Method for correcting movable hydrocarbon content of high gas-oil ratio shale oil based on phase behavior and rock pyrolysis

Abstract

A method for correcting a movable hydrocarbon content of high gas-oil ratio shale oil based on phase behavior and rock pyrolysis includes: S1, simulating and preparing a fluid under original formation conditions based on formation fluid properties of a target block; S2, performing a pressure-volume-temperature (PVT) experiment and a fluid property test on the fluid prepared in the step S1 to obtain a composition of well fluid and a deviation factor; S3, establishing a theoretical shale movable hydrocarbon content prediction model to calculate a shale theoretical movable hydrocarbon content and a light hydrocarbon correction factor, and S4, determining, based on the light hydrocarbon correction factor obtained in the step S3, a restored light hydrocarbon content of shale oil and a restored original total oil content. This method, considering geological conditions and fluid properties of various shale oil reservoirs, corrects the movable hydrocarbon content of high gas-oil ratio shale oil.

Claims

1. A method for correcting a movable hydrocarbon content of shale oil based on phase behavior and rock pyrolysis, comprising following steps: S1, simulating and preparing a fluid under original formation conditions based on formation fluid properties of a target block; S2, performing a pressure-volume-temperature (PVT) experiment and a fluid property test on the fluid prepared in the step S1 to obtain a composition of well fluid and a deviation factor; S3, establishing a theoretical shale movable hydrocarbon content prediction model to calculate a shale theoretical movable hydrocarbon content and a light hydrocarbon correction factor; wherein the theoretical shale movable hydrocarbon content prediction model is as follows: $\begin{array}{cc}{S}_{\mathrm{KD}}=\frac{P_p{V}_b{S}_{0}M{10}^6}{{\mathrm{ZRT}}_p{m}_b}& \left(1\right)\end{array}$ where S.sub.KD represents the shale theoretical movable hydrocarbon content, in a unit of milligram per gram (mg/g); P.sub.p represents a formation pressure, in a unit of megapascal (MPa); V.sub.b represents a volume of a core sample, in a unit of cubic meter (m.sup.3); represents a porosity of the core sample, in percentage (%); S.sub.0 represents an oil saturation of the core sample, in percentage (%); M represents a relative molecular weight of the fluid as simulated, dimensionless; Z represents the deviation factor, dimensionless; R represents a molar gas constant 0.008314; T.sub.p represents a formation temperature, in a unit of Kelvin (K); and m.sub.b represents a weight of the core sample, in a unit of gram (g); wherein the light hydrocarbon correction factor is calculated as per the following formula: $\begin{array}{cc}K=\frac{S_{\mathrm{KD}}-S_{1\mathrm{total}}}{S_{1\mathrm{total}}}& \left(2\right)\end{array}$ where K represents the light hydrocarbon correction factor, dimensionless; S.sub.KD represents the shale theoretical movable hydrocarbon content, in the unit of mg/g; and S.sub.1total=S.sub.1-1+S.sub.1-2, where S.sub.1-1 represents a content of light oil, S.sub.1-2 represents a content of light-medium oil, and S.sub.1total represents a total light hydrocarbon content; S4, determining, based on the light hydrocarbon correction factor obtained in the step S3, a restored light hydrocarbon content of shale oil and a restored original total oil content; and S5, determining, based on the restored light hydrocarbon content of shale oil and the restored original total oil content, the target block whether as a to-be-exploited region; and in response to the target block is determined as the to-be-exploited region, exploiting shale oil from the to-be-exploited region.

2. The method for correcting a movable hydrocarbon content of shale oil based on phase behavior and rock pyrolysis as claimed in claim 1, wherein the formation fluid properties of the target block in the step S1 comprise a formation temperature, a formation pressure, a gas-oil ratio, and a deviation factor.

3. The method for correcting a movable hydrocarbon content of shale oil based on phase behavior and rock pyrolysis as claimed in claim 1, wherein in the step S4, the restored light hydrocarbon content of shale oil is calculated as per the following formula:
S.sub.light hydrocarbon=KS.sub.1total+S.sub.1total(3) wherein the restored original total oil content is calculated as per the following formula:
S.sub.TOL=KS.sub.1total+S.sub.1total+S.sub.2-1(4) where S.sub.2-1 represents a content of light-heavy oil.

