CN111638550A - Fracture-controlled-storage evaluation method - Google Patents
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Abstract
According to the method for evaluating fracture reservoir control, the problem of oil sources in a research area is fully considered through the relative position of a main reservoir fracture and a hydrocarbon source rock stratum and the structural position of the main reservoir fracture. Secondly, when the control capacity of the fracture is evaluated, the fractures of the whole research area are considered uniformly, the fractures of the exploratory area and the exploratory new area are not considered separately, a large amount of statistics on the data of the exploratory area is not needed, and the evaluation can be finished quickly through semi-quantitative analysis and is not limited by little data of the new area. The method has wide application range, is not limited by basin types, does not cause the problem that different formulas of statistical parameters of basins of different types are not applicable in the prior art, and can be suitable for basins with low exploration degree.
Description
Technical Field
The invention belongs to the field of petroleum geology, and particularly relates to an evaluation method for fracture control.
Background
The control of hydrocarbon reservoirs by fractures is a very common phenomenon in hydrocarbon-bearing basins, and many researchers have studied this mechanism, most notably the "seismic pumping" model, which considers the seismic action as a pump, pumping out deeper thermal fluids, migrating through fracture zones into fissures of lower positive stress, and indicating that the seismic pumping action is beneficial to the migration and accumulation of hydrocarbons into reservoirs in the formation of mobile zones. However, there are many fractures in a hydrocarbon-bearing basin, not all fractures have control over the spatial distribution of the reservoir, and the greater the probability of which fractures contain hydrocarbon, is a great concern in oil and gas exploration. Two methods for fracture-controlled occlusion evaluation have been proposed.
(1) Ternary coupling reservoir control evaluation method
The method considers that trapped oil gas aggregation controlled by faults in a fracture-developing basin is mainly controlled by 3 factors, namely fault vertical fault distance L, cover shale apparent thickness M and reservoir sandstone apparent thickness R. The extent of fracture containment control can be quantitatively evaluated by the following three factors:
in the formula:
l is the fault vertical fault distance, m;
m is the apparent thickness of the cover layer mudstone, M;
r is the apparent thickness of reservoir sandstone, m;
MR is the proportional coefficient of the cover layer mudstone and is dimensionless;
RR is reservoir sandstone proportional coefficient, dimensionless;
LR is a fault vertical fault-distance proportional coefficient and is dimensionless.
According to the method, firstly, the data of MR, RR and LR of fractured exploratory areas in the basin are counted, and the data are projected onto a triangular diagram of 3 end member components, as shown in figure 1, the analysis method considers that under the condition that an oil-gas source is sufficient, when MR is larger than LR and MR is larger than RR, the probability of oil-gas containing of the fault-shaped ring closure is higher, and otherwise, the probability of oil-gas containing is lower. On the basis, the data of the new exploration area fracture are counted, and the position of the new area fracture projection in the triangular graph is seen, so that the purpose of evaluating the new area fracture is achieved.
The payment also provides a similar analysis method as Yangjinbo (2013), and the method adopts a research method of comparing the thickness of a regional cover layer with the size of a fracture distance and analyzing the oil-gas distribution relation, and researches the sealing effect of the fracture cover configuration on oil gas migration along the fracture.
The relevant references are as follows:
[1] new evaluation method and preliminary application of fault type trap in Mazhongzhen et al, Daqing petroleum geology and development, 2010.29(2), pp 29-34.
[2] The sealing effect of the broken cover configuration on oil gas migration along the fracture is shown in the example of shallow layer in the depression of a Nanbao, the globe science-the institute of geological university of China, 2013.38(4): page 783-791.
The method has the following disadvantages:
the precondition for the application of this method is that the fracture zone is not short of oil source and not all fractures are incorporated into a unified evaluation system.
Secondly, the method comprises the front and the rear parts of the workflow. The front part needs to count a large amount of fracture data of the surveyed area, and the workload is large. The latter part needs to explore the data of the new area, which is limited by the original data of the new area.
(2) Fracture controlled-storage probability evaluation method
Penghui et al (2016) discovered that three factors affecting fracture control were fracture mobility rate, fracture plane length, and relative distance between oil source fracture and trap through the dissection of fracture zone, and the relationship between controlled fracture and oil and gas reservoir is shown in that ① fracture mobility rate is between 0-The control capacity of fracture is increased and then reduced when the fracture reaches the maximum value about 15m/Ma between 30m/Ma, the maximum distance of lateral migration of oil gas after vertical migration through the fracture is larger when the fracture plane length of ② is larger, the hydrocarbon content of trap in a reservoir control range is controlled by ③ relative distance, the hydrocarbon content of trap in the trap control range is worse when the trap is farther away from the relative distance, a comprehensive control capacity index is calculated by fitting on the basis, and the hydrocarbon content index value of each data point is correspondingly evaluated, namely the fracture reservoir control probability value PfThe value is:
in the formula:
Pfthe probability of the outage;
x is the rate of late-stage activity at break;
y is the relative distance to the break.
