CN102174888A - Method for processing formation data based on lithologic parameter of reservoir rock - Google Patents

Abstract

The invention provides a method for processing formation data based on the lithologic parameter of a reservoir rock, which belongs to the field of geophysical exploration and well logging evaluation and development of lithologic parameters of reservoir rocks and the formation data. The method comprises the following steps of: acquiring formation lithology and fluid information by using geological exploration and development equipment; analyzing the acquired formation lithology and fluid information by using analytical equipment to acquire a basic parameter required by the calculation of pore fluid volume of the reservoir rock; and establishing a petroleum volume and petroleum geological reserve calculation equation by selecting reservoir parameters such as corresponding porosity, oil saturation and the like. The method is suitable for evaluating reservoir rock petroleum resources with proved reserves, controlled reserves and predicted reserves, which belongs to the field of reserve calculation by a volume method. By a volume method reserve calculation equation established in the method, system errors caused by the original volume method reserve calculation formula are eliminated, so that the calculation accuracy of petroleum geological reserves is improved by 6 to 21 percent.

Description

A kind of formation data processing method based on the reservoir rock rock parameter

Technical field

The present invention relates to geophysical exploration and logging evaluation development approach, be specially a kind of formation data processing method, further obtain reservoir rock pore-fluid volume by handling based on the formation data of reservoir rock rock parameter to calculate based on the reservoir rock rock parameter.

Background technology

Oil is a kind of in the reservoir rock pore-fluid, and calculating petroleum-in-place has several different methods, and wherein the oil in place of Ji Suaning comprises and verifies oil in place, control oil in place and predict oil in place.Verify oil in place and be meant, after the evaluation probing confirms that oil reservoir can provide exploitation and can obtain economic benefit, estimate oil in place that try to achieve, that certainty is very big in the reservoir evaluation stage.In addition, estimate reservoir geology reserves scale is the technical barrier that oil field prospecting exploitation scientific and technical personnel will solve objective and accurately always.

Calculate the oil reservoir petroleum-in-place at present and mainly contain three kinds of methods: the one, volumetric method, the formula that provides according to " the petroleum gas reserves calculate standard " calculates the oil reservoir petroleum-in-place; The 2nd, dynamic method, by oil reservoir multidate information test analysis to the production certain phase, obtain various information and the formation temperature and the strata pressure information of formation pore fluid,, adopt the relevant art method to calculate the oil reservoir petroleum-in-place according to obtaining the Regularity Analysis of information; The 3rd, probabilistic method is obtained the oil reservoir petroleum-in-place by the geological information analysis of obtaining.

As everyone knows, probabilistic method determines that petroleum-in-place is mainly used in the prediction oil in place, and required precision is low, is of limited application; Dynamic method calculating oil reservoir petroleum-in-place requires the production dynamic data of oil reservoir can reflect the production capacity of whole oil reservoir, and the petroleum-in-place that calculates when oil reservoir is produced the middle and later periods is just representative.Volumetric method calculates its each later stage of each stage, particularly reservoir evaluation stage and phase that petroleum-in-place is applicable to exploration and development., the reserve calculation with volumetric method formula N=100A that for example in Chinese patent application CN101937108A, uses _oH φ S _Oi/ B _Oi, what it required calculating is theoretical static oil oil in place, but the petroleum-in-place N of its calculating is the actual petroleum-in-place of oil reservoir (100 φ/φ _t) % or (100S _Oi/ S _Oe) %, there is systematic error with actual petroleum-in-place." petroleum gas reserves calculate standard " are to make great efforts the achievement in research summed up for many years through experts and scholars, it also is the reservoir geology Reserves Evaluation technology that all is suitable in each stage of exploration and development, but find that in application still there are some problems in the petroleum reserves design formulas in the standard, need further improve, as stratum effecive porosity φ and initial oil saturation S _OiProduct and be not equal to oil percent by volume in the reservoir rock hole, multiply by oil area and effective pay thickiness again, also be not equal to the oil volume in the reservoir rock hole under the formation condition, but less than the oil volume in the reservoir rock hole; Owing to many reasons such as application habit and managerial periodicity, prolonging with this not perfect volumetric method petroleum-in-place design formulas at present always.

In sum, in order accurately to calculate the oil reservoir petroleum-in-place, need revise the reserve calculation with volumetric method formula that provides in the prior art, and then overcome the systematic error of the calculating petroleum-in-place that causes because of computational methods.

Summary of the invention

In order to solve the problem that exists in the top background technology, the present invention proposes a kind of formation data processing method based on the reservoir rock rock parameter, further obtains reservoir rock pore-fluid volume by handling based on the formation data of reservoir rock rock parameter to calculate.

Technical scheme according to the present invention proposes provides a kind of formation data processing method based on the reservoir rock rock parameter, and it may further comprise the steps:

1) utilizes geological exploration and development equipment, can gather formation lithology, pore-fluid and well logging information;

2), obtain the stratum total porosity φ of reservoir rock by the lithology data analytical equipment based on the formation lithology data that collect _t, stratum effecive porosity φ, irreducible water saturation S _Wi, effective water saturation S _We, effective irreducible water saturation S _WieWith water saturation S _w

3), obtain effective pay thickiness h and oil area A in conjunction with the lithology data analytical equipment based on pore-fluid that collects and well logging information _o

4), obtain original oil volume factor B by fluid analysis equipment based on the formation pore fluid information that collects _Oi

5) according in step 2) in the reservoir rock stratum total porosity φ of acquisition _t, stratum effecive porosity φ, irreducible water saturation S _Wi, effective water saturation S _We, effective irreducible water saturation S _WieWith water saturation S _w, obtain the oil percent by volume O in the reservoir rock hole _R(f of unit);

Wherein, O _RBe the oil percent by volume, refer to the voids volume that oil in the rock sample hole is occupied and the ratio of rock sample cumulative volume, the f of unit;

6) according to the oil percent by volume O that obtains _RWith effective pay thickiness h that in step 3), obtains (m of unit) and oil area A _o(the km of unit ²), obtain the oil volume V in the oil-containing reservoir rock hole _f(unit 10 ⁴m ³);

7) according to the oil volume V that obtains _fWith the original oil volume factor B that in step 4), obtains _Oi(zero dimension) obtains oil reservoir petroleum-in-place N ' (unit 10 ⁴m ³), petroleum-in-place N ' is respectively following several situation;

For net pay zone: N '=100A _oH φ _tS _Oi/ B _OiOr N '=100A _oH φ S _Oie/ B _Oi

For containing movable water oil reservoir: N '=100A _oH φ _tS _o/ B _OiOr N '=100A _oH φ S _Oe/ B _Oi

Preferably, oil percent by volume O _RBe respectively following situation:

Net pay zone is: O _R=φ t (1-S _Wi); Or O _R=φ (1-S _Wie); Or O _R=φ _tS _OiOr O _R=φ S _Oie

Containing movable water oil reservoir is: O _R=φ _t(1-S _w); Or O _R=φ (1-S _We); Or O _R=φ _tS _oOr O _R=φ S _Oe

Wherein, φ is stratum effecive porosity (referring to the active porosity volume of rock sample and the ratio of rock sample cumulative volume), the f of unit; φ _tBe stratum total porosity (referring to the total pore size volume of rock sample and the ratio of rock sample cumulative volume), the f of unit; S _OiBe corresponding stratum total porosity φ in net pay zone _tInitial oil saturation (in net pay zone, referring to the voids volume that rock sample PetroChina Company Limited. is occupied and the ratio of rock sample total pore size volume), and S is arranged _Oi=1-S _Wi, the f of unit; S _OieBe the effective initial oil saturation of corresponding stratum effecive porosity φ in net pay zone (in net pay zone, referring to the voids volume that rock sample PetroChina Company Limited. is occupied and the ratio of rock sample active porosity volume), and S is arranged _Oie=1-S _Wie, the f of unit; S _oBe corresponding stratum total porosity φ in containing movable water oil reservoir _tOil saturation (in containing movable water oil reservoir, referring to the voids volume that rock sample PetroChina Company Limited. is occupied and the ratio of rock sample total pore size volume), and S is arranged _o=1-S _w, the f of unit; S _OeBe the effective oil saturation of corresponding stratum effecive porosity φ in containing movable water oil reservoir (containing in the movable water oil reservoir, referring to the voids volume that rock sample PetroChina Company Limited. is occupied and the ratio of rock sample active porosity volume), and S is arranged _Oe=1-S _We, the f of unit.

More preferably, the oil volume V in the reservoir rock hole _fBe respectively following situation: be V during net pay zone _f=100A _oH φ _tS _OiOr V _f=100A _oH φ S _OieWhen containing movable water oil reservoir is V _f=100A _oH φ _tS _oOr V _f=100A _oH φ S _Oe

Use the formation data processing method based on the reservoir rock rock parameter of the present invention, utilize calculating reservoir rock pore-fluid volume to calculate the oil reservoir petroleum-in-place, realized objectivity and reasonability that reserves calculate.The present invention has eliminated the systematic error that original volumetric method reserves formula itself produces, and has improved and has verified the petroleum-in-place computational accuracy.

Brief Description Of Drawings

Fig. 1 is saturated sandstone reservoir formation degassed crude density and formation oil density relationship schematic diagram;

Fig. 2 be the original dissolved gas oil ratio of saturated sandstone oil reservoir with formation oil density relationship schematic diagram;

Fig. 3 is a unit physical model of bulk-volume rock schematic diagram;

Fig. 4 is that saturated sandstone oil reservoir volume factor and original dissolved gas oil ratio concern schematic diagram.

The specific embodiment

According to a kind of formation data processing method of the present invention based on the reservoir rock rock parameter, utilize calculating reservoir rock pore-fluid volume to calculate the oil reservoir petroleum-in-place, have advantage objective, reasonable, system error-free.This formation lithology, pore-fluid information gathering processing method and stratum well logging information mainly obtain based on following fact research.

Under identical geology reservoir, utilize stratum effecive porosity and effective oil saturation (or effective initial oil saturation), or the oil volume that utilizes stratum total porosity and initial oil saturation (or oil saturation) to calculate in the reservoir rock hole is constant.That is to say at a certain oil reservoir, no matter adopt the stratum effecive porosity still to adopt the stratum total porosity to calculate petroleum-in-place, as long as oil saturation of selecting for use and formation porosity are complementary, the petroleum-in-place of calculating is invariable.

The present invention adopts following technical scheme to calculate the oil reservoir petroleum-in-place, and promptly a kind of formation data processing method based on the reservoir rock rock parameter utilizes calculating reservoir rock pore-fluid volume to calculate the oil reservoir petroleum-in-place, and it may further comprise the steps:

1) utilizes geological exploration and development equipment, can gather formation lithology, pore-fluid and well logging information;

2), obtain stratum total porosity, stratum effecive porosity, irreducible water saturation, effective water saturation, effective irreducible water saturation and the water saturation of reservoir rock by the lithology data analytical equipment based on the formation lithology data that collect;

3), obtain effective pay thickiness and oil area in conjunction with the lithology data analytical equipment based on pore-fluid that collects and well logging information;

4) based on the formation pore fluid information that collects, obtain original oil volume factor by fluid analysis equipment;

5) according in step 2) in the reservoir rock stratum total porosity, stratum effecive porosity, irreducible water saturation, effective water saturation, effective irreducible water saturation and the water saturation that obtain, obtain the oil percent by volume in the reservoir rock hole;

In net pay zone:

O _R＝φ _t(1-S _wi) (1)

Or O _R=φ (1-S _Wie) (2)

Or O _R=φ _tS _Oi(3)

Or O _R=φ S _Oie(4)

In containing movable water oil reservoir:

O _R＝φ _t(1-S _w) (5)

