q_e=\frac{10M{h}_s\mathrm{\Φ}{P}_e}{Z{\mathrm{\ρ}}_g\mathrm{RT}}$

Wherein, q _erepresent the critical venting intensity of exhaust source rock, unit is m ³/ m ², M represents rock gas amount of substance, and unit is kg/mol, h _srepresent Effective source rocks thickness, unit is that m, Φ represent hydrocarbon source rock factor of porosity, P _erepresent the gas tension under dynamic balance condition, unit is Mpa, ρ _grepresent natural gas density, unit is kg/m ³, Z represents gas deviation factor, and R represents universal gas constant, and value is 0.008314Mpam ³/ (kmolK), T represents formation temperature, and unit is K.