CN111485863B - Method for calculating capacity multiple of steam huff-puff well of heavy oil field - Google Patents
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Abstract
The invention relates to the technical field of methods for determining steam huff and puff productivity of offshore heavy oil fields, in particular to a method for calculating the capacity multiple of a steam huff and puff well of a heavy oil field, which comprises the following steps: measuring geological reservoir parameters of the offshore heavy oil field, and establishing a steam huff and puff directional well productivity prediction model under different well inclination angles of the offshore heavy oil and a horizontal well productivity prediction model under a steam huff and puff development condition according to the geological reservoir parameters; and establishing a steam huff-puff exploitation directional well and horizontal well productivity multiple model of the offshore heavy oil field according to the obtained directional well and horizontal well productivity prediction model and productivity prediction model. The invention provides a method for determining the productivity multiples of a directional well and a horizontal well for steam huff and puff development of an offshore heavy oil field, which can provide a basis for steam huff and puff development of horizontal wells with different horizontal segment lengths of offshore heavy oil. The invention provides a quantitative and operable technical method and implementation steps, and the method is suitable for the steam huff and puff directional well development of an offshore heavy oil field.
Description
Technical Field
The invention relates to the technical field of methods for determining steam huff and puff productivity of offshore heavy oil fields, in particular to a method for calculating the productivity multiple of a steam huff and puff well of a heavy oil field.
Background
The Bohai sea thick oil has huge reserve, low cold production capacity, low recovery rate and poor economic benefit for the thick oil. Thermal oil recovery is an effective means for improving the single-well yield and recovery ratio of a special heavy oil reservoir, and has remarkable economic and social benefits in onshore oil field thermal recovery development of Liaohe, Xinjiang, Shengli, Henan and the like in China. In order to effectively use the part of special thick oil reserves, the offshore oil field carries out a thermal recovery pilot test of multi-element thermal fluid swallowing-spitting and steam swallowing-spitting in the Bohai sea at present, and compared with the conventional water drive, the development effect is obvious.
Due to the limited space of offshore platforms, for multi-layer reservoirs, platform drilling with directional wells is abundant, and the inclination angles are different at different positions, as shown in fig. 1. For offshore heavy oil steam huff and puff development, the determination of the production energy of the directional well under different well inclination angle conditions is an important parameter for accurately predicting the heavy oil thermal recovery development index and is also the key for compiling the oil field development scheme.
At present, steam throughput capacity prediction research mainly focuses on two well types, namely a vertical well and a horizontal well, but the steam throughput capacity prediction research on directional wells with different well inclination angles is less, and related research on the productivity times of the directional wells and the horizontal well is not available.
Disclosure of Invention
The invention aims to provide a method for calculating the steam huff-puff well productivity multiple of a heavy oil field, and aims to solve the problems that in the prior art, the steam huff-puff productivity prediction research of directional wells with different well inclination angles is less, and the related research on the steam huff-puff productivity multiple of the directional wells and the horizontal well is unavailable.
In order to achieve the purpose, the invention provides the following technical scheme: a method for calculating the capacity multiple of a steam huff-puff well of a heavy oil field comprises the following steps:
(1) measuring geological reservoir parameters of the offshore heavy oil field;
(2) establishing a directional well skin-simulating factor, a horizontal well productivity prediction model developed by steam huff-and-puff of the offshore heavy oil field and a horizontal well productivity prediction model developed by steam huff-and-puff under different well inclination angles under different well inclination angle conditions according to the geological reservoir parameters;
(3) and obtaining a directional well productivity prediction model and a horizontal well productivity prediction model according to the steps, and establishing a steam huff and puff exploitation directional well and horizontal well productivity multiple model of the offshore heavy oil field.
Preferably, the geological reservoir parameters comprise the absolute permeability of the stratum, the relative permeability of the crude oil in the stratum, the horizontal permeability of the oil layer, the vertical permeability of the oil layer, the thickness of the oil layer, the well length of an inclined well, the viscosity of the crude oil in the hot zone, the heating radius of the hot zone, the radius of a shaft, the pollution skin coefficient of a directional well, the viscosity of the crude oil in the cold zone and the oil drainage radius.
Preferably, the calculation formula of the directional well pseudo-skin factor is as follows:
in the formula (1), the acid-base catalyst,
in the formula (1), S Θ Representing a directional well pseudoepidermal factor; θ represents the well angle, °; h represents the oil layer thickness, m; l represents the length of the inclined shaft well body, m; k h Represents the reservoir horizontal permeability, mD; kv represents the reservoir vertical permeability, mD; rw represents the wellbore radius, m.
Preferably, the directional well productivity prediction model is as follows:
in the formula (2), J dΘh Representing steam stimulation development Directional well Productivity, m 3 /(d.MPa); k represents the absolute permeability of the stratum, mD; k is ro Represents the relative permeability of the formation crude oil, mD; h represents the oil layer thickness, m; mu.s h Represents the hot zone average formation crude oil viscosity, mPa · s; r eh Represents the hot zone heating radius, m; rw represents the wellbore radius, m; s. the Θ Representing a directional well pseudoepidermal factor; s represents the pollution skin coefficient of the directional well; mu.s c The viscosity of the crude oil in the cold area is expressed as mPa & s; r e Denotes the drainage radius, m.
Preferably, the horizontal well productivity prediction model is as follows:
wherein:
in the formula (3), mu h Represents the hot zone average formation crude oil viscosity, mPa · s; mu.s c The viscosity of the crude oil in the cold area is expressed as mPa & s; r eh Represents the hot zone heating radius, m; r w Represents the wellbore radius, m; r e Represents the drainage radius, m; s. the Θ Indicating the directional well pseudoepidermal factor.
Preferably, the steam throughput development directional well and horizontal well productivity multiple model is as follows:
wherein:
in the formula (4), J dΘh Representing steam stimulation development Directional well Productivity, m 3 /(d·MPa)；Q dΘh Representing steam stimulation directional well production, m 3 D; Δ P represents the production pressure difference, MPa; k represents the absolute permeability of the formation, mD; k ro Represents the relative permeability of the formation crude oil, mD; h represents the oil layer thickness, m; mu.s c The viscosity of the crude oil in the cold area is expressed as mPa & s; r e Represents the drainage radius, m; r w Represents the wellbore radius, m; s represents the pollution skin coefficient of the directional well; l represents the horizontal segment length.
Preferably, when the steam huff and puff exploitation straight well productivity prediction model is established, the steam huff and puff heavy oil reservoir is considered as a hot zone and cold recovery composite coupling reservoir.
Preferably, when the steam stimulation is established to develop the straight well productivity prediction model, the method also considers,
the hot area and the cold area are isothermal models, or the hot area is an isothermal area and the cold area is the original oil layer temperature;
single-phase and stable flow;
the inclined well reservoir section is completely jetted;
the longitudinal temperature distribution is equal.
Compared with the prior art, the invention has the beneficial effects that: the method for determining the productivity multiple of the directional well and the horizontal well for steam huff and puff development of the offshore heavy oil field can provide a basis for the steam huff and puff development of the directional well with different well inclination angles of the offshore heavy oil. The invention provides a quantitative and operable technical method and implementation steps, and the method is suitable for the steam huff and puff directional well development of an offshore heavy oil field;
the method can consider the influence of different well inclination angles, different horizontal segment lengths and different heating radiuses on the productivity multiple; the method has strong operability and high accuracy, and can guide the determination of the production performance of the directional wells with different well inclination angles in the steam huff-and-puff development of the offshore multilayer heavy oil reservoir.
Drawings
FIG. 1 is a schematic diagram of an offshore directional well and horizontal well development of the present invention;
FIG. 2 is a steam huff and puff hot zone and cold recovery complex reservoir model of the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
The method for determining the capacity multiple of the directional well and the horizontal well in steam huff and puff development of the offshore heavy oil field comprises the following steps:
(1) measuring geological reservoir parameters of the offshore heavy oil field, and establishing a directional well skin-simulating factor under different well inclination angle conditions, a directional well productivity prediction model developed by steam huff-puff of the offshore heavy oil field and a horizontal well productivity prediction model developed by steam huff-puff under different well inclination angle conditions according to the geological reservoir parameters;
(2) and (3) establishing a steam huff and puff exploitation directional well and horizontal well productivity multiple model of the offshore heavy oil field according to the directional well productivity prediction model and the horizontal well productivity prediction model obtained in the step (1).
In the step (1), the geological oil reservoir parameters comprise stratum absolute permeability, stratum crude oil relative permeability, oil layer horizontal permeability, oil layer vertical permeability, oil layer thickness, inclined well length, hot zone average stratum crude oil viscosity, hot zone heating radius, well bore radius, directional well pollution skin coefficient, cold zone stratum crude oil viscosity and oil drainage radius.
In the step (1), establishing a steam huff-puff development vertical well productivity prediction model, considering a steam huff-puff heavy oil reservoir as a hot zone and cold recovery composite coupling reservoir, and considering the following assumptions:
(1) the hot area and the cold area are isothermal models, the hot area is an isothermal area, and the cold area is the original oil layer temperature;
(2) single-phase and stable flow;
(3) the inclined shaft reservoir section is completely jetted;
(4) the longitudinal temperature distribution is equal.
As shown in fig. 1, a (left) in fig. 1 is a schematic diagram of directional well development, and B (right) in fig. 1 is a schematic diagram of horizontal well development.
The steam stimulation development vertical well model is shown in FIG. 2, and according to the Darcy formula, a conventional development vertical well productivity formula is as follows:
wherein K represents the absolute formation permeability, mD; k ro Represents the relative permeability of the formation crude oil, mD; h represents the oil layer thickness, m; j is a unit of v Represents the conventional vertical well productivity, m 3 /(d·MPa)；Q v Represents conventional vertical well production, m 3 D; Δ P represents the production pressure difference, MPa; mu.s c The viscosity of the crude oil in the cold area is expressed as mPa & s; s represents the contamination skin coefficient of the directional well.
Determining a steam huff and puff horizontal well productivity model of the hot area and cold area composite oil reservoir according to an equivalent seepage resistance method:
wherein:
in the formula (1), J vh Represents the steam throughput to develop the productivity of the horizontal well, m 3 /(d·MPa)；J v Representing steam stimulation to develop vertical well productivity, m 3 /(d·MPa)；Q vh Representing steam stimulation development vertical well production, m 3 D; Δ P represents the production pressure difference, MPa; k represents the absolute permeability of the formation, mD; k ro Represents the relative permeability of the formation crude oil, mD; h represents the oil layer thickness, m; mu.s h Represents the hot zone average formation crude oil viscosity, mPa · s; r eh Represents the hot zone heating radius, m; r w Represents the wellbore radius, m; s represents the pollution skin coefficient of the directional well; mu.s c The viscosity of the crude oil in the cold zone is expressed as mPa & s; r e Represents the drainage radius, m; l represents the horizontal segment length, m.
Directional well skin-like factor S under different inclination angle conditions Θ Can be expressed as:
in the formula (2), the reaction mixture is,
θ represents the well angle, °; h represents the oil layer thickness, m; l represents the length of a well body of the inclined well, and m; k is h Represents the reservoir horizontal permeability, mD; k v Represents the vertical permeability of the oil layer, mD; r w Represents the wellbore radius, m.
The steam huff and puff exploitation productivity prediction model under different well inclination angle conditions comprises the following steps:
wherein, J dθ Indicating steam stimulation directional well productivity，m 3 /(d·MPa)；Q θ Representing steam stimulation directional well production, m 3 /d。
According to an equivalent seepage resistance method, establishing a steam huff and puff productivity model of a composite oil reservoir directional well in a hot area and a cold area, wherein the steam huff and puff productivity model comprises the following steps:
assuming that the contaminated skin coefficient S is 0, the absolute permeability K of the oil layer and the relative permeability K of the oil phase ro If not, according to the obtained steam huff and puff development vertical well and directional well productivity prediction models, establishing a steam huff and puff development directional well and horizontal well productivity multiple model:
determining the function mu of the viscosity of the crude oil in the hot zone along with the change of the radial distance according to the numerical reservoir simulation h (x) Establishing average crude oil viscosity mu in hot zones of different heating radii h With different heating radii R eh The relation model is as follows:
μ h represents the hot zone average formation crude oil viscosity, mPa · s; r eh Represents the hot zone heating radius, m; r w Represents the wellbore radius, m; x represents any distance, m, from the wellbore.
According to the model for the steam huff and puff development of the directional well and the productivity multiple of the horizontal well in the offshore heavy oil field, the productivity of the steam huff and puff development of the directional well in the offshore heavy oil field can be determined by combining the following steps:
1) establishing a relation model between the average crude oil viscosity and different heating radiuses in the hot zones with different heating radiuses according to the crude oil viscosity change with different radial distances;
2) according to the productivity multiple model of the directional well and the horizontal well obtained by the method, combining the average crude oil viscosity in the hot area, the shaft radius, the oil drainage radius, the cold area stratum crude oil viscosity and the directional well skin-like factor obtained in the step 1) under different heating radiuses, the productivity multiple of the steam huff-puff developed directional well and the horizontal well is obtained; and (4) developing the productivity of the horizontal well according to the steam huff-and-puff determined by the offshore oil field test, namely obtaining the productivity of the steam huff-and-puff developed directional well of the offshore heavy oil field.
Although embodiments of the present invention have been shown and described, it will be appreciated by those skilled in the art that changes, modifications, substitutions and alterations can be made in these embodiments without departing from the principles and spirit of the invention, the scope of which is defined in the appended claims and their equivalents.
Claims (1)
1. A method for calculating the productivity multiple of a steam huff and puff well in a heavy oil field is characterized by comprising the following steps: the method comprises the following steps:
(1) measuring geological reservoir parameters of the offshore heavy oil field;
(2) establishing a directional well skin-simulating factor, a horizontal well productivity prediction model for steam huff-and-puff development of the offshore heavy oil field and a horizontal well productivity prediction model for steam huff-and-puff development of different well inclination angles under different well inclination angle conditions according to the geological reservoir parameters;
(3) obtaining a directional well productivity prediction model and a horizontal well productivity prediction model according to the steps, and establishing an offshore heavy oil field steam huff-puff exploitation directional well and horizontal well productivity multiple model;
the geological oil deposit parameters comprise stratum absolute permeability, stratum crude oil relative permeability, oil layer horizontal permeability, oil layer vertical permeability, oil layer thickness, inclined well length, hot zone average stratum crude oil viscosity, hot zone heating radius, well bore radius, oriented well pollution skin coefficient, cold zone stratum crude oil viscosity and oil drainage radius,
the calculation formula of the directional well pseudo-skin factor is as follows:
in the formula (1), the reaction mixture is,
S Θ representing a directional well pseudoepidermal factor; θ represents the well angle, °; h represents the oil layer thickness, m; l represents the length of the inclined shaft well body, m; kh represents the reservoir horizontal permeability, mD; k is v Represents the vertical permeability of the oil layer, mD; r is w The radius of the wellbore, m,
the directional well productivity prediction model is as follows:
in the formula (2), J dΘh Representing steam stimulation development Directional well Productivity, m 3 V (d.MPa); k represents the absolute permeability of the stratum, mD; k is ro Represents the relative permeability of the formation crude oil, mD; h represents the oil layer thickness, m; mu.s h Represents the hot zone average formation crude oil viscosity, mPa · s; r is eh Represents the hot zone heating radius, m; rw represents the wellbore radius, m; s. the Θ Representing a directional well pseudoepidermal factor; s represents the pollution skin coefficient of the directional well; mu.s c The viscosity of the crude oil in the cold zone is expressed as mPa & s; r e And represents the radius of drainage, m,
the horizontal well productivity prediction model comprises the following steps:
wherein:
in the formula (3), mu h Represents the hot zone average formation crude oil viscosity, mPa · s; mu.s c The viscosity of the crude oil in the cold area is expressed as mPa & s; r is eh Represents the hot zone heating radius, m; r w Represents the wellbore radius, m; r e Represents the drainage radius, m; s Θ The pseudo-epidermal factor of the directional well is shown,
the steam huff and puff exploitation directional well and horizontal well productivity multiple model comprises the following steps:
wherein:
in the formula (4), J represents the productivity multiple of the directional well and the horizontal well; j is a unit of dΘh Representing steam stimulation development Directional well Productivity, m 3 /(d·MPa)；Q dΘh Representing steam stimulation directional well production, m 3 D; Δ P represents the production pressure difference, MPa; k represents the absolute permeability of the formation, mD; k is ro Represents the relative permeability of the formation crude oil, mD; h represents the oil layer thickness, m; mu.s c The viscosity of the crude oil in the cold zone is expressed as mPa & s; r e Represents the drainage radius, m; r w Represents the wellbore radius, m; s represents the pollution skin coefficient of the directional well; l represents the horizontal segment length, m;
when a steam huff and puff development vertical well productivity prediction model is established, a steam huff and puff heavy oil reservoir is considered as a hot zone and cold recovery composite coupling reservoir;
when the steam huff and puff development vertical well productivity prediction model is established, the method also considers,
the hot area and the cold area are isothermal models, or the hot area is an isothermal area and the cold area is the original oil layer temperature;
single-phase and stable flow;
the inclined shaft reservoir section is completely jetted;
the longitudinal temperature distribution is equal.
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| CN114165202B (en) * | 2020-08-20 | 2024-04-16 | 中国石油化工股份有限公司 | Method for improving radius for throughput after high-pass throughput |
| CN114386678A (en) * | 2021-12-24 | 2022-04-22 | 中国石油大学(北京) | Method and device for determining residual heat of oil layer |
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