CN116517531A - Method for judging fluid property based on real-time carbon isotope logging technology - Google Patents
Method for judging fluid property based on real-time carbon isotope logging technology Download PDFInfo
- Publication number
- CN116517531A CN116517531A CN202310503710.5A CN202310503710A CN116517531A CN 116517531 A CN116517531 A CN 116517531A CN 202310503710 A CN202310503710 A CN 202310503710A CN 116517531 A CN116517531 A CN 116517531A
- Authority
- CN
- China
- Prior art keywords
- gas
- carbon isotope
- oil
- fluid
- layer
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 83
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 title claims abstract description 44
- 229910052799 carbon Inorganic materials 0.000 title claims abstract description 44
- 238000005516 engineering process Methods 0.000 title claims abstract description 38
- 238000000034 method Methods 0.000 title claims abstract description 36
- 238000004458 analytical method Methods 0.000 claims abstract description 18
- 238000004321 preservation Methods 0.000 claims abstract description 12
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 8
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 43
- GMACPFCYCYJHOC-UHFFFAOYSA-N [C].C Chemical compound [C].C GMACPFCYCYJHOC-UHFFFAOYSA-N 0.000 claims description 35
- 239000004215 Carbon black (E152) Substances 0.000 claims description 19
- 229930195733 hydrocarbon Natural products 0.000 claims description 19
- 150000002430 hydrocarbons Chemical class 0.000 claims description 19
- YNIXPIABGHKZPS-UHFFFAOYSA-N [C].CC Chemical compound [C].CC YNIXPIABGHKZPS-UHFFFAOYSA-N 0.000 claims description 8
- 238000005259 measurement Methods 0.000 claims description 8
- 239000011435 rock Substances 0.000 claims description 8
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 claims description 6
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims description 3
- 239000001294 propane Substances 0.000 claims description 3
- 238000004364 calculation method Methods 0.000 claims description 2
- 238000011161 development Methods 0.000 abstract description 6
- 239000003208 petroleum Substances 0.000 abstract description 5
- 238000005520 cutting process Methods 0.000 abstract description 4
- 239000007789 gas Substances 0.000 description 102
- 230000006872 improvement Effects 0.000 description 6
- 230000002159 abnormal effect Effects 0.000 description 4
- 230000005856 abnormality Effects 0.000 description 4
- 238000010586 diagram Methods 0.000 description 4
- 238000005553 drilling Methods 0.000 description 4
- 238000005070 sampling Methods 0.000 description 3
- 239000003034 coal gas Substances 0.000 description 2
- 238000001514 detection method Methods 0.000 description 2
- 230000004807 localization Effects 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 238000000197 pyrolysis Methods 0.000 description 2
- 150000001335 aliphatic alkanes Chemical class 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000009530 blood pressure measurement Methods 0.000 description 1
- 238000004587 chromatography analysis Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics (AREA)
- Other Investigation Or Analysis Of Materials By Electrical Means (AREA)
- Geophysics And Detection Of Objects (AREA)
Abstract
The invention discloses a method for judging fluid properties based on a real-time carbon isotope logging technology, which comprises the steps of firstly acquiring isotope parameters and judging to obtain the fluid type of an oil and gas reservoir, secondly establishing an analysis chart and judging the filling degree of the oil and gas, thirdly establishing the methane isotope ratio of a reservoir layer and judging the preservation condition of the oil and gas, and fourthly determining the property of the stored fluid according to the fluid type of the oil and gas reservoir, the filling degree and the preservation condition; according to the invention, the carbon isotope data is obtained through a real-time carbon isotope logging technology, and the complex fluid property problem that the existing logging technologies such as gas logging, ground logging and cuttings fluorescent logging are difficult to realize can be supplemented and utilized by combining with the established fluid filling degree analysis plate, so that the accuracy of fluid property judgment is further improved, and a more reliable judgment method is provided for petroleum exploration, development and submission.