Description

BRIEF DESCRIPTION OF DRAWINGS

(1) FIG. 1 illustrates a schematic flowchart of a method for correcting a movable hydrocarbon content of high gas-oil ratio shale oil based on phase behavior and rock pyrolysis provided by the disclosure.

(2) FIG. 2 illustrates a schematic diagram of light hydrocarbon contents in segmented pyrolysis of core samples and calculated movable hydrocarbon contents according to an embodiment of the disclosure.

(3) FIG. 3 illustrates a schematic diagram of total oil contents in the segmented pyrolysis of the core samples and corrected total oil contents according to the embodiment of the disclosure.

DETAILED DESCRIPTION OF EMBODIMENTS

(4) Below, technical solutions in embodiments of the disclosure will be clearly and completely described in conjunction with attached drawings. Apparently, the described embodiments are only some of embodiments of the disclosure, and not all of embodiments of the disclosure. Based on the described embodiments of the disclosure, all other embodiments obtained by those skilled in the art without creative labor are within the scope of protection of the disclosure.

(5) Referring to FIG. 1 through FIG. 3, a method for correcting a movable hydrocarbon content of high gas-oil ratio shale oil based on phase behavior and rock pyrolysis according to an embodiment of the disclosure is provided. The method includes following steps.

(6) S1, a formation fluid (i.e., a fluid under original formation conditions) is prepared based on formation fluid properties of an acquired target block. Specifically, a formation temperature and a formation pressure are inferred from a gas-oil ratio obtained from a hydrocarbon generation experiment and a formation depth of a formation fluid in the target block, to stimulate and prepare the fluid under original formation conditions.

(7) S2, a PVT experiment and a fluid property test are performed on the formation fluid prepared in the step S1 to obtain a composition of well fluid, a deviation factor, a viscosity of the prepared formation fluid, and a condensate oil density. The composition of well fluid includes carbon dioxide (CO.sub.2), nitrogen (N.sub.2), methane (C.sub.1), ethane (C.sub.2), propane (C.sub.3), isobutane (iC.sub.4), normal butane (nC.sub.4), isopentane (iC.sub.5), normal pentane (nC.sub.5), hexane (C.sub.6), heptane (C.sub.7), octane (C.sub.8), nonane (C.sub.9), decane (C.sub.10), undecane and heavier hydrocarbons (C.sub.11+), etc. In addition, basic data of a core sample are tested, including a volume, a dry weight, a porosity, an oil saturation, and a density.

(8) S3, a theoretical shale movable hydrocarbon content prediction model is established to calculate a shale theoretical movable hydrocarbon content and a light hydrocarbon correction factor. Specifically, a segmented pyrolysis (also referred to as stepwise pyrolysis) method is used/employed for an ordinary shale core sample to establish a correction model associated with the shale theoretical movable hydrocarbon content S.sub.KD and a total light hydrocarbon content (also referred to a total content of light hydrocarbons) S.sub.1total obtained from segmented pyrolysis of the ordinary shale core sample.

(9) Specific operations of the segmented pyrolysis method are as follows.

(10) The core sample is crushed to less than 100 meshes, and a segmented temperature rise pyrolysis experiment is performed by using a rock pyrolysis analyzer to measure a content of light oil S.sub.1-1, a content of light-medium oil S.sub.1-2, and a content of light-heavy oil S.sub.2-1. Specifically, S.sub.1-1 corresponds to hydrocarbons with a carbon number roughly ranging from C.sub.7 to C.sub.14, and these hydrocarbons are considered a mobile fraction of light oil and are decomposed and released at a temperature of 200 C. S.sub.1-2 corresponds to hydrocarbons with a carbon number roughly ranging from C.sub.14 to C.sub.25, and these hydrocarbons are decomposed and released at a temperature ranging from 200 C. to 350 C. S.sub.2-1 corresponds to hydrocarbons with a carbon number roughly ranging from C.sub.25 to C.sub.38, and theses hydrocarbons are mainly adsorbed in form of colloids, asphaltenes, and heavy hydrocarbons, and are decomposed and released at a temperature range ranging from 350 C. to 450 C. Light hydrocarbons specifically refer to hydrocarbons with a carbon number ranging from C.sub.1 to C.sub.14. Due to a significant loss of the light hydrocarbons in the ordinary shale core sample during storage, a calculated movable hydrocarbon content includes all components of free hydrocarbons. Therefore, it is necessary to further determine the light hydrocarbon correction factor, i.e., a ratio of a difference between the shale theoretical movable hydrocarbon content S.sub.KD and the total light hydrocarbon content S.sub.1total obtained from the segmented pyrolysis of the ordinary shale core sample to the total light hydrocarbon content S.sub.1total.

(11) The theoretical shale movable hydrocarbon content prediction model is as follows:

(12) $\begin{array}{cc}{S}_{\mathrm{KD}}=\frac{P_p{V}_b{S}_{0}M{10}^6}{{\mathrm{ZRT}}_p{m}_b}& \left(1\right)\end{array}$ where S.sub.KD represents the shale theoretical movable hydrocarbon content, in a unit of mg/g; P.sub.p represents a formation pressure, in a unit of MPa; V.sub.b represents the volume of the core sample, in a unit of m.sup.3; represents the porosity of the core sample, in percentage (%); S.sub.0 represents the oil saturation of the core sample, in percentage (%); M represents a relative molecular weight, dimensionless; Z represents the deviation factor, dimensionless; R represents a molar gas constant 0.008314; T.sub.p represents a formation temperature, in a unit of K; and mb represents a weight of the core sample, in a unit of g.

(13) The light hydrocarbon correction factor is calculated as per the following formula:

(14) $\begin{array}{cc}K=\frac{S_{\mathrm{KD}}-S_{1\mathrm{total}}}{S_{1\mathrm{total}}}& \left(2\right)\end{array}$ where K represents the light hydrocarbon correction factor, dimensionless; S.sub.KD represents the shale theoretical movable hydrocarbon content, in the unit of mg/g; and S.sub.1total=S.sub.1-1+S.sub.1-2, where S.sub.1-1 represents the content of light oil, S.sub.1-2 represents the content of light-medium oil, and S.sub.1total represents the total light hydrocarbon content.

(15) S4, based on the light hydrocarbon correction factor obtained in the step S3, a corrected light hydrocarbon content and a corrected original total oil content are determined.

(16) A calculation expression for the corrected/restored light hydrocarbon content of shale oil is as follows:
S.sub.light hydrocarbon=KS.sub.1total+S.sub.1total(3)

(17) A calculation expression for the corrected/restored original total oil content is as follows:
S.sub.TOL=KS.sub.1total+S.sub.1total+S.sub.2-1(4) where S.sub.2-1 represents the content of light-heavy oil.

(18) In a specific embodiment, a high gas-oil ratio shale oil reservoir (i.e., a target shale oil reservoir) is used as an example. The method provided by the disclosure is used to correct an original total oil content of the target shale oil reservoir. Specific steps are as follows.

(19) 1, Formation fluid data of a target well is obtained, as shown in Table 1.

(20) TABLE-US-00001 TABLE 1 fluid property data of the target shale oil reservoir pressure temperature gas-oil ratio (MPa) (K) (m.sup.3/m.sup.3) deviation factor 30 362.15 1000 1.1129

(21) 2, A viscosity of the prepared formation fluid is 0.256 millipascal-second (mPa.Math.s), and a condensate oil density is 0.8024 grams per cubic centimeter (g/cm.sup.3). A composition of the prepared formation fluid is calculated, as shown in Table 2.

(22) TABLE-US-00002 TABLE 2 composition of well fluid oil gas well fluid relative components components components molecular % (mole % (mole % (mole components weight fraction) fraction) fraction) CO.sub.2 44 0.00 0.69 0.65 N.sub.2 26 0.00 1.01 0.96 C.sub.1 16 0.00 79.35 74.93 C.sub.2 30 0.00 11.54 10.89 C.sub.3 44 0.00 4.84 4.57 iC.sub.4 58 0.09 0.64 0.61 nC.sub.4 58 0.05 1.14 1.08 iC.sub.5 72 0.18 0.31 0.31 nC.sub.5 72 0.25 0.26 0.26 C.sub.6 86 1.18 0.18 0.24 C.sub.7 100 4.6 0.04 0.29 C.sub.8 114 4.26 0.00 0.24 C.sub.9 128 3.69 0.00 0.21 C.sub.10 142 5.28 0.00 0.29 C.sub.11+ 172.4 80.42 0.00 4.48

(23) 3, Basic data of tested core samples are shown in table 3.

(24) TABLE-US-00003 TABLE 3 basic data of core samples core sample oil serial volume dry weight porosity saturation density number (cm.sup.3) (g) (%) (%) (g/cm.sup.3) 1 43.29657 91.712 4.952 37.78 2.118227841 2 31.88601 83.002 2.521541 36.42 2.603085177 3 26.13408 40.509 4.872376 38.86 1.550044999 4 35.53108 81.207 7.077 37.13 2.28552017 5 29.89767 42.085 6.979 36.96 1.407634776 6 49.79016 98.013 7.892 38.94 1.968521491 7 28.78569 51.973 6.93 30.88 1.805515171 8 17.63145 41.5 3.985 28.74 2.353748557 9 27.79489 50.011 6.895 34.88 1.799287567 10 24.21509 58.073 4.8758 32.45 2.398215328 . . . . . . . . . . . . . . . . . .

(25) 4, A movable hydrocarbon content (i.e., the shale theoretical movable hydrocarbon content) S.sub.KD of each core sample is calculated.

(26) Based on different core samples, the movable hydrocarbon content S.sub.KD of each core sample is calculated as per the formula (1), and calculation results are shown in Table 4.

(27) TABLE-US-00004 TABLE 4 calculation results of movable hydrocarbon content for different core samples serial number 1 2 3 4 5 S.sub.KD 0.465 0.88 0.471 0.582 0.33 serial number 6 7 8 9 10 S.sub.KD 0.33 0.706 1.065 0.366 0.739

(28) 5, Segmental pyrolysis is performed on each ordinary core sample to establish a correction model associated with a total light hydrocarbon content S.sub.1total obtained from segmental pyrolysis of each ordinary core sample and the theoretical shale movable hydrocarbon content S.sub.KD.

(29) A Segmental pyrolysis experiment is performed on the core samples, and a light hydrocarbon correction factor of each core sample is calculated according to the formula (2). Calculation results are shown in Table 5, and in Table 5, S.sub.2-2 corresponds to hydrocarbons with a carbon number ranging from C.sub.38 to C.sub.60.

(30) TABLE-US-00005 TABLE 5 results of segmental pyrolysis and light hydrocarbon correction core sample S.sub.1-1 + serial S.sub.1-1 S.sub.1-2 S.sub.2-1 S.sub.2-2 S.sub.1-2 number (mg/g) (mg/g) (mg/g) (mg/g) (mg/g) K 1 0.29 1.22 0.86 0.72 1.51 0.464856 2 0.14 0.33 0.14 0.23 0.47 0.879844 3 0.41 1.67 0.77 1.01 2.08 0.470747 4 0.22 1.6 1.11 0.91 1.82 0.582048 5 0.61 2.84 1.28 1.82 3.45 0.330204 6 0.43 2.51 1.35 1.31 2.94 0.329834 7 0.21 1.53 0.82 0.71 1.74 0.705934 8 0.16 0.43 0.14 0.38 0.59 1.065404 9 0.35 2.1 0.98 0.88 2.45 0.3663 10 0.23 0.72 0.31 0.24 0.95 0.739205 . . . . . . . . . . . . . . . . . . . . .

(31) 6, A corrected original total oil content STOL of each core sample is calculated.

(32) The corrected original total oil content STOL of each core sample is calculated as per the formula (3), and calculation results are shown in Table 6.

(33) TABLE-US-00006 TABLE 6 results of corrected original total oil content serial number 1 2 3 4 5 S.sub.TOL 3.072 1.024 3.829 3.989 5.869 serial number 6 7 8 9 10 S.sub.TOL 5.26 3.788 1.359 4.327 1.962

(34) As shown in FIG. 2 and FIG. 3, the theoretical shale movable hydrocarbon content and the total oil content are compared with the experimentally measured values. It is found that calculated results have a good correlation with measured results, with a correlation coefficient R.sup.2>0.9. This indicates that the method can be effectively used for the correction of movable hydrocarbon content in high gas-oil ratio shale oil.

(35) The above is only a specific implementation of the disclosure, but the scope of protection of the disclosure is not limited to this. Those skilled in the art can easily think of changes or replacements within the technical scope disclosed in the disclosure, which should be included in the scope of protection of the disclosure. Therefore, the scope of protection of the disclosure should be determined by the scope of protection defined by the appended claims.