Or O _R=φ (1-S _We) (6)

Or O _R=φ _tS _o(7)

Or O _R=φ S _Oe(8)

O in the formula _R-oil percent by volume (referring to the voids volume that oil in the rock sample hole is occupied and the ratio of rock sample cumulative volume), f; φ-stratum effecive porosity (referring to the active porosity volume of rock sample and the ratio of rock sample cumulative volume), f; φ _t-stratum total porosity (referring to the total pore size volume of rock sample and the ratio of rock sample cumulative volume), f; S _Oi-corresponding stratum total porosity φ in net pay zone _tInitial oil saturation, S _Oi=1-S _W1, f; S _Oie-effective initial oil saturation of corresponding stratum effecive porosity φ in net pay zone, S _Oie=1-S _Wie, f; S _o-corresponding stratum total porosity φ in containing movable water oil reservoir _tOil saturation, S _o=1-S _w, f; S _Oe-effective oil saturation of corresponding stratum effecive porosity φ in containing movable water oil reservoir, S _Oe=1-S _We, f.

6) according to the oil percent by volume O that obtains above _R(unit, f) and effective pay thickiness h that in step 3), obtains (m of unit) and oil area A _o(the km of unit ²), obtain the oil volume V in the oil-containing reservoir rock hole _f(unit 10 ⁴m ³);

In net pay zone:

V _f＝100A _ohφ _tS _oi (9)

Or V _f=100A _oH φ S _Oie(10)

In movable water oil reservoir:

V _f＝100A _ohφ _tS _o (11)

Or V _f=100A _oH φ S _Oe(12)

7) according to the oil volume V that obtains above _f(unit 10 ⁴m ³)) and the original oil volume factor B that in step 4), obtains _Oi(zero dimension) obtains oil reservoir petroleum-in-place N ' (unit 10 ⁴m ³);

In net pay zone:

N′＝100A _ohφ _tS _oi/B _oi (13)

Or N '=100A _oH φ S _Oie/ B _Oi(14)

In movable water oil reservoir:

N′＝100A _ohφ _tS _o/B _oi (15)

Or N '=100A _oH φ S _Oe/ B _Oi(16)

In order further to describe technical scheme of the present invention in detail, it is a kind of formation data processing method based on the reservoir rock rock parameter, utilize calculating reservoir rock pore-fluid volume to calculate the oil reservoir petroleum-in-place, describe formation lithology, pore-fluid and the well logging information relevant parameter how to obtain adopting among the present invention below in detail.But explanation and explanation to various relevant parameters below it will be apparent to those skilled in the art that only are exemplary; It is not desired to limit the invention to specific embodiment, those skilled in the art also can pass through creative work, obtain reservoir rock stratum total porosity, stratum effecive porosity, irreducible water saturation, effective irreducible water saturation, effective water saturation, water saturation, oil area, effective pay thickiness and original oil volume factor etc. by other approach.

1 formation parameter

1.1 rock porosity (or being called ground degree of porosity or rock stratum degree of porosity or formation porosity)

Rock porosity divides effecive porosity and total porosity, and effecive porosity is meant the active porosity volume of rock sample and the ratio of rock sample cumulative volume; Total porosity is meant the total pore size volume of rock sample and the ratio of rock sample cumulative volume.Effecive porosity comprises ground effecive porosity and stratum effecive porosity again; Total porosity comprises ground total porosity and stratum total porosity again.

(1) stratum total porosity φ _t

For consolidated rock, can directly adopt rock core pore compressibility sample analysis result to determine the stratum total porosity; Also can ask for the stratum total porosity according to the sound wave formation factor equation that people such as J.P.Martin in 1986 propose:

${\mathrm{\φ}}_t=1-{\left(\frac{{\mathrm{\Δt}}_{\mathrm{ma}}}{\mathrm{\Δt}}\right)}^{1/x}---\left(17\right)$

In the formula: φ _t-stratum total porosity, f; Δ t-well logging sonic differential time, μ s/m; Δ t _Ma-skeleton the time difference, μ s/m; The x-lithology factor.

According to the limited core analysis stratum total porosity φ of consolidated rock _tWith the actual measurement interval transit time Δ t of correspondence, try to achieve skeleton time difference Δ t by (17) formula distortion back recurrence _MaWith lithology factor x.

logΔt＝logΔt _ma-xlog(1-φ _t) (18)

According to interval transit time Δ t, calculate the stratum total porosity φ of consolidated rock by (17) formula again _t

For loose rock, the ground total porosity φ of lab analysis _aNeed proofread and correct and be the stratum total porosity, the degree of porosity correction equation after the branch lithology is respectively:

Granule shape sandstone:

φ _t＝φ _a[0.381+0.619(P _e+1) ^-0?1628] (19)

The seriate sandstone:

φ _t＝φ _a[0.381+0.619(P _e+1)- ^0?1169] (20)

In-gritstone:

φ _t＝φ _a[0.381+0.619(P _e+1) ^-0?0907] (21)

In-packsand:

φ _t＝φ _a[0.381+0.619(P _e+1) ^-0?0675] (22)

Packsand:

φ _t＝φ _a[0.381+0.619(P _e+1) ^-0?0481] (23)

Powder-packsand:

φ _t＝φ _a[0.381+0.619(P _e+1) ^-0?0298] (24)

Clean overburden pressure P _e(units MPa) be buried depth D per sample, is tried to achieve by following formula:

P _e＝0.01Dρ _b-P _f (25)

ρ in the formula _b-go up overlying strata stone averag density, get 2.30g/cm ³P _f-actual measurement formation pore fluid pressure, MPa.

Loose rock adopts (19)～(25) formula can try to achieve stratum total porosity φ _t

(2) stratum effecive porosity φ

Adopting the degree of porosity of kerosene method analysis in the laboratory is the ground effecive porosity.For consolidated rock, the stratum effecive porosity can adopt the pore compressibility result of core analysis directly to calculate petroleum-in-place; For loose rock, the ground effecive porosity needs to ask for stratum effecive porosity φ by following equation form recurrence after pore compressibility research:

φ＝A+Bφ _e (26)

In the formula: A, B-regression coefficient; φ _e-lab analysis ground effecive porosity, f.

1.2 oil saturation

Oil saturation divides effective oil saturation and initial oil saturation, and initial oil saturation is meant the voids volume that rock sample PetroChina Company Limited. is occupied and the ratio of rock sample total pore size volume; Effectively oil saturation is meant the voids volume that rock sample PetroChina Company Limited. is occupied and the ratio of rock sample active porosity volume.

(1) initial oil saturation

The relation of initial oil saturation and irreducible water saturation:

S _oi＝1-S _wi (27)

The initial oil saturation utilization presses the mercury data to ask for.At first utilize J (S _w) function classifies to capillary pressure curve and average:

$J\left(S_w\right)=\frac{P_c}{\mathrm{\σ}\cos \mathrm{\θ}}\sqrt{\frac{K}{\mathrm{\φ}}}---\left(28\right)$

In the formula: σ, θ and P _c-be respectively interfacial tension, contact angle and capillary pressure in the laboratory; K-sandstone permeability, mD; φ-stratum effecive porosity, f.

J (S _w) function determines the concrete steps of initial oil saturation:

The first step is calculated the C value of every sample.

For the capillary pressure curve of a certain sample, σ, cos θ, K and φ are constant.Be convenience of calculation, making the constant term in (28) formula is C, that is:

$C=0.086\sqrt{\frac{K}{\mathrm{\φ}}}---\left(29\right)$

Second step, the J (S of each pressure tap of calculating rock sample _w) functional value.

J(S _w)＝CP _c (30)

The 3rd step, the average mercury saturation ratio in statistics different saturation interval, average J (S _w) function and average pressure data.

In the 4th step, represent J (S with ordinate _w) function, abscissa is represented mercury saturation ratio S _Hg, J (S on the point _w) idea.

If idea is concentrated, illustrate that these samples belong to a kind of pore structure type, can comprehensively be a J (S who represents such reservoir _w) function curve.

The 5th goes on foot, and asks for the average capillary pressure curve of such reservoir.

The mean permeability of known such reservoir and average pore, (29) formula of utilization is calculated on average

Then with J (S _w) J (S of arbitrary mercurous saturation ratio correspondence on the function curve _w) on duty with on average

The inverse of value can obtain the corresponding average capillary pressure value of this point And then draw the average capillary pressure curve of such reservoir.

${\stackrel{\‾}{P}}_c=\frac{1}{\stackrel{\‾}{C}}J\left(S_w\right)---\left(31\right)$

In the 6th step, the average capillary pressure curve under the laboratory condition is scaled capillary pressure curve under the reservoir condition.

The capillary pressure curve of in the laboratory, measuring, though the sample that uses is actual rock core, but non-wetting phase and wetting phase fluid can not directly adopt the fluid under the reservoir condition, and the fluid boundary tension force of various combination is different with moisten contact angle, and the capillary pressure that records also has nothing in common with each other.Therefore the capillary pressure curve that no matter adopts oil-water or that system of mercury-air to record when calculating initial oil saturation, must be proofreaied and correct and is the average capillary pressure curve under the reservoir condition.

Laboratory capillary pressure expression formula and oil reservoir capillary pressure expression formula are respectively:

$P_c=\frac{2\mathrm{\σ}\cos \mathrm{\θ}}{r}---\left(32\right)$

$P_{\mathrm{cR}}=\frac{{2\mathrm{\σ}}_R\cos {\mathrm{\θ}}_R}{r}---\left(33\right)$

In the formula: σ, θ and P _c-be respectively interfacial tension, contact angle and capillary pressure in the laboratory; σ _R, θ _RAnd P _CR-be respectively interfacial tension, contact angle and capillary pressure under the reservoir condition.

Get by (32), (33) formula simultaneous:

$P_{\mathrm{cR}}=\frac{{\mathrm{\σ}}_R\cos {\mathrm{\θ}}_R}{\mathrm{\σ}\cos \mathrm{\θ}}{P}_c---\left(34\right)$

Parameter (table 1 is interfacial tension, contact angle experiments chamber analysis results) substitution (34) formula of lab analysis is got:

$P_{\mathrm{cR}}=\frac{P_c}{15.8403}---\left(35\right)$

Table 1 interfacial tension, contact angle experiments chamber analysis results

In the 7th step, the capillary pressure under the reservoir condition is scaled oil column height.

The capillary pressure of oil reservoir is come balance by the gravitational difference of profit, and capillary pressure can be expressed as:

P _cR＝10 ^-3H(ρ _wf-ρ _of)g (36)

In the formula: the above height of the table of H-oil reservoir, m; G-acceleration of gravity, 9.80m/s ²

To get after the simplification of (36) formula:

$H=\frac{102.0408P_{\mathrm{cR}}}{{\mathrm{\ρ}}_{\mathrm{wf}}-{\mathrm{\ρ}}_{\mathrm{of}}}---\left(37\right)$

In the formula: P _CR-oil reservoir capillary pressure, MPa; ρ _Wf, ρ _Of-be respectively reservoir condition sub-surface water density and formation oil density, g/cm ³

In the 8th step, ask for initial oil saturation.

(35) formula substitution (37) formula is got:

$H=\frac{6.4418P_c}{{\mathrm{\ρ}}_{\mathrm{wf}}-{\mathrm{\ρ}}_{\mathrm{of}}}---\left(38\right)$

Initial oil saturation and oil reservoir height relationships be can obtain by (38) formula and the average capillary pressure curve of oil reservoir, and then initial oil saturation and irreducible water saturation under the different oil reservoir height tried to achieve.Formation oil density p in the following formula _OfWith the formation water density p _WfAdopt following method to ask for.