PfThe value is between 0 and 1, with a larger value indicating a higher probability of being hidden.
The relevant references are as follows:
[1] penghui and the like, the quantitative characterization of the first depression and fracture of the beads in the basin at the bead river mouth and the prediction of favorable exploration areas, modern geology 2016.30(6) 1318 page 1328.
The method has the following disadvantages:
the statistical parameters proposed by the method may be very different in different basins, and the proposed formula is only applicable to the basin studied by the author.
If the method is popularized to other basins, a large amount of known fracture data and oil reservoir data are needed to be used as samples for establishing the relationship between the fracture reservoir control probability value and the fracture activity rate, the fracture plane length, the fracture trap and the relative distance, and then the fracture of the exploration new area is evaluated by using the relationship function. This is only applicable to basins with a high degree of exploration, whereas for basins with a low degree of exploration this method cannot be applied due to the limited number of samples.
Disclosure of Invention
In order to solve the technical problems in the prior art, the invention provides an evaluation method for fracture controlled sequestration, which comprises the following specific scheme:
a fracture control assessment method comprises the operation steps of assessing fracture control ability through assessment indexes: the evaluation index includes:
(1) relative position of primary reservoir fracture and source formation;
(2) a structural site that is mainly fractured in the depot period;
(3) whether the primary reserve break is active or not;
(4) whether the primary reservoir fracture is in communication with the source rock and the reservoir;
(5) whether the fracture is active after the primary stage of accumulation and whether the fracture breaks through the earth's surface after the primary stage of accumulation.
Further, it is determined whether the evaluation index satisfies at least four of the following conditions:
the first condition is as follows: the primary reservoir fracture is located in the planar distribution area of the source rock;
and a second condition: the primary reservoir fracture is positioned on an oil and gas migration path or a structure high part of a primary reservoir ancient structure on the top surface of the reservoir;
and (3) carrying out a third condition: primary reserve fracture activity;
and a fourth condition: primary reservoir fractures are in communication with the source rock and reservoir;
and a fifth condition: breaking and moving after the primary accumulation period and breaking and not breaking through the ground surface after the primary accumulation period;
if the evaluation index meets at least four conditions, the fracture control capability is high, and the accumulation is facilitated; if the evaluation index satisfies less than four conditions, it indicates that the fracture controllability is low and it is not favorable for accumulation.
Further, in condition four, the pattern of primary reservoir fractures in communication with the source rock and reservoir includes direct communication and indirect communication.
Further, in the second condition, the oil and gas migration path comprises a slope part and a non-slope part between a construction high part and a construction low part with the same slope trend.
Further, whether the evaluation index meets at least four of the conditions is judged through a hydrocarbon source rock stratum plane distribution diagram, a reservoir top surface main burial period ancient structural diagram, a main burial period fracture activity plane distribution diagram and a main post-burial fracture activity plane distribution diagram.
Furthermore, a hydrocarbon source rock stratum plane distribution diagram is drawn according to the statistical hydrocarbon source rock stratum thickness data and the organic carbon content data in the research area.
Furthermore, a current structural map is drawn through seismic profile horizon interpretation and fracture interpretation, and a main pre-existing period ancient structural map of the top surface of the reservoir is obtained through the current structural map.
Further, the present day tectonic map includes a reservoir top surface present day tectonic map and a rock top surface present day tectonic map formed during primary reservoir formation.
Further, the primary reservoir fracture activity histogram is superimposed with the source formation histogram to identify the relative location of the primary reservoir fracture and the source formation.
Further, the primary reserve-period fracture activity planogram is overlaid with the reservoir top surface primary reserve-period ancient tectonic chart to identify the tectonic site of the primary reserve-period fracture.
