CN106968649B - Ignition method and exploitation method for steam channeling oil reservoir - Google Patents
Ignition method and exploitation method for steam channeling oil reservoir Download PDFInfo
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- CN106968649B CN106968649B CN201710287745.4A CN201710287745A CN106968649B CN 106968649 B CN106968649 B CN 106968649B CN 201710287745 A CN201710287745 A CN 201710287745A CN 106968649 B CN106968649 B CN 106968649B
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- 238000000034 method Methods 0.000 title claims abstract description 62
- 230000005465 channeling Effects 0.000 title abstract description 42
- 238000002347 injection Methods 0.000 claims abstract description 161
- 239000007924 injection Substances 0.000 claims abstract description 161
- 238000004519 manufacturing process Methods 0.000 claims abstract description 103
- 238000010793 Steam injection (oil industry) Methods 0.000 claims abstract description 10
- 230000008859 change Effects 0.000 claims abstract description 10
- 230000000977 initiatory effect Effects 0.000 claims abstract description 4
- 230000035699 permeability Effects 0.000 claims description 45
- 230000015572 biosynthetic process Effects 0.000 claims description 14
- 238000011084 recovery Methods 0.000 claims description 9
- 238000010304 firing Methods 0.000 claims 1
- 239000003921 oil Substances 0.000 abstract description 245
- 239000000295 fuel oil Substances 0.000 abstract description 15
- 230000000694 effects Effects 0.000 abstract description 7
- 239000010410 layer Substances 0.000 description 140
- 239000007789 gas Substances 0.000 description 25
- 238000009413 insulation Methods 0.000 description 18
- 238000007254 oxidation reaction Methods 0.000 description 13
- 230000003647 oxidation Effects 0.000 description 10
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 8
- 230000008569 process Effects 0.000 description 7
- 230000000638 stimulation Effects 0.000 description 7
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 6
- 238000002485 combustion reaction Methods 0.000 description 4
- 238000000605 extraction Methods 0.000 description 4
- 239000004615 ingredient Substances 0.000 description 4
- 238000011065 in-situ storage Methods 0.000 description 3
- 238000005065 mining Methods 0.000 description 3
- 229910052757 nitrogen Inorganic materials 0.000 description 3
- 239000003129 oil well Substances 0.000 description 3
- 239000010779 crude oil Substances 0.000 description 2
- 238000010438 heat treatment Methods 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000007872 degassing Methods 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 230000008014 freezing Effects 0.000 description 1
- 238000007710 freezing Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 239000011229 interlayer Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000000750 progressive effect Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- -1 specifically Substances 0.000 description 1
- 239000002349 well water Substances 0.000 description 1
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/11—Perforators; Permeators
- E21B43/116—Gun or shaped-charge perforators
- E21B43/1185—Ignition systems
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- Fats And Perfumes (AREA)
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Abstract
The invention discloses an ignition method and a exploitation method of a steam channeling oil reservoir, wherein the ignition method comprises the steps of injecting air into an oil layer of the oil reservoir through an oil casing annulus formed by a first pipe column of an injection well and a casing, and detecting a product in a production well; when the tail gas is detected to appear in the production well, injecting steam through an injection pipe column of the production well; and detecting a temperature change at a predetermined location in the injection well; stopping steam injection when the temperature at the predetermined location in the injection well rises to a first preset temperature and initiating production through a second tubing string in the production well; and acquiring the air temperature at the outlet position of the injection well, when the outlet temperature reaches a second preset temperature, putting an igniter into the injection well, and starting the igniter to ignite after the igniter is put to the bottom boundary of an oil layer. The ignition method and the exploitation method of the steam channeling oil reservoir provided by the invention can greatly improve the ignition success rate and the exploitation effect of the steam channeling heavy oil reservoir.
Description
Technical Field
The invention relates to the field of in-situ combustion oil extraction, in particular to an ignition method and a exploitation method of a steam channeling oil reservoir.
background
Heavy oil refers to a high viscosity heavy crude oil having a viscosity greater than 100mpa.s (millipascal seconds) at formation temperature and degassing conditions. According to the viscosity, the oil can be divided into common thick oil (100 to 10000mPa.s), extra thick oil (10000 to 50000mPa.s) and super thick oil (more than 50000 mPa.s). In the oil exploitation of oil fields, because thick oil has the characteristics of special high viscosity and high freezing point, the thick oil has poor mobility in reservoirs and mineshafts, and the conventional exploitation recovery ratio is low, namely normal economic yield cannot be ensured. To ensure reasonable recovery, oil is often recovered by reducing the viscosity of the crude oil. The prior art heavy oil recovery techniques include thermal recovery techniques. Among them, a typical thermal oil recovery method is steam stimulation recovery by injecting steam into an oil reservoir.
For heavy oil reservoirs, especially heavy oil reservoirs with high porosity and permeability, steam channeling can occur after an early steam stimulation exploitation mode. Specifically, the locations where steam channeling occurs mainly include the upper portion of the oil reservoir and the oil reservoir having a very poor permeability.
among them, the main reasons why the upper part of the oil layer is liable to cause the steam channeling are: in the prior art, the steam injection mode is generally a general injection mode, the dryness of upper steam is high, the steam channeling degree is strong, the dryness of the lower part is gradually reduced, and the steam channeling degree is weak under the same oil layer condition; meanwhile, as the steam huff and puff turns are increased, the upper portion is used more, and the large stratum is used for serious depletion.
In addition, the permeability range specifically refers to the ratio of the maximum permeability to the minimum permeability of the oil layer, and generally, when the permeability range is greater than 4, the permeability range of the oil layer is relatively large. The reason why the oil layer with extremely poor permeability is easy to cause the steam channeling is that the oil layer has strong suction capacity due to the large difference of permeability, and therefore is a steam channeling layer.
After the early stage of steam stimulation, the exploitation degree of the steam channeling layer is far greater than that of the non-steam channeling layer, and the oil saturation degree of the steam channeling layer is very low and is generally about 10%. For in-situ combustion, low oil saturation is a fatal factor of low success rate of ignition. Therefore, for a heavy oil reservoir which is easy to generate steam channeling after steam stimulation, an effective ignition method needs to be provided to solve the problem of low ignition success rate of the steam channeling heavy oil reservoir.
Disclosure of Invention
The invention aims to provide an ignition method and a mining method for a steam channeling oil reservoir, which can greatly improve the ignition success rate and the mining effect of the steam channeling heavy oil reservoir.
The above object of the present invention can be achieved by the following technical solutions:
A method of exploiting a steam-channeling oil reservoir, comprising:
The method comprises the steps that a preset number of perforation forming perforation sections are arranged in unit length of positions where oil layers are located of a production well and an injection well;
Running a first string in the injection well, running a second string and an injection string in the production well, wherein the injection string extends into the reservoir at a predetermined incline;
Injecting air into an oil layer of an oil reservoir through an oil casing annulus formed by a first string of an injection well and a casing, and detecting a product in the production well;
When the tail gas is detected to appear in the production well, injecting steam through an injection pipe column of the production well; and detecting a temperature change at a predetermined location in the injection well;
stopping injecting steam when the temperature at the preset position in the injection well rises to a first preset temperature, and performing primary oil recovery through a second pipe column in the production well;
Acquiring the air temperature at the outlet position of the injection well, when the air temperature at the outlet position of the injection well reaches a second preset temperature, lowering an igniter into the injection well, and starting the igniter to ignite after the igniter is lowered to the bottom boundary of an oil layer;
producing oil through a second string of the production well.
In a preferred embodiment, the determination formula of the number of perforations in the perforation segment per unit length is as follows:
N＝N0-(A-A0)/(A0/N0)
Wherein N represents the number of perforations per meter of perforation segment, and the unit is hole/meter; n0 represents the average number of perforations per meter, in units of perforations per meter; a represents the current permeability of the reservoir in Darcy; a0 represents the average permeability of the reservoir in Darcy.
In a preferred embodiment, before the igniter ignites, the method further includes:
acquiring oil pressure, and extracting oil through a first tubular column of the injection well when the oil pressure is greater than preset oil pressure;
When the oil pressure is below a preset oil pressure, the first string of the injection well stops producing and gas is injected through the first string of the injection well for a predetermined length of time.
In a preferred embodiment, the method further comprises: increasing the power of the igniter after injecting gas into the first string of the injection well for a predetermined period of time.
A method of igniting a gas channeling reservoir, comprising:
Injecting air into an oil layer of the oil reservoir through an oil casing annulus formed by a first tubular column of the injection well and a casing, and detecting a product in the production well;
When the tail gas is detected to appear in the production well, injecting steam through an injection pipe column of the production well; and detecting a temperature change at a predetermined location in the injection well;
Stopping steam injection when the temperature at the predetermined location in the injection well rises to a first preset temperature and initiating production through a second tubing string in the production well;
And acquiring the air temperature at the outlet position of the injection well, when the outlet temperature reaches a second preset temperature, putting an igniter into the injection well, and starting the igniter to ignite after the igniter is put to the bottom boundary of an oil layer.
In a preferred embodiment, the injection strength of air into the reservoir of the reservoir through the oil jacket annulus formed by the first string of injection wells and the casing is 500 squares per meter of reservoir thickness and increases with a strength of 50 squares per month per meter of reservoir thickness.
In a preferred embodiment, the reservoir comprises a plurality of oil zones, wherein the uppermost zone is an upper zone, and the predetermined locations in the injection well comprise: the upper oil layer and an oil layer having a permeability greater than a predetermined value.
in a preferred embodiment, the first preset temperature is 250 to 300 degrees celsius.
In a preferred embodiment, the reservoir comprises a plurality of oil zones, wherein the lowermost oil zone is a lower zone and the injector well exit location is within the lower zone depth.
In a preferred embodiment, the second predetermined temperature is greater than 400 degrees celsius.
In a preferred embodiment, the reservoir comprises a plurality of oil layers, and at the position of each oil layer, the first pipe column and the second pipe column are provided with perforated sections at the positions of the oil layers, and the perforated sections are positioned in a preset thickness range of the oil layer close to the lower part.
In a preferred embodiment, the number of perforations per unit length of each perforation segment is determined according to the current permeability of the oil layer corresponding to the perforation segment, the average permeability of the oil reservoir, the average number of perforations per unit length and the theoretical number of perforations per unit length.
in a preferred embodiment, the determination formula of the number of perforations per meter of perforation segments is as follows:
N＝N0-(A-A0)/(A0/N0)
Wherein N represents the number of perforations per meter of perforation segment, and the unit is hole/meter; n0 represents the average number of perforations per meter, in units of perforations per meter; a represents the current permeability of the reservoir in Darcy; a0 represents the average permeability of the reservoir in Darcy.
in a preferred embodiment, before the igniter ignites, the method further includes:
acquiring oil pressure, and extracting oil through a first tubular column of the injection well when the oil pressure is greater than preset oil pressure;
When the oil pressure is below a preset oil pressure, the first string of the injection well stops producing and gas is injected through the first string of the injection well for a predetermined length of time.
In a preferred embodiment, the method further comprises: increasing the power of the igniter after injecting gas into the first string of the injection well for a predetermined period of time.
the invention has the characteristics and advantages that: when the ignition method of the steam channeling oil reservoir provided by the application is used for ignition, in the whole ignition process, the original steam channeling layer is ignited by utilizing the heat of both sides of steam and air low-temperature oxidation heat release, because the steam pushes the process from the production well to the injection well, the lighter components are pushed at first, and therefore the oil saturation of the near well of the injection well is equivalently improved, especially the oil saturation of the light components, the low-temperature oxidation heat release rate of the light components is high, the rapid temperature rise is facilitated, and the ignition requirement is met. And (4) igniting non-steam-channeling layers by utilizing steam and the heat of an igniter, wherein the layers have high oil saturation and are easy to ignite. In addition, the ignited steam channeling layer can transfer heat upwards and downwards after a temperature field is formed, the temperature field of the subsequent layer to be ignited is improved, the ignition effect is improved in an auxiliary mode, and the ignition success rate of the steam channeling heavy oil reservoir can be greatly improved on the whole.
drawings
FIG. 1 is a flow chart illustrating the steps of a method for igniting a gas channeling reservoir in accordance with an embodiment of the present disclosure;
FIG. 2 is a schematic illustration of a well pattern arrangement in an embodiment of the present application;
FIG. 3 is a schematic plan view of one of the patterns in an embodiment of the present application;
Fig. 4 is a flow chart illustrating steps of a method for producing a gas channeling reservoir in accordance with an embodiment of the present disclosure.
Description of reference numerals:
the injection well comprises an injection well 1, a first casing 10, a first oil pipe 11, an injection and production primary pump 12, a first tail pipe 13, a first plug 14, an injection perforation section 15, a first packer 16, a thermal insulation layer 17, a production well 2, a second casing 20, a second oil pipe 21, an oil well pump 22, a second tail pipe 23, a second plug 24, a production perforation section 25, a thermal insulation pipe 3, a sieve pipe 31, a second packer 32 and an opening 33.
Detailed Description
The technical solutions of the present invention will be described in detail below with reference to the accompanying drawings and specific embodiments, it should be understood that these embodiments are merely illustrative of the present invention and are not intended to limit the scope of the present invention, and various equivalent modifications of the present invention by those skilled in the art after reading the present invention fall within the scope of the appended claims.
Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. The terminology used herein in the description of the present application is for the purpose of describing particular embodiments only and is not intended to be limiting of the application.
It will be understood that when an element is referred to as being "disposed on" another element, it can be directly on the other element or intervening elements may also be present. When an element is referred to as being "connected" to another element, it can be directly connected to the other element or intervening elements may also be present. The terms "vertical," "horizontal," "upper," "lower," "left," "right," and the like as used herein are for illustrative purposes only and do not denote a unique embodiment.
the invention provides an ignition method of a steam channeling oil reservoir and a well pattern arrangement structure, which can greatly improve the ignition success rate of the steam channeling heavy oil reservoir.
As steam stimulation is used, the parameters of the developed heavy oil reservoir and the change of the water saturation of a near well are shown in table 1, the oil saturation of the heavy oil reservoir is greatly reduced relative to that before steam stimulation, the stimulation degree of a steam channeling layer is far greater than that of a non-steam channeling layer, and the oil saturation is very low and is about 10 percent. For in-situ combustion, low oil saturation is a fatal factor of low success rate of ignition.
Table 1 developed heavy oil reservoir parameters and near-well water saturation changes
Referring to fig. 1, a method for igniting a gas channeling reservoir provided in an embodiment of the present application may include the following steps.
Step S10: injecting air into an oil layer of the oil reservoir through an oil casing annulus formed by a first tubular column of the injection well and a casing, and detecting a product in the production well;
Step S12: when the tail gas is detected to appear in the production well, injecting steam through an injection pipe column of the production well; and detecting a temperature change at a predetermined location in the injection well;
step S14: stopping steam injection when the temperature at the predetermined location in the injection well rises to a first preset temperature and initiating production through a production string in the production well;
step S16: and acquiring the air temperature at the outlet position of the injection well, when the outlet temperature reaches a second preset temperature, putting an igniter into the injection well, and starting the igniter to ignite after the igniter is put to the bottom boundary of an oil layer.
referring to fig. 2 and 3 in combination, a well pattern arrangement provided in an embodiment of the present application may include: an injection well 1 and a production well 2 at a predetermined distance from the injection well 1; the injection well 1 is provided with a first casing 10, the depth of an oil layer of the first casing 10 is provided with an injection perforation section 15, the first casing 10 is internally provided with a first oil pipe 11, and the lower end of the first oil pipe 11 is sequentially provided with an injection-production primary pump 12, a first tail pipe 13 and a first plug 14; the production well 2 is provided with a second casing 20, the second casing 20 is provided with a production perforation section 25 at the depth of an oil layer, a second oil pipe 21 is arranged in the second casing 20, and the lower end of the second oil pipe 21 is sequentially provided with an oil well pump 22, a second tail pipe 23 and a second plug 24; and an insulating pipe 3 extending into the oil reservoir is further arranged in the second sleeve 20, and a sieve pipe 31 is arranged outside the pipe section of the insulating pipe 3 in the oil reservoir.
In this embodiment, the well pattern arrangement may be applied in a reservoir comprising at least one oil layer in the depth direction, in particular for a reservoir which may comprise a plurality of oil layers in the depth direction. Wherein, in the plurality of oil layers, an interlayer is arranged between any two adjacent oil layers.
In this embodiment, the well pattern arrangement may comprise: an injection well 1 and a production well 2 at a predetermined distance from said injection well 1. As shown in fig. 3, in a single well pattern arrangement, the number of injection wells 1 may be one, which may be located at a central position of the well pattern arrangement. The number of the production wells 2 may be plural, for example, 8. When the number of production wells 2 is 8, 8 production wells 2 may be evenly arranged around the injection well 1, forming an inverse nine-point well pattern. Of course, the particular form of the well pattern arrangement is not limited to the above examples, and the application is not specifically limited thereto. Specifically, the well spacing between the injection well 1 and the production well 2 is a well spacing between injection wells and production wells, wherein the well spacing between the injection well 1 and the production wells 2 can be adaptively adjusted according to actual conditions such as distribution of an actual oil layer, and the application is not specifically limited herein.
in this embodiment, the first string in the injection well 1 may be used for injecting air and also for producing oil from the lower oil layer. Specifically, a first casing 10 may be disposed within the injection well 1, and the first casing 10 may be provided with an injection perforation section 15 at a depth of an oil formation. The injection perforation segment 15 is used to communicate the first casing 10 with the oil formation. A first oil pipe 11 is arranged in the first sleeve 10, and an injection-production primary pump 12, a first tail pipe 13 and a first plug 14 are sequentially arranged at the lower end of the first oil pipe 11. Wherein, the injection-production primary pump 12 can be used for gas injection and oil production. During injection, gas can enter an oil layer through the oil pipe and the injection-production primary pump 12 in sequence.
before the igniter ignites, the method for igniting the gas channeling oil reservoir further comprises the following steps: acquiring oil pressure, and extracting oil through a first pipe column of the injection well 1 when the oil pressure is greater than preset oil pressure; when the oil pressure is below a preset oil pressure, the first string of the injection well 1 stops producing and gas is injected through the first string of the injection well 1 for a predetermined period of time.
Further, the power of the igniter is increased after injecting gas into the first string of the injection well 1 for a predetermined period of time.
in this embodiment, the oil pressure may be recorded at the wellhead. Specifically, the wellhead valve is provided with a pressure gauge, the wellhead tubing valve is communicated to the tubing, and the pressure in the pressure gauge represents the tubing pressure.
And when the oil pressure is greater than the preset oil pressure, oil extraction is carried out through the first tubular column 12 of the injection well 1, and oil extraction is mainly carried out by starting the injection-production primary pump 12. When the primary injection and production pump 12 is used for oil extraction, the primary injection and production pump 12 is mainly used for pushing oil, gas and water in an oil layer into the injection well 1 due to steam injected into the production well 2 after steam is injected, and at the moment, the primary injection and production pump 12 is required to be utilized for extracting the oil, gas and water from the injection well 1 so as to prevent the bottom of the well from being ignited due to the oil, gas and water pushed by the steam in the production well 2 during subsequent ignition. Wherein, the production time of the injection-production one-time pump 12 can be determined according to the oil pressure.
and when the oil pressure is lower than 0.5MPa, the injection-production primary pump 12 stops production. In this case, an igniter may be directly inserted into the injection well 1, the igniter may be turned on to heat the air to about 200 ℃, and a gas, specifically, nitrogen may be injected into the first column of the injection well 1. At this time, air is continuously injected into the oil jacket annulus of the injection well 1. The injected nitrogen is used to heat displace oil from the injection well bore into the formation. Specifically, the time for injecting nitrogen may be 1-2d (days), that is, the predetermined time period may be 1-2 days, and of course, the predetermined time period may be adaptively adjusted according to the oil-gas-water discharge condition of the injection well 1, and the application is not specifically limited herein.
Then the power of the electric igniter is started to increase. When the air temperature is 400 ℃, the total ignition requirement is met, and air is continuously injected into the oil sleeve annulus of the injection well 1 at the moment, and the ignition time is kept between 7 and 15 days.
in this embodiment, a second casing 20 may be disposed in the production well 2, a production perforation section 25 is disposed at the depth of the oil layer of the second casing 20, a second oil pipe 21 is disposed in the second casing 20, and an oil well pump 22, a second tail pipe 23 and a second plug 24 are sequentially disposed at the lower end of the second oil pipe 21. And an insulating pipe 3 extending into the oil reservoir is further arranged in the second sleeve 20, and a sieve pipe 31 is arranged outside the pipe section of the insulating pipe 3 in the oil reservoir. The heat insulation pipe 3 is used for injecting high-temperature high-pressure high-dryness steam into an oil layer so as to reduce the viscosity of the thick oil. The heat insulation pipe 3 is provided with an opening 33 for communicating the sieve pipe 31 and an external oil layer.
The thermal insulation pipe 3 has a relative head end and a tail end, wherein the head end is located in the straight well section of the production well 2, the tail end extends into the oil layer, especially when the oil reservoir contains a plurality of oil layers, all oil layers are worn to establish by the tail end, and the tail end is located in the oil layer of the lowest part. In a specific embodiment, the tail end of the thermal insulation pipe 3 is positioned at a half position of the well spacing of the injection and production well. When the tail end of the heat insulation pipe 3 is positioned at the half position of the well distance of the injection and production well, the steam injected from the heat insulation pipe 3 can be fully injected into each oil layer by a length which is economic and reasonable, and an ideal viscosity reduction effect is achieved.
In the present embodiment, the number of stages of the injection perforation stage 15 or the production perforation stage 25 may be equal to the number of layers of the oil layer. And when the number of oil layers in the oil reservoir is more than 2, the number of the injection perforation section 15 or the production perforation section 25 is more than 2. Specifically, the opening 33 of the injection perforation segment 15 may be configured in a selective perforation manner, for example, may be configured according to parameters such as permeability corresponding to an oil layer, and the application is not limited in this respect.
In a specific embodiment, the oil formation may include a first oil formation and a second oil formation, a sandwich layer is arranged between the first oil formation and the second oil formation, the injection perforation section 15 includes a first injection perforation section 15 and a second injection perforation section 15, and a first packer 16 is arranged in an annulus between the first casing 10 and the first oil pipe 11 and at the depth of the sandwich layer. The first packer 16 is used to separate two adjacent oil zones and can ensure that air injected from the annulus between the first tubing 11 and the first casing 10 can reliably enter the respective oil zone through the injection perforation segment 15. Furthermore, the reservoir may comprise three or more oil layers, the injection well 1 being provided with perforated sections at the location of the respective oil layers, and a first packer 16 being provided in the interval between two adjacent oil layers.
Further, a heat insulation layer 17 is arranged between the position below the first packer 16 and the injection-production primary pump 12. The insulation layer 17 is primarily used to ensure that the igniter outlet air is maintained at a higher temperature.
For example, the length of the thermal insulation layer 17 may be 50 meters, and of course, the length of the thermal insulation layer 17 is not limited to the above examples, and may be adjusted according to the distribution of the actual oil reservoir, and the like, and the application is not limited in this respect. The specific form of the thermal insulation layer 17 may be an insulation layer provided outside the oil pipe and having a thermal insulation function, and the thermal insulation layer 17 may also be a pipe column directly having a thermal insulation function, although the specific form of the thermal insulation layer 17 is not limited to the above examples, and the present application is not limited thereto.
In a specific embodiment, when the reservoir comprises a first oil layer and a second oil layer along a depth direction, wherein the first oil layer is located at an upper portion of the second oil layer, the first injection perforation segment 15 is located within the first oil layer, and the second injection perforation segment 15 is located within the second oil layer, the injection-production secondary pump 12 is located within the second injection perforation segment 15. That is, the injection-production one-time pump 12 is located in the depth range of the lowest oil layer, which can be used to inject air into the oil layer on the one hand, and can produce oil in the oil layer to the surface on the other hand.
in one embodiment, when the reservoir comprises a first layer, a sandwich and a second layer from top to bottom along the depth direction, the production bore section 25 comprises a first production bore section and a second production bore section, the first production bore section is located within the first layer, the second production bore section is located within the second layer, and the pump 22 is located within the second production bore section. That is, the oil layer at the lowest position of the oil pump 22 is located within the depth range, and since the oil flows downward under the action of gravity after entering the shaft of the production well 2, the oil flowing into the production well 2 from the oil reservoir can be fully extracted by reasonably setting the position of the oil pump 22.
In one embodiment, the insulated pipe 3 has a first pipe section located within the second casing 20 and a second pipe section located within the oil formation, the second pipe section having a predetermined slope.
In this embodiment, the first section of the insulated pipe 3 may be a straight section of the well located in the second casing 20 of the production well 2, and the second section of the insulated pipe extends out of the second casing 20 to the reservoir. And a certain included angle is formed between the second pipe section and the first pipe section, namely the second pipe section has a preset inclination. Specifically, the slope of the second pipe section may be 45 degrees to 85 degrees, but the predetermined slope may be different according to actual conditions such as the well spacing between the production well 2 and the injection well 1, the number of layers and the total depth of oil layers, and the application is not limited in particular.
In one embodiment, the screen 31 is positioned outside the second pipe section, a second packer 32 is positioned between the second pipe section and the screen 31, and the second pipe section is provided with openings 33 at locations that are disposed in the formation.
In this embodiment, the second packer 32 is used to pack each oil layer, and is used to ensure that layered steam injection can be achieved during steam injection. The second pipe section is provided with an opening 33 at a position penetrating the oil layer, and injected steam can be injected into the corresponding oil layer through the opening 33. Wherein the opening 33 may be implemented by a sliding sleeve switch disposed on the second pipe section. When the opening 33 is realized by a sliding sleeve switch, the opening 33 has two states of opening and closing, and the opening 33 can be opened and closed according to actual requirements. In addition, the opening 33 may be implemented in other forms, and the present application is not limited thereto.
In this embodiment, the number of the second packers 32 is the same as the number of layers of oil layers in the oil reservoir, so as to ensure that each oil layer is separated, thereby realizing layered steam injection development.
When utilizing above-mentioned well pattern arrangement structure to ignite, can inject the air into the injection well with the mode of general injection, the air of injecting into the well can get into the oil reservoir through the perforation section in from the air that injects into the well, is favorable to the oil in the oil reservoir to take place low temperature oxidation reaction, carries out heat release. Specifically, the intensity of the injected air may be 500 squares per meter of oil layer thickness. When the injection strength of the air is 500 square of the thickness of each meter of oil layer, an ideal oxidation effect can be achieved. Specifically, the strength of the injected air may also be adaptively adjusted according to the parameter conditions of the actual oil reservoir, and the application is not specifically limited herein. The strength of 50 square/month per meter of oil layer thickness can be increased gradually subsequently, so that sufficient air supply amount in the production process is ensured.
In this embodiment, when air is injected into the oil layer of the reservoir through the first string of the injection well, the product in the injection well can be detected. Specifically, a tail gas detection device can be arranged at the wellhead of the injection well.
In this embodiment, the number of oil layers of the oil reservoir may be one layer or may be multiple layers. When the presence of tail gas in the injection well is detected, it is an indication that at least one reservoir is present that has undergone a low temperature oxidation reaction with the injected air.
In most cases, the reservoir includes a plurality of oil zones, wherein an uppermost zone is an upper zone, and the predetermined locations in the injection well include: the upper oil layer and an oil layer having a permeability greater than a predetermined value. Wherein, the permeability is larger than the predetermined value, which indicates that the oil layer is a high permeability oil layer, and the permeability range is larger than 3. The permeability grade difference (K mn) is the ratio of the maximum permeability (K max) to the minimum permeability (K min), and shows the distribution range and the difference degree of the permeability, wherein K mn is Kmax/K min and the permeability grade difference (K mn) is larger than l. For oil layers with very poor permeability greater than 3, a high permeability layer is defined.
When injecting air, it is preferable to inject air into the upper oil layer and the high-permeability oil layer through an injection well. The specific reasons are as follows: firstly, because the oil layer has a fast temperature rise speed and a high permeable layer has strong air suction capacity, the formation temperature is high in the steam injection huff-puff process in the early stage, the low-temperature oxidation heat release is facilitated, the low-temperature oxidation reaction is fast when air enters the formation, when the steam is injected by the opposite side, the oil layer can be heated by the heat of the steam and the low-temperature oxidation heat release, and the oil layer has a fast temperature rise speed; secondly, the lighter components are pushed by the steam/hot water firstly, the temperature of the stratum rises, low-temperature oxidation is intensified after the steam/hot water meets air, the steam/hot water further rises, and the fire is easy to catch fire. I.e. the horizons can be ignited without an igniter.
Detecting the temperature change at a preset position in the injection well while injecting steam through an injection pipe column of the production well, and determining the next process by judging the temperature change condition at the preset position of the injection well.
When the temperature at a predetermined location in the injection well rises to a first preset temperature it is indicated that the ignition temperature of the lighter component has been reached at this point.
At this time, the injection of steam into the injection string of the production well can be stopped, and the oil pump in the second string of the production well is opened to recover oil.
specifically, the first preset temperature may be 250 to 300 ℃. When the temperature reaches the above temperature range, the oil layer is on fire because the lighter components burn under underground conditions at a fire temperature of 200 ℃ to 250 ℃.
When the number of layers of the oil layer of the oil reservoir is multiple, steam can be respectively injected into the injection pipe column of the production well in a layered injection mode. And continuously injecting the well air in the steam injection process of the production well without stopping.
In the embodiment, by detecting the air temperature at the outlet position of the injection well, when the air temperature at the outlet position reaches a second preset temperature, an igniter is put into the injection well, and the igniter is started to ignite after the igniter is put to the bottom boundary of an oil layer. That is, in this embodiment, the initial position of the igniter is in a position close to the oil layer at the lowermost end, and when the oil reservoir includes a plurality of oil layers, it is not necessary to perform mobile ignition because after the lowermost oil layer is ignited, the temperature of the oil layer is raised by the heat of combustion of the oil layer, and the air will get a chance of secondary heating when passing through, so that the temperature of the air can reach the ignition requirement.
wherein the second preset temperature is above 400 ℃. When the air temperature at the outlet of the injection well reaches above 400 ℃, the temperature requirement that the oil layer at the moment can meet electric ignition is indicated.
in the embodiment of the application, in the whole ignition process, the original steam channeling layer is ignited by utilizing the heat of both steam and air low-temperature oxidation heat release, because the steam pushes the oil-containing saturation near the injection well, especially the oil-containing saturation of the light component, the low-temperature oxidation heat release rate of the light component is high, thereby being beneficial to rapid temperature rise and achieving the ignition requirement. And (4) igniting non-steam-channeling layers by utilizing steam and the heat of an igniter, wherein the layers have high oil saturation and are easy to ignite. In addition, the ignited steam channeling layer can transfer heat upwards and downwards after a temperature field is formed, the temperature field of the subsequent layer to be ignited is improved, the ignition effect is improved in an auxiliary mode, and the ignition success rate of the steam channeling heavy oil reservoir can be greatly improved on the whole.
In one embodiment, the reservoir comprises a plurality of oil layers, and at the position of each oil layer, the first pipe column and the second pipe column are provided with perforated sections at the positions of the oil layers, and the perforated sections are located in a preset thickness range of the oil layer close to the lower part.
in this embodiment, the casing layers corresponding to the first and second columns of the injection and production wells of the oil reservoir are provided with perforated sections for communicating with the oil layer, and the perforated sections may be located in the middle lower part of the oil layer, and may be located within a predetermined thickness range near the lower part, for example, may be below 2/3 thickness. When steam or air is injected into the oil layer from the perforation section, the utilization rate of the steam or air can be preferably improved. Specifically, the injected steam or air may contact or react with the oil in the lower-middle portion of the oil layer, and then transfer heat upward, thereby driving the upper oil layer to flow together.
Furthermore, the number of perforations in the unit length of each perforation segment is determined according to the current permeability of an oil layer corresponding to the perforation segment, the average permeability of the oil reservoir, the average number of perforations in the unit length and the theoretical number of perforations in the unit length.
the determination formula of the number of perforations per meter of the perforation section is as follows:
N＝N0-(A-A0)/(A0/N0)
Wherein N represents the number of perforations per meter of perforation segment, and the unit is hole/meter; n0 represents the average number of perforations per meter, in units of perforations per meter; a represents the current permeability of the reservoir in Darcy; a0 represents the average permeability of the reservoir in Darcy.
the determination of the number of perforations per meter of perforation segments is illustrated below in connection with table 2.
TABLE 2
| Current permeability | Difference of perforation | Theoretical calculated value of perforation |
| 583.9 | 5 | 11 |
| 308.8 | -5 | 21 |
| 740.2 | 11 | 5 |
| 176.3 | -10 | 26 |
| 560.9 | 4 | 12 |
| 284.8 | -6 | 22 |
Taking the first permeability in table 2 as an example, the current permeability is 583, the average value of the permeability is 442, the average number of perforations is 16/m, and the perforation difference 5 (583 + 442)/(442/16), then the theoretical number of perforations is 16-5-11 perforations/m
Referring to fig. 4, in an embodiment of the present application, a method for exploiting a steam channeling oil reservoir may include the following steps:
Step S11: the method comprises the steps that a preset number of perforation forming perforation sections are arranged in unit length of positions where oil layers are located of a production well and an injection well;
Step S13: running a first string in the injection well, running a second string and an injection string in the production well, wherein the injection string extends into the reservoir at a predetermined incline;
Step S15: injecting air into an oil layer of an oil reservoir through an oil casing annulus formed by a first string of an injection well and a casing, and detecting a product in the production well;
Step S17: when the tail gas is detected to appear in the production well, injecting steam through an injection pipe column of the production well; and detecting a temperature change at a predetermined location in the injection well;
Step S19: stopping injecting steam when the temperature at the preset position in the injection well rises to a first preset temperature, and performing primary oil recovery through a second pipe column in the production well;
step S21: acquiring the air temperature at the outlet position of the injection well, when the air temperature at the outlet position of the injection well reaches a second preset temperature, putting an igniter into the injection well, and starting the igniter to ignite after the igniter falls to the bottom boundary of an oil layer;
Step S23: producing oil through a second string of the production well.
In this embodiment, the location of the production or injection well perforation segments may be determined based on the location of the reservoir. The determination formula of the number of the perforations in the perforation section unit length is as follows:
N＝N0-(A-A0)/(A0/N0)
Wherein N represents the number of perforations per meter of perforation segment, and the unit is hole/meter; n0 represents the average number of perforations per meter, in units of perforations per meter; a represents the current permeability of the reservoir in Darcy; a0 represents the average permeability of the reservoir in Darcy.
In addition, the specific structure and composition of the first tubular column in the injection well or the second tubular column in the production well may refer to the specific description of the well screen arrangement structure in the above embodiments, which is not repeated herein.
In addition, in the above mining method, reference may be made to the detailed description of the ignition implementation of the gas channeling oil reservoir in steps 15 to 21, and specific details of this application are not described herein again.
After successful ignition, oil production may be performed through the second string of the production well.
On the whole, when the exploitation method of the steam channeling oil deposit that this application provided utilized the well pattern arrangement structure that this application provided to ignite, whole ignition in-process, can inject air through the injection well, inject steam through the producing well, utilize steam and the exothermic position of both sides heat ignition of air low temperature oxidation, because steam promotes the in-process from the producing well to the injection well, it is lighter component at first to promote to come over, consequently, the oil saturation of having improved injection well near, especially the oil saturation of light component, the component low temperature oxidation heat release rate of light point is high, help rapid heating up, thereby reach the ignition requirement. And (4) igniting non-steam-channeling layers by utilizing steam and the heat of an igniter, wherein the layers have high oil saturation and are easy to ignite. In addition, the ignited steam channeling layer can transfer heat upwards and downwards after a temperature field is formed, the temperature field of the subsequent layer to be ignited is improved, the ignition effect is improved in an auxiliary mode, and the ignition success rate of the steam channeling heavy oil reservoir can be greatly improved on the whole. After the ignition is successful, the gas channeling oil reservoir can be effectively exploited by utilizing a fire flooding development mode.
Any numerical value recited herein includes all values from the lower value to the upper value that are incremented by one unit, provided that there is a separation of at least two units between any lower value and any higher value. For example, if it is stated that the number of a component or a value of a process variable (e.g., temperature, pressure, time, etc.) is from 1 to 90, preferably from 20 to 80, and more preferably from 30 to 70, it is intended that equivalents such as 15 to 85, 22 to 68, 43 to 51, 30 to 32 are also expressly enumerated in this specification. For values less than 1, one unit is suitably considered to be 0.0001, 0.001, 0.01, 0.1. These are only examples of what is intended to be explicitly recited, and all possible combinations of numerical values between the lowest value and the highest value that are explicitly recited in the specification in a similar manner are to be considered.
Unless otherwise indicated, all ranges include the endpoints and all numbers between the endpoints. The use of "about" or "approximately" with a range applies to both endpoints of the range. Thus, "about 20 to about 30" is intended to cover "about 20 to about 30", including at least the endpoints specified.
All articles and references disclosed, including patent applications and publications, are hereby incorporated by reference for all purposes. The term "consisting essentially of …" describing a combination shall include the identified element, ingredient, component or step as well as other elements, ingredients, components or steps that do not materially affect the basic novel characteristics of the combination. The use of the terms "comprising" or "including" to describe combinations of elements, components, or steps herein also contemplates embodiments that consist essentially of such elements, components, or steps. By using the term "may" herein, it is intended to indicate that any of the described attributes that "may" include are optional.
A plurality of elements, components, parts or steps can be provided by a single integrated element, component, part or step. Alternatively, a single integrated element, component, part or step may be divided into separate plural elements, components, parts or steps. The disclosure of "a" or "an" to describe an element, ingredient, component or step is not intended to foreclose other elements, ingredients, components or steps.
The above embodiments in the present specification are all described in a progressive manner, and the same and similar parts among the embodiments may be referred to each other, and each embodiment is described with emphasis on being different from other embodiments.
the above description is only a few embodiments of the present invention, and although the embodiments of the present invention are described above, the above description is only for the convenience of understanding the present invention, and is not intended to limit the present invention. It will be understood by those skilled in the art that various changes in form and details may be made therein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (15)
1. A method of exploiting a steam-channeling oil reservoir, comprising:
The method comprises the steps that a preset number of perforation forming perforation sections are arranged in unit length of positions where oil layers are located of a production well and an injection well;
Running a first string in the injection well, running a second string and an injection string in the production well, wherein the injection string extends into the reservoir at a predetermined incline;
Injecting air into an oil layer of an oil reservoir through an oil casing annulus formed by a first string of an injection well and a casing, and detecting a product in the production well;
When the tail gas is detected to appear in the production well, injecting steam through an injection pipe column of the production well; and detecting a temperature change at a predetermined location in the injection well;
stopping injecting steam when the temperature at the preset position in the injection well rises to a first preset temperature, and performing primary oil recovery through a second pipe column in the production well;
Acquiring the air temperature at the outlet position of the injection well, when the air temperature at the outlet position of the injection well reaches a second preset temperature, lowering an igniter into the injection well, and starting the igniter to ignite after the igniter is lowered to the bottom boundary of an oil layer;
producing oil through a second string of the production well.
2. the method of claim 1, wherein the number of perforations per unit length of said perforation segment is determined by the formula:
N＝N0-(A-A0)/(A0/N0)
Wherein N represents the number of perforations per meter of perforation segment, and the unit is hole/meter; n0 represents the average number of perforations per meter, in units of perforations per meter; a represents the current permeability of the reservoir in Darcy; a0 represents the average permeability of the reservoir in Darcy.
3. The method of claim 1, wherein prior to the igniter firing, the method further comprises:
Acquiring oil pressure, and extracting oil through a first tubular column of the injection well when the oil pressure is greater than preset oil pressure;
When the oil pressure is below a preset oil pressure, the first string of the injection well stops producing and gas is injected through the first string of the injection well for a predetermined length of time.
4. The method of claim 3, wherein the method further comprises: increasing the power of the igniter after injecting gas into the first string of the injection well for a predetermined period of time.
5. a method of igniting a gas-channeling oil reservoir, comprising:
Injecting air into an oil layer of the oil reservoir through an oil casing annulus formed by a first tubular column of the injection well and a casing, and detecting a product in the production well;
When the tail gas is detected to appear in the production well, injecting steam through an injection pipe column of the production well; and detecting a temperature change at a predetermined location in the injection well;
stopping steam injection when the temperature at the predetermined location in the injection well rises to a first preset temperature and initiating production through a second tubing string in the production well;
And acquiring the air temperature at the outlet position of the injection well, when the outlet temperature reaches a second preset temperature, putting an igniter into the injection well, and starting the igniter to ignite after the igniter is put to the bottom boundary of an oil layer.
6. The method of claim 5, wherein the injection of air into the reservoir of the reservoir via the oil casing annulus formed by the first string of injection wells and the casing has an injection strength of 500 squares per meter of reservoir thickness and increases in strength at 50 squares/month per meter of reservoir thickness.
7. The method of claim 5, wherein the reservoir comprises a plurality of oil layers, wherein an uppermost layer is an upper layer, and wherein the predetermined location in the injection well comprises: the upper oil layer and an oil layer having a permeability greater than a predetermined value.
8. the method of claim 7, wherein the first predetermined temperature is 250 degrees Celsius to 300 degrees Celsius.
9. the method of claim 5 wherein the reservoir comprises a plurality of oil layers, wherein the lowermost oil layer is a lower oil layer and the injector well exit location is within a depth of the lower oil layer.
10. The method of claim 9, wherein the second predetermined temperature is greater than 400 degrees celsius.
11. The method of claim 5, wherein the reservoir comprises a plurality of oil layers, and wherein at the location of each of the oil layers, the first string and the second string are provided with a perforated section at the location of the oil layer, the perforated section being located within a predetermined thickness of the oil layer adjacent the lower portion.
12. The method of claim 11, wherein the number of perforations per unit length of each perforation segment is determined based on a current permeability of an oil formation to which the perforation segment corresponds, an average permeability of the oil reservoir, an average number of perforations per unit length, and a theoretical number of perforations per unit length.
13. The method of claim 12, wherein the number of perforations per meter of perforation segments is determined by the formula:
N＝N0-(A-A0)/(A0/N0)
Wherein N represents the number of perforations per meter of perforation segment, and the unit is hole/meter; n0 represents the average number of perforations per meter, in units of perforations per meter; a represents the current permeability of the reservoir in Darcy; a0 represents the average permeability of the reservoir in Darcy.
14. The method of claim 5, wherein prior to the igniter igniting, the method further comprises:
Acquiring oil pressure, and extracting oil through a first tubular column of the injection well when the oil pressure is greater than preset oil pressure;
When the oil pressure is below a preset oil pressure, the first string of the injection well stops producing and gas is injected through the first string of the injection well for a predetermined length of time.
15. The method of claim 14, wherein the method further comprises: increasing the power of the igniter after injecting gas into the first string of the injection well for a predetermined period of time.
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| CN202810813U (en) * | 2012-08-08 | 2013-03-20 | 张方礼 | Well pattern structure for using combustion and steam combination flooding to jointly exploit thick oil |
| CN103161437B (en) * | 2013-03-05 | 2015-07-08 | 中国石油天然气股份有限公司 | Fleeing sealing sand-prevention ignition method of fireflooding oil extraction |
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| CN105257269B (en) * | 2015-10-26 | 2017-10-17 | 中国石油天然气股份有限公司 | A kind of steam drive combines oil production method with fireflood |
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