CN106869911B - Evaluation method for describing compressibility of shale reservoir - Google Patents
Evaluation method for describing compressibility of shale reservoir Download PDFInfo
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Abstract
The invention relates to an evaluation method for describing compressibility of a shale reservoir, which comprises the steps of collecting data contents of a well to be evaluated, including a well position design report, logging data and logging data of the well to be evaluated, determining the shale reservoir and the vertical depth H in the middle of the shale reservoir according to the collected data, determining formation pore fluid pressure gradient FPG of the shale reservoir, obtaining rock density DEN of an overlying formation of the shale reservoir, calculating the maximum horizontal stress Kimax of the shale reservoir and the minimum horizontal stress Kimin of the shale reservoir according to the FPG and DEN, calculating the horizontal stress difference coefficient △ Ki of the shale reservoir to evaluate compressibility of the shale reservoir, and outputting an evaluation result.
Description
Technical Field
The invention belongs to the field of evaluation of unconventional oil and gas exploration and development shale reservoirs, and particularly relates to an evaluation method for describing compressibility of a shale reservoir.
Background
Shale oil gas is a novel energy, particularly shale gas is a very good novel clean energy, and the development and utilization of the shale oil gas have important practical significance for national economic sustainable development and current haze treatment.
Shale oil gas is shale rich in organic matters, can be stored automatically, and is greatly different from conventional oil gas formed by buoyancy aggregation. The shale has extremely low permeability, the shale oil-gas well usually has no natural productivity, a high-quality shale oil-gas interval is drilled in a horizontal well mode, a staged fracturing method is adopted for the horizontal oil-gas interval of the shale oil-gas horizontal well, pores and microcracks in the shale oil-gas interval are communicated, and the high-yield oil-gas well is cultivated, so that the shale oil-gas efficient development is realized.
In the horizontal section shale oil-gas layer staged fracturing of the horizontal well, the stratum fracture pressure of a shale oil-gas layer section possibly rich in oil gas (the shale oil-gas layer section is called as a shale reservoir layer in the invention) needs to be mastered before operation, and the compressibility of the shale reservoir layer is well evaluated. The shale reservoir fracturing which is good in compressibility and easy to form complex network fractures is selected, and is one of the keys for cultivating the high-yield wells rich in oil and gas shale.
And the shale reservoir in the horizontal section of the horizontal well is fractured in stages, so that the operation cost is high and the risk is high. Therefore, the evaluation requirement on the compressibility of the shale reservoir is higher and higher, and the evaluation means of the compressibility of the shale reservoir requiring mutual on-site verification is also more and more.
CN104775810A discloses a shale gas reservoir compressibility evaluation method, which sequentially comprises the following steps: (1) calculating shale brittleness index Brit(ii) a (2) Calculating fracture toughness index K of shalen(ii) a (3) Calculating the natural weak plane opening difficulty index Pn(ii) a (4) Calculating natural weak plane penetration index Cn(ii) a (5) Introducing a complex seam net probability index FcfAnd modified volume probability index FsrvDetermining a reservoir compressibility coefficient FI; (6) and evaluating the compressibility of the shale stratum of the block according to the compressibility coefficient FI of the reservoir. CN104775810B discloses a shale gas reservoir compressibility evaluation method, which sequentially comprises the following steps: (1) calculating shale brittleness index Brit(ii) a (2) Calculating fracture toughness index K of shalen(ii) a (3) Calculating the natural weak plane opening difficulty index Pn(ii) a (4) Calculating natural weak plane penetration index Cn(ii) a (5) Introducing a complex seam net probability index FcfAnd modified volume probability index FsrvDetermining a reservoir compressibility coefficient FI; (6) and evaluating the compressibility of the shale stratum of the block according to the compressibility coefficient FI of the reservoir.
Disclosure of Invention
The invention aims to provide an evaluation method for describing the compressibility of the shale reservoir, which can calculate the horizontal ground stress difference coefficient △ Ki of the shale reservoir through parameters such as the formation pore fluid pressure gradient FPG of the shale reservoir, the rock density DEN of the overlying formation of the shale reservoir and the like, evaluate the compressibility of the shale reservoir according to △ Ki, and verify the high coincidence rate of the staged fracturing effect of the shale reservoir at the horizontal section of the horizontal well.
The objective realization mode of the invention is to describe the evaluation method of the shale reservoir compressibility, which comprises the following specific steps:
1) collecting data of well to be evaluated
(1) Collecting the data content of the well to be evaluated, including the well position design report, logging data and logging data of the well to be evaluated,
the logging information comprises lithology, total hydrocarbon, methane, total organic carbon content, formation pore fluid pressure gradient and formation fracture pressure;
the logging information comprises natural gamma rays, lithologic density and an interpretation result;
2) determining shale reservoir and its middle vertical depth H
Determining a shale reservoir according to shale oil and gas logging lithology, oil and gas display characteristics and a logging comprehensive interpretation result, and determining the vertical depth H in the middle of the shale reservoir according to the shale oil and gas logging and logging interpretation result of the shale reservoir, wherein the dimension is 100m or hm;
3) determining formation pore Fluid Pressure Gradient (FPG) of shale reservoir
According to the shale oil and gas logging while-drilling formation pressure prediction interpretation result, taking the formation pore fluid pressure gradient of a shale reservoir section rich in oil and gas, and recording the arithmetic mean value of the formation pore fluid pressure gradient FPG of the shale reservoir section as the formation pore fluid pressure gradient FPG of the shale reservoir, wherein the dimension is MPa/100m or MPa/hm;
4) obtaining DEN (Density of rock) of overlying stratum of shale reservoir
5) Calculating the maximum horizontal stress Kimax of the shale reservoir according to the formation pore fluid pressure gradient FPG of the shale reservoir;
6) rock density DEN of an overlying stratum of the shale reservoir, and calculating the maximum horizontal stress Kimax of the shale reservoir and the minimum horizontal stress Kimin of the shale reservoir;
7) calculating a horizontal stress difference coefficient △ Ki of the shale gas reservoir according to the maximum horizontal stress Kimax of the shale reservoir and the minimum horizontal stress Kimin of the shale reservoir;
(1) obtaining the range of 10-60 m above the shale reservoir through logging lithologic density dataWell logging lithologic density data of each depth point in the enclosure, with the dimension being g/cm3The arithmetic mean value is recorded as rock density DEN of an overlying stratum of the shale gas reservoir, the product of the rock density DEN and the vertical depth H is recorded as the maximum horizontal crustal stress Kimax, the Kimax is DEN × H, and the dimension is MPa;
(2) calculating the minimum horizontal ground stress Kimin of the shale gas reservoir according to a formula Kimin ═ DEN + FPG)/2 × H according to the formation pore fluid pressure gradient FPG of the shale reservoir, the rock density DEN of the overlying formation of the shale reservoir and the vertical depth H parameter of the step 7) (1) determined in the step 3) and the step 4), wherein the dimension is MPa;
8) according to the stratum pore fluid pressure gradient FPG of the shale reservoir, the rock density DE of the overlying stratum of the shale reservoir, the maximum horizontal stress Kimax of the shale gas reservoir and the minimum horizontal stress Kimin of the shale gas reservoir determined in the steps 3) and 4), the horizontal ground stress difference coefficient △ Ki and △ Ki dimensionless of the shale gas reservoir are calculated according to the following calculation formula,
△ Ki ═ Kimax-Kimin)/Kimin or
△Ki＝(DEN－FPG)/(DEN+FPG)；
9) The compressibility of the shale reservoir is evaluated,
10) and outputting an evaluation result.
According to the method, the horizontal ground stress difference coefficient △ Ki of the shale reservoir is calculated through parameters such as the formation pore fluid pressure gradient FPG of the shale reservoir, the rock density DEN of the overlying formation of the shale reservoir and the like, and the compressibility of the shale reservoir is evaluated according to △ Ki, so that the evaluation method for describing the compressibility of the shale reservoir is formed.
The shale gas well 300 wells have been applied to the areas of south gas fields, Fuling shale gas fields and Xiang Hui West in the Zhongyang region, and the shale reservoir stratum of the horizontal section of the horizontal well is verified to have staged fracturing effect, so that the coincidence rate is 97.1 percent.
Drawings
FIG. 1 is a block diagram of the workflow of the present invention.