Compared with the prior art, the method for evaluating fracture reservoir control fully considers the oil source problem of a research area by identifying the relative position of the main reservoir fracture and the hydrocarbon source rock stratum and identifying the structural part where the main reservoir fracture is located. For example, primary reservoir fractures are located either in planar distributed areas of the hydrocarbon source rock formation, or at primary reservoir fractures at formation high points, or on relatively abundant hydrocarbon migration paths of these sources, such as slopes of the reservoir's top primary reservoir formations. Secondly, when the control ability of the fracture is evaluated, the fracture of the whole research area is considered uniformly, the fracture of the exploratory area and the fracture of the exploratory new area are not considered separately, a large amount of statistics on data of the exploratory area is not needed, and statistics on data which are difficult to perform statistics such as the fracture distance, the reservoir thickness and the cover layer thickness are not needed to be performed on the exploratory new area. The method has wide application range, is not limited by basin types, can not cause the problem that different formulas of statistical parameters of different types of basins in the prior art are not applicable, even if basins with low exploration degree are used, the method can be applied as long as the relative positions of the main component reservoir period fracture and the hydrocarbon source rock stratum, the communication states of the main component reservoir period fracture and the hydrocarbon source rock stratum and the reservoir stratum, the structural parts of the main component reservoir period fracture, whether the main component reservoir period fracture moves and whether the main component reservoir period fracture passes through the ground surface or not can be identified, and the problems that in the prior art, the exploration degree of certain areas in the research area is low, the data information is few, the statistical analysis is difficult, and the fracture evaluation is limited are avoided.
Drawings
The invention will be described in more detail hereinafter on the basis of embodiments and with reference to the accompanying drawings. Wherein:
FIG. 1 is a schematic projection diagram of three-member components used in a fracture ternary coupling reservoir control evaluation method in the prior art;
FIG. 2 is a schematic diagram illustrating a basic principle of a fracture occlusion control evaluation method according to an embodiment of the present invention;
FIG. 3 is a schematic view of a fracture controlled sequestration evaluation process according to an embodiment of the present invention;
FIG. 4 is a schematic diagram illustrating a fracture controlled-coverage evaluation assignment type according to an embodiment of the present invention;
FIG. 5 is a graph of the superposition of early Hydrocarbon source rock thickness and late Haisis fracture distribution in the early Hanwu world (Yuertuss group depositional phase) in the southwestern region of the tower in accordance with an embodiment of the present invention;
FIG. 6 is a schematic diagram showing the superposition of the Haxi late stage ancient building diagram and the Haxi late stage fracture distribution of the top surface of the Otto-eagle mountain group in the southwest area of the tower in accordance with the present invention;
fig. 7 is a schematic diagram of a slope trend according to an embodiment of the present invention.
In the drawings, like parts are designated with like reference numerals, and the drawings are not necessarily to scale.
Detailed Description
The invention will be further described with reference to the accompanying drawings.
The present embodiment provides a method for evaluating fracture control, and fig. 2 shows the basic principle of the method, in which a cap rock 100, a reservoir 200 and a source rock 300 are shown, and the method studies the control effect of fractures on hydrocarbon reservoirs for all four cases of fractures in a study area.
The first scenario is to analyze the connectivity of the primary reservoir fracture with the source and reservoir formations. The best match between primary reservoir fractures and the source rock is that the fractures are deep into the source rock and the primary reservoir fractures are deep into the reservoir where the hydrocarbons are easily transported along the fractures to the reservoir to aggregate into the reservoir. Such as the fracture F1 and the fracture F4 in fig. 2, both penetrate deep into the source 300 and reservoir 200, directly communicating the source 300 and reservoir 200.
Even if the primary reservoir fracture does not extend deep into the hydrocarbon source rock stratum, as long as the primary reservoir fracture is located above the hydrocarbon source rock stratum and within the planar distribution area range of the hydrocarbon source rock and the fracture enters the reservoir stratum, oil and gas generated by the hydrocarbon source rock can be diffused into the fracture above under the action of buoyancy, and then the oil and gas are guided into the reservoir stratum near the fracture by the fracture. As with the fracture F2 in fig. 2, the fracture F2 is located above the source rock formation 300, the fracture F2 is located within the planar distribution of the source rock formation 300, and the fracture F2 is into the reservoir 200.
The relatively poor match is that although the primary reservoir fractures are within the confines of the planar distribution of the source rock, they do not connect the source rock to the reservoir. As with the fracture F7 in fig. 2, the fracture F7 is located between the source rock 300 and the reservoir 200 and is not in communication with the source rock 300 and the reservoir 200.
The worst matching scenario is where the primary reservoir fracture is neither deep into nor above the source formation, but is in a low formation where the fracture will not trap hydrocarbons in any way. Such as break F3 in fig. 2.
The communication of the fracture with the source rock and reservoir may be determined by seismic profiling.
The second scenario is to analyze whether fractures in the primary reservoir unconnected hydrocarbon source formations relay the migration of hydrocarbons from fractures in the connected hydrocarbon source formations. The key point is whether the two fractures can dredge oil gas in a relay way or not, and whether the two fractures are located at a higher structural position than the two fractures is determined, because the oil gas is moved upwards by buoyancy, the fractures are located on an oil gas migration path at the moment, and the oil gas migrated from the previous fracture can be captured. As shown in fig. 2 by fracture F5, whose outcrop line at the top surface of the reservoir is higher than that of fracture F4, fracture F5 is at a higher formation site than fracture F4, and thus fracture F5 can capture hydrocarbons transported by fracture F4.
If the formation of fractures that are not connected to the source formation is low relative to the formation of connected source formation, then hydrocarbons cannot be trapped. As shown in fig. 2 for fracture F6, whose outcrop line at the top surface of the reservoir is lower than that of fracture F4 at the top surface of the reservoir, fracture F6 is at a lower formation site than fracture F4, and therefore fracture F6 cannot capture hydrocarbons that fracture F4 is migrating to.
The third case is to analyze whether the fracture is active during the period of the onset. If the fracture exists before the accumulation period, the fracture per se plays a dredging role on the oil and gas, and if the accumulation period is reached and the fracture is activated again, the oil and gas are promoted to be further gathered.
The fourth scenario is to analyze whether the fracture is active after the main build-up period. Generally, the more active a fracture is, the more oil and gas will accumulate near the fracture as long as the fracture does not reach the surface.
The height of the fracture at the formation site is judged by the outcrop line of the fracture at the top surface of the reservoir, i.e., the height of the intersection of the fracture surface and the top surface of the reservoir. The same slope trend refers to a slope or a combination of a series of slopes and non-slopes which integrally rise or fall towards the same direction, the same slope trend allows a terrain flat part and a part with slightly reduced height to exist, and the bottom end of the same slope trend is a low-structured part, usually a low-lying place or a basin; the top end of the same slope trend is a high-structure part; the flat part of the terrain between the high part and the low part of the structure with the same slope trend or the part with slightly reduced height and the slope belong to the oil and gas migration path; if the terrain decline of the construction part is abnormally obvious, the construction part is in another slope trend. As shown in fig. 7, the structure portion M14 is a terrain flat portion, the height of which is unchanged, and the height of the structure portion M12 is in a descending trend, but the height is only slightly reduced, so the structure portions M11, M12, M13, M14, M15 and M16 are in the same slope trend, wherein the structure portion M10 is a structure low portion with the slope trend, the structure portion M16 is a structure high portion with the slope trend, and the structure portions M12 and M14 are also oil and gas migration paths. The height is abnormally obviously reduced after the high part M16 is constructed, the construction part M17 belongs to another slope trend, the construction part M18 is a construction low part of the slope trend, and the construction part M16 is a construction high part of the slope trend.
Preferably, according to the above principle, in order to achieve the purpose of fracture reservoir control evaluation, it is usually necessary to create a hydrocarbon source rock stratum plan view, a primary burial period ancient structural diagram primary burial period fracture activity plan view of the top surface of the reservoir, and a primary post-burial period fracture activity plan view, and determine the relative position of the primary burial period fracture and the hydrocarbon source rock stratum, the communication state of the primary burial period fracture and the hydrocarbon source rock stratum and the reservoir, the structural position of the primary burial period fracture, whether the primary burial period fracture is active, whether the primary post-burial fracture is active, and whether the primary post-burial fracture penetrates through the ground surface by identifying the diagrams, and further evaluate the fracture control capability. The control capability of the fracture is the control capability of the fracture on oil and gas.
The method fully considers the problem of oil sources in a research area through the relative positions of the main reservoir fracture and the hydrocarbon source rock stratum and the construction positions of the main reservoir fracture, for example, the main reservoir fracture is positioned in the plane distribution area of the hydrocarbon source rock, or the main reservoir fracture is positioned at a construction high point or on an oil and gas migration path, such as the slope of a main reservoir ancient structure on the top surface of a reservoir stratum, which are places with sufficient oil sources. Secondly, when the control ability of the fracture is evaluated, the fracture of the whole research area is considered uniformly, the fracture of the exploratory area and the fracture of the exploratory new area are not considered separately, a large amount of statistics on data of the exploratory area is not needed, and statistics on data which are difficult to perform statistics such as the fracture distance, the reservoir thickness and the cover layer thickness are not needed to be performed on the exploratory new area. The method has wide application range, is not limited by basin types, can not cause the problem that different formulas of statistical parameters of different types of basins in the prior art are not applicable, even if basins with low exploration degree are used, the method can be applied as long as the relative positions of the main component reservoir period fracture and the hydrocarbon source rock stratum, the communication states of the main component reservoir period fracture and the hydrocarbon source rock stratum and the reservoir stratum, the structural parts of the main component reservoir period fracture, whether the main component reservoir period fracture moves and whether the main component reservoir period fracture passes through the ground surface or not can be identified, and the problems that in the prior art, the exploration degree of certain areas in the research area is low, the data information is few, the statistical analysis is difficult, and the fracture evaluation is limited are avoided.
The method comprises the following specific evaluation flows:
compiling a hydrocarbon source rock stratum plane distribution diagram;
and (4) counting the thickness data of the hydrocarbon source rock layer section in the well in the research area, so that a hydrocarbon source rock layer thickness plane distribution diagram can be compiled. The hydrocarbon source rock stratum is generally darker in color, and the hydrocarbon source rocks in the carbonate rock stratum system are mainly black and grayish black thin-layer marl rocks and gray mudstone; the source rock in the clastic rock series is typically black mudstone. Of course, if the data of the organic carbon content can be combined in the process of preparing the hydrocarbon source formation plane distribution diagram, the determination of the distribution range of the organic carbon content can be more accurate.
Compiling a main ancient constitutional graph of the reservoir top surface;
the compilation of the main integral reserve period ancient tectonic chart of the top surface of the reservoir layer is completed on the basis of the current tectonic chart. The present-day map is not a single one, but rather a present-day map of a series of strata, the most prominent of which includes a reservoir-top-surface present-day map and a top-surface present-day map of rock formations formed during primary reservoir formation, these present-day maps being primarily compiled on the basis of seismic profile horizon interpretation and fracture interpretation.
Based on the present reservoir top surface map, the present reservoir top surface map can be simply converted into an ancient reservoir top surface map at the main hydrocarbon reservoir stage by flattening the present reservoir top surface map formed during the main reservoir. Generally, the high construction position is considered as an oil and gas migration direction area, and an ancient structural diagram of the top surface of a reservoir layer in a main reservoir period is compiled, so that the oil and gas migration direction after oil and gas are generated by hydrocarbon source rocks can be reflected. It is explicitly noted that there must be a distribution of fractures on the reservoir top principal lifetime paleograms in order to identify where the fractures are located on the grams.
The active period of fracture is less;
the fracture activity period is the time for judging whether the fracture moves in the main accumulation period and the main accumulation period, the fracture activity plays a positive role in oil and gas migration and aggregation, and the fracture activity period can be analyzed through whether stratum fracture exists after the main accumulation periods on two sides of the fracture of the seismic section, whether the fractured stratum changes, whether stratum traction phenomenon exists and the like.
And compiling a main accumulation period fracture activity plane distribution diagram and a main accumulation period fracture activity plane distribution diagram according to the seismic section structural analysis.
And judging whether the fracture moves in the main burial period and after the main burial period or not through seismic section horizon interpretation and fracture interpretation, and compiling a main burial period fracture activity plane distribution map and a main burial period fracture activity plane distribution map according to the judgment.
Preferably, when the fracture distribution is embodied on the reservoir top surface ancient architecture diagram, the main integral period fracture activity plane distribution diagram can be superposed with the reservoir top surface main integral period ancient architecture diagram.
The hydrocarbon source rock stratum plane distribution diagram, the reservoir top surface main integral reserve ancient structural diagram, the main integral reserve fracture activity plane distribution diagram and the main integral reserve post fracture activity plane distribution diagram are compiled in no order, and it does not matter which diagram is compiled first and then later. Fig. 3 illustrates the evaluation flow of the evaluation method of the embodiment, and in other embodiments, the compilation order of the graphs is not necessarily compiled in the order shown in fig. 3, and the reservoir top surface main ancient architecture diagram can be compiled first, or the fracture activity plane distribution diagram can be compiled first.
After the drawing is compiled, superposing the main reservoir fracture activity plane distribution diagram and the hydrocarbon source rock stratum plane distribution diagram to identify the relative position of the main reservoir fracture and the hydrocarbon source rock stratum; and overlapping the primary reserve fracture activity plane distribution map with the reservoir top surface primary reserve ancient structural map to identify the structural part of the primary reserve fracture.
Assigning a value to a fracture within the study area;
on the basis of drawing and drawing superposition, identifying the relative position of a main reserve fracture and a hydrocarbon source rock stratum, the communication state of the main reserve fracture and the hydrocarbon source rock stratum and a reservoir stratum, the structural position of the main reserve fracture, whether the main reserve fracture is active and whether the main reserve fracture is broken through the earth surface, and performing corresponding assignment, wherein the specific assignment types are as follows:
the first condition is as follows: and when the main reservoir fracture is positioned in the hydrocarbon source rock distribution area of the hydrocarbon source rock stratum plane distribution diagram, assigning A, otherwise, not assigning.
And a second condition: and when the main reservoir fracture is positioned on an oil and gas migration path or a tectonic high part of the reservoir top surface main reservoir ancient tectonic graph, assigning A, otherwise, not assigning.
The hydrocarbon migration path typically includes a ramp and a non-ramp region between a build high region and a build low region of the same ramp tendency.
And (3) carrying out a third condition: when the fracture is active in the primary burial period, value A is assigned, otherwise value is not assigned.
And a fourth condition: a is assigned when the primary reservoir fracture connects the source rock to the reservoir, otherwise it is not assigned.
And a fifth condition: and when the fracture moves again after the primary accumulation period and the earth surface is not fractured, assigning A, otherwise, not assigning. If the multi-stage activities exist, the multi-stage activities are assigned again according to the rule, the multi-stage activities are not assigned with a plurality of values, but the multi-stage activities are considered to be assigned with one value comprehensively, for example, if the multi-stage fracture activities exist after the main accumulation period and the earth surface is not broken, the multi-stage fracture activities are assigned with the value A, and if any one of the multi-stage fracture activities exists after the main accumulation period, the earth surface is broken, the multi-stage fracture activities are not assigned.
Fig. 4 schematically lists the fracture occlusion control evaluation assignment types, that is, the five assignment conditions are assigned according to the order in which no assignment is performed when the five assignment conditions are assigned, and the assignment may be sequentially determined according to the order indicated by the arrow in fig. 4, or according to other orders.
In a determination of condition four, the pattern of fractures communicating the source rock and the reservoir includes direct communication and indirect communication. The direct communication means that one end of a certain fracture enters a hydrocarbon source rock stratum, and the other end of the certain fracture enters a reservoir stratum, so that the hydrocarbon source rock stratum and the reservoir stratum are directly communicated; indirect communication refers to relay communication of a fracture, for example, a fracture enters a reservoir but does not enter a source rock, but the fracture has a higher formation site than a fracture that directly communicates the source rock with the reservoir and is capable of relay transport of hydrocarbons, so the fracture is equivalent to communicating the source rock with the reservoir.
When a certain fracture is evaluated to obtain more than four A, namely, more than four of the five conditions are met, the fracture control capability is high, the oil and gas can be well gathered to form the oil and gas reservoir generally, and the fracture zones of the three A or less evaluations are obtained, so that the oil and gas gathering capability is weak and the oil and gas reservoir is difficult to form.
The control capacity of the fracture is a relative concept, and the control capacity of the fracture with more than four A values on the oil gas is higher than the control capacity of the fracture with less than three A values on the oil gas.
Taking the example of the southwest area of the Tarim basin, the Tarim basin is a superposed basin with multi-cycle evolution, and is in the earliest cycle of basin evolution in the early ancient times. From the cambrian age to the middle aotao world, clarithrone bicarbonate terraces and slope-deep water stropanthus grooves under a stretching background develop in the tali wood basin. Under the structural background, the Hanwu system comprises Yuertusi group, Xiaoerbulake group, Wusongguer group, Shayirike group, avatager group and Sumariteger group from bottom to top, and the Ordovician system comprises Penglai dam group, Yingshan group, one room group, Qialback group, Lianglidata group and Santana group from bottom to top.
For Hanwu-ao pottery system, except for the sangta wood group at the uppermost part of the ao pottery system, the rest layers of the Hanwu-ao pottery system are all carbonate rocks. Wherein the Yuersi group at the lowest part of the Hanwu system is the source rock, the distribution range is shown in figure 5, wherein the middle part (Bachu bump part) of the southwest area of the tower is positioned between two contour lines with the thickness of 0 of the thickness contour line of the source rock, and the source rock does not develop. The eagle mountain group of the aoto system is the main reservoir, and the T74 interface in this embodiment refers to the top surface of the eagle mountain group, i.e., the top surface of the reservoir.
The main component of the reservoir is the advanced Haxi stage, and oil and gas generated by hydrocarbon source rocks in Yuertos group of Hanwu system enter reservoirs in the Yingshan group through fracture in the advanced Haxi stage and naturally enter clastic rocks in the Xiongshi group and the third clastic rock, so that the evaluation of the fracture is very important.
The present example is concerned with the control of hydrocarbon access to the eagle mountain group reservoir by fractures.
The fracture in the southwest area of the tower is very complex, and the fracture mainly has three groups of trends in plane distribution, wherein the first group is the northwest fracture, the second group is the northeast fracture, and the third group is the near east west fracture. These three sets of fractures are regularly distributed in different regions on the plane. The first set of northwest breaks are distributed primarily on the barchu ridges; the second group of northeast fractures are mainly distributed on the east side of the barchu bump; the third group of near-east-west breaks were mainly distributed in the south side of the barchu ridges (fig. 5, 6). This example evaluated the ability to control the primary fracture of 21 of them.
Previous studies have shown that the southern tower region does not lack a peatmoss cap layer, which should not be one of the factors that would contribute to the evaluation of hydrocarbon reservoir formation at the fracture zone. The fracture zone evaluation must take into account five factors: whether the fracture zone is located in the hydrocarbon source rock zone, the structural position of the Haishi advanced stage of the T74 interface relative to the hydrocarbon source rock zone, whether the Haishi advanced stage is active, whether the fractures are connected, and the Xishan fracture activity characteristics. The Xishan period follows the primary Tibetan (advanced Haxi).
Evaluation factor 1: whether the fractured zone is located in the hydrocarbon source rock zone;
because the hydrocarbon source rocks of Yuersi group of the Han-Wu system do not develop in a full basin, whether the fracture zone is in the hydrocarbon source rock area or not is very important, and only the fracture zone in the hydrocarbon source rock area can be obtained in the early morning of the waterfront stage to capture oil and gas from the hydrocarbon source rocks in the period of the reservoir. A is assigned at evaluation if a fracture zone is within the hydrocarbon source rock region, otherwise, no value is assigned. In particular, it can be determined from fig. 5 whether the fracture zone is located in a region where the source rock thickness is greater than 0.
Evaluation factor 2: whether the fracture zone is positioned at the advanced ancient uplift high part and the slope part of the Shanxi on the top surface of the eagle mountain group;
hydrocarbon generation and discharge are started in the late Haizi Yuersi group hydrocarbon source rock, the ancient raised high points (construction high points) are the directional points of oil and gas migration, if the position of a certain fracture zone is just positioned on a migration path (such as a slope) or the ancient raised high points at the moment, the fractures are undoubtedly favorable for oil and gas accumulation, A is assigned during evaluation, and otherwise, A is not assigned. Fig. 6 judges the structural part by the color in the figure corresponding to the color scale, the unit of the value shown by the color scale is meter, for example, -6000 and-1000 at both ends of the color scale represent 6000 meters underground and 1000 meters underground respectively.
Evaluation factor 3: whether the fractured zone is active in the advanced Haishi stage or not;
the main accumulation period is the advanced Haxi stage, if the fracture zone moves in the advanced Haxi stage, the oil and gas accumulation is facilitated due to the consistency with the oil and gas accumulation period, the A value is assigned during evaluation, and otherwise, the A value is not assigned.
Evaluation factor 4: whether the fracture communicates with the source rock and the reservoir;
a is assigned to a fracture if communication between the source and reservoir will favor hydrocarbon accumulation, otherwise no value is assigned.
Evaluation factor 5: characteristic of scission events in the hill-like period;
the characteristic of the activity in the Xishan period is after the advanced Haxi stage, namely the fracture characteristic after the main adult period is judged.
For the zone on the south-east side of the Bachu hump, due to the existence of a recent cream-salt layer, the fracture cannot break through the earth surface, the fracturing activity in the hill-like period cannot cause the escape of oil and gas, and the oil and gas can be favorably accumulated in various reservoirs, so if the fracturing activity in the hill-like period is assigned with the value A, otherwise, the fracturing activity is not assigned with the value A. However, for a barchu ridge boundary break, a combination of factors 4 and 5 should be considered. For example, the fracture of the chromobusha boundary on the south side of the Bachu bump is direct communication type open source fracture, but a recent cream-salt layer does not exist, and the earth surface is easily broken through by strong activities in the hill-like period of fracture, so that oil and gas storage is not facilitated, so that the value A is not assigned. The same is true for the attolith and vomitus shock zone, with no assignment of A. However, because the Mazata lattice fracture zone has a paste salt layer, although the fracture in the Happy mountain period is strong and is in a direct communication type common source mode, the fracture cannot break through the ground surface, and the value A is still assigned.
The highest assigned score is AAAAA, according to the assignment criteria described above. The results of fracture evaluation in the southwestern area of tower are shown in table 1. Since the mid-southwest (barchu bump) fracture characteristics are the same, the table does not list the fractures within the barchu bump one by one, but rather a uniform name, i.e., the barchu bump internal fracture zone is shown in the 21 st sequence number row.
In the southwest area of the tower, a large number of exploratory wells have been drilled on fracture zones, some producing oil, only oil and gas display, and some empty wells. We compared the results of fracture evaluation with the hydrocarbon-bearing properties of these wells (table 1) and showed that the exploratory wells on the fracture zones where AAAA and AAAAA evaluations were obtained were mostly hydrocarbon flow wells, and that the reservoirs found were concentrated on these fracture zones, although individual wells also seen hydrocarbon display or gas logging anomalies. Fracture zones were obtained for AAA and the following evaluations, even when drilling was performed, with no hydrocarbon display visible on the exploratory well page.
Further hydrocarbon exploration should be carried out on fracture zones of AAAA and AAAAA, which have not been found in reservoirs, and which are evaluated to find more favorable exploration targets in the direction of the strike of these fracture zones. Exploration work was avoided as much as possible on those fractured zones rated AAA and below.
The unclear text in fig. 5 is the place name and fracture zone name, and the unclear text in fig. 6 is the place name. The place name can be ignored. FIG. 6 corresponds one-to-one to the fracture zone in FIG. 5.
The fracture zone reference numbers and designations in FIG. 5 are as follows: north pishanensis 2 well south fault zone X1; yubei No. 8-Pishan Bei No. 1 fracture zone X2; jabei No. 4 fault zone X3; yubei No. 7 fracture X4; yubei 1 fracture zone X5; jadon 1 fracture zone X6; jadon No. 2 breaking zone X7; jadon No. 3 breaking zone X8; jadon 4 break band X9; and the No. 5 Takara X10; macanthan fracture zone X11; jade interruption fracture zone X12; north Pishan fracture zone No. 2X 13; bird's hill fracture zone X14; the bundling fracture zone X15; a color strength buya fracture zone X16; hamios fracture zone X17; macattager fracture zone X18; aptachite break zone X19; vomit wood shock zone X20; the inside rupture zone X21 of the barchu ridge.
TABLE 1 evaluation chart of main fracture zone in Bamai area
While the invention has been described with reference to a preferred embodiment, various modifications may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In particular, the various features mentioned in the various embodiments may be combined in any combination as long as there is no logical or structural conflict. It is intended that the invention not be limited to the particular embodiments disclosed, but that the invention will include all embodiments falling within the scope of the appended claims.
Claims (10)
1. A fracture-containment control evaluation method is characterized by comprising the operation steps of evaluating the fracture control ability through an evaluation index: the evaluation index includes:
(1) relative position of primary reservoir fracture and source formation;
(2) a structural site that is mainly fractured in the depot period;
(3) whether the primary reserve break is active or not;
(4) whether the primary reservoir fracture is in communication with the source rock and the reservoir;
(5) whether the fracture is active after the primary stage of accumulation and whether the fracture breaks through the earth's surface after the primary stage of accumulation.
2. The evaluation method according to claim 1, wherein it is determined whether the evaluation index satisfies at least four of the following conditions:
the first condition is as follows: the primary reservoir fracture is located in the planar distribution area of the source rock;
and a second condition: the primary reservoir fracture is positioned on an oil and gas migration path or a structure high part of a primary reservoir ancient structure on the top surface of the reservoir;
and (3) carrying out a third condition: primary reserve fracture activity;
and a fourth condition: primary reservoir fractures are in communication with the source rock and reservoir;
and a fifth condition: breaking and moving after the primary accumulation period and breaking and not breaking through the ground surface after the primary accumulation period;
if the evaluation index meets at least four conditions, the fracture control capability is high, and the accumulation is facilitated; if the evaluation index satisfies less than four conditions, it indicates that the fracture controllability is low and it is not favorable for accumulation.
3. The evaluation method according to claim 2, wherein in condition four, the pattern of primary reservoir fractures in communication with the hydrocarbon source rock formation and the reservoir comprises direct communication and indirect communication.
4. The evaluation method according to claim 2, wherein in the second condition, the oil and gas migration path includes a slope portion and a non-slope portion between a configuration high portion and a configuration low portion of the same slope tendency.
5. The evaluation method according to any one of claims 2 to 4, wherein whether the evaluation index satisfies at least four of the conditions is judged by a hydrocarbon source formation plan view, a reservoir top surface principal burial period ancient tectonic map, a principal burial period fracture activity plan view, and a principal post-burial fracture activity plan view.
6. The evaluation method of claim 5, wherein the hydrocarbon source formation floorplan is plotted based on statistical hydrocarbon source formation thickness data and organic carbon content data within the study area.
7. The evaluation method of claim 5, wherein the current-day tectonic map is constructed by seismic profile horizon interpretation and fracture interpretation, and the reservoir top surface principal pre-existing tectonic map is obtained from the current-day tectonic map.
8. The evaluation method of claim 7, wherein the present day tectonic map comprises a reservoir top surface present day tectonic map and a top rock surface present day tectonic map formed during primary reservoir formation.
9. The evaluation method of claim 5, wherein the primary reservoir fracture activity plan is superimposed with the hydrocarbon source formation plan to identify the relative location of the primary reservoir fracture and the hydrocarbon source formation.
10. The evaluation method of claim 5, wherein the primary-reserve fracture activity planogram is overlaid with the reservoir-top primary-reserve ancient tectonic map to identify the tectonic sites of the primary-reserve fractures.
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