Description
Technical Field
The invention relates to the technical field of petroleum exploration and development, in particular to a method for judging fluid properties based on a real-time carbon isotope logging technology.
Background
Logging is a process of using methods such as rock and mineral analysis, geophysics, geochemistry and the like to observe, collect, record and analyze returned object information of a shaft such as solid, liquid, gas and the like in the while-drilling process, so as to establish a logging geological section, discover oil and gas display, evaluate an oil and gas layer and provide drilling information service for petroleum engineering (investors, drilling engineering and other engineering); the logging technology is the most basic technology in oil and gas exploration and development activities, is the most timely and direct means for finding and evaluating oil and gas reservoirs, and has the characteristics of timely and various underground information acquisition and rapid analysis and interpretation.
With the complicating of deep water and deep oil gas exploration targets of offshore oil gas, conventional oil gas logging and logging technology comprises gas logging, localization logging, cuttings fluorescent logging technology and resistivity while drilling, density and neutron logging technology, and the fluid properties of reservoirs are difficult to evaluate, and great challenges are brought to exploration and development decisions and reservoir implementation submission on areas, so that the invention provides a method for judging the fluid properties based on a real-time carbon isotope logging technology to solve the problems in the prior art.
Disclosure of Invention
In view of the above problems, the present invention aims to provide a method for determining fluid properties based on a real-time carbon isotope logging technology, which obtains carbon isotope data by using the real-time carbon isotope logging technology, and combines with an established analysis chart of fluid filling degree, so that the problem of complex fluid properties which are difficult to implement by using logging technologies such as gas logging, ground logging, and cuttings fluorescent logging can be supplemented, thereby further improving the accuracy of determining fluid properties, and providing a more reliable determination method for petroleum exploration, development and submission.
In order to achieve the purpose of the invention, the invention is realized by the following technical scheme: a method for judging fluid properties based on a real-time carbon isotope logging technique, comprising the following steps:
firstly, acquiring isotope parameters, namely acquiring parameters of methane carbon isotopes and ethane carbon isotopes by using a real-time carbon isotope logging technology, acquiring gas measurement derivative parameters by using a gas logging technology, and judging by combining the parameters to obtain the fluid type of the oil and gas reservoir;
establishing an analysis chart, namely acquiring isotope parameters by using a real-time carbon isotope logging technology to establish a fluid filling degree analysis chart, and judging to obtain the oil gas filling degree according to the analysis chart;
step three, judging the fluid property, establishing a methane-carbon isotope ratio eta of the reservoir layer according to the parameters of the methane-carbon isotopes and the ethane-carbon isotopes, evaluating the effectiveness of the reservoir layer, and judging to obtain the oil-gas preservation condition;
and fourthly, analyzing and judging according to the fluid type, the oil gas filling degree and the oil gas preservation condition of the oil gas reservoir, and finally determining the reservoir fluid property by combining the predicted water saturation by using isotopes.
The further improvement is that: the fluid filling degree analysis plate establishment in the second step specifically comprises
S1, acquiring carbon isotope parameter values of methane, ethane and propane by using a real-time carbon isotope logging technology;
s2, establishing an oil gas filling degree trend area by using the high-quality gas layer area with high oil gas filling degree verified on the area;
s3, establishing a local shallow hydrocarbon source rock low maturity trend region;
and S4, judging the oil gas filling degree according to the trend region of the carbon isotope parameter value falling in the S2 and the S3.
The further improvement is that: the specific judgment result in the step S4 is that when the gas falls in a high-quality gas layer area with high oil gas filling degree, the deep oil gas filling degree is high, and the fluid property is a gas layer with high hydrocarbon saturation; when the oil-gas well-killing device falls in a local shallow hydrocarbon source rock low-maturity trend area, the deep oil-gas filling degree is low, and the fluid property is a gas-containing water layer with low hydrocarbon saturation.
The further improvement is that: in the third step, the calculation formula of the methane carbon isotope ratio eta of the reservoir layer is as follows
Where m represents the reservoir methane carbon isotope maximum and n represents the overburden isotope average of 100 m.
The further improvement is that: and in the third step, when the oil gas preservation condition is judged, the smaller the methane-carbon isotope ratio eta of the reservoir layer is, the fluid property is a gas layer with low water saturation, and the larger the methane-carbon isotope ratio eta of the reservoir layer is, the fluid property is a gas-containing water layer with high water saturation.
The further improvement is that: and in the fourth step, when the isotope is used for predicting the water saturation, the lower the methane carbon isotope ratio of the reservoir layer is, the lower the water saturation is, and the higher the water saturation is conversely.
The further improvement is that: and in the fourth step, determining the fluid property of the reservoir, wherein the fluid property comprises a condensate gas layer, an oil-type gas layer, a biological gas layer, a coal-type gas layer and a gas-containing water layer, and the results are given from the two aspects of the oil-gas filling type and the hydrocarbon-containing saturation.
The beneficial effects of the invention are as follows: according to the invention, the carbon isotope data is obtained through a real-time carbon isotope logging technology, and the complex fluid property problem that the existing logging technologies such as gas logging, ground logging and cuttings fluorescent logging are difficult to realize can be supplemented and utilized by combining with the established fluid filling degree analysis plate, so that the accuracy of fluid property judgment is further improved, and a more reliable judgment method is provided for petroleum exploration, development and submission.
Drawings
FIG. 1 is a flow chart of a method according to embodiment 1 of the present invention.
FIG. 2 is a schematic diagram of the method according to example 1 of the present invention.
FIG. 3 is a graph of methane carbon isotope ratio versus water saturation for a reservoir according to example 1 of the present invention.
FIG. 4 shows the methane carbon isotope and the gas measurement component C in example 2 of the present invention 1 /(C 2 +C 3 ) The plate is explained.
Fig. 5 is an explanatory diagram of the methane carbon isotope and the ethane carbon isotope in example 2 of the present invention.
FIG. 6 is a diagram of example 2 of the present invention 1 And judging the fluid property graph layout by the abnormal multiple and the resistivity.
Fig. 7 is an explanatory diagram of an ethane carbon isotope and a methane carbon isotope according to example 2 of the present invention.
FIG. 8 shows the abnormal fold ratio of Tg and C in example 2 of the present invention 1 And judging the plate by using the abnormal multiple fluid property.
Detailed Description
The present invention will be further described in detail with reference to the following examples, which are only for the purpose of illustrating the invention and are not to be construed as limiting the scope of the invention.
Example 1
According to the embodiments shown in fig. 1, 2 and 3, the method for determining the property of a fluid based on the real-time carbon isotope logging technique includes the following steps:
firstly, acquiring isotope parameters, namely acquiring parameters of methane carbon isotopes and ethane carbon isotopes by using a real-time carbon isotope logging technology, acquiring gas measurement derivative parameters by using a gas logging technology, and judging by combining the parameters to obtain the fluid type of the oil and gas reservoir;
establishing an analysis chart, namely acquiring isotope parameters by using a real-time carbon isotope logging technology to establish a fluid filling degree analysis chart, and judging to obtain the oil gas filling degree according to the analysis chart;
the fluid filling degree analysis plate establishment specifically comprises the following steps:
s1, acquiring carbon isotope parameter values of methane, ethane and propane by using a real-time carbon isotope logging technology;
s2, establishing an oil gas filling degree trend area by using the high-quality gas layer area with high oil gas filling degree verified on the area;
s3, establishing a local shallow hydrocarbon source rock low maturity trend region;
s4, judging the oil gas filling degree according to the trend region of the carbon isotope parameter value falling in the S2 and the S3;
the specific judgment result is that when the gas falls in a high-quality gas layer area with high oil gas filling degree, the deep oil gas filling degree is high, and the fluid property is a gas layer with high hydrocarbon saturation; when the oil-gas well-killing device falls in a local shallow hydrocarbon source rock low-maturity trend area, the deep oil-gas filling degree is low, and the fluid property is a gas-containing water layer with low hydrocarbon saturation.