Detailed Description
Referring to fig. 1, the method comprises the following specific steps:
1) collecting data of well to be evaluated
(1) Collecting the data content of the well to be evaluated, including the well position design report, logging data, etc.,
the logging information comprises lithology, total hydrocarbon, methane, total organic carbon content, formation pore fluid pressure gradient, formation fracture pressure and the like;
the logging information comprises natural gamma rays, lithologic density, interpretation results and the like.
2) Determining shale reservoir and its middle vertical depth H
Determining a shale reservoir according to the lithology of shale oil and gas logging, the oil and gas display characteristics and the logging comprehensive interpretation result, particularly determining the vertical depth H in the middle of the shale reservoir in an oil and gas-rich shale reservoir section, wherein the dimension is 100m or hm;
the oil-gas-rich shale reservoir section is particularly selected because the oil-gas-rich shale reservoir section has the characteristics of good display of gas-measuring all hydrocarbons and methane, high relative high shale physical development, natural gamma value and acoustic wave time difference value, more than 2 percent of total organic carbon content, more than or equal to 2 percent of total porosity and the like.
3) Determining formation pore Fluid Pressure Gradient (FPG) of shale reservoir
According to the shale oil and gas logging while-drilling formation pressure prediction interpretation result, formation pore fluid pressure gradient data of each depth point of the shale reservoir section rich in oil and gas are obtained according to the depth interval of 1 point per meter, the arithmetic mean value of the data is recorded as the formation pore fluid pressure gradient FPG of the shale reservoir, and the dimension is MPa/100m or MPa/hm.
4) And acquiring rock density DEN of overlying strata of the shale reservoir.
5) And calculating the maximum horizontal stress Kimax of the shale reservoir according to the formation pore fluid pressure gradient FPG of the shale reservoir.
6) And calculating rock density DEN of an overlying stratum of the shale reservoir, and calculating the maximum horizontal stress Kimax of the shale reservoir and the minimum horizontal stress Kimin of the shale reservoir.
7) Calculating a horizontal stress difference coefficient △ Ki of the shale gas reservoir according to the maximum horizontal stress Kimax of the shale reservoir and the minimum horizontal stress Kimin of the shale reservoir;
(1) by logging lithologic density dataObtaining the well logging lithology density data of each depth point within the range of 10-60 m above the shale reservoir at the depth interval of 1 point per meter, wherein the dimension is g/cm3The arithmetic mean value is recorded as rock density DEN of an overlying stratum of the shale gas reservoir, the product of the rock density DEN and the vertical depth H is recorded as the maximum horizontal crustal stress Kimax, the Kimax is DEN × H, and the dimension is MPa;
(2) calculating the minimum horizontal ground stress Kimin of the shale gas reservoir according to a formula Kimin ═ DEN + FPG)/2 × H according to the formation pore fluid pressure gradient FPG of the shale reservoir, the rock density DEN of the overlying formation of the shale reservoir and the vertical depth H parameter of the step 7) (1) determined in the step 3) and the step 4), wherein the dimension is MPa;
8) according to the stratum pore fluid pressure gradient FPG of the shale reservoir and the rock density DEN of the overlying stratum of the shale reservoir determined in the steps 3) and 4), the maximum horizontal stress Kimax of the shale gas reservoir and the minimum horizontal stress Kimin of the shale gas reservoir are used for solving the horizontal ground stress difference coefficient △ Ki and △ Ki dimensionless according to the following calculation formula,
△ Ki ═ Kimax-Kimin)/Kimin or
△Ki＝(DEN－FPG)/(DEN+FPG)。
9) Evaluating the compressibility of the shale reservoir, wherein the evaluation standard is as follows:
(1) △ Ki is less than or equal to 0.35, the compressibility of the shale reservoir is evaluated to be good (class I), and when the fracturing construction pressure acting on the shale reservoir is greater than the stratum fracture pressure, the shale reservoir can be promoted to form a complex fracture network, which is beneficial to cultivating a shale oil and gas horizontal well to form high yield;
(2) ki is more than 0.35 and less than △ and less than or equal to 0.6, the compressibility of the shale reservoir is evaluated to be medium (class II), and when the fracturing construction pressure acting on the shale reservoir is far greater than the stratum fracture pressure, the shale gas reservoir can be promoted to form a sufficient fracture network, which is beneficial to cultivating a shale oil gas horizontal well to form a certain capacity;
(3) △ Ki is more than 0.6, the compressibility of the shale reservoir is evaluated to be poor (class III), and when the fracturing construction pressure acting on the shale reservoir is far greater than the stratum fracture pressure, the shale reservoir often forms a single crack, which affects the full improvement of the productivity of the shale oil gas horizontal well.
10) And outputting an evaluation result and guiding the fracturing reformation of the shale reservoir.
The following examples are provided to describe the effects of the present invention.
Example 1: jian nan gas field J-1HF well
Establishing a south gas field J-1HF well, logging and well logging to explain that the horizontal section of the shale reservoir rich in shale gas is 1000m long, the vertical depth H in the middle is 630m (6.3hm), and the monitoring of formation pressure while drilling in logging shows that the formation pore fluid pressure gradient FPG of the shale reservoir is 1.05MPa/hm, and the arithmetic mean of rock density DEN of overlying strata in the range of 10-60 m above the shale reservoir is 2.65g/cm3The maximum horizontal stress of the shale reservoir Kimax is 2.65 × 6.3(MPa), and Kimin is (2.65+1.05)/2 × 6.3(MPa) is 1.85 × 6.3(MPa) according to △ Ki(Kimax-Kimin)/Kimin ═ 0.43 (2.65-1.85)/1.85. according to △ KiThe equation (DEN-FPG)/(DEN + FPG) yields a shale reservoir horizontal ground stress difference coefficient △ Ki of 0.43, and the calculation results of both equations are the same, and both show that the shale reservoir compressibility evaluation result is medium (class ii).
Microseism monitoring shows that the hydraulic fracturing operation of the J-1HF well forms multiple seams at one side of the well, the number of the seams formed at the other side of the well is small, 1.2 ten thousand square of natural gas is produced in the early stage after flowback is completed, and the gas well productivity is close to the fracturing prediction result.
Example 2: fuling shale gas field JY-1HF well
The horizontal section of a shale reservoir (gas layer) rich in shale gas is 1008m in length, the vertical depth H in the middle of the shale gas layer is 2380m (23.8hm), and the logging while-drilling formation pressure monitoring shows that the formation pore fluid pressure gradient FPG of the shale reservoir is 1.45MPa/hm, and the arithmetic mean Den of the rock density of overlying strata in the range of 10-60 m above the shale reservoir is 2.70g/cm3△ Ki is (2.70-1.45)/(2.70+1.45) is 0.30, which shows that the shale reservoir compressibility evaluation result is good (class I). The pilot hole core test of the shale gas horizontal well shows that the shale reservoir maximum horizontal crustal stress Kimax is 63.5MPa, the shale reservoir minimum horizontal crustal stress Kimin is 48.4MPa, and the shale reservoir horizontal crustal stress difference coefficient △ Ki is 0.31, which is basically consistent with the calculation result of the invention.
Micro-seismic monitoring shows that JY1-HF well large-scale hydraulic fracturing operation forms relatively complex network cracks, flowback and blowout are carried out, natural gas produced in the initial stage is 20.3 ten thousand square, and gas well productivity is close to fracturing prediction results.
According to the invention, the horizontal ground stress difference coefficient △ Ki of the shale reservoir is calculated through parameters such as the formation pore fluid pressure gradient FPG of the shale reservoir, the rock density DEN of the overlying formation of the shale reservoir and the like, the compressibility of the shale reservoir is described and evaluated according to △ Ki, an evaluation method for describing the compressibility of the shale reservoir is formed, the staged fracturing effect of the shale reservoir at the horizontal section of the horizontal well is verified, and the coincidence rate is 97.1%.
Claims (4)
1. An evaluation method for describing the compressibility of a shale reservoir is characterized by comprising the following steps: the method comprises the following specific steps:
1) collecting data of well to be evaluated
(1) Collecting the data content of the well to be evaluated, including the well position design report, logging data and logging data of the well to be evaluated,
the logging information comprises lithology, total hydrocarbon, methane, total organic carbon content, formation pore fluid pressure gradient and formation fracture pressure,
the logging information comprises natural gamma rays, lithologic density and an interpretation result;
2) determining shale reservoir and its middle vertical depth H
Determining a shale reservoir according to shale oil and gas logging lithology, oil and gas display characteristics and a logging comprehensive interpretation result, and determining the vertical depth H in the middle of the shale reservoir according to the shale oil and gas logging and logging interpretation result of the shale reservoir, wherein the dimension is 100m or hm;
3) determining formation pore Fluid Pressure Gradient (FPG) of shale reservoir
According to the shale oil and gas logging while-drilling formation pressure prediction interpretation result, taking the formation pore fluid pressure gradient of a shale reservoir section rich in oil and gas, and recording the arithmetic mean value of the formation pore fluid pressure gradient FPG of the shale reservoir section as the formation pore fluid pressure gradient FPG of the shale reservoir, wherein the dimension is MPa/100m or MPa/hm;
4) obtaining DEN (Density of rock) of overlying stratum of shale reservoir
5) Calculating the maximum horizontal stress Kimax of the shale reservoir according to the formation pore fluid pressure gradient FPG of the shale reservoir;
6) rock density DEN of an overlying stratum of the shale reservoir, and calculating the maximum horizontal stress Kimax of the shale reservoir and the minimum horizontal stress Kimin of the shale reservoir;
7) calculating a horizontal stress difference coefficient △ Ki of the shale gas reservoir according to the maximum horizontal stress Kimax of the shale reservoir and the minimum horizontal stress Kimin of the shale reservoir,
(1) obtaining the logging lithologic density data of each depth point within the range of 10-60 m above the shale reservoir through the logging lithologic density data, wherein the dimension is g/cm3The arithmetic mean value is recorded as rock density DEN of an overlying stratum of the shale gas reservoir, the product of the rock density DEN and the vertical depth H is recorded as the maximum horizontal crustal stress Kimax, the Kimax is DEN × H, and the dimension is MPa;
(2) calculating the minimum horizontal ground stress Kimin of the shale gas reservoir according to a formula Kimin ═ DEN + FPG)/2 × H according to the formation pore fluid pressure gradient FPG of the shale reservoir, the rock density DEN of the overlying formation of the shale reservoir and the vertical depth H parameter of the step 7) (1) determined in the step 3) and the step 4), wherein the dimension is MPa;
8) according to the stratum pore fluid pressure gradient FPG of the shale reservoir and the rock density DEN of the overlying stratum of the shale reservoir determined in the steps 3) and 4), the maximum horizontal stress Kimax of the shale gas reservoir and the minimum horizontal stress Kimin of the shale gas reservoir are used for solving the horizontal ground stress difference coefficient △ Ki and △ Ki dimensionless according to the following calculation formula,
△ Ki ═ Kimax-Kimin)/Kimin or
△Ki＝(DEN－FPG)/(DEN+FPG)；
9) The compressibility of the shale reservoir is evaluated,
the evaluation criteria for evaluating the compressibility of the shale reservoir are as follows:
(1) △ Ki is less than or equal to 0.35, the compressibility of the shale gas reservoir is evaluated to be good,
(2) ki of 0.35- △ is less than or equal to 0.6, the compressibility of the shale gas reservoir is evaluated to be medium,
(3) △ Ki is more than 0.6, and the compressibility of the shale gas reservoir is evaluated to be poor;
10) and outputting an evaluation result.
2. An evaluation method for describing the compressibility of shale reservoirs according to claim 1, wherein: and 3) acquiring formation pore fluid pressure gradient data of each depth point of the shale reservoir section rich in oil and gas according to the depth interval of 1 point per meter, and taking the arithmetic mean value of the data.
3. An evaluation method for describing the compressibility of shale reservoirs according to claim 1, wherein: and 7) in the step (1), obtaining the logging lithologic density data of each depth point within the range of 10-60 m above the shale reservoir according to the logging lithologic density data and the depth interval of 1 point per meter.
4. An evaluation method for describing the compressibility of shale reservoirs according to claim 1, wherein: the shale reservoir is an oil and gas-rich shale reservoir interval; the gas logging of the oil-gas-rich shale reservoir section has good display of all hydrocarbon and methane, high shale physical development, high natural gamma value and high sound wave time difference value, the total organic carbon content is more than or equal to 2 percent, and the total porosity is more than or equal to 2 percent.
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