CN104948164A - Acquisition method of high-temperature high-pressure reservoir carbon dioxide fluid density skeleton parameters - Google Patents
Acquisition method of high-temperature high-pressure reservoir carbon dioxide fluid density skeleton parameters Download PDFInfo
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Abstract
The invention discloses an acquisition method of high-temperature high-pressure reservoir carbon dioxide fluid density skeleton parameters. The method includes the following steps: sampling carbon dioxide fluid; acquiring multiple groups of test experiment data; constructing a primary computing model, to be more specific, utilizing a data fitting analysis method to perform parameter fitting analysis on the multiple groups of data so as to obtain the primary computing model; constructing a density skeleton parameter computing model, to be more specific, on the basis of the primary computing model, utilizing a density well logging response principle to convert volume density of the carbon dioxide fluid into an apparent volume density value so as to obtain the density skeleton parameter computing model; substituting a measured temperature value and a pressure value into the density skeleton parameter computing model to obtain the density skeleton parameters off the carbon dioxide fluid in a high-temperature high-pressure reservoir. By the method, accuracy in acquisition of the carbon dioxide fluid skeleton density parameters can be improved remarkably, further precision in porosity evaluation of high-temperature high-pressure carbon-dioxide-enriched gas reservoir well logging interpretation is improved, and high universality is obtained.
Description
Technical field
The present invention relates in a kind of oil-gas exploration technology, HTHP is rich in the logging evaluation technology that carbon dioxide gas-bearing formation degree of porosity is explained, specifically refers to the acquisition methods of HTHP reservoir CO 2 fluid density matrix parameter.
Background technology
Be rich in the evaluation procedure of carbon dioxide gas-bearing formation well log interpretation at HTHP, logging technique personnel are needed to carry out well log interpretation timely to the down-hole density log data obtained according to stratum component volume-based model, obtain the degree of porosity parameter of gas-bearing formation, the key of work is to determine formation condition carbon dioxide fluid density matrix parameter.The acquisition methods of existing CO 2 fluid density matrix parameter mostly is region empirical method, the carbon dioxide gas sample that the method mainly utilizes down-hole to get carries out PVT experiment, then the density value under certain temperature and pressure is obtained, it can be used as the matrix parameter empirical value in region, but technician finds that the accuracy of the CO 2 fluid density matrix parameter that said method obtains is lower in long production practices, its pressure coefficient excursion of main HTHP reservoir of tracing it to its cause is larger, and between well HTHP to be rich in carbon dioxide gas-bearing formation also different in aboveground buried depth scope, cause the strata pressure of gas-bearing formation, temperature value is inconsistent, the subjectivity of the method is comparatively large in addition, has used the process of some estimations, thus make CO 2 fluid density matrix parameter empirical value differ larger with the value in actual formation.
Summary of the invention
The object of this invention is to provide a kind of highly versatile and the acquisition methods of the high HTHP reservoir CO 2 fluid density matrix parameter of accuracy.
For achieving the above object, the technical solution adopted in the present invention is:
An acquisition methods for HTHP reservoir CO 2 fluid density matrix parameter, comprises the steps:
Step 1, CO 2 fluid is sampled: utilize sample apparatus to choose CO 2 fluid sample from well site, HTHP gas field;
Step 2, obtains many group test experiments data: under different temperatures and pressure condition, CO 2 fluid sample is carried out to the determination test of bulk density, obtain the multi-group data be made up of bulk density parameter, temperature parameter and pressure parameter;
Step 3, builds primary calculations model: utilize the data fitting analytical method in mathematical statistics category, carry out parameter fitting analysis to above-mentioned multi-group data, the primary calculations model that the bulk density obtaining CO 2 fluid changes with temperature and pressure;
Step 4, build density matrix parameter computation model: on the basis of described primary calculations model, utilize density log response theory, the bulk density of CO 2 fluid is converted into apparent bulk density value, the density matrix parameter computation model that the density matrix parameter obtaining the CO 2 fluid of HTHP reservoir changes with temperature and pressure;
Step 5, obtain density matrix parameter: actual detection is carried out to the temperature in HTHP reservoir and pressure, by the temperature value that records and force value, be updated in density matrix parameter computation model, obtain the density matrix parameter of CO 2 fluid in HTHP reservoir.
Further, in described step 2, in determination test, equipment used is fluid volume penetron.
Further, in described step 2, multi-group data is 20 groups, and wherein, the selected value of temperature is 20 DEG C, 50 DEG C, 100 DEG C and 150 DEG C, and the selected value of pressure is 20MPa, 30 MPa, 40MPa, 50MPa and 60MPa.
Further, in described step 3, primary calculations model is specific as follows:
Y=0.28758*ln (X)+1.0122, wherein, Y is the CO 2 fluid bulk density that experiment measuring obtains, and unit is (g/cm3), X be force value divided by temperature value, unit is (MPa/ DEG C).
Further, in described step 4, described density matrix parameter computation model is specific as follows:
ρ
a(CO2)＝1.0697*(0.2875*ln(x)+1.0122)-0.1883，
Wherein ρ
a(CO2) be HTHP reservoir CO 2 fluid density matrix parameter, unit is (g/cm3), X be force value divided by temperature value, unit is (MPa/ DEG C).
Beneficial effect of the present invention: prove through production practices, utilize the method can significantly improve the degree of accuracy obtaining CO 2 fluid skeletal density parameter, and then improve the precision that HTHP is rich in carbon dioxide gas-bearing formation well log interpretation evaluation degree of porosity, there is stronger versatility.The present invention is that in the well log interpretation evaluation of HTHP gas field, CO 2 fluid skeletal density parameter choose provides better acquisition methods more efficiently.
Accompanying drawing explanation
Below in conjunction with
accompanying drawingwith detailed description of the invention to this
inventionbe described in further detail:
fig. 1for flow process of the present invention
figure;
fig. 2the data of CO 2 fluid bulk density under different temperatures, pressure condition obtaining all formation of many group test experiments data for the present invention are in step 2 fallen apart a little
figure;
fig. 3for the present invention in step 3 force value fall apart a little divided by the result of temperature value and the data of CO 2 fluid bulk density relation
figure.
Detailed description of the invention
as Fig. 1shown in, a kind of acquisition methods of HTHP reservoir CO2 fluid density skeleton, it comprises the steps:
Step 1, CO 2 fluid is sampled: CO 2 fluid sample is chosen: utilize sample apparatus to collect CO 2 fluid sample from well site, HTHP gas field;
Step 2, obtain many group test experiments data: the analysis of common laboratory fluids volume density test is carried out to CO 2 fluid sample, it is 20 DEG C, 50 DEG C, 100 DEG C and 150 DEG C in temperature respectively, pressure is 20MPa, measure CO 2 fluid bulk density under 30 MPa, 40MPa, 50MPa and 60MPa condition, altogether measurement obtains 20 groups of CO 2 fluid bulk density experimental datas, by these 20 groups of CO 2 fluid bulk density experimental datas with
figuremode embody, obtain the data of CO 2 fluid bulk density under different temperatures, pressure condition and fall apart a little
figure, as Fig. 2shown in.Fall apart a little through testing the data obtained
figureknown, what CO 2 fluid bulk density and temperature, pressure presented is dyadic correlation relation, under same temperature condition, along with the increase of pressure, CO 2 fluid bulk density increases, and under same pressure condition, along with the rising of temperature, CO 2 fluid bulk density reduces, and that is CO 2 fluid bulk density has different numerical value under different temperatures pressure condition.
Step 3, builds primary calculations model: utilize the data fitting analytical method in mathematical statistics category, carry out parameter fitting analysis to above-mentioned multi-group data, the primary calculations model that the bulk density obtaining CO 2 fluid changes with temperature and pressure.
Concrete steps are as follows: in order to state the Changing Pattern between CO 2 fluid bulk density and temperature, pressure better, more accurately, take optimization data Fitting Analysis, first Treatment Analysis is carried out to temperature, pressure parameter, by pressure data values divided by temperature data value, construct the parameter X that makes new advances, the loose point that to obtain with CO 2 fluid bulk density and X be coordinate
figure.In a particular embodiment, experimental data is processed, take X as abscissa, CO 2 fluid bulk density is that ordinate sets up loose point
figure, CO 2 fluid bulk density data and X parameter are set up logarithmic function relational expression Y=0.28758*ln (X)+1.0122,
as Fig. 3shown in, wherein, Y is the CO 2 fluid bulk density that experiment measuring obtains, and unit is (g/cm3), X be force value divided by temperature value, unit is (MPa/ DEG C);
in figure, R2 represent the index of correlation of CO 2 fluid bulk density and Pressure/Temperature value square, the correlation of this value larger expression CO 2 fluid bulk density and Pressure/Temperature Value Data is better.
Step 4, build density matrix parameter computation model: on the basis of described primary calculations model, utilize density log response theory, the bulk density of CO 2 fluid is converted into apparent bulk density value, the density matrix parameter computation model that the density matrix parameter obtaining the CO 2 fluid of HTHP reservoir changes with temperature and pressure.