Step three, judging the fluid property, namely establishing a methane-carbon isotope ratio eta of the reservoir according to parameters of methane-carbon isotopes and ethane-carbon isotopes, evaluating the effectiveness of the reservoir, judging to obtain oil-gas preservation conditions, wherein when the oil-gas preservation conditions are judged, the smaller the methane-carbon isotope ratio eta of the reservoir is, the fluid property is a gas layer with low water saturation, and the larger the methane-carbon isotope ratio eta of the reservoir is, the fluid property is a gas-containing water layer with high water saturation;
the methane carbon isotope ratio eta of the medium reservoir layer is calculated as follows:
wherein m represents a reservoir methane carbon isotope maximum value and n represents a overburden isotope average value of 100 m;
the methane carbon isotope ratio of the reservoir layer has good correlation with the water saturation, the correlation coefficient reaches 0.93, and the smaller the methane carbon isotope ratio of the reservoir layer is, the lower the water saturation is, as shown in figure 3 of the specification. Thus, water saturation can be predicted using the reservoir methane carbon isotope. The methane-carbon isotope ratio of the reservoir may reflect the effectiveness of the reservoir, with a smaller ratio indicating a better reservoir occlusion and a lower water saturation, and vice versa.
And fourthly, analyzing and judging according to the fluid type of the oil and gas reservoir, the filling degree of the oil and gas and the preservation condition of the oil and gas, and simultaneously combining the predicted water saturation by utilizing isotopes, wherein the smaller the methane-carbon isotope ratio of the reservoir layer is, the lower the water saturation is, and the higher the water saturation is, and finally determining the reservoir fluid properties from the two aspects of the filling gas type and the hydrocarbon saturation, wherein the fluid properties comprise a condensate gas layer, an oil-type gas layer, a biological gas layer, a coal-type gas layer and a gas-containing water layer.
When the method for judging the fluid property based on the real-time carbon isotope logging technology is used, firstly, conventional logging and data measurement are utilized to judge whether the oil-gas-containing abundance can preliminarily determine the fluid property, if the hydrocarbon-containing abundance is high, but the fluid phase state is complex and difficult to distinguish, the real-time carbon isotope logging technology is utilized to realize the oil-gas-filling fluid type, if the conventional logging and data measurement are utilized to judge the oil-gas-containing abundance, the real-time carbon isotope logging technology is utilized to realize the oil-gas filling degree and the cap layer plugging condition, and finally, the fluid property is realized.
Example 2
According to fig. 4-8, the embodiment provides a method for determining a property of a fluid based on a real-time carbon isotope logging technique, which comprises the following steps:
1. and (3) analyzing the type of the oil filling gas by using a real-time carbon isotope technology, and realizing the properties of complex fluids.
The fluid in a certain structure reservoir is judged to have higher hydrocarbon abundance through conventional logging data such as gas logging, underground logging and the like, but the fluid is in a critical phase state, and the fluid type is complex and difficult to distinguish.
Compared with the same set of reservoir stratum of the well A, the well B has unobvious fluorescence characteristics of rock debris, low localization pyrolysis value, no abnormality of normal alkane peak of pyrolysis chromatography, and conventional gas detection component C 1 The percentage is higher, as shown in figure 4 of the specification, the B well shows critical state gas bias characteristics, and the A well shows oil phase characteristics. The logging resistivity values are close, neutron density intersection is not obvious, and oil-gas characteristic difference is not obvious. The fluid phase type of the B well requires further implementation.