1) formation oil density calculation method

Formation oil density is meant under the prime stratum condition, the quality (g/cm of unit volume oil ³).

The data of having enrolled according to Rate in Liaohe Oil-bearing Area are converted to stratum degassed crude density under the formation temperature with stock tank oil density, thereby make formation oil density and stratum degassed crude density have unified contrast basis, have improved the correlation of statistical analysis.Different geology reservoir sub-surface oil density statistic equations have been set up respectively.

Saturated sandstone reservoir formation oil density statistic equation (Fig. 1 be saturated sandstone reservoir formation degassed crude density and formation oil density relationship schematic diagram, Fig. 2 for the original dissolved gas oil ratio of saturated sandstone oil reservoir with formation oil density relationship schematic diagram)

ρ _of＝1.7527ρ _ot-0.7298，n＝280，r＝0.9380 (39)

ρ _of＝1.3486-0.3116logR _si，n＝280，r＝0.9962 (40)

The preceding the 3rd is and height coagulates oily undersaturated oil pool formation oil density p _OfStatistic equation:

ρ _of＝0.7997ρ _ot+0.1855，n＝44，r＝0.90896 (41)

The stratum degassed crude density p in (39) formula and (41) formula wherein _Ot(referring to formation temperature t) is degassed crude density p during by 20 ℃ of Ground analysis _oAsk for:

ρ _ot＝ρ _o+(13.560-0.191ξ)×10 ^-3-(63.900-0.870ξ)×10 ^-5t ¹⁰² (42)

ξ＝INT[100(ρ _o-0.8001)] (43)

2) formation water density calculation method

Adopt S-K series equation to calculate the formation water density p _Wf:

${\mathrm{\ρ}}_{\mathrm{wf}}^{\′}=1.02238-2.959\×{10}^{-4}t+5.10\×{10}^{-4}{P}_i-\frac{3.30707+3.3620\×{10}^{-3}{P}_i}{200-t}---\left(44\right)$

When SC≤12964.28mg/L:

ρ _wf＝1.00249ρ′ _wf+1.3094×10 ^-6S·C-4.7710×10 ^-7ρ′ _wfS·C-0.00236 (45)

When SC＞12964.28mg/L:

ρ _wf＝1.02827ρ′ _wf+5.3106×10 ^-8S·C+6.3135×10 ^-7ρ′ _wfS·C-0.02376 (46)

Work as Cl ^-1During≤8000mg/L:

ρ _wf＝1.00249ρ′ _wf+2.1219×10 ^-6Cl ^-1-7.7316×10 ^-7ρ′ _wfCl--0.00236 (47)

Work as Cl ^-1During＞8000mg/L:

ρ _wf＝1.64215ρ′ _wf-8.6060×10 ^-8Cl ^-1-1.0231×10 ^-6ρ′ _wfCl ^-+0.02788 (48)

Formation water salinity SC in the formula (mg/L of unit) is a measured value; ρ ' _WfBe the pure water density (g/cm of unit ³); Cl ^-1Be chlorine ion concentration (mg/L of unit); Formation temperature t (unit ℃) calculates according to the statistic equation that the actual measurement formation temperature of research area and vertical depth D (m of unit) set up; Strata pressure P _i(units MPa) is the statistic equation calculating according to Measured formation pressure and vertical depth D foundation.

$t=10+\frac{3.2D}{100}---\left(49\right)$

P _i＝a+bD (50)

A, b are regression coefficients in the formula.

(2) effective oil saturation

Effectively oil saturation and effective water saturation relational expression are:

S _oe＝1-S _we (51)

Ask for effective oil saturation according to the initial oil saturation and the relational expression of effective oil saturation.

Reservoir rock oil-containing volume is meant to have the oil-containing reservoir rock cumulative volume that commercial production is worth, and is the product of oil area and effective pay thickiness; And the oil volume is meant the occupied voids volume of oil-containing reservoir rock PetroChina Company Limited. under formation condition.The ratio of oil volume and original oil volume factor is the petroleum-in-place under the degassing phase of ground.

Can derive the relation equation between formation pore PetroChina Company Limited. volume and stratum total porosity, stratum effecive porosity and corresponding saturation ratio by unit physical model of bulk-volume rock (Fig. 3 is a unit physical model of bulk-volume rock schematic diagram), derivation is as follows:

V _ma＝V _sma+V _shma (52)

V _p＝V _shwi+V _swi+V _sb+V _sf (53)

V＝V _ma+V _p＝1 (54)

V-unit's rock volume in the formula, V=1m ³V _Ma-unit rock matrix volume, m ³V _p-unit rock pore volume, m ³V _Shma-unit rock shale skeleton volume, m ³V _Sma-unit rock sandstone skeleton volume, m ³V _ShwiFluid volume in-unit rock shale or the clay, m ³V _SwiVBW beyond the-unit rock shale in the invalid hole, m ³V _SbFilm water volume in the effective pore throat of-unit rock, m ³V _SfMovable fluid volume in the effective pore throat of-unit rock, m ³V _fOil volume under the-formation condition, m ³

According to the unit physical model of bulk-volume rock,, set up stratum total porosity φ in conjunction with the degree of porosity definition _tWith stratum effecive porosity φ theoretical expression:

${\mathrm{\φ}}_t=\frac{V_p}{V}---\left(55\right)$

$\mathrm{\φ}=\frac{V_{\mathrm{sb}}+V_{\mathrm{sf}}}{V}---\left(56\right)$

For net pay zone, with stratum total porosity φ _tCorresponding irreducible water saturation S _WiTheoretical expression, and with initial oil saturation S _OiTheoretical relationship be:

$S_{\mathrm{wi}}=\frac{V_{\mathrm{shwi}}+V_{\mathrm{swi}}+V_{\mathrm{sb}}}{V_p}---\left(57\right)$

S _oi＝1-S _wi (58)

Can derive corresponding net pay zone oil percent by volume O according to stratum total porosity and initial oil saturation _R(f of unit):

$O_R=\frac{V_{\mathrm{sf}}}{V}={\mathrm{\φ}}_t(1-S_{\mathrm{wi}})---\left(59\right)$

For net pay zone, the effective irreducible water saturation S corresponding with the stratum effecive porosity _WieTheoretical expression, and with effective initial oil saturation S _OieTheoretical relationship be:

$S_{\mathrm{wie}}=\frac{V_{\mathrm{sb}}}{V_{\mathrm{sb}}+V_{\mathrm{sf}}}---\left(60\right)$

S _oie＝1-S _wie (61)

According to stratum effecive porosity φ and effective initial oil saturation S _OieCan derive corresponding net pay zone oil percent by volume:

$O_R=\frac{V_{\mathrm{sf}}}{V}=\mathrm{\φ}(1-S_{\mathrm{wie}})---\left(62\right)$

Get net pay zone stratum total porosity φ by (58), (59), (61), (62) formula simultaneous _tWith stratum effecive porosity φ theoretical relationship:

φ _t(1-S _wi)＝φ(1-S _wie) (63)

Or φ _tS _Oi=φ S _Oie(64)

For containing movable water oil reservoir, with stratum total porosity φ _tCorresponding water saturation S _wExpression formula, and with oil saturation S _oWith mobile water saturation S _WfThe theoretical relationship of equisaturation parameter is:

$S_w=\frac{V_{\mathrm{shwi}}+V_{\mathrm{swi}}+V_{\mathrm{sb}}+V_{\mathrm{wf}}}{V_p}---\left(65\right)$

S _o＝1-S _w (66)

S _w＝S _wi+S _wf (67)

S _o＝S _oi-S _wf (68)

Oil saturation S in the formula _oThe chamber core analysis is directly obtained by experiment.

According to stratum total porosity φ _tWith oil saturation S _oCan derive correspondence and contain movable water oil reservoir oil percent by volume:

$O_R=\frac{V_{\mathrm{sf}}-V_{\mathrm{wf}}}{V}={\mathrm{\φ}}_t(1-S_w)---\left(69\right)$

For containing movable water oil reservoir, the effective water saturation S corresponding with stratum effecive porosity φ _WeThe definition, and with effective oil saturation S _OeWith effective mobile water saturation S _WfeThe theoretical relationship of equisaturation parameter is:

$S_{\mathrm{we}}=\frac{V_{\mathrm{sb}}+V_{\mathrm{wf}}}{V_{\mathrm{sb}}+V_{\mathrm{sf}}}---\left(70\right)$

S _we+S _oe＝1 (71)

S _we＝S _wie+S _wfe (72)

S _oe＝S _oie-S _wfe (73)

Can derive correspondence according to the stratum effecive porosity with effective oil saturation and contain movable water oil reservoir oil percent by volume:

$O_R=\frac{V_{\mathrm{sf}}-V_{\mathrm{wf}}}{V}=\mathrm{\φ}(1-S_{\mathrm{we}})---\left(74\right)$

Must contain movable water oil reservoir stratum total porosity φ by (66), (69), (71), (74) formula simultaneous _tWith stratum effecive porosity φ theoretical relationship:

φ _t(1-S _w)＝φ(1-S _we) (75)

Or φ _tS _o=φ S _Oe(76)

1.3 effective pay thickiness

(1) the effective thickness standard is determined

Formulate oil reservoir division and interlayer deduction standard respectively; Based on core analysis data and well log interpretation data, test data is a foundation, research lithology, rerum natura, electrically with the oiliness relation after, determine lithology, rerum natura, electrical lower limit standard that its effective thickness is divided; The a plurality of small-sized oil reservoir that reservoir characteristic and fluid properties are close can be formulated unified standard respectively; Using contiguous oil reservoir lower limit standard should prove the analogy foundation and indicate list of references; Effective thickness standard plate coincidence rate is greater than 80%.

(2) effective thickness is divided

When dividing effective thickness, tackle relevant log and carry out necessary wellbore environment (as well radius variations, the mud intrusion etc.) correction and the normalized of different logging programs with the well log interpretation data; When dividing effective thickness with the core analysis data, the oil gas interval should be got the total rock heart, and yield rate is not less than 80%; The thickness of starting at of effective thickness is 0.2～0.4m, and it is 0.2m that interlayer plays button thickness.

(3) computing unit effective thickness value

Calculated reserves need obtain the effective pay thickiness of representing the reserves computing unit.Computing unit effective pay thickiness obtaining value method is relevant with the well point distribution situation with the oil field geologic condition.Conclude and get up to have two kinds of methods: arithmetic average and area balance.

1) arithmetic mean of instantaneous value

The exploration and development district of well point distribution uniform, reserves computing unit effective pay thickiness adopts arithmetic mean of instantaneous value:

$\stackrel{\‾}{h}=\frac{1}{n}\underset{k=1}{\overset{n}{\mathrm{\Σ}}}{h}_k---\left(77\right)$

In the formula

Computing unit effective thickness average, m; h _kThe effective pay thickiness of-Di k mouth well, m; N-computing unit well number, mouthful.

2) area trade-off value

Evaluation probing pockety district, well point, effective pay thickiness adopts the area trade-off value, divides following two kinds of forms:

1. isopleth area balance

Core intersection between Jiang Jing and the well is considered as linear change, adopts method of linear interpolation to draw the effective pay thickiness isopleth map.

$\stackrel{\‾}{h}=\left\{\underset{i=1}{\overset{l}{\mathrm{\Σ}}}{A}_i\left(\frac{h_i+h_{i+1}}{2}\right)\right\}/\underset{i=1}{\overset{l}{\mathrm{\Σ}}}{A}_i---\left(78\right)$

A in the formula _iOil area between-Di i bar and i+1 bar isopleth, km ²h _i, h _I+1The effective pay thickiness of-Di i bar and i+1 bar isopleth, m.

