CN110821462B - Method for drawing tail end of horizontal well group with interlayer in SAGD control well reservoir - Google Patents
Method for drawing tail end of horizontal well group with interlayer in SAGD control well reservoir Download PDFInfo
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- CN110821462B CN110821462B CN201910981376.8A CN201910981376A CN110821462B CN 110821462 B CN110821462 B CN 110821462B CN 201910981376 A CN201910981376 A CN 201910981376A CN 110821462 B CN110821462 B CN 110821462B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2406—Steam assisted gravity drainage [SAGD]
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
Abstract
The invention discloses a method for drawing the tail end of a horizontal well group with an interlayer in an SAGD control well reservoir, which comprises the following steps: s1: well selection; s2: testing and analyzing; s3: designing a control well; s4: designing a perforation layer position; s5: the drilled SAGD double horizontal well group should keep the two wells parallel as much as possible and coplanar in the vertical direction; s6: injecting steam into the SAGD horizontal well group, S7: steam circulation; s8: selecting a single well or double wells to inject hot water simultaneously according to the geological condition of a reservoir; s9: entering an SAGD production stage; s10: injecting steam into the control well to assist in oil displacement; s11: increasing the recovery ratio at the initial development stage of a steam cavity of the SAGD well group; the invention reestablishes the steam channel, changes the permeability of the reservoir, ensures the secondary development of the steam cavity, and has simple operation and low cost; different permeability steam communication zones can be created in the heel and toe of the SAGD horizontal well group, respectively, limiting the impact of the completion structure on the non-uniform development of the steam cavity.
Description
Technical Field
The invention belongs to the field of oil exploitation, and particularly relates to a method for using the tail end of a horizontal well group with an interlayer in an SAGD control well reservoir.
Background
In the steam assisted neutral drainage (SAGD) production technology, high-temperature steam is injected into an upper injection well to heat a reservoir, so that the viscosity of thick oil is reduced, the flowing capacity of the thick oil is improved, and the thick oil or super thick oil flows into a production well from the upper reservoir under the action of gravity and is extracted by an extraction system. And establishing thermal communication between horizontal well groups between the SAGD well and the production stage, and enabling the thickened oil heated by the steam injection well to enter the production well. Conventional SAGD well preheating methods circulate steam in the injection and production wells at a pressure above the reservoir pore pressure below the reservoir minimum principal stress until the zone between horizontal well banks is heated, a process that typically exceeds 6 months.
The reservoir natural interbed is a region of natural stress non-uniformity that exists between the production and steam injection wells in the horizontal direction. Steam can not break through the interlayer, so that steam can not be transmitted to the tail end in the SAGD preheating stage, or the stress distribution is uneven, and the development of a steam cavity is poor. The natural interbedding of the reservoir is a difficult problem to solve in conventional SAGD preheat and can severely impact recovery. The control well can create a controllable artificial pressure communication channel in the range of the abnormal stress area, penetrate through the interlayer up and down, communicate with the reservoir and increase the tail end temperature and the steam injection pressure. The SAGD steam injection time is shortened, and the recovery efficiency is improved.
Basic principle of weak consolidation stratum capacity expansion:
geomechanics dilatation refers to the rock deformation phenomenon that the pore volume of a pore medium rock body is increased under the load action of shear stress or pore fluid pressure increase. At this point, the total stress experienced by the rock mass may also be a compressive stress state. The expansion behavior of weakly consolidated (unconsolidated) sandstone may come from shear stress (shear expansion) or pore pressure increase (fluid pressure expansion). On a microscopic level, the expansion behavior can be viewed as a rearrangement of the sand grains. Wong et al [ Wong et al.1993[1 ]; samieh and Wong 1998[2 ]; wong 2003[3] studied the geomechanical characteristics of the acan Athabasca (Athabasca) and cold lake (Colllake) oil sands.
They performed a triaxial test at low confining pressure on oil sand cores. Volume expansion (up to 7%) was measured in the triaxial test. They performed stress-strain curves and volume expansion curves measured by a triaxial test. Meanwhile, they studied the change of microstructure before and after the triaxial test using electron microscope Scanning (SEM). Clearly, a significant increase in porosity can be seen under electron microscope scanning. It is noted that in these triaxial tests, the total stress of the core is also the state of compressive stress, and therefore the increase in porosity is mainly caused by shear stress.
Yuan et al (2011) [4] and Xu and Wong (2013) [5] summarize existing laboratory and field data, and meanwhile, numerical simulation is carried out on the expansion process in the weakly consolidated sandstone reservoir. Xu et al [ Xu et al.2010] proposed a finite element model for the hydraulic fracturing and dilatation phenomena of weakly consolidated (unconsolidated) sandstone formations. They concluded that dilation in oil sands is a combination of shear failure and tensile microcracking.
When shear expansion occurs, the sand grains are still in contact with each other, although the original contact positions between the grains are disturbed by their mutual rolling. In the tensile fracture stage, the sand grains are separated from each other and do not contact each other; to this end, we propose a SAGD well reservoir with a interbed horizontal well group end-draw method to solve the problems mentioned in the background above.
Disclosure of Invention
The invention aims to provide a method for drawing a tail end of a horizontal well group with an interlayer in an SAGD control well reservoir so as to solve the problems in the background technology.
In order to achieve the purpose, the invention provides the following technical scheme:
as shown in fig. 2 and 3:
a method for drawing at the tail end of a horizontal well group with a sandwich layer in a SAGD control well reservoir comprises the following steps:
s1: well selection:
(1) the new block steam cavity does not develop into an SAGD double horizontal well group, and the bottom of the well has no natural crack and no abnormal pressure area;
(2) the tail end of the converted SAGD double horizontal well group is poor in development, and a low-yield well group is formed;
(3) SAGD dual horizontal well groups with natural sandwiches resulting in poor temperature connectivity;
s2: and (3) testing and analyzing:
measuring the ground stress data of the oil reservoir; permeability of an interlayer and a reservoir with poor connectivity, lithology analysis and a micro-differential pressure permeability experiment; well group production history data including, but not limited to, steam volume, temperature, pressure, production;
s3: and (3) controlling well drilling design:
analyzing oil reservoir cover layer data, designing fracturing pressure breakthrough by an interlayer, finding areas with minimum stress at the upper end layer and the lower end layer of the interlayer, and drilling a well to penetrate through the interlayer;
establishing a geological stress model through data analysis, obtaining an area with poor horizontal section permeability, and performing a pressure difference experiment to obtain a fracturing control pressure value;
designing reservoir pressure to obtain the minimum distance and the maximum distance range from a control well to the SAGD double-horizontal well group;
s4: designing a perforation layer, and selecting two positions above and below a reservoir interlayer for perforation;
s5: the drilled SAGD double horizontal well group should keep the two wells parallel as much as possible and coplanar in the vertical direction; the short pipe is arranged at the beginning of the SAGD double horizontal well group, namely the heel, and the long pipe is arranged at the tail end of the horizontal well group, namely the toe;
s6: injecting steam into the SAGD horizontal well group, performing steam circulation for 5-7 days, wherein the pressure of the injected steam is less than the pressure of an original stratum, preheating a reservoir layer around the SAGD horizontal well group, and removing thick oil deposition in the well group;
s7: steam circulation, the steam injection pressure of the steam circulation is higher than the pore pressure of the reservoir and lower than the minimum main stress of the stratum;
carrying out steam circulation in the SAGD horizontal well group at the same time until the well group realizes thermal communication to reach a production transfer condition;
steam circulation means injecting steam into the horizontal well group through the long pipe and discharging condensed water in the horizontal well group through the short pipe to achieve the purpose of heating the reservoir;
s8: according to the geological condition of a reservoir, selecting a single well or double wells to inject hot water simultaneously, wherein the SAGD double-horizontal well group comprises an injection well and a production well, the hot water is injected from one of the injection well or the production well by the single well, and the hot water is injected from the double wells into the injection well and the production well simultaneously, so that the original ground stress and the water saturation of the reservoir are changed;
the injection pressure is monitored and controlled in the whole process, the hot water injection speed is adjusted in time, and macroscopic tension cracks are prevented from being formed between the horizontal well groups;
injecting hot water into the long pipe or the short pipe to fill the area with poor permeability of the horizontal section with the hot water, and continuously injecting water into the shaft to form pressurization and extend hydraulic fractures;
s9: the standard of the conversion production is that when the temperature between the steam injection well and the production well reaches more than 80 ℃, an effective oil drainage channel is established between the steam injection well and the production well, so as to judge whether the steam circulation can be stopped or not, and the SAGD production stage is started;
s10: injecting steam into the control well to assist in oil displacement; in the production stage of the SAGD double horizontal wells, steam is injected into a control well to assist oil displacement;
s11: at the initial development stage of a steam cavity of the SAGD well group, injecting steam through a control well, increasing the temperature of the tail end, supplementing formation energy, assisting oil displacement and increasing the recovery ratio;
s12: improving steam flow of a well with a sandwich layer at the tail end through a control well, and opening an auxiliary steam cavity; changing the original ground stress and water saturation of a reservoir;
s13: and controlling the well to produce and recover oil at the later development stage of the steam cavity of the SAGD well group.
Preferably, the adjustment of the earth stress around the wellbore is based primarily on two principles:
1) the porous elasticity principle, the diffusion of the injected hot solvent in the oil sand of the reservoir can change the pore pressure around the shaft;
2) the thermoelastic principle, the injected hot water can heat the reservoir, and can cause the reservoir around the shaft to generate thermal stress.
Preferably, the method for determining the temperature connectivity between the horizontal well groups in step S7 is to inject hot water into the injection well and monitor the changes of the temperature sensors in the horizontal direction of the production well.
Preferably, the different region communication requirement means that steam communication regions with different permeability are formed in the horizontal section for the purpose of realizing uniform development of the steam cavity along the horizontal section in the SAGD production stage.
Compared with the prior art, the invention has the beneficial effects that: the invention provides a method for using the tail end of an interlayer horizontal well group in an SAGD control well reservoir, which is used for pertinently transforming a heavy oil reservoir by penetrating a control well through an interlayer according to the geological condition of a horizontal section; the steam channel is reestablished, the permeability of the reservoir is changed, the secondary development of the steam cavity is realized, the operation is simple, and the cost is low; different permeability steam communication zones can be created in the heel and toe of the SAGD horizontal well group, respectively, limiting the impact of the completion structure on the non-uniform development of the steam cavity.
Drawings
FIG. 1 is a schematic diagram of the placement of a SAGD horizontal well group of the present invention in a heavy oil reservoir;
FIG. 2 is a first structural schematic of an FHW3076I horizontal well string of the present invention;
FIG. 3 is a schematic representation of a second construction of an FHW3076I horizontal well string according to 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.
Example 1
As shown in fig. 2 and 3: the invention provides a method for drawing a tail end of a horizontal well group with an interlayer in an SAGD control well reservoir, which comprises the following steps:
s1: well selection:
(1) the new block steam cavity does not develop into an SAGD double horizontal well group, and the bottom of the well has no natural crack and no abnormal pressure area;
(2) the tail end of the converted SAGD double horizontal well group is poor in development, and a low-yield well group is formed;
(3) SAGD dual horizontal well groups with natural sandwiches resulting in poor temperature connectivity;
s2: and (3) testing and analyzing:
measuring the ground stress data of the oil reservoir; permeability of an interlayer and a reservoir with poor connectivity, lithology analysis and a micro-differential pressure permeability experiment; well group production history data including, but not limited to, steam volume, temperature, pressure, production;
s3: and (3) controlling well drilling design:
analyzing oil reservoir cover layer data, designing fracturing pressure breakthrough by an interlayer, finding areas with minimum stress at the upper end layer and the lower end layer of the interlayer, and drilling a well to penetrate through the interlayer;
establishing a geological stress model through data analysis, obtaining an area with poor horizontal section permeability, and performing a pressure difference experiment to obtain a fracturing control pressure value;
designing reservoir pressure to obtain the minimum distance and the maximum distance range from a control well to the SAGD double-horizontal well group;
s4: designing a perforation layer, and selecting two positions above and below a reservoir interlayer for perforation;
s5: the drilled SAGD double horizontal well group should keep the two wells parallel as much as possible and coplanar in the vertical direction; the short pipe is arranged at the beginning of the SAGD double horizontal well group, namely the heel, and the long pipe is arranged at the tail end of the horizontal well group, namely the toe;
s6: injecting steam into the SAGD horizontal well group, performing steam circulation for 5-7 days, wherein the pressure of the injected steam is less than the pressure of an original stratum, preheating a reservoir layer around the SAGD horizontal well group, and removing thick oil deposition in the well group;
s7: steam circulation, the steam injection pressure of the steam circulation is higher than the pore pressure of the reservoir and lower than the minimum main stress of the stratum;
carrying out steam circulation in the SAGD horizontal well group at the same time until the well group realizes thermal communication to reach a production transfer condition;
steam circulation means injecting steam into the horizontal well group through the long pipe and discharging condensed water in the horizontal well group through the short pipe to achieve the purpose of heating the reservoir;
s8: according to the geological condition of a reservoir, selecting a single well or double wells to inject hot water simultaneously, wherein the SAGD double-horizontal well group comprises an injection well and a production well, the hot water is injected from one of the injection well or the production well by the single well, and the hot water is injected from the double wells into the injection well and the production well simultaneously, so that the original ground stress and the water saturation of the reservoir are changed;
injecting solvent with large displacement, and judging the temperature connectivity among the horizontal well groups;
the injection pressure is monitored and controlled in the whole process, the hot water injection speed is adjusted in time, and macroscopic tension cracks are prevented from being formed between the horizontal well groups;
injecting hot water into the long pipe or the short pipe to fill the area with poor permeability of the horizontal section with the hot water, and continuously injecting water into the shaft to form pressurization and extend hydraulic fractures;
s9: the standard of the conversion production is that when the temperature between the steam injection well and the production well reaches more than 80 ℃, an effective oil drainage channel is established between the steam injection well and the production well, so as to judge whether the steam circulation can be stopped or not, and the SAGD production stage is started;
s10: injecting steam into the control well to assist in oil displacement; in the production stage of the SAGD double horizontal wells, steam is injected into a control well to assist oil displacement;
s11: at the initial development stage of a steam cavity of the SAGD well group, injecting steam through a control well, increasing the temperature of the tail end, supplementing formation energy, assisting oil displacement and increasing the recovery ratio;
s12: improving steam flow of a well with a sandwich layer at the tail end through a control well, and opening an auxiliary steam cavity; changing the original ground stress and water saturation of a reservoir;
s13: and controlling the well to produce and recover oil at the later development stage of the steam cavity of the SAGD well group.
Specifically, the adjustment of the earth stress around the wellbore is mainly based on two principles:
1) the porous elasticity principle, the diffusion of the injected hot solvent in the oil sand of the reservoir can change the pore pressure around the shaft;
2) the thermoelastic principle, the injected hot water can heat the reservoir, and can cause the reservoir around the shaft to generate thermal stress.
Specifically, the method for determining the temperature connectivity between the horizontal well groups in step S7 is to inject hot water into the injection well and monitor the changes of the temperature sensors in the horizontal direction of the production well.
Specifically, the requirement for communication among different areas means that steam communication areas with different permeabilities need to be formed in a horizontal section in order to achieve the purpose that a steam cavity is uniformly developed along the horizontal section in the SAGD production stage.
The arrangement of the SAGD horizontal well groups in the thick oil reservoir is shown in figure 1, the SAGD horizontal well groups are basically kept parallel and are kept coplanar in the vertical direction, the upper horizontal well is an injection well, and the lower horizontal well is a production well.
As shown in figure 1, due to the influence of reservoir heterogeneity, when the SAGD horizontal well group extends along the horizontal direction, the permeability of the reservoir fluctuates to a large extent, so that the traditional SAGD rapid preheating technology has difficulty in enabling the whole horizontal section to generate a uniform steam cavity communication area.
In addition, due to the influence of the well completion structure, the liquid suction capacity of the whole horizontal section has large difference, and the liquid suction capacity of the heel part of the horizontal well is generally far larger than that of the toe part, so that a flow channel is preferentially formed at the heel part when steam circulates, the injected steam cannot effectively heat the toe part, and a non-uniform steam cavity is formed.
The state modification of the horizontal well group is closely related to the pressure diffusion of the injected hot water in the reservoir, and the faster the pressure diffusion speed of the injected hot water in the reservoir, the faster the state modification speed of the horizontal well group. In the process of modifying the state of the horizontal well group, the storage area which is modified by the ground stress can be calculated through a variable pressure test, whether the pore water pressure and the temperature between the horizontal well groups are communicated with each other or not is checked, and after the pore water pressure and the temperature between the double wells interact with each other, the operation of modifying the state of the horizontal well group can be finished.
After the double wells or the single well is continuously injected and pressurized, an expansion area is formed between the double wells in the area 2 and is connected with the double wells, and the judgment can be carried out by adopting the mutual response of the pressure in the double wells
Whether the flash zone between the twin wells in zone 2 is already open.
After the whole expansion operation construction is finished, steam is injected into the long pipes in the horizontal well group at the same time, condensed water is removed through the short pipes, and steam circulation is carried out. And when the horizontal well groups are uniformly communicated with each other, the SAGD production stage can be switched to.
The aim of the invention is the uniform exploitation of SAGD horizontal well groups during the production phase (uniform development of the steam cavity). Due to the effects of reservoir permeability, completion configuration, etc., it is desirable to create steam communication zones of different permeability in different zones along the horizontal section to achieve uniform development of the steam cavity along the horizontal section.
In conclusion, compared with the prior art, the invention adopts the control well to penetrate the interlayer according to the geological condition of the horizontal section, and the heavy oil reservoir is transformed in a targeted manner; the steam channel is reestablished, the permeability of the reservoir is changed, the secondary development of the steam cavity is realized, the operation is simple, and the cost is low; different permeability steam communication zones can be created in the heel and toe of the SAGD horizontal well group, respectively, limiting the impact of the completion structure on the non-uniform development of the steam cavity.
Finally, it should be noted that: although the present invention has been described in detail with reference to the foregoing embodiments, it will be apparent to those skilled in the art that modifications may be made to the embodiments or portions thereof without departing from the spirit and scope of the invention.
Claims (3)
1. A method for drawing at the tail end of a horizontal well group with an interlayer in a SAGD control well reservoir is characterized by comprising the following steps: the method comprises the following steps:
s1: well selection:
(1) the new block steam cavity does not develop into an SAGD double horizontal well group, and the bottom of the well has no natural crack and no abnormal pressure area;
(2) the tail end of the converted SAGD double horizontal well group is poor in development, and a low-yield well group is formed;
(3) SAGD dual horizontal well groups with natural sandwiches resulting in poor temperature connectivity;
s2: and (3) testing and analyzing:
measuring the ground stress data of the oil reservoir; permeability of an interlayer and a reservoir with poor connectivity, lithology analysis and a micro-differential pressure permeability experiment; well group production history data including, but not limited to, steam volume, temperature, pressure, production;
s3: and (3) controlling well drilling design:
analyzing oil reservoir cover layer data, designing fracturing pressure breakthrough by an interlayer, finding areas with minimum stress at the upper end layer and the lower end layer of the interlayer, and drilling a well to penetrate through the interlayer;
establishing a geological stress model through data analysis, obtaining an area with poor horizontal section permeability, and performing a pressure difference experiment to obtain a fracturing control pressure value;
designing reservoir pressure to obtain the minimum distance and the maximum distance range from a control well to the SAGD double-horizontal well group;
s4: designing a perforation layer, and selecting two positions above and below a reservoir interlayer for perforation;
s5: the drilled SAGD double horizontal well group should keep the two wells parallel as much as possible and coplanar in the vertical direction; the short pipe is arranged at the beginning end of the SAGD double horizontal well group and is called heel for short, and the long pipe is arranged at the tail end of the horizontal well group and is called toe for short;
s6: injecting steam into the SAGD double-horizontal well group, performing steam circulation for 5-7 days, wherein the pressure of the injected steam is less than the original formation pressure, preheating a reservoir layer around the SAGD horizontal well group, and removing heavy oil deposition in the well group;
s7: steam circulation, the steam injection pressure of the steam circulation is higher than the pore pressure of the reservoir and lower than the minimum main stress of the stratum;
carrying out steam circulation in the SAGD double-horizontal well group at the same time until the well group realizes thermal communication to reach a production transfer condition;
steam circulation means injecting steam into the horizontal well group through the long pipe and discharging condensed water in the horizontal well group through the short pipe to achieve the purpose of heating the reservoir;
s8: according to the geological condition of a reservoir, selecting a single well or double wells to inject hot water simultaneously, wherein the SAGD double-horizontal well group comprises an injection well and a production well, the hot water is injected from one of the injection well or the production well by the single well, and the hot water is injected from the double wells into the injection well and the production well simultaneously, so that the original ground stress and the water saturation of the reservoir are changed;
injecting solvent with large displacement, and judging the temperature connectivity among the horizontal well groups;
the injection pressure is monitored and controlled in the whole process, the hot water injection speed is adjusted in time, and macroscopic tension cracks are prevented from being formed between the horizontal well groups;
injecting hot water into the long pipe or the short pipe to fill the area with poor permeability of the horizontal section with the hot water, and continuously injecting water into the shaft to form pressurization and extend hydraulic fractures;
s9: the standard of the conversion production is that when the temperature between the steam injection well and the production well reaches more than 80 ℃, an effective oil drainage channel is established between the steam injection well and the production well, so as to judge whether the steam circulation can be stopped or not, and the SAGD production stage is started;
s10: injecting steam into the control well to assist in oil displacement; in the production stage of the SAGD double horizontal wells, steam is injected into a control well to assist oil displacement;
s11: at the initial development stage of a steam cavity of the SAGD well group, injecting steam through a control well, increasing the temperature of the tail end, supplementing formation energy, assisting oil displacement and increasing the recovery ratio;
s12: improving steam flow of a well with a sandwich layer at the tail end through a control well, and opening an auxiliary steam cavity; changing the original ground stress and water saturation of a reservoir;
s13: and controlling the well to produce and recover oil at the later development stage of the steam cavity of the SAGD well group.
2. The SAGD control well reservoir tail tieback method of claim 1, wherein: the adjustment of the earth stress around the wellbore is mainly based on two principles:
1) the porous elasticity principle, the diffusion of the injected hot solvent in the oil sand of the reservoir can change the pore pressure around the shaft;
2) the thermoelastic principle, the injected hot water can heat the reservoir, and can cause the reservoir around the shaft to generate thermal stress.
3. The SAGD control well reservoir tail tieback method of claim 1, wherein: the method for judging the temperature connectivity between the horizontal well groups in step S7 is to inject hot water into the injection well and monitor the changes of the temperature sensors in the horizontal direction of the production well.
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