Its concrete implementation step is as follows: from density log response theory, and that density log is measured is the electron density ρ on stratum
e, with the scale equation that hydrophite limestone scale represents be:
ρ
a＝1.07(ρ
e)
i-0.1883 (1)
Wherein (ρ
e)
ifor electron density index, be defined as:
In formula, N is Avogadro's number;
After scale equation scale, density logging instrument record be the apparent bulk density ρ on stratum
a, the bulk density on stratum and the relation of electron density:
In formula, N is Avogadro's number, and Z is atomic number, and A is atomic weight;
(3) and (2) are substituted into formula (1).For the compound of polyatom composition, the apparent bulk density after its scale is:
The molecular formula of carbon dioxide is CO2, the atom coefficient of C, O and atomic weight are substituted into formula (4), and the CO 2 fluid bulk density of step 103 gained and temperature, pressure parameter computation model are substituted into formula (4) and the apparent bulk density mathematic(al) representation of CO2 under formation condition can be obtained be:
ρ
a(CO2)＝1.0697*(0.2875*ln(x)+1.0122)-0.1883(5)
Wherein ρ
a(CO2) be HTHP reservoir CO 2 fluid density matrix parameter, unit is (g/cm3), X be force value divided by temperature value, unit is (MPa/ DEG C).
Step 5, obtain density matrix parameter: actual detection is carried out to the temperature in HTHP reservoir and pressure, by the temperature value that records and force value, be updated in density matrix parameter computation model, obtain the density matrix parameter of CO 2 fluid in HTHP reservoir.
Above-described detailed description of the invention; object of the present invention, technical scheme and beneficial effect are further described; be understood that; the foregoing is only the specific embodiment of the present invention; the protection domain be not intended to limit the present invention; within the spirit and principles in the present invention all, any amendment made, equivalent replacement, improvement etc., all should be included within protection scope of the present invention.The content that this manual is not described in detail belongs to the known prior art of professional and technical personnel in the field.
Claims (5)
1. an acquisition methods for HTHP reservoir CO 2 fluid density matrix parameter, is characterized in that, comprise the steps:
Step 1, CO 2 fluid is sampled: utilize sample apparatus to choose CO 2 fluid sample from well site, HTHP gas field;
Step 2, obtains many group test experiments data: under different temperatures and pressure condition, CO 2 fluid sample is carried out to the determination test of bulk density, obtain the multi-group data be made up of bulk density parameter, temperature parameter and pressure parameter;
Step 3, builds primary calculations model: utilize the data fitting analytical method in mathematical statistics category, carry out parameter fitting analysis to above-mentioned multi-group data, the primary calculations model that the bulk density obtaining CO 2 fluid changes with temperature and pressure;
Step 4, build density matrix parameter computation model: on the basis of described primary calculations model, utilize density log response theory, the bulk density of CO 2 fluid is converted into apparent bulk density value, the density matrix parameter computation model that the density matrix parameter obtaining the CO 2 fluid of HTHP reservoir changes with temperature and pressure;
Step 5, obtain density matrix parameter: actual detection is carried out to the temperature in HTHP reservoir and pressure, by the temperature value that records and force value, be updated in density matrix parameter computation model, obtain the density matrix parameter of CO 2 fluid in HTHP reservoir.
2. the acquisition methods of HTHP reservoir CO 2 fluid density matrix parameter according to claim 1, it is characterized in that: in described step 2, in determination test, equipment used is fluid volume penetron.
3. the acquisition methods of HTHP reservoir CO 2 fluid density matrix parameter according to claim 1, it is characterized in that: in described step 2, multi-group data is 20 groups, wherein, the selected value of temperature is 20 DEG C, 50 DEG C, 100 DEG C and 150 DEG C, and the selected value of pressure is 20MPa, 30MPa, 40MPa, 50MPa and 60MPa.
4. the acquisition methods of the HTHP reservoir CO 2 fluid density matrix parameter according to any one of claims 1 to 3, it is characterized in that: in step 3, primary calculations model is specific as follows: Y=0.28758*ln (X)+1.0122, wherein, Y is the CO 2 fluid bulk density that experiment measuring obtains, unit is (g/cm3), X be force value divided by temperature value, unit is (MPa/ DEG C).
5. the acquisition methods of HTHP reservoir CO 2 fluid density matrix parameter according to claim 4, it is characterized in that: in described step 4, described density matrix parameter computation model is specific as follows:
ρa(CO2)＝1.0697*(0.2875*ln(x)+1.0122)-0.1883，
Wherein ρ a (CO2) is HTHP reservoir CO 2 fluid density matrix parameter, and unit is (g/cm3), X be force value divided by temperature value, unit is (MPa/ DEG C).
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| CN105952446A (en) * | 2016-04-26 | 2016-09-21 | 中国海洋石油总公司 | Measurement method for component content of petroleum and natural gas reservoir |
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Address after: 100010 Chaoyangmen North Street, Dongcheng District, Dongcheng District, Beijing Co-patentee after: CNOOC (China) Limited Zhanjiang Branch Patentee after: China Offshore Oil Group Co., Ltd. Address before: 100010 China oil tower, 25 Chaoyangmen North Street, Dongcheng District, Beijing Co-patentee before: CNOOC (China) Limited Zhanjiang Branch Patentee before: China National Offshore Oil Corporation |
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