Methane carbon isotope and gas detection component C through real-time carbon isotope logging technology 1 /(C 2 +C 3 ) The plate, the target layer of the B well falls into the condensate associated gas and coal gas area, as shown in figure 5 of the specification, in order to further distinguish the oil gas from the coal gas, the plate is used for realizing the target layer as the condensate associated gasAs shown in figure 7 of the specification.
Judging the target layer of the B well as condensate oil associated gas through an isotope logging technology, and finally sampling to prove that the target layer is condensate gas, wherein the gas-oil ratio is 1391.8m 3 /m 3 The reliability of the isotope interpretation conclusion was confirmed.
2. And (3) analyzing the oil gas filling degree by utilizing a real-time carbon isotope technology, and realizing the properties of complex fluid.
Typical recorded and measured data of a high-quality air layer in a certain area are characterized by high-air measurement abnormality and high C 1 Percentage, high resistivity, full gas measurement. Some wells develop 2 sets of reservoirs, the upper layer 1 meets the characteristics of the gas layer, the lower layer 2 falls into a differential gas layer, and is very close to a high-quality gas layer, so that certain questions exist about the fluid properties, and further implementation is required, as shown in the figure 6 of the specification.
The method comprises the steps of establishing an isotope oil gas filling degree judging plate, wherein the plate is known that a layer 1 is similar to a regional high-quality air layer, hydrocarbon maturity is higher than that of local mudstone hydrocarbon production, the characteristic of deep high-maturity gas strong filling is shown, the maturity of a layer 2 is similar to that of upper and lower mudstones, and the reliability of isotope conclusion is confirmed by the fact that the deep high-maturity gas filling degree is lower although the reservoir has a certain air layer abnormality as shown in an attached drawing 7 of the specification, and therefore the layer 2 is realized, the nature of the fluid is a gas-containing water layer, and sampling is carried out to form the gas-containing water layer.
3. And (3) analyzing the oil gas preservation condition by utilizing a real-time carbon isotope technology, and realizing the properties of complex fluid.
The gas logging of the target layer of the A well is obvious in abnormality, the gas logging components, absolute values and abnormal multiple amplitudes all meet the regional upper gas layer interpretation standard, the pressure measurement sampling proves that the gas logging component is a water layer, the water layer is a high-gas logging water layer, and the implementation of the reserves of the region has relatively large challenges, as shown in an attached drawing 8 of the specification.
A well zone structure with a bottom wall, sand bodies and fracture forms an efficient migration system, and the adjacent well gas layer of the same migration path develops, so that the well zone structure can be migrated into a reservoir in a target zone. The methane carbon isotope ratio of the target reservoir layer of the adjacent well B well is 0.83, the plugging property of the reservoir layer is good, the predicted water saturation is 58.2%, the fluid property is judged to be a gas layer, the water saturation calculated by well logging is 57.4%, and the interpretation conclusion is that the gas layer. The methane carbon isotope ratio of the reservoir layer of the well A is 0.94, the predicted water saturation is 99.1%, the reservoir layer has poor plugging property, the fluid property is a water layer, the water saturation calculated by well logging is as high as 91.9%, and the interpretation conclusion is the water layer. The isotope interpretation conclusion is consistent with the actual conclusion, which indicates that the isotope logging technique can realize reservoir fluid properties.
The foregoing has shown and described the basic principles, principal features and advantages of the invention. It will be understood by those skilled in the art that the present invention is not limited to the embodiments described above, and that the above embodiments and descriptions are merely illustrative of the principles of the present invention, and various changes and modifications may be made without departing from the spirit and scope of the invention, which is defined in the appended claims. The scope of the invention is defined by the appended claims and equivalents thereof.