2. well point area balance

The basis of this method is: the single well-controlled area is that this well is to the interior area of offset well distance 1/2nd scopes, the area size that each well can be controlled changes and different with well spacing, and the effective pay thickiness of chance that every mouthful of well bores is represented the effective pay thickiness in this well control system area.

Specific practice: at first contiguous well point is linked to be the triangulation network successively, gets the single well-controlled oil area of perpendicular bisector (obtuse triangle the is got the mid point line) division of acute triangle then.Water to oil area thickness is got offset well thickness partly, and adjacent oil well thickness is got partly to oil well distance 1/2nd places in the lithology border, and the average effective pay thickiness of single oil area and core intersection stability region is got well point area trade-off value, and design formulas is:

$\stackrel{\‾}{h}=\left(\underset{k=1}{\overset{n}{\mathrm{\Σ}}}{A}_k{h}_k\right)/\underset{k=1}{\overset{n}{\mathrm{\Σ}}}{A}_k---\left(79\right)$

A in the formula _kThe oil area of-Di k mouth well control system, km ²

1.4 oil area

The oil area of developed proven reserves is comprehensively drawn a circle to approve according to producing well static state and dynamic data.

The oil area of undeveloped proven reserves, definite need on various borders reach following condition:

1) in order to the fluid boundary of delineation oil area, should be through well logging or test data, the drilling and coring delivery data confirms, or the pressure test data is determined reliably.

2) do not find out the oil reservoir of fluid boundary, minimum oil-yielding stratum (or the well section) circle, the end that should confirm with test, the effective thickness aggregate-value or concentrate section highly extrapolation draw a circle to approve oil area.

3) oil reservoir tomography (or stratum) blocks the border, should push up the outer oil bondary delineation oil area that (end) face and tomography (or stratigraphic unconformity) face intersect with oil reservoir.

4) oil reservoir lithology (or rerum natura) is blocked the border, with effective thickness zero line or permeable reservoir strata relative contour delineation oil area; The calculating line is drawn in 1～1.5 times of extrapolation with the development well distance when not finding out the border.

5) under conditions such as reservoir thickness and buried depth, the fluid boundary and the lithology border of the prediction of high resolution seismic interpretation when the drilling data constrained interpretation, can be used as the foundation of delineation oil area.

6) in the oil bondary of determining, limit portion oil well to the distance of oil bondary greater than 3 times of development wells apart from the time, can draw a calculating line according to 1～1.5 times of extrapolation of oil reservoir development well spacing.

1.5 original oil volume factor

Original oil volume factor B _OiBe meant the oil volume V under the prime stratum condition _f(the m of unit ³) with the ground standard condition under degassed crude volume V _s(the m of unit ³) the ratio:

$B_{\mathrm{oi}}=\frac{V_f}{V_s}---\left(80\right)$

Determine that the computing unit oil volume factor has three kinds of methods:

The one, sampling analysis method, this is the most accurate, effective method, but most computing units all are difficult to realize.

The 2nd, analogy method, by with relevant parameter analogy analyses such as the geological conditions of known oil reservoir and oil property, directly select the original oil volume factor of similar oil reservoir, this method is more suitable in undersaturated reservoir and specific type oil reservoir, and saturated pool also is suitable for certainly.

The 3rd, the empirical equation computing method, this method is not suitable for the specific type oil reservoir.

Rate in Liaohe Oil-bearing Area is analyzed data according to the crude oil high pressure property of the hundreds of mouthfuls of wells of having enrolled, and branch lithology, subregion band have been set up the oil volume factor statistic equation.

1. the saturated sandstone oil reservoir oil volume factor of Rate in Liaohe Oil-bearing Area B _OiStatistic equation:

$B_{\mathrm{oi}}=1+0.01176{\mathrm{\ρ}}_o^{-1622}+0.01589{\left(\frac{D}{1000}\right)}^{327},n=292,r=0.9645---\left(81\right)$

2. Rate in Liaohe Oil-bearing Area the preceding the 3rd is undersaturated oil pool oil volume factor B _OiStatistic equation:

$B_{\mathrm{oi}}=1+0.00169{\mathrm{\ρ}}_o^{-1769}+0.01894{\left(\frac{D}{100}\right)}^{193},n=46,r=0.9107---\left(82\right)$

3. western sag buried hill (Pt, Ar) oil reservoir oil volume factor B _OiStatistic equation:

$B_{\mathrm{oi}}=1+0.00073{\mathrm{\ρ}}_o^{-204465}+0.003306{\left(\frac{D}{1000}\right)}^{4287},n=22,r=0.9523---\left(83\right)$

4. the big people collect depression buried hill (Pt, Ar) oil reservoir oil volume factor B _OiStatistic equation:

$B_{\mathrm{oi}}=1+0.00201{\mathrm{\ρ}}_o^{-204465}+0.000707{\left(\frac{D}{1000}\right)}^{4287},n=15,r=0.9544---\left(84\right)$

5. the saturated sandstone oil reservoir volume factor of Rate in Liaohe Oil-bearing Area B _OiWith original dissolved gas oil ratio R _SiStatistic equation (Fig. 4 is that saturated sandstone oil reservoir volume factor and original dissolved gas oil ratio concern schematic diagram):

R _si＝321(B _oi-1) ^1?02，n＝307，r＝0.9868 (85)

6. Rate in Liaohe Oil-bearing Area the preceding the 3rd is undersaturated oil pool volume factor B _OiWith original dissolved gas oil ratio R _SiStatistic equation:

R _si＝280(B _oi-1) ^1?02，n＝43，r＝0.9524 (86)

2 oil volumes and petroleum-in-place calculate

2.1 the oil volume V in the reservoir rock hole _f(unit 10 ⁴m ³)

Oil volume in the net pay zone reservoir rock hole:

V _f＝100A _ohφ _tS _oi

Or V _f=100A _oh _φS _Oie

Contain the oil volume in the movable water oil reservoir reservoir rock hole:

V _f＝100A _ohφ _tS _o

Or V _f=100A _oH φ S _Oe

2.2 ground degassed oil oil in place N '

Net pay zone petroleum-in-place accounting equation:

N′＝100A _ohφ _tS _oi/B _oi

Or N '=100A _oH φ S _Oie/ B _Oi

Contain movable water oil reservoir petroleum-in-place accounting equation:

N′＝100A _ohφ _tS _o/B _oi

Or N '=100A _oH φ S _Oe/ B _Oi

Method described in the technical solution of the present invention, through the real data checking, obtained obvious effects, be specially: above-mentioned serial reserve calculation with volumetric method equation is after ten reserves in Liaohe Oil Field calculate unit application, effect is remarkable, makes to verify the oil in place computational accuracy improving 6%～21% on original basis.Following illustrative example is illustrated.

Example

Rate in Liaohe Oil-bearing Area preferred the proved reserves computing unit in 10 different aperture degree, saturation ratio interval, and according to degree of porosity, the saturation data of actual analysis, adopt the present invention and original volumetric method reserves formula to calculate proved reserves, its relative error is-6.0%～-21.3%, average out to-11.0% (table 2) belongs to systematic error.

The interval oil in place error analysis of calculating of table 2 different aperture degree and saturation ratio

As mentioned above, the clear a kind of formation data processing method based on the reservoir rock rock parameter that has described the present invention's proposition in detail calculates the oil reservoir petroleum-in-place.Although the present invention is described and explained to the preferred embodiments of the present invention in detail, but this area those skilled in the art be appreciated that, under the situation of the spirit and scope of the present invention that do not deviate from the claims definition, can in form and details, make multiple modification.

Claims (3)

1. formation data processing method based on the reservoir rock rock parameter may further comprise the steps:

1) utilizes geological exploration and development equipment, can gather formation lithology, pore-fluid and well logging information;

2), obtain the stratum total porosity φ of reservoir rock by the lithology data analytical equipment based on the formation lithology data that collect _t, stratum effecive porosity φ, irreducible water saturation S _Wi, effective water saturation S _We, effective irreducible water saturation S _WieWith water saturation S _w

3), obtain effective pay thickiness h and oil area A in conjunction with the lithology data analytical equipment based on pore-fluid that collects and well logging information _o

4), obtain original oil volume factor B by the fluid data analytical equipment based on the formation pore fluid information that collects _Oi

5) according in step 2) in the reservoir rock stratum total porosity φ of acquisition _t, stratum effecive porosity φ, irreducible water saturation S _Wi, effective water saturation S _We, effective irreducible water saturation S _WieWith water saturation S _w, obtain the oil percent by volume O in the reservoir rock hole _R

Wherein, O _RBe the oil percent by volume, refer to the voids volume that oil in the rock sample hole is occupied and the ratio (f of unit) of rock sample cumulative volume;

6) according to the oil percent by volume O that obtains _R(f of unit) and the effective pay thickiness h (m of unit) and the oil area A that in step 3), obtain _o(the km of unit ²), obtain the oil volume V in the oil-containing reservoir rock hole _f(unit 10 ⁴m ³);

7) according to the oil volume V that obtains _fWith the original oil volume factor B that in step 4), obtains _Oi(zero dimension) obtains oil reservoir petroleum-in-place N ' (unit 10 ⁴m ³), petroleum-in-place N ' is respectively following several situation;

For net pay zone: N '=100A _oH φ _tS _Oi/ B _OiOr N '=100A _oH φ S _Oie/ B _Oi

For containing movable water oil reservoir: N '=100A _oH φ _tS _o/ B _OiOr N '=100A _oH φ S _Oe/ B _Oi

2. method according to claim 1 is characterized in that oil percent by volume O _RBe respectively following situation:

Net pay zone is: O _R=φ _t(1-S _Wi); Or O _R=φ (1-S _Wie); Or O _R=φ _tS _OiOr O _R=φ S _Oie

Containing movable water oil reservoir is: O _R=φ _t(1-S _w); Or O _R=φ (1-S _We); Or O _R=φ _tS _oOr O _R=φ S _Oe

Wherein, φ is the stratum effecive porosity, is meant the active porosity volume of rock sample and the ratio of rock sample volume, the f of unit; φ _tBe the stratum total porosity, be meant the total pore size volume of rock sample and the ratio of rock sample volume, the f of unit; S _OiBe corresponding stratum total porosity φ in net pay zone _tInitial oil saturation (in net pay zone, initial oil saturation is meant voids volume that rock sample PetroChina Company Limited. is occupied and the ratio of rock sample total pore size volume), and S is arranged _Oi=1-S _Wi, the f of unit; S _OieBe the effective initial oil saturation of corresponding stratum effecive porosity φ in net pay zone (in net pay zone, effectively initial oil saturation is meant voids volume that rock sample PetroChina Company Limited. is occupied and the ratio of rock sample active porosity volume), and S is arranged _Oie=1-S _Wie, the f of unit; S _oBe corresponding stratum total porosity φ in containing movable water oil reservoir _tOil saturation (in containing movable water oil reservoir, oil saturation is meant voids volume that rock sample PetroChina Company Limited. is occupied and the ratio of rock sample total pore size volume), and S is arranged _o=1-S _w, the f of unit; S _OeBe the effective oil saturation of corresponding stratum effecive porosity φ in containing movable water oil reservoir (containing in the movable water oil reservoir, effectively oil saturation is meant voids volume that rock sample PetroChina Company Limited. is occupied and the ratio of rock sample active porosity volume), and S is arranged _Oe=1-S _We, the f of unit.

3. method according to claim 1 and 2 is characterized in that the oil volume V in the reservoir rock hole _fBe respectively following situation: be V during net pay zone _f=100A _oH φ _tS _OiOr V _f=100A _oH φ S _OieWhen containing movable water oil reservoir is V _f=100A _oH φ _tS _oOr V _f=100A _oH φ S _Oe

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