WO2009084973A1 - Methods of forecasting and analysing gas-condensate flows into a well - Google Patents
Methods of forecasting and analysing gas-condensate flows into a well Download PDFInfo
- Publication number
- WO2009084973A1 WO2009084973A1 PCT/RU2007/000742 RU2007000742W WO2009084973A1 WO 2009084973 A1 WO2009084973 A1 WO 2009084973A1 RU 2007000742 W RU2007000742 W RU 2007000742W WO 2009084973 A1 WO2009084973 A1 WO 2009084973A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- flow
- fracture
- condensate
- gas
- production performance
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims abstract description 38
- 238000004519 manufacturing process Methods 0.000 claims abstract description 44
- 239000012530 fluid Substances 0.000 claims abstract description 22
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 7
- 239000011159 matrix material Substances 0.000 claims abstract description 6
- 239000000203 mixture Substances 0.000 claims abstract description 5
- 230000007704 transition Effects 0.000 claims abstract description 5
- 238000009795 derivation Methods 0.000 claims abstract description 4
- 230000008569 process Effects 0.000 claims description 10
- 230000003068 static effect Effects 0.000 claims description 6
- 238000012937 correction Methods 0.000 claims description 4
- 230000001186 cumulative effect Effects 0.000 claims description 2
- 239000000463 material Substances 0.000 claims description 2
- 230000037230 mobility Effects 0.000 claims description 2
- 230000035699 permeability Effects 0.000 claims description 2
- 238000004458 analytical method Methods 0.000 abstract description 9
- 238000007405 data analysis Methods 0.000 description 6
- 238000011156 evaluation Methods 0.000 description 3
- 238000005206 flow analysis Methods 0.000 description 3
- 238000005457 optimization Methods 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 238000004364 calculation method Methods 0.000 description 2
- 230000000638 stimulation Effects 0.000 description 2
- 238000009825 accumulation Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005111 flow chemistry technique Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 238000011282 treatment Methods 0.000 description 1
- 230000005514 two-phase flow Effects 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
Definitions
- This invention relates to methods for forecasting or analysing condensate production from a fractured formation.
- the invention relates to the effective use of multi-component models for forecasting and analysis.
- US 6,101 ,447, SPE 102111 , US 5,881 ,811 , and US 5,675,147 proposed separate components of a workflow for forecasting and evaluating the production performance for single phase flow and a 3D gas-condensate flow model for use in the vicinity of a vertically fractured well (including consideration of the fluid flow inside the fracture).
- the workflow includes a rigorous semi-analytic reservoir inflow performance model for various well types and completions, and reservoir outer boundary conditions, with using industry-accepted production performance analysis techniques.
- US 6,842,700, US 5,960,369, US 6,571 ,619, SPE 64774, SPE 94727, and SPE 29561 demonstrate the use of a number of methods for better well production optimization based on type curve methods, production performance history matching, and other analysis methods to reduce the non-uniqueness of the solution. These methods can be applied for the well production performance analysis of different types of reservoirs, such as in conventional and tight gas reservoirs, and even in situations in which there are incomplete pressure and flow rate history records available for use in the analysis. Each of these well performance analysis methods are directly applicable in single or two-phase flow (gas-water fracture flow inside a vertically fractured well).
- a first aspect of this invention provides a method of deriving gas-condensate flow into a wellbore via a vertical fracture, comprising deriving production performance data for the flow; - deriving a multi-component, gas-condensate fluid flow model for evaluating the inflow to a wellbore via a fracture; and
- the production performance data can be derived from measured and/or calculated input values.
- the method preferably comprises derivation of:
- the production performance data can include: bottomhole flowing and/or static pressures; reservoir pressure; geometry and dimensions of the fracture; size of the region and the grid system; PVT properties; phase permeabilities, conductivities and/or mobilities; and a description of the wellbore, its completion, and tubular components.
- One particularly preferred embodiment of the invention comprises forecasting the flow over a period of time.
- the method typically comprises:
- the parameters can be updated and steps (a)-(e) repeated until a predetermined precision is achieved.
- Another preferred embodiment of the invention comprises analysing the production performance of a wellbore.
- the method can include:
- Figure 1 shows a flowchart of a workflow for the forecast of a multi-component (gas-condensate) inflow to a wellbore via a fracture
- Figure 2 shows a flowchart of a workflow for a gas-condensate flow analysis in the vicinity of the fractured well (including the multiphase flow inside the fracture)
- Figure 3 shows a flowchart of a workflow for a production performance data analysis that is based on a multi-variable non-linear minimization of the production performance data with a multi-component (gas-condensate) fluid flow model for the inflow to a wellbore via a fracture.
- This invention provides a methodology and workflow for use in forecasting and production performance evaluation of gas-condensate inflow to a wellbore via a vertical fracture, which in turn can be used to maximize the efficiency of the reservoir production performance data analysis.
- This is achieved by the use of a workflow for forecasting the gas-condensate inflow to a well, as well as a workflow for production performance data analysis which is based on a multi-variable non-linear minimization of the production performance data with a multi-component (gas-condensate) fluid flow model for evaluating the inflow to a wellbore via a fracture.
- the results of the method of the invention can provide a more reliable and accurate production performance evaluation and well production performance forecast of gas-condensate reservoir systems, and also can result in an optimization of the candidate recognition process for identifying wells whose production performance can be improved using well stimulation treatments or well interventions operations.
- the technical result of the invention is the utilization of a workflow for improvement of the reservoir production performance data analysis process. This can provide the following benefits:
- Figure 1 shows a flowchart of a workflow for the forecast of a multi-component (gas-condensate) inflow to a wellbore via a fracture, in accordance with an embodiment of the invention.
- This process starts with the derivation of input data 10. These can be obtained from measurements made in the well in question, in offset wells, or from theoretical calculations.
- the input data are used to specify PVT (pressure, volume, temperature) values for the fluids in the well 12.
- the workflow operates on time increments, each cycle representing one increment 14. Following incrementing of the time interval, it is checked against the maximum for the forecast 16. If it is greater, i.e. the time period is complete 18, the workflow is used to generate an output, for example by generating a report 20. If it is less 22, values are computed 24 for losses in the flowstring (structures in the well through which the fluids flow) and flowing pressures at the assumed flow rates. If perforations and gravel pack completions are present, losses in these are likewise calculated. Finally, the sandface flowing pressure is calculated. The computed values are then input into a multi-component (gas condensate) model for flow into the wellbore via a fracture 26.
- a multi-component (gas condensate) model for flow into the wellbore via a fracture 26.
- the output of this model is compared with a target precision for the result 28. If the target is reached 30, the time interval is again incremented 14 and the process iterated for the next time interval. If not 32, the various parameters are updated for better convergence and precision and the computation 24 and model 26 steps are iterated until the desired precision is achieved.
- Figure 2 shows a flowchart of the workflow for a gas-condensate flow analysis in the vicinity of the fractured well (including multiphase flow inside the fracture).
- the input data 40 are first subjected to a preliminary flow calculation 42, the output of which is provided to a flow model for implicit matrix properties 44. These are then applied to a series of explicit steps according to the fracture of interest 46. The output is again tested against a target precision 48. if this is not met 50, the process is iterated 52 through the implicit matrix 44 and explicit fracture 46 steps. If the target precision is achieved 54, an output can be generated, such as a written report 60.
- Figure 3 shows a flowchart of a workflow for a production performance data analysis that is based on a multi-variable non-linear minimization of the production performance data with a multi-component (gas-condensate) fluid flow model for the inflow to a wellbore via a fracture.
- the first step 72 is input/correction of parameters for control and regularisation of the minimisation process, precision, etc.
- the parameters are then applied to the multi-variable non- linear minimization of the production performance data with a multi-component (gas- condensate) fluid flow model for the inflow to a wellbore via a fracture 74.
- the output of the minimisation process is tests for precision against a desired target 76. If this level is not reached 78, the steps for input and correction of parameters 72, and application to the model 76 are repeated 80 until it does.
- an output is generated, for example as a written report 84.
- Multi-component two-phase mixture with phase transitions and with the phase transition aspect separated from the hydrodynamic aspect; 2D geometry of the fracture with any shape;
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)
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
Abstract
This invention relates to methods for forecasting or analysing condensate production from a fractured formation. In particular, the invention relates to the effective use of multi-component models for forecasting and analysis. A method of deriving gas-condensate flow into a wellbore via a vertical fracture, comprises deriving production performance data for the flow; deriving a multi-component, gas- condensate fluid flow model for evaluating the inflow to a wellbore via a fracture; and performing a multi-variable non-linear minimization of the production performance data with the flow model so as to derive the gas-condensate flow into the wellbore, wherein the production performance data are derived from measured and/or calculated input values with derivation of multi-component two-phase mixtures with phase transition and hydrodynamic considerations taken together and separately; 2D geometry of the fracture for any shape; 2D fluid flow inside the fracture; and 3D fluid flow in the formation matrix.
Description
METHODS OF FORECASTING AND ANALYSING GAS-CONDENSATE FLOWS
INTO A WELL Technical field
This invention relates to methods for forecasting or analysing condensate production from a fractured formation. In particular, the invention relates to the effective use of multi-component models for forecasting and analysis. Background art
It is well known that there are many gas-condensate reservoirs in the world. Maximizing the efficiency of the gas-condensate reservoir production is a very important issue in developing and producing these reservoirs. The pressure and flow rate behaviour of such a reservoir is often dramatically different from the pressure and flow rate behaviour of a conventional two-phase gas or oil reservoir. A number of published papers have documented the specific production and inflow behaviour of gas-condensate mixtures into wells. The condensate system specific production characteristics may include condensate bank accumulation due to condensate dropout, stripping and non-Darcy flow effects which cannot generally or adequately be described using conventional "black oil" reservoir analysis techniques. In the case of a gas condensate reservoir, a multi-component multiphase fluid flow analysis and methodology are necessary to correctly predict the production performance of a hydraulically-fractured well in a gas-condensate formation.
US 6,101 ,447, SPE 102111 , US 5,881 ,811 , and US 5,675,147 proposed separate components of a workflow for forecasting and evaluating the production
performance for single phase flow and a 3D gas-condensate flow model for use in the vicinity of a vertically fractured well (including consideration of the fluid flow inside the fracture). The workflow includes a rigorous semi-analytic reservoir inflow performance model for various well types and completions, and reservoir outer boundary conditions, with using industry-accepted production performance analysis techniques.
US 6,842,700, US 5,960,369, US 6,571 ,619, SPE 64774, SPE 94727, and SPE 29561 demonstrate the use of a number of methods for better well production optimization based on type curve methods, production performance history matching, and other analysis methods to reduce the non-uniqueness of the solution. These methods can be applied for the well production performance analysis of different types of reservoirs, such as in conventional and tight gas reservoirs, and even in situations in which there are incomplete pressure and flow rate history records available for use in the analysis. Each of these well performance analysis methods are directly applicable in single or two-phase flow (gas-water fracture flow inside a vertically fractured well).
It is an object of the invention to provide an improved methodology that is applicable to gas-condensate systems. Disclosure of the invention
A first aspect of this invention provides a method of deriving gas-condensate flow into a wellbore via a vertical fracture, comprising deriving production performance data for the flow; - deriving a multi-component, gas-condensate fluid flow model for evaluating the inflow
to a wellbore via a fracture; and
- performing a multi-variable non-linear minimization of the production performance data with the flow model so as to derive the gas-condensate flow into the wellbore.
The production performance data can be derived from measured and/or calculated input values.
The method preferably comprises derivation of:
- multi-component two-phase mixtures with phase transition and hydrodynamic considerations taken together and separately;
2D geometry of the fracture for any shape; 2D fluid flow inside the fracture; and
- 3D fluid flow in the formation matrix.
The production performance data can include: bottomhole flowing and/or static pressures; reservoir pressure; geometry and dimensions of the fracture; size of the region and the grid system; PVT properties; phase permeabilities, conductivities and/or mobilities; and a description of the wellbore, its completion, and tubular components.
One particularly preferred embodiment of the invention comprises forecasting the flow over a period of time. In this case, the method typically comprises:
(a) computation of flowstring pressure losses and corresponding bottomhole flowing or static pressures for assumed flow rates;
(b) computation of perforation and gravel pack completion losses, where necessary;
(c) computation of sandface flowing and/or static pressures;
(d) computation of reservoir performance based on the fluid flow mode; and
(e) computation of the cumulative well production and solution of the system phase material balances at appropriate levels of precision.
The parameters can be updated and steps (a)-(e) repeated until a predetermined precision is achieved.
Another preferred embodiment of the invention comprises analysing the production performance of a wellbore. In this case, the method can include:
(a) input or correction of control parameter: regularization parameters, and precision of the minimization process;
(b) multi-variable non-linear minimization of production data with the flow mode; and
(c) iteration of steps (a) and (b) until a predetermined precision is achieved.
Further aspects of the invention will be apparent from the following description. Brief description of the drawings
Figure 1 shows a flowchart of a workflow for the forecast of a multi-component (gas-condensate) inflow to a wellbore via a fracture; Figure 2 shows a flowchart of a workflow for a gas-condensate flow analysis in the vicinity of the fractured well (including the multiphase flow inside the fracture); and Figure 3 shows a flowchart of a workflow for a production performance data analysis that is based on a multi-variable non-linear minimization of the production performance data with a multi-component (gas-condensate) fluid flow model for the inflow to a wellbore via a fracture.
Mode(s) for carrying out the invention
This invention provides a methodology and workflow for use in forecasting and production performance evaluation of gas-condensate inflow to a wellbore via a vertical fracture, which in turn can be used to maximize the efficiency of the reservoir production performance data analysis. This is achieved by the use of a workflow for forecasting the gas-condensate inflow to a well, as well as a workflow for production performance data analysis which is based on a multi-variable non-linear minimization of the production performance data with a multi-component (gas-condensate) fluid flow model for evaluating the inflow to a wellbore via a fracture. The results of the method of the invention can provide a more reliable and accurate production performance evaluation and well production performance forecast of gas-condensate reservoir systems, and also can result in an optimization of the candidate recognition process for identifying wells whose production performance can be improved using well stimulation treatments or well interventions operations.
The technical result of the invention is the utilization of a workflow for improvement of the reservoir production performance data analysis process. This can provide the following benefits:
1) a fast method of analysis for 3D gas-condensate flow in the vicinity of the fractured well (including the flow inside the fracture);
2) a workflow for the forecast of a multi-component (gas-condensate) inflow to a wellbore via a fracture;
3) a workflow for production performance data analysis based on multi-variable non-
linear minimization of the production performance data with a multi-component (gas- condensate) fluid flow model for evaluating the inflow to a wellbore via a fracture.
These advantages result in a more reliable and accurate production evaluation and forecast of the performance of a gas-condensate system well, as well as the optimization of a candidate recognition process for identifying wells whose productivity could be improved by well stimulation techniques or other wellbore intervention operations.
Figure 1 shows a flowchart of a workflow for the forecast of a multi-component (gas-condensate) inflow to a wellbore via a fracture, in accordance with an embodiment of the invention. This process starts with the derivation of input data 10. These can be obtained from measurements made in the well in question, in offset wells, or from theoretical calculations. The input data are used to specify PVT (pressure, volume, temperature) values for the fluids in the well 12.
As the workflow is to forecast flow over a period of time, the workflow operates on time increments, each cycle representing one increment 14. Following incrementing of the time interval, it is checked against the maximum for the forecast 16. If it is greater, i.e. the time period is complete 18, the workflow is used to generate an output, for example by generating a report 20. If it is less 22, values are computed 24 for losses in the flowstring (structures in the well through which the fluids flow) and flowing pressures at the assumed flow rates. If perforations and gravel pack completions are present, losses in these are likewise calculated. Finally, the sandface flowing pressure is calculated.
The computed values are then input into a multi-component (gas condensate) model for flow into the wellbore via a fracture 26. The output of this model is compared with a target precision for the result 28. If the target is reached 30, the time interval is again incremented 14 and the process iterated for the next time interval. If not 32, the various parameters are updated for better convergence and precision and the computation 24 and model 26 steps are iterated until the desired precision is achieved.
In this way, the flow can be forecast (predicted).
Figure 2 shows a flowchart of the workflow for a gas-condensate flow analysis in the vicinity of the fractured well (including multiphase flow inside the fracture). In this case, the input data 40 are first subjected to a preliminary flow calculation 42, the output of which is provided to a flow model for implicit matrix properties 44. These are then applied to a series of explicit steps according to the fracture of interest 46. The output is again tested against a target precision 48. if this is not met 50, the process is iterated 52 through the implicit matrix 44 and explicit fracture 46 steps. If the target precision is achieved 54, an output can be generated, such as a written report 60.
Figure 3 shows a flowchart of a workflow for a production performance data analysis that is based on a multi-variable non-linear minimization of the production performance data with a multi-component (gas-condensate) fluid flow model for the inflow to a wellbore via a fracture. Starting again with input data 70, the first step 72 is input/correction of parameters for control and regularisation of the minimisation process, precision, etc. The parameters are then applied to the multi-variable non-
linear minimization of the production performance data with a multi-component (gas- condensate) fluid flow model for the inflow to a wellbore via a fracture 74. The output of the minimisation process is tests for precision against a desired target 76. If this level is not reached 78, the steps for input and correction of parameters 72, and application to the model 76 are repeated 80 until it does. When the desired precision is achieved 82, an output is generated, for example as a written report 84.
The basic features of the method/workflow according to the invention include the following components:
Multi-component two-phase mixture with phase transitions, and with the phase transition aspect separated from the hydrodynamic aspect; 2D geometry of the fracture with any shape;
2D fluid flow inside the fracture; and
3D fluid flow in the formation matrix.
Further variations within the scope of the invention will be apparent.
Claims
1. A method of deriving gas-condensate flow into a wellbore via a vertical fracture, comprising deriving production performance data for the flow;
- deriving a multi-component, gas-condensate fluid flow model for evaluating the inflow to a wellbore via a fracture; and
- performing a multi-variable non-linear minimization of the production performance data with the flow model so as to derive the gas-condensate flow into the wellbore.
2. A method as claimed in claim 1 , wherein the production performance data are derived from measured and/or calculated input values.
3. A method as claimed in claim 2, comprising derivation of:
- multi-component two-phase mixtures with phase transition and hydrodynamic considerations taken together and separately;
2D geometry of the fracture for any shape; 2D fluid flow inside the fracture; and
- 3D fluid flow in the formation matrix.
4. A method as claimed in claim 2 or 3, wherein the production performance data include: bottomhole flowing and/or static pressures; reservoir pressure; geometry and dimensions of the fracture; size of the region and the grid system; PVT properties; phase permeabilities, conductivities and/or mobilities; and a description of the wellbore, its completion, and tubular components.
5. A method as claimed in any preceding claim, comprising forecasting the flow over a period of time.
6. A method as claimed in claim 5, comprising:
(a) computation of flowstring pressure losses and corresponding bottomhole flowing or static pressures for assumed flow rates;
(b) computation of perforation and gravel pack completion losses, where necessary;
(c) computation of sandface flowing and/or static pressures;
(d) computation of reservoir performance based on the fluid flow mode; and
(e) computation of the cumulative well production and solution of the system phase material balances at appropriate levels of precision.
7. A method as claimed in claim 6, comprising updating parameters and repeating steps (a)-(e) until a predetermined precision is achieved.
8. A method as claimed in any of claims 1-4, comprising analysing the production performance of a wellbore.
9. A method as claimed in claim 7, comprising:
(a) input or correction of control parameter: regularization parameters, and precision of the minimization process;
(b) multi-variable non-linear minimization of production data with the flow mode; and
(c) iteration of steps (a) and (b) until a predetermined precision is achieved.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| PCT/RU2007/000742 WO2009084973A1 (en) | 2007-12-27 | 2007-12-27 | Methods of forecasting and analysing gas-condensate flows into a well |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| PCT/RU2007/000742 WO2009084973A1 (en) | 2007-12-27 | 2007-12-27 | Methods of forecasting and analysing gas-condensate flows into a well |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| WO2009084973A1 true WO2009084973A1 (en) | 2009-07-09 |
Family
ID=40824534
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| PCT/RU2007/000742 WO2009084973A1 (en) | 2007-12-27 | 2007-12-27 | Methods of forecasting and analysing gas-condensate flows into a well |
Country Status (1)
| Country | Link |
|---|---|
| WO (1) | WO2009084973A1 (en) |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106837310A (en) * | 2016-12-15 | 2017-06-13 | 中法渤海地质服务有限公司 | Oil well kick leakage forecasting procedure and device based on mass flow comprehensive detection |
| US9689245B2 (en) | 2014-01-24 | 2017-06-27 | King Fahd University Of Petroleum And Minerals | Quantification of skin in hydraulic fracturing of low and tight reservoirs |
| CN113931621A (en) * | 2020-07-14 | 2022-01-14 | 中国石油天然气股份有限公司 | Method and device for determining gas well accumulated liquid information and storage medium |
Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US6101447A (en) * | 1998-02-12 | 2000-08-08 | Schlumberger Technology Corporation | Oil and gas reservoir production analysis apparatus and method |
| RU2274747C2 (en) * | 2000-10-04 | 2006-04-20 | Шлюмбергер Текнолоджи Б.В. | Optimization method for oil production from multilayer compound beds with the use of dynamics of oil recovery from compound beds and geophysical production well investigation data |
-
2007
- 2007-12-27 WO PCT/RU2007/000742 patent/WO2009084973A1/en active Application Filing
Patent Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US6101447A (en) * | 1998-02-12 | 2000-08-08 | Schlumberger Technology Corporation | Oil and gas reservoir production analysis apparatus and method |
| RU2274747C2 (en) * | 2000-10-04 | 2006-04-20 | Шлюмбергер Текнолоджи Б.В. | Optimization method for oil production from multilayer compound beds with the use of dynamics of oil recovery from compound beds and geophysical production well investigation data |
Cited By (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US9689245B2 (en) | 2014-01-24 | 2017-06-27 | King Fahd University Of Petroleum And Minerals | Quantification of skin in hydraulic fracturing of low and tight reservoirs |
| US10294759B2 (en) | 2014-01-24 | 2019-05-21 | King Fahd University Of Petroleum And Minerals | Method and system for hydraulic fracturing based on skin factor analysis |
| CN106837310A (en) * | 2016-12-15 | 2017-06-13 | 中法渤海地质服务有限公司 | Oil well kick leakage forecasting procedure and device based on mass flow comprehensive detection |
| CN106837310B (en) * | 2016-12-15 | 2020-07-07 | 中法渤海地质服务有限公司 | Petroleum well kick and leakage forecasting method and device based on mass flow comprehensive detection |
| CN113931621A (en) * | 2020-07-14 | 2022-01-14 | 中国石油天然气股份有限公司 | Method and device for determining gas well accumulated liquid information and storage medium |
| CN113931621B (en) * | 2020-07-14 | 2023-08-22 | 中国石油天然气股份有限公司 | Method, device and storage medium for determining gas well hydrops information |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| EP2038809B1 (en) | Method for comparing and back allocating production | |
| US10997518B2 (en) | Method for predicting oil and gas reservoir production | |
| EP1982046B1 (en) | Methods, systems, and computer-readable media for real-time oil and gas field production optimization using a proxy simulator | |
| EP1984860B1 (en) | Methods, systems, and computer-readable media for fast updating of oil and gas field production models with physical and proxy simulators | |
| CA2665122A1 (en) | System and method for performing oilfield simulation operations | |
| CA3100391C (en) | Well operations involving synthetic fracture injection test | |
| NO344286B1 (en) | Well modeling related to the extraction of hydrocarbons from subterranean formations | |
| Hong et al. | Robust production optimization with capacitance-resistance model as precursor | |
| US20230059014A1 (en) | Reduced physics well production monitoring | |
| Molinari et al. | A Reduced Physics Modeling Approach to Understand Multiphase Well Production Performance for Unconventional Reservoirs | |
| US10922454B2 (en) | Method and apparatus for fast economic analysis of production of fracture-stimulated wells | |
| WO2009084973A1 (en) | Methods of forecasting and analysing gas-condensate flows into a well | |
| US11767750B1 (en) | Gas-oil ratio forecasting in unconventional reservoirs | |
| US11501043B2 (en) | Graph network fluid flow modeling | |
| US11933165B2 (en) | Hydraulic fracture conductivity modeling | |
| Jamalbayov et al. | New waterflooding efficiency evaluation method (on the example of 9th horizon of the Guneshli field) | |
| Fattah et al. | New inflow performance relationship for solution-gas drive oil reservoirs | |
| RU2768341C1 (en) | Well production rate prediction method taking into account anisotropy of permeability of carbonate rocks | |
| Tokita et al. | Development of the MULFEWS multi-feed wellbore simulator | |
| Carpenter | Method Integrates Pressure-Transient and Fracture Area To Detect Well Interference | |
| Carpenter | Automated Work Flow for Sand Prediction, Monitoring Improves Operational Efficiency | |
| Chen et al. | A New GOR Forecasting Methodology for Unconventional Reservoirs | |
| Aceros et al. | A First Principles Model for Virtually Sensing Operational Parameters in an ESP Well | |
| Thenon et al. | Multi-Fidelity Proxy Models for Reservoir Engineering | |
| RU2149992C1 (en) | Method of prognostication of efficiency of geological and engineering measures in carbonate reservoirs |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| ENP | Entry into the national phase |
Ref document number: 2008137457 Country of ref document: RU Kind code of ref document: A |
|
| 121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 07873385 Country of ref document: EP Kind code of ref document: A1 |
|
| NENP | Non-entry into the national phase |
Ref country code: DE |
|
| 122 | Ep: pct application non-entry in european phase |
Ref document number: 07873385 Country of ref document: EP Kind code of ref document: A1 |