Claims (7)
1. The method for judging the fluid property based on the real-time carbon isotope logging technology is characterized by comprising the following steps of:
firstly, acquiring isotope parameters, namely acquiring parameters of methane carbon isotopes and ethane carbon isotopes by using a real-time carbon isotope logging technology, acquiring gas measurement derivative parameters by using a gas logging technology, and judging by combining the parameters to obtain the fluid type of the oil and gas reservoir;
establishing an analysis chart, namely acquiring isotope parameters by using a real-time carbon isotope logging technology to establish a fluid filling degree analysis chart, and judging to obtain the oil gas filling degree according to the analysis chart;
step three, judging the fluid property, establishing a methane-carbon isotope ratio eta of the reservoir layer according to the parameters of the methane-carbon isotopes and the ethane-carbon isotopes, evaluating the effectiveness of the reservoir layer, and judging to obtain the oil-gas preservation condition;
and fourthly, analyzing and judging according to the fluid type, the oil gas filling degree and the oil gas preservation condition of the oil gas reservoir, and finally determining the reservoir fluid property by combining the predicted water saturation by using isotopes.
2. The method for determining fluid properties based on real-time carbon isotope logging technique of claim 1 wherein: the fluid filling degree analysis plate establishment in the second step specifically comprises
S1, acquiring carbon isotope parameter values of methane, ethane and propane by using a real-time carbon isotope logging technology;
s2, establishing an oil gas filling degree trend area by using the high-quality gas layer area with high oil gas filling degree verified on the area;
s3, establishing a local shallow hydrocarbon source rock low maturity trend region;
and S4, judging the oil gas filling degree according to the trend region of the carbon isotope parameter value falling in the S2 and the S3.
3. The method for determining fluid properties based on real-time carbon isotope logging technique of claim 2 wherein: the specific judgment result in the step S4 is that when the gas falls in a high-quality gas layer area with high oil gas filling degree, the deep oil gas filling degree is high, and the fluid property is a gas layer with high hydrocarbon saturation; when the oil-gas well-killing device falls in a local shallow hydrocarbon source rock low-maturity trend area, the deep oil-gas filling degree is low, and the fluid property is a gas-containing water layer with low hydrocarbon saturation.
4. The method for determining fluid properties based on real-time carbon isotope logging technique of claim 1 wherein: in the third step, the calculation formula of the methane carbon isotope ratio eta of the reservoir layer is as follows
Where m represents the reservoir methane carbon isotope maximum and n represents the overburden isotope average of 100 m.
5. The method for determining fluid properties based on real-time carbon isotope logging technique of claim 1 wherein: and in the third step, when the oil gas preservation condition is judged, the smaller the methane-carbon isotope ratio eta of the reservoir layer is, the fluid property is a gas layer with low water saturation, and the larger the methane-carbon isotope ratio eta of the reservoir layer is, the fluid property is a gas-containing water layer with high water saturation.
6. The method for determining fluid properties based on real-time carbon isotope logging technique of claim 1 wherein: and in the fourth step, when the isotope is used for predicting the water saturation, the lower the methane carbon isotope ratio of the reservoir layer is, the lower the water saturation is, and the higher the water saturation is conversely.
7. The method for determining fluid properties based on real-time carbon isotope logging technique of claim 1 wherein: and in the fourth step, determining the fluid property of the reservoir, wherein the fluid property comprises a condensate gas layer, an oil-type gas layer, a biological gas layer, a coal-type gas layer and a gas-containing water layer, and the results are given from the two aspects of the oil-gas filling type and the hydrocarbon-containing saturation.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202310503710.5A CN116517531A (en) | 2023-05-06 | 2023-05-06 | Method for judging fluid property based on real-time carbon isotope logging technology |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202310503710.5A CN116517531A (en) | 2023-05-06 | 2023-05-06 | Method for judging fluid property based on real-time carbon isotope logging technology |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN116517531A true CN116517531A (en) | 2023-08-01 |
Family
ID=87399104
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202310503710.5A Pending CN116517531A (en) | 2023-05-06 | 2023-05-06 | Method for judging fluid property based on real-time carbon isotope logging technology |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN116517531A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN118208214A (en) * | 2024-04-12 | 2024-06-18 | 中海石油(中国)有限公司湛江分公司 | Gas-oil ratio correction method for oil-based slurry pump sampling sample |
-
2023
- 2023-05-06 CN CN202310503710.5A patent/CN116517531A/en active Pending
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN118208214A (en) * | 2024-04-12 | 2024-06-18 | 中海石油(中国)有限公司湛江分公司 | Gas-oil ratio correction method for oil-based slurry pump sampling sample |
| CN118208214B (en) * | 2024-04-12 | 2024-08-20 | 中海石油(中国)有限公司湛江分公司 | Gas-oil ratio correction method for oil-based slurry pump sampling sample |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US7174254B2 (en) | Mud gas isotope logging interpretative process utilizing mixing lines in oil and gas drilling operations | |
| Cazier et al. | Petroleum geology of the Cusiana field, Llanos Basin foothills, Colombia | |
| Whitson et al. | Khuff gas condensate development | |
| GB2582294A (en) | Prediction of reservoir fluid properties from mud-gas data | |
| Schowalter et al. | Interpretation of subsurface hydrocarbon shows | |
| Mirzaei-Paiaman et al. | A new framework for selection of representative samples for special core analysis | |
| CN116517531A (en) | Method for judging fluid property based on real-time carbon isotope logging technology | |
| Ge et al. | Time-lapse monitoring of inter-well communication and drainage frac height using geochemical fingerprinting technology with case studies in the midland basin | |
| Elshahawi et al. | The missing link—Identification of reservoir compartmentalization through downhole fluid analysis | |
| van Bergen et al. | Production geochemistry: fluids don't lie and the devil is in the detail | |
| CN109142682A (en) | A kind of unit volume rock void fraction and formation testing effect evaluation method | |
| CN109138986B (en) | Quantitative interpretation and evaluation method for gas content of rock in unit volume | |
| Breviere et al. | Gas Chromatography-Mass Spectrometry (Gcms)-A New Wellsite Tool For Continuous C1-C8 Gas Measurement In Drilling Mud-Including Original Gas Extractor And Gas Line Concepts. First Results And Potential | |
| US20230314646A1 (en) | Reservoir fluid mapping in mature fields | |
| CN115788418A (en) | Unconventional oil and gas reservoir fine evaluation method based on logging multi-parameter comprehensive analysis | |
| Goldsmith* et al. | Gas isotope analysis: A cost effective method to improve understanding of vertical drainage in the Delaware Basin | |
| CN107392505A (en) | Natural gas hydrate exploration develops well logging engineering comprehensive explanation evaluating method | |
| CN110792425B (en) | Method for measuring water content of formation fluid | |
| Weinheber et al. | Optimizing Hardware Options for Maximum Flexibility and Improved Success in Wireline Formation Testing, Sampling and Downhole Fluid Analysis Operations | |
| McCalmont et al. | Predicting pump-out volume and time based on sensitivity analysis for an efficient sampling operation: prejob modeling through a near-wellbore simulator | |
| Biscayart et al. | “Factory Mode” Development of Fortín de Piedra Block, Gas Window | |
| Tittlemier et al. | Integrated reservoir characterization aids target selection, production fluid prediction and completions optimization in the southern Delaware Basin resource plays | |
| Pavlov et al. | Oil fingerprinting technology for well and reservoir management | |
| Schlecht et al. | 1. Drilling & Production DNA diagnostics improve offshore reservoir analysis April 6, 2020 DNA diagnostics provide insights for production allocation, water flooding, zonal isolation, and well integrity. Sequencing the microbial DNA in rock from producing formations results in reservoir-specific mapping from produced water or oil samples. | |
| Ahsan et al. | Advanced Gas While Drilling GWD Comparison with Pressure Volume Temperature PVT Analysis to Obtain Information About the Reservoir Fluid Composition, a Case Study from East Kuwait Jurassic Reservoir |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |