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Collaborating Authors
RIPED, PetroChina
Assessment of Different Field Development Strategies Deploying Maximum Reservoir Contacting (MRC) Well in Carbonate Reservoir: A case study of Oilfield R
Jia, Han (RIPED, PetroChina) | Tong, Min (Artificial Intelligence Technology R&D Center for Exploration and Development, CNPC) | Peng, Hui (RIPED, PetroChina) | Deng, Xili (Artificial Intelligence Technology R&D Center for Exploration and Development, CNPC) | Song, Ruixuan (RIPED, PetroChina) | Wang, Rui (Artificial Intelligence Technology R&D Center for Exploration and Development, CNPC)
Abstract Deploying horizontal well is one of the efficient methods to enhanced oil recovery. Maximum Reservoir Contact (MRC) well, based on the horizontal well, which indicates the contacting area of wellbore and reservoir should be as large as possible to obtain the optimum exploration effects. The purpose of this paper is to build an assessment and optimization work-flow, which guides the well pattern improvement and well-type selection via a case study of the filed R in a Middle East Carbonate Reservoir. Analyzing several field development index, like production performance, gas oil ratio, water cut, pressure, etc. in a pilot-scale well pattern both for the conventional horizontal wells and MRC wells using different injection schemes, including injection timing, injection volume, and injection components, via reservoir numerical simulation. The method using to evaluating reservoir exploration effect in this paper is numerical simulation, assuming different development strategies and well-type, via reservoir numerical simulator. Control-variate method as well as used in this study, which focus on keeping single factor analysis for the simulation. Comparing all the field development indexes among different cases while keeping other factors consistent, for example, exploring the influence from well types, which are MRC well and conventional horizontal well, two cases must be deployed the same injection schemes. Simulating different cases with analyzing the results, MRC wells obtain the better oil production generally compared with conventional horizontal wells. However, oil production performance is not the only index which is cared for in oil & gas industry, additionally, in terms of reservoir engineering, water cut, water breakthrough, gas breakthrough, gas oil ratio, oil steady production plateau, etc., while some economic indexes are extremely concerned by the experts and companies. Consequently, assessment of MRC wells effect should consider many factors from the perspective of oil & gas industry. Well trajectories adjusting with target layer or reservoir is also the MRC technique, optimization of well trajectories profits the production performance both for MRC wells and conventional horizontal wells.
Fracture Characterisation Methods and Application of Unconventional Oil and Gas Reservoirs in Reservoir Numerical Simulation
Li, Qiaoyun (RIPED, PetroChina) | Wu, Shuhong (Artificial Intelligence Technology R&D Center for Exploration and Development, CNPC) | Cao, Zijian (RIPED, PetroChina) | Wang, Baohua (Artificial Intelligence Technology R&D Center for Exploration and Development, CNPC) | Li, Hua (RIPED, PetroChina) | Jia, Han (Artificial Intelligence Technology R&D Center for Exploration and Development, CNPC)
Abstract It's necessary to solve the problem of fine characterization and efficient simulation of three types of fractures, i.e. natural fractures, artificial fractures and complex fracture network, for the development optimization design and scheme adjustment of unconventional oil and gas reservoirs. This paper describes a set of efficient and practical fracture characterization techniques for reservoir numerical model, which integrates various numerical simulation methods of fractures in different scales, including single-medium equivalent model, LGR model, double-medium model, MINC model, non-structural discrete fracture model and embedded discrete fracture model. For different reservoir types and different fracture dimensions, different models are adopted to depict the spatial distribution and fluid flow characteristics of fracture-matrix, matrix-matrix and fracture-fracture. The application in a shale gas shows that the set of fracture characterization methods can accurately describe the shape, geometric characteristics and spatial position of natural fractures, artificial fractures and fracture network. The methods also can simulate the fluid flow characteristics in multi-scale fracture network efficiently, and accurately predict the productivity of fracture network.
- Geology > Geological Subdiscipline > Geomechanics (0.89)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.37)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Faults and fracture characterization (1.00)
Geobody-oriented interpretable velocity fusion modeling in depth domain with seismic facies informed segmentation method
Li, Meng (RIPED, PetroChina) | Zeng, Qingcai (RIPED, PetroChina) | Shou, Hao (RIPED, PetroChