• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    A zone of increased heat and enhanced fluid mobility is established between an injection well and a production well vertically traversing a heavy oil (bitumen, tar) reservoir by (a) first horizontally hydraulically fracturing between the wells, and (b) then injecting hot water and/or steam into the injection well at a very high rate, at a sufficient pressure, and for a sufficient time (holding sufficient back pressure on the production well if needed) to float the formation along the fracture system between the wells, to effect channel flow of fluids through the floated fracture system (with production from the production well), and to effect effective and uniform heating of substantial reservoir volume perpendicular to the channel flow. Thereupon, other thermal methods such as matrix flow steam flooding can be employed to recover additional oil.
    公开号:SU1082332A3
    申请号:SU792821197
    申请日:1979-10-02
    公开日:1984-03-23
    发明作者:Д.Макдэниэл Джек；В.Брайттон Микаэль；Л.Мартин Вильям；А.Вал Хэрри
    申请人:Континентал Ойл Компани (Фирма)；
    IPC主号:
    专利说明:

    The invention relates to a method for producing heavy oil, in particular, can be used in the extraction of heavy oil or tar from rocks lying at a relatively small depth and having a relatively low permeability. There is a known method of developing an oil reservoir by carrying out a hydraulic fracture in the plate between the injection and production wells, through which water circulates with increasing temperature until the viscosity of the resin becomes less than 50 cP, and then steam passes from the injection well into the production well lj, There is a known method for the development of oil deposits, including the drilling of injection and production wells; creating a permeability zone in the reservoir by performing a hydraulic fracture the reservoir between the injection wells and the associated production wells, maintaining the fracture in the open state, injecting a heat transfer medium 2j into it. However, the known methods are not sufficiently effective for obtaining heavy oil and reservoirs with loose reservoirs in which the reservoir is impermeable at natural temperature, as well as for the extraction of heavy oil from porosity, increased density, occurring at a relatively shallow depth or having a low permeability. Typically, the thermal efficiency (THESZ) in the known methods is about 20-40%, but does not exceed 40%. TE is defined by the following equation: Г х. 2x L e.kx..j, TEfiH OB / 1/2 GA, e X blpcjrV kob The aim of the invention is to increase the efficiency of oil displacement due to the high thermal COD. The goal is achieved by the fact that, according to the method of developing oil deposits, including drilling of injection and operational wells, creating a permeability zone in the reservoir by performing a hydraulic fracturing of the plate between injection wells and interacting with them, maintaining the fracture injection of heat transfer fluid into it, injection and production wells open the oil-bearing formation to the full thickness, fracturing is created by means of injection wells, and after forming a flow zone, the displacing agent is pumped through the reservoir to displace oil i extract it to the surface through production wells, and the heat carrier injection to maintain the cracks in the opened state is performed at a rate calculated using the formulas napaQg 0.021 74 A / h exp (0.02739 TEjjJ, for hot water or water-steam mixture Q 5.0410 (0.02739 TEq where Qg is the rate of steam injection, m water / day; QH — water injection rate, J / d; between skanagreva area zhinamk, thickness of the heated reservoir, m, thermal efficiency, equal to 40-90%. Moreover, the fracturing is carried out in production wells in turn. Before the hydraulic horizontal fracturing is performed by injection wells, the pressure in the production wells is aligned with the reservoir. At the same time, as a displacing agent, steam or steam with water, or steam with oxygen, or steam with hot water, -steam scouste soda, or water is pumped through the formation. When performing hydraulic fracturing in injection wells in production wells, the backpressure is maintained. The method is carried out as follows. A zone of increased heating and fluidity is established between the injection and production wells, vertically passing the oil-bearing formation, by means of hydraulic fracturing between the wells, steam injection into the injection well, and receiving flowing media from the production well. Steam is injected into the system of a gap between wells with sufficient speed and pressure and c. sufficient time to establish thermal efficiency to heat the THEC formation (above 40% and, preferably, above 70%. In accordance with one aspect, the steam is injected at a rate Qg expressed in barrels x (159 dm) of water / day, which is as far as 1812 A / hexp 0.02739 x TED ", where A is the horizontal area heated between wells, expressed in acres (0.4 ha); h is the thickness of the heated formation in feet (30.48 cm); above 40% and, preferably, 70% and above. In other metric units of measure p g 0.021 74 A / hexp 0.02739 x X TEOC, Tety, 40%, preferably not 70%, where Qg m N O / day, A, m, h, m. If a different aqueous medium is injected instead of steam (for example hot water or a mixture of hot water and steam), the velocity of the medium for the aqueous medium is similar i.e. Q can be easily determined from the following formula: l Qs -1000 safHf where the subscript f is the injected medium; Hf is the enthalpy at the bottom of the medium well, expressed in British thermal units per pound; SGf is the specific gravity of the medium at an average temperature, a barrel of steam has enthalpy at the well bottom equal to 1000 British thermal units per pound (2323 J / g) or 350,000 British thermal units per barrel (5.86 x 10 3 / m). Thus, since He is QS x X 350 X H, H 1000 in terms of equivalent injection rate, and Q is the daily injection rate, the equations for the daily speed are expressed as: 342 X 10 A / h exp 0.02739xTE, 5 and 1 in American units or QM 5.05 X 10 A / Lep 0.02739 x X THz in metric units (Jj expressed in J / day (0.239 cal). The heated heavy oil flow zone, which horizontally intersects the oil-bearing stratum, pumped out by displacing steam, stimulated with water, steam with water, hot water with caustic or hot water. 1 24 A heated heavy oil flow zone that horizontally crosses a heavy oil reservoir is installed in a formation with a density of 10 American Institute of Oil, which is impermeable to media at the oil-bearing temperature. a wellbore system is shown; the moment of the process of water flooding through a system of rupture under pressure sufficient to maintain the gap in the opened state, the cross section; in fig. 2 - the same, the moment of subsequent establishment of the fluidity zone and elevated temperature, as well as the propagation of the heated zone of increased fluidity by filling with steam of the source rock extending from the injection well to the operational wells distant from the center; in fig. 3 is a plot of heat distribution over time. Soil 1, containing overburden 2, shown with fracture line 3, and overlapping rock 4, is located on top of oil reservoir 5, which is underlain by formation 6. Overburden and oil reservoir 5 vertically intersect by a wellbore system consisting of a central injection 7 and remote from the center of production of 8-11 wells. Each well intersects an oil-bearing formation that contains a casing 12 fixed in the formation with cement 13 and has a pipe string communicating with external equipment through an outlet 14 at the wellhead 15 and forming an annular space 16 between the pipe string and the casing which communicates with external equipment through the outlet 17. The wells pass through the reservoir and are bonded to the underlying rock with cement 18. In each production well, a hole is made first by rotating g a hydraulic cutting tool and then hydraulic fracturing is carried out until a horizontal fracture is formed 19. The fracturing of the reservoir can be ensured either by injecting aqueous medium into the resulting fracture through opening 14 or pipe string 20. or through opening 17 and through the annular space 16. At the next moment separation pressurized steam, i.e. under pressure sufficient to maintain hydraulic fracturing. The operations are carried out alternately in all production wells, after which the production wells per orutratat throughout the thickness of the reservoir. After that, in the central injection well, a gap is made and subjected to hydraulic fracturing to establish a message to the operational wells through the horizontal fracture 21. In the production wells, the return flow is set up necessary for distributing the hydraulic horizontal fracture according to a typical scheme. Thereafter, steam is pumped immediately or through hole 14, either through the hole t7, or through both holes of the injection well and through the fracture system with a sufficiently high C By the SPINE; with enough pressure and enough time to disconnect the reservoir along at least the main part of the well fracturing system, providing directional flow of fluids through the reservoir with a disconnected fracture and heating the conductivity of a significant volume of oil-bearing reservoir perpendicular to the flow through the wellbore wells maintain the back pressure required to distribute the flow evenly throughout the system as the medium exits the corner production wells. FIG. 1 shows a process c at the moment of steam injection at high speed. The fluids pass (shown by arrows) through the fracture channel and adjacent to it, providing heating by formation conductivity limited by zone 22 and 23, with hot tar and hot water coming out of production wells by interchanging the media from the fracture channel into the stronger zone 23 and to a lesser extent, 3 less heated zone 22. In the production wells, a back pressure is maintained sufficient to maintain the fracture system in a separated state of at least measures until the gum is near the fracture wall. .;with . providing free communication between the injection and production wells. When the resin is subsequently heated by conduction in the zone between the wells, the steam injection rate and the pressure of the oil-bearing formation decrease, resulting in compression of the fracturing system (Fig. 2, position 24). In the injection well, perforations are made and steam is injected at reduced speed and pressure to direct steam flooding and pump the source through the heated zone 22, as shown by the front 25 passing between the injection and production wells. The flow of media is indicated by arrows in the oil paste. Water is then flooded with source rock at high and economical speeds to produce a significant amount of resin, and there is no need to continuously discharge the medium. A high percentage of resin is produced in the exit system. The invention includes the establishment of an increased heat and fluidity zone. fluid in injection and production wells, vertically passing the oil-bearing formation, by successive: hydraulic fracturing between wells, steam injection an injection well and production of media by an improved method, with steam being pumped at a sufficiently high speed with sufficient pressure and for a sufficient time, which maintains the separation of the reservoir along the fracture system between the wells, ensuring fluid flow through the channel through the divided fracture system and heating up a significant volume of the perpendicular reservoir The direction of flow through the channel. The hydraulic fractures formed are horizontal and the steam is injected so as to support l split the reservoir along the fracture system and heat a significant volume of the reservoir vertically and perpendicular to the flow direction. The establishment of a zone of increased heat and fluidity between the injection and production wells, when the steam is pumped at a sufficient rate, at a sufficient pressure and for a sufficient time, leads to the establishment of thermal efficiency (TEC) for heating the formation at 40% and, preferably, 70- 90% and higher.
    To ensure this thermal efficiency according to the invention, the steam injection rate flg is not less than
    0.02174 A / hexp (0.02739 X), where QJ m HjO / day; A, m; h, bj. The proposed method can be used to extract heavy oil from any type of well-known underground heavy oil deposits, and it also has practical use in two classes of oil-bearing rocks that are currently not economically viable to be developed by known methods.
    The first class of oil-bearing rocks is rocks that occur at relatively shallow depth, so that in normal flooding the vapor of the surrounding rocks loses too much heat at any practical distance between wells, especially in rocks with heavy oil with a density of the institute is between 10–20.
    The oil-bearing rocks of the first Trfna usually have a depth of 20–600 m and contain heavy oil with a density in degrees of American Petroleum Institute 20–2 and, usually, 20–10. Such oil-bearing formations usually have a thickness of 3–10 m.
    The second class of oil-bearing pores are seams with heavy oil or resin, occurring at shallow depths. The proposed method is particularly effective when the formation has a depth of less than 1500 m and when the density of heavy oil is 10 degrees or less.
    The proposed method is used even more efficiently when the oil-bearing formation has a depth of less than 600 m, when it contains heavy oil and rock that is not compacted at temperatures at which the heavy oil flows, and which is impermeable to movement of media at the natural temperatures of the formation. ; In the practical implementation of the proposed method is preferred
    is drilling wells through a heavy oil reservoir to the underlying rock and securing the casing in a pre-stressed state in place using high temperature cements and high-strength casing strings.
    Making a hole in the formation is preferably carried out using a spreading tool and a water and sand blasting tool. The tool makes a sufficient number of transitions to open windows or gaps in the formation to ensure a good initial horizontal orientation of the fracture and its sufficient width so that the expansion of the casing when the well is heated by steam injection and the formation of hot media does not substantially restrict the flow of fluids into and out of the well.
    Although not limited to.  the ratio of fracture sizes that are drawn from production wells or from injection wells using a closed system of five, seven, nine, and so on. d.  wells, usually more often produce a first break in the production wells and meter the amount of medium injected by the pressure gauge to ensure a gap from 1/4 to 1/3 of the distance from the production well to the injection well.  According to the proposed method, production wells can also be subjected to an explosive fracture, or they can not be subjected at all.  Thus, for oil-bearing rocks occurring at shallow depths, from an economic point of view, it can be more efficient to break only from injection wells.  In other cases, for example, in compacted oil reservoirs, especially with low permeability, it may be more effective to first carry out a hydraulic fracturing from production wells, introduce suspensions into fracturing systems and then explode by detonating explosive suspensions.  Gaps should run horizontally in the middle of the formation.  However, there are special circumstances in which the rupture is best to be carried out near the vein of shale, near the soil of the tar formation and in other places.  The process injection phase, in which water and / or steam is injected into the injection well and media obtained from the production well, is carried out by the proposed method, which differs from the known very high injection rates, pressure and time sufficient to ensure the following effects.  A sufficiently high pressure is used so that a significant part of the system of rupture along the length between the injection and production wells is maintained in a divided position.  This achieves a flow of media through the channel through a significant part of the system of rupture, as well as such heating by the conductivity of significant tea.  The volume of the oil reservoir, that TE ots exceeds 40%, and the heat loss of adjacent non-productive layers is minimized.  Steam is pumped in this phase at a rate of Qg expressed in barrels x WATER per day, which is at least 1812 A / hexr 0.02739 x X (TE)), where A is the horizontal part, which is subject to significant h warming between wells , acre n is the thickness of the formation being heated, ft1 TEOi is more than 40% and, preferably, is equal to or more than 70%.  In metric units, Qg s ° dy / day is at least 0.02174 A / hexptO, 02739 x TERn where A is the horizontal section subjected to significant heating between wells, m, h is the thickness of the formation being heated, m; A TEg of more than 40% and, preferably, equal to a pitch exceeding 70%, the steam injection rates exceeding a TEgj approaching 100% are shown. body speeds 5 although the target speed is usually such that TE m is 80-90%.  The described injection rates at heat are obtained only during the injection phase at high speed.  This phase continues until a predominant injection, medium and transfer phenomena take place through the directional flow in the discharge.  At the moment when steam injection into the parent rock and oil displacement become significant either for natural reasons or due to a decrease in the injection rate and pressure, the optimum steam injection rate is determined empirically for each project.  1 3210 In some oil-bearing formations, characteristics such as the size and location of shale veinlets and the distribution of vertical and horizontal permeability require a decrease in steam injection rate and pressure to ensure transitions from the predominant directional flow in the fracture to the flow in the source rock.  In other cases, steam breakthrough channels are formed between the injection and production wells.  This leads to inefficient oil displacement, which is high in the ratio of water to oil and poor thermal efficiency, as can be seen from the high ratio of steam to oil.  In some oil reservoirs, in particular, with significant vertical permeability and integrity and viscosity characteristics, in which oil becomes fluid only at an average heating temperature, the convection mechanism becomes significant.  As more and more fluid oil rushes & amps & s, convects or is forced out of the bedrock at the fracture channel, more and more steam and / or hot water leaves the fracture channel, providing further displacement.  In such oil reservoirs, there is a gradual transition from the flow in the fracture channel, where heat transfer occurs mainly by conduction, in a combination of flow in the fracture and source rock, which starts from the injection well and propagates to the production well.  In such a combination, the flow in the fracture and the parent rock of both the conductive and convection mechanisms of heat transfer becomes significant.  In such situations, the process of circulation of the flow through the channel with heating conductivity gradually and naturally goes into the process of circulation in the parent rock, since the media continue to flow from the injection well to production wells.  In other deposits, for example, in typical deposits or bitumen, the transition from the predominant circulation in the rupture channel to a combination of circulation in the rupture channel and in the parent rock is not always easy.  In such oil-bearing formations, during sufficient heating of the formation in the zone conducting radially to the fracture channel as a result of heating by conduction from the flow of fluids in the fracture channel, it is necessary to pump out or remove production wells in order to create effective pressure drops and to reduce whose water, so that the fracture system is opened, is closed and circulation in the maternal rock is established with the displacement of heavy oil.  At the end of the preheating phase, it is effective to re-break from the injection well, for example, with steam.  You can also form and maintain small fractures from production wells.  Such a variation provides increased productivity in the vapor displacement phase and the prevention of well plugging as a result of curing the viscous heavy oil or tar, especially if the gaps are formed by steam.  To maintain a sufficient number of media in the process of water flooding with steam pumped through the parent rock, it is effective to use half-round cycles on production wells.  Perforation of production wells is usually effective in compacted; oil reservoirs can be used open. holes.  For operation on an industrial scale, it is economically advantageous to use several injection wells and production wells.  It is preferable to use two production wells for each injection well, although it is possible to use one or several production wells for each injection well.  When using a deployed system, such as a reversed well, etc. d. It is better that the distance between them is no more than 607 x Yu m.  In the preferred embodiment, this distance is 5.06 x 10 - 4.5 x 10 m.  Systems can be processed individually or in groups, and operations can be carried out in accordance with different phases of the process.  In order to be able to implement the proposed method in a certain oil-bearing formation of a heavy oil or resin, it is necessary to reduce the viscosity by heating to a degree sufficient to ensure its mobility upon application of hydraulic pressure.  Oil and tar fields are usually of this type, and flowability is usually set at temperatures of 66, 121 An example of a relatively shallow heavy oil is a field that contains oil-bearing deposits at a depth of 61 and 152 meters.  The zones are 5.5 and 3.7 m thick, respectively.  Each oil reservoir is 74% oil rich and has negligible gas expansion.  Under reservoir conditions, the oil viscosity exceeds 700 cP at a depth of 61 m and 200 cP at a depth of 152 m.  Heavy oil has a density of 20 degrees Celsius and a very low flow in natural reservoir conditions.  Earlier attempts to use stimulated production processes, including flooding with water, hot water, steam and oil type stimulation and water pumping out, enhanced by water, were not successful in extracting oil of the same type.  Inverted well systems are drilled and logged.  Each scheme covers approximately 10.1 X 10 m.  Induction and gamma logging are conducted, cores are taken from two wells to determine the thickness of the formation, the quality of the oil-bearing formation, porosity and saturation.  A casing string of class 3-55 with a diameter of 14.0 cm and a weight of 23.1 kg / m is installed over the entire length of the well, attached to the surface with class H cement containing 40% silica in powder and 2% calcium chloride.  In the preparation for hydraulic stimulation in the casing, gaps are made in the central part using salt water containing 120 kg / m of sand of 20-40 mesh.  The mixture is pumped through a column of pipes with a diameter of 6.4 cm and through a nozzle with a speed of 0.59.  The tubes rotate to breach.  In injection wells, gaps are made second time at a height of 1.27 cm from the first hole, which ensures very high rates of steam injection and prevents the casing from expanding when steam is injected as a result of interrupting or blocking the flow of steam into the rock.  The formation of gaps also contributes to the formation of horizontal disruption during this operation.  In turn, each well of the inverted well of the system is subjected to a salt break in a field containing no additives or sand at a speed of 6.36. Because of the relatively soft and unconsolidated oil-bearing formation, no propping agent is used.  No thickeners are used, since blocking the passage of steam and leaking hot water from the gap are undesirable.  The horizontal fractures from production wells are calculated so that the radius of the horizontal hydraulic fracture is equal to half the distance to the injection well, t. e.  about 35 m.  Because of the relatively small distance between the wells and when the viscosity of the oil in the formation is from medium to high stimulation, the production wells are not necessary.  Upon completion of the hydraulic fracturing from each external well in the well system, production wells are punched through the entire thickness of the rock with an interval of 6.6 holes per 1 m.  After that, a hole is made in the same way in the central injection well of the well system.  From this gap, a relatively massive horizontal hydraulic discharge is conducted in the direction: outward to a distance of about 70 m to reach each production well.  Each well is monitored by a manometer and an echo sounder that fixes the level of the media, to record the reaction on the supercharger.  Injection wells do not perforate.  The production wells are equipped with a 7.3 cm diameter pipe, plug-in sucker-rod pumps 5.4 cm in diameter and pump units with a capacity of 922 kg m.  Injection wells are equipped with 6 cm diameter pipe with a thermal expansion compensator and a packer.  The packer is installed in the casing at 6 m above the gap.  Wellhead connections include a thermocouple, pressure gauge, and a cooling coil sampler for quality measurements.  The annular space between the casing and the tubing is provided with a tapping channel to prevent overpressure and overheating in the rbass column.  Steam is provided by a conventional 6.3 kcal / h generator.  This unit is capable of heating 238 m of water per day until 80% quality steam is generated, and has an output gauge pressure of about 176 kg / cm.  For the treatment and supply of water to the steam generator, two anthracite filters are provided, one water softener unit containing four sodium zeolite cleaners, a tank for filtered water and a brine tank.  In one example of implementation of the proposed method, the downhole system is implemented by driving a reservoir reservoir to a depth of about 61 m.  The production wells are treated with a composition to provide a fracture in the amount of 13.2 m, and injection wells - in the amount of 681 m.  Communication with production wells when the injection well breaks is indicated by filling the well with medium and gauge pressure on the surface, exceeding 2.5 kg / cm by the end of the hydraulic fracture of the central injection well of the well system.  Immediately after the rupture of the central injection well, steam begins to be injected at a rate of Q5 with a supply of about 143 m of water per day in the form of 70% quality steam ensuring 85 million kcal / day.  The pressure at the wellhead is about 25 kg / cm, and the temperature is about.  A is 1 ha, h is 5.5 m.  Thus, TERC is calculated from the equation of T & and p 36.5 SP ToToT Ch1o is about 1 2A about 50%.  In metric units for given values of Q, h and A, TE. . .   Qsh 36.51 6 and 46-e-.  The fact that steam is injected at a sufficiently high rate with sufficient pressure and / or for a sufficient time to maintain separation of the formation in the interruption system and ensure directional flow of media through the interruption system for Harpeeji is perpendicular to the flow. the next day, one of the production wells and the extraction of 32 m of oil per day from the system for at least 7 days, In the production wells after (two weeks of work with productivity 32 meters of oil per day is noted Speed povsheni wellhead temperature of 27 to 43 ° C.  Such an increase in temperature is observed after injection into the injection well of about 1907 m of water (in the form of steam), which is equivalent to 1.18 billion kcal.  After 39 days, temperatures show up to 107 ° C in production wells.  The daily productivity of the downhole system averages more than 32 meters over several months.  After that, the steam injection is stopped and water is injected into the injection well to eliminate heating and provide a pushing-up hot water stream with the flow of the reservoir rock. At the same time, significant additional quantities of oil are obtained.  This example illustrates the use of the invention for the efficient production of heavy oil from oil bearing rocks,. occurring at a relatively shallow depth, of which oil production by known methods was economically unproductive.  The implementation of the proposed method is based on the example of a very heavy oil field.  The field contains 1.6 x X m of very heavy oil or resin, which has a density in degrees of the American Petroleum Institute (-2) - (+2).  The thickness of the reservoir is about 15 m, the permeability is 0.5–1 m and the viscosity is about 30%.  The initial oil saturation is about 55 vol.% And the depth is about 457 m. Attempts were made to develop these fields for several years and, although some projects produced some heavy oil, none of them proved economically successful. .  Moreover, none of the mined products was even sold due to difficulties associated with dehydration.  Heavy oil from this reservoir has a flow temperature of 82 ° C, and the formation is solid and impermeable for passage of media at its natural temperature.  When heated, the resin becomes flowable and, since the sand particles in the formation are in contact with each other, they are not bound to each other, t. e.  is unstable at temperatures at which the resin is flowable.  The oil reservoir is vertically drilled using an downhole system containing four production wells and one injection well in the center.  The well placement grid with the area of 20234 m occupies a square on the surface of the field, in which the injection wells are located at a distance of 142 m from each other, and the distance between the injection and production wells is 100 m.  In such a well system, the formation thickness is 13.7 m with a depth of 457 m.  The reservoir temperature is 37 ,, pressure 47.4 kg / cm, oil saturation 0,.  Pour point W of resin 82c.  All wells have casing with a diameter of 17.8 cm and a slug of 34.3 kg / m, which passes on.  a depth of 533 m and fixed in place high temperature materials suitable for use in thermal production methods.  All wells are provided with prestressed casing strings to prevent accidents due to thermal expansion when heated with steam up to 315.5 ° C. Wells are usually located in the system shown in FIG.  1 and 2.  Two paired steam generators operating on oil with a capacity of 6.3 million kcal / h are installed on site.  Their possible stable performance of 508 m of water vapor per day at 324-C, a pressure of 120 kg / cm and 75% quality.  In production wells of the downhole system, gaps are made near the vertical center of the alezhe through a rotating tool emitting a jet of water with sand at high speed, which breaks the casing and cement and makes gaps in the rock.  By repeated passes, the gap is widened to a sufficient width so that when the wells are heated. the window in the rock has not narrowed or closed.  The tool has phase-shifted nozzles with a diameter of 0.95 cm.  It works under pressure of 210 kg / cm at a speed of 0.56 at 120 kg / cm of sand with a particle size of 20-40 mesh.  One gap takes 30 minutes at a rotational speed of 610 rpm. / min  After that, each of the production wells is hydraulically horizontal fractured with water in an amount sufficient to open the hydraulic fracture, but one third of the distance between the production wells and the central injection well.  Fresh water in the amount of 208 m is injected at a rate of 4.8-6.4 (Since the medium is injected through. , pipes with a diameter of 8.9 cm, pressure reduction is added.  Immediately after breaking each well, high pressure steam is injected into each of the production wells at a rate of 254 m of water at 316 C and a pressure of 120 kg / cm to return 3.7 billion kcal of energy to each production well. gin  This is expressed in maintaining the hydraulic fracture in the open state and the formation of heating radii of about 44 m around each production well and heating the rock to a temperature of above 93 C at a distance of about 3 m from the top and bottom of the horizontal fracture.  This steam stimulation is carried out using a single generator per well.  Upon completion of steam injection into four wells, they are perforated in a number of 13 holes per 1 m.  Then, all four wells are pumped with steam injection simultaneously into all four wells for a short time and thereafter, wells are pumped to absorb the steam and provide formation heating.  After steaming the production wells and subsequently relieving the pressure from them, the central injection well is subjected to horizontal hydraulic fracturing through a gap passing near the vertical center of the oil-bearing formation to provide communication with the fracture zone and steam stimulation surrounding each production well.  In production wells, back pressure is used to distribute the fracture throughout the system.  Maintaining the back pressure on the reservoir through all the wells required to maintain the fracture in the opened state, steam is immediately injected into the production well at a speed of about 509 m of water per day under a pressure of 120 kg / cm and at which the fracture between the wells is opened the fracture system and the passage through it through the flow channel of liquids, as well as providing heating with a conductivity of a significant volume of the reservoir perpendicular to the flow in the channel.  .  The back pressure at production wells is adjusted as needed to radially distribute heat through the formation.  To break through heat to corner wells requires about 102 centimeters.  The heat distribution over time is shown in FIG.  3  A horizontal fracture system is represented on the x-axis or horizontal axis.  The thermal distribution within the fracturing system at the moment shown in the graph is about 324 ° C, which is approximately equal to the temperature of the soil of the formation at the injection well 1 3.  The temperature distribution above the hydrogen break system is approximately the same; therefore, only cr are shown. Ntura over the system gap.  The graph shows the isotherms 93, 149, 204 and 260C.  At the time of the breakthrough, about 15% of the volume of the system was heated to temperatures in excess of 30% - above 20.  and 47% - above 149 C.  Near the injection well, the 93 C isotherm runs vertically at 5.64 m Ucifi and under the fracture, and in 70% of the system this temperature is exceeded as a result of steam injection from the injection well.
    Q is 509 m of water per day, h is 13.7 m, and A is 2025 m. It is calculated to exceed 90% with relatively little heat loss outside the formation. The steam injected into the production wells slightly changes these contours around the production wells, as shown in FIG. 1 and 2.
    The steam continues to be pumped at the indicated rates and pressures to maintain separation of the formation along the fracture system and to form a channel for the molten fluid resin in the formation near the fracturing system for a certain period of time to ensure optimal heating of the formation in the system. heavy oil is obtained from production wells. Hot media produced from production wells is directed through a heat exchanger to heat the steam used to form steam, which creates significant savings. The cooling of the resulting media by heat exchange also contributes to the efficient operation of the equipment on the surface used to separate oil from steam and hot water,
    After a considerable period of time and oil production, carried out by steam injection at high speeds, opt is achieved; 1 the maximum heating of the formation. Thereafter, the steam injection rate in the injection well is reduced, the production wells are forced to operate at maximum capacity until it decreases, with the result that the fracturing system near the production wells closes.
    Thereafter, the injection well is perforated and steam is injected at the maximum rate of displacement of the parent rock from the central injection well to ensure rapid steam flow with pumping of the parent rock in the system heated to the described technology. The process is also carried out using water heated by the resulting media and containing caustic, which is injected into the injection well, or cold water, air, cold water and / or other gases are used.
    / t5f7
    权利要求:
    Claims (5)
    [1]
    • 154) 1. HALL DEVELOPMENT METHOD • • LIFE OIL, including drilling injection and production wells, creating a zone of increased permeability by performing hydraulic fracturing between injection and interacting production wells with maintaining the crack in the open state by pumping coolant into it, characterized in that, in order to increase the efficiency of oil displacement by increasing thermal efficiency, injection and production wells open the oil reservoir in This thickness, hydraulic fracturing is created by injection wells, and after the formation of the yield zone, the displacing agent is pumped through the reservoir to displace the oil and extract it to the surface through the production wells, and the coolant * is pumped in to the open state at a speed calculated by the formulas for steam φθ = 0.02174 A / h exp (0.027391Ets m ) ', for hot water or water-steam; l of the mixture = 5.04 * * 10 r Ah exp (0.0273911 RK ), where Q s - steam injection rate, m 3 water / day;
    - water injection rate, J / day;
    D - heating area between wells, m ^;
    h is the thickness of the heated.
    layer, m;
    TEgq- thermal efficiency.
    [2]
    2. The method according to p. ^ Characterized in that the fracturing is carried out in production wells alternately.
    [3]
    3. The way · πο p. 1 It is important that before the horizontal hydraulic fracturing by injection wells, the pressure in the production wells is leveled with the reservoir.
    [4]
    4. The way to pop. 1, with the fact that, as a displacing agent, steam or steam with water, or steam with oxygen, or steam with hot water, or steam with caustic soda, and water are pumped through the formation.
    [5]
    5. The method of pop. ^ characterized in that during the implementation of formation hydraulic fracturing in injection wells in production wells, backpressure is maintained.
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    同族专利:
    公开号 | 公开日
    CA1122113A|1982-04-20|
    DE2924493A1|1980-04-17|
    US4265310A|1981-05-05|
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    法律状态:
    优先权:
    申请号 | 申请日 | 专利标题
    US05/948,359|US4265310A|1978-10-03|1978-10-03|Fracture preheat oil recovery process|
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