CN109667564B - Method for determining yield of directional well for steam huff-puff development of offshore heavy oil field - Google Patents
Method for determining yield of directional well for steam huff-puff development of offshore heavy oil field Download PDFInfo
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Abstract
The invention discloses a method for determining the yield of a directional well for steam huff-puff development of an offshore heavy oil field, which comprises the following steps: measuring geological reservoir parameters of the offshore heavy oil field, and establishing a directional well skin-simulating factor and a steam huff-puff development directional well and vertical well productivity multiple model under different well inclination angles of the offshore heavy oil field according to the geological reservoir parameters; 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; according to the obtained oriented well and vertical well productivity multiple model, combining the relation model to obtain the productivity multiple of the steam huff-puff development oriented well and the vertical well; and (4) developing the productivity of the vertical 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. The method is suitable for the development of the steam huff and puff directional well of the offshore heavy oil field.
Description
Technical Field
The invention relates to a method for determining steam huff and puff productivity of an offshore heavy oil field, in particular to a method for determining steam huff and puff development directional well productivity of an offshore heavy oil field.
Background
The thick oil reserve of the Bohai sea is huge, and for special thick oil with the viscosity of more than 350mPa & s, the cold recovery productivity is low, the recovery ratio is low, and the economic benefit is poor. 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, the platform drilling wells for directional wells is abundant, and the well 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 directional well productivity 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.
Currently, steam throughput capacity prediction research mainly focuses on two well types, namely a vertical well and a horizontal well, and the steam throughput capacity prediction research on directional wells with different well inclination angles is less.
Disclosure of Invention
The invention aims to provide a method for determining the production capacity of a directional well under the conditions of different well angles for steam huff-and-puff development of an offshore heavy oil reservoir, which can consider the influence of different well angles, different well distances and different heating radii on the production capacity of the steam huff-and-puff directional well; the method has strong operability and high accuracy, and can guide the steam huff and puff development of the directional well performance design with different well inclination angles of the offshore multilayer heavy oil reservoir.
The method for determining the yield of the directional well for steam huff-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 and an offshore heavy oil field steam huff-puff development directional well and vertical well productivity multiple model under different well inclination angle conditions of the offshore heavy oil field according to the geological reservoir parameters;
(2) 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;
(3) according to the oriented well and vertical well productivity multiple model obtained in the step (1), combining the relation model obtained in the step (2), and obtaining the productivity multiple of the steam huff and puff development oriented well and the vertical well; and (4) developing the productivity of the vertical 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.
In the determination method, in the step (1), the directional well skin-like factor is represented by the formula (1):
in the formula (1), the reaction mixture is,
θ represents the well angle, °; h represents the oil layer thickness, m; l represents the length of the inclined shaft well body, m; khRepresents the reservoir horizontal permeability, mD; kvRepresents the vertical permeability of the oil layer, mD; rwRepresents the wellbore radius, m.
In the determination method, in the step (1), the steam throughput development oriented well and vertical well productivity multiple model is shown as the formula (2):
in the formula (2), uhRepresents the hot zone average formation crude oil viscosity, mPa · s; u. ofcThe viscosity of the crude oil in the cold zone is expressed as mPa & s; rehRepresents the hot zone heating radius, m; rwRepresents the wellbore radius, m; reRepresents the drainage radius, m; sθIndicating the directional well pseudoepidermal factor.
Specifically, the steam stimulation development directional well and vertical well productivity multiple model can be obtained by a steam stimulation development vertical well productivity prediction model and a directional well productivity prediction model.
The method comprises the following steps of 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;
conventionally developing a vertical well productivity formula according to the Darcy formula:
determining a steam huff and puff vertical well productivity model of the hot area and cold area composite oil reservoir according to an equivalent seepage resistance method:
in the above formula, JvhRepresenting steam stimulation to develop vertical well productivity, m3/(d·MPa·m)；QvhRepresenting steam stimulation development vertical well production, m3D; Δ P represents the production pressure difference; k represents the absolute permeability of the formation, mD; kroRepresents the relative permeability of the formation crude oil, mD; h represents the oil layer thickness, m; u. ofhRepresents the hot zone average formation crude oil viscosity, mPa · s; rehRepresents the hot zone heating radius, m; rwRepresents the wellbore radius, m; s represents the pollution skin coefficient of the directional well; u. ofcThe viscosity of the crude oil in the cold zone is expressed as mPa & s; reDenotes the drainage radius, m.
The steam throughput development productivity prediction model considering different well inclination angle conditions comprises the following steps:
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:
in the formula, JdθRepresenting steam stimulation development Directional well Productivity, m3V (d.MPa.m); Δ P represents the production pressure difference; k represents the absolute permeability of the formation, mD; kroRepresents the relative permeability of the formation crude oil, mD; h represents the oil layer thickness, m; u. ofcThe viscosity of the crude oil in the cold zone is expressed as mPa & s; reRepresents the drainage radius, m; rwRepresents the wellbore radius, m; sθAnd (4) expressing the pseudo-skin factor of the directional well, and S expressing the pollution skin coefficient of the directional well.
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 phaseroIf not, developing a vertical well and directional well productivity prediction model according to the obtained steam huff and puff, and establishing the prediction modelAnd developing a productivity multiple model of the directional well and the vertical well by steam stimulation.
In the determination method, in the step (2), the relationship model is represented by the following formula (3):
in the formula (3), uhRepresents the hot zone average formation crude oil viscosity, mPa · s; rehRepresents the hot zone heating radius, m; rwRepresents the wellbore radius, m; x represents any distance from the wellbore, m;
in the step (3), average formation crude oil viscosity in the hot area under different heating radiuses can be obtained according to the relation model, and the productivity multiple of the steam huff-puff development directional well and the straight well as the obtained average formation crude oil viscosity, the shaft radius, the drainage radius, the cold area formation crude oil viscosity and the directional well skin-like factor in the hot area are obtained, so that the productivity multiple of the steam huff-puff development directional well and the straight well is obtained.
The invention provides a method for determining the capacity of a steam huff and puff development directional well of an offshore heavy oil field, provides a quantitative and operable technical method and implementation steps, and is suitable for the steam huff and puff development directional well of the offshore heavy oil field.
Drawings
FIG. 1 is a schematic diagram of an offshore directional well development.
FIG. 2 is a steam stimulation hot zone and cold recovery complex reservoir model.
FIG. 3 is a schematic view of a steam stimulation directional well model.
FIG. 4 is a diagram of a viscosity distribution of formation crude oil at the last time of thermal recovery huff-and-puff well soaking.
FIG. 5 is a plot of directional well and vertical well productivity multiple as a function of well inclination.
Detailed Description
The experimental procedures used in the following examples are all conventional procedures unless otherwise specified.
Materials, reagents and the like used in the following examples are commercially available unless otherwise specified.
The method comprises the following steps of establishing a vertical well productivity prediction model for steam huff-and-puff development of the offshore heavy oil field, considering a steam huff-and-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.
Steam stimulation development vertical well model as shown in figure 2,
conventionally developing a vertical well productivity formula according to the Darcy formula:
wherein K represents the absolute formation permeability, mD; kroRepresents the relative permeability of the formation crude oil, mD; h represents the oil layer thickness, m; j. the design is a squarevRepresents the conventional vertical well productivity, m3/(d·MPa·m)；QvRepresents conventional vertical well production, m3D; Δ P represents the production pressure difference; u. ofcThe viscosity of the crude oil in the cold zone is expressed as mPa & s; s represents the contamination skin coefficient of the directional well.
Determining a steam huff and puff vertical well productivity model of the hot area and cold area composite oil reservoir according to an equivalent seepage resistance method:
in the above formula, JvhRepresenting steam stimulation to develop vertical well productivity, m3/(d·MPa·m)；QvhRepresenting steam stimulation development vertical well production, m3D; Δ P represents the production pressure difference; k represents the absolute permeability of the formation, mD; kroRepresents the relative permeability of the formation crude oil, mD; h represents the oil layer thickness, m; u. ofhIndicating mean formation oil viscosity in hot zoneDegree, mPa · s; rehRepresents the hot zone heating radius, m; rwRepresents the wellbore radius, m; s represents the pollution skin coefficient of the directional well; u. ofcThe viscosity of the crude oil in the cold zone is expressed as mPa & s; reDenotes the drainage radius, m.
A schematic diagram of a steam stimulated directional well is shown in fig. 3, where θ represents the angle of inclination, °; h represents the oil layer thickness, m; l represents the length of the inclined shaft well body, m.
Directional well skin-like factor S under different inclination angle conditionsθCan be expressed as:
in the formula (1), the reaction mixture is,
θ represents the well angle, °; h represents the oil layer thickness, m; l represents the length of the inclined shaft well body, m; khRepresents the reservoir horizontal permeability, mD; kvRepresents the vertical permeability of the oil layer, mD; rwRepresents the wellbore radius, m.
The steam throughput exploitation productivity prediction model under different well inclination angle conditions comprises the following steps:
wherein, JdθRepresenting steam stimulation directional well productivity, m3/(d·MPa·m)；QdθRepresenting steam stimulation directional well production, m3/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 a contaminated skin factor S of 0, oil layerAbsolute permeability K and relative permeability K of the oil phaseroAnd if not, establishing a steam huff and puff exploitation directional well and vertical well productivity multiple model according to the obtained steam huff and puff exploitation vertical well and directional well productivity prediction model:
determining the function u of the viscosity of the crude oil in the hot zone along with the change of the radial distance according to the numerical simulation of the oil reservoirh(x) Establishing average crude oil viscosity u in hot zones of different heating radiihWith different heating radii RehThe relation model is as follows:
uhrepresents the hot zone average formation crude oil viscosity, mPa · s; rehRepresents the hot zone heating radius, m; rwRepresents the wellbore radius, m.
Taking a certain heavy oil reservoir in Bohai sea as an example, the average porosity of the reservoir is 28.5 percent, the average permeability is 668mD, a longitudinal multi-set oil-water system is a lamellar structure edge water heavy oil reservoir, and the ground crude oil density is 0.972t/m3The viscosity of the crude oil in the stratum is calculated to be 472 mPa.s, and the function u of the viscosity of the crude oil in the hot zone along with the change of the radial distance is determined through numerical reservoir simulationh(x) As shown in fig. 4.
By making a pair uh(x) And (4) integrating and weighting in different well distance ranges, and solving the average crude oil viscosity in the hot zone, wherein the heating radius is 20m in the embodiment, and the average oil layer viscosity in the hot zone is 17.2mPa & s.
Heating the above-obtained mixture to different heating radiuses RehAverage crude oil viscosity u in the hot zonehAnd applying a wellbore radius RwRadius R of oil drainageeCold zone formation crude oil viscosity ucInclined shaft skin-like factor SθBringing in a steam huff and puff exploitation oriented well and vertical well productivity multiple model, and solving the steam huff and puff exploitation oriented well and vertical well productivity multiple
Taking the heating radius of the hot zone as an example, when the well spacing is 200m, the steam throughput capacity multiple curve of the directional well and the straight well under different inclination angles can be determined, as shown in fig. 5.
Considering that the number of offshore platform wells is large, and when the inclination angle is small, the steam throughput capacity multiple of the directional well and the vertical well changes slowly, the steam throughput development directional well, the steam throughput capacity multiple of the vertical well and the steam throughput capacity of the directional well are determined in a classification mode according to the size of the inclination angle so that the directional well has operability, and the specific classification is shown in table 1.
Taking a certain heavy oil reservoir in Bohai sea as an example, the steam huff and puff directional well yield is determined to be 40m through offshore testing3/d。
TABLE 1 steam huff and puff thermal recovery productivity multiple at different well angles
Claims (1)
1. A method for determining the yield of a directional well for steam huff-puff development of an 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 and an offshore heavy oil field steam huff-puff development directional well and vertical well productivity multiple model under different well inclination angle conditions of the offshore heavy oil field according to the geological reservoir parameters;
the geological oil reservoir parameters comprise oil layer horizontal permeability, oil layer vertical permeability, oil layer thickness, inclined well body length, hot zone average stratum crude oil viscosity, hot zone heating radius, shaft radius, oriented well pollution skin coefficient, cold zone stratum crude oil viscosity and oil drainage radius;
the directional well skin-like factor is shown as the formula (1):
in the formula (1), the reaction mixture is,
θ represents the well angle, °; h represents the oil layer thickness, m; l represents the length of the inclined shaft well body, m; khRepresents the reservoir horizontal permeability, mD; kvRepresents the vertical permeability of the oil layer, mD; rwRepresents the wellbore radius, m;
the steam huff and puff exploitation directional well and vertical well productivity multiple model is shown as the formula (2):
in the formula (2), uhRepresents the hot zone average formation crude oil viscosity, mPa · s; u. ofcThe viscosity of the crude oil in the cold zone is expressed as mPa & s; rehRepresents the hot zone heating radius, m; rwRepresents the wellbore radius, m; reRepresents the drainage radius, m; sθRepresenting a directional well pseudoepidermal factor;
(2) 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;
the relationship model is shown as formula (3):
in the formula (3), uhRepresents the hot zone average formation crude oil viscosity, mPa · s; rehRepresents the hot zone heating radius, m; rwRepresents the wellbore radius, m; x represents any distance from the wellbore, m;
(3) according to the oriented well and vertical well productivity multiple model obtained in the step (1), combining the relation model obtained in the step (2), and obtaining the productivity multiple of the steam huff and puff development oriented well and the vertical well; and (4) developing the productivity of the vertical 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.
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| CN112508727A (en) * | 2019-08-26 | 2021-03-16 | 中国石油天然气股份有限公司 | Method and system for determining recovery ratio of steam huff-puff heavy oil reservoir |
| CN110513089A (en) * | 2019-09-06 | 2019-11-29 | 中国海洋石油集团有限公司 | A kind of Offshore Heavy Oil Field thermal recovery, which is handled up, develops production capacity multiple and determines method |
| CN111485863B (en) * | 2020-04-16 | 2022-09-06 | 北京默凯斯能源技术有限公司 | Method for calculating capacity multiple of steam huff-puff well of heavy oil field |
| CN113669037B (en) * | 2020-05-13 | 2023-04-07 | 中国石油化工股份有限公司 | Step design method for multi-element directional viscosity reduction after multiple times of huffing and puff of thick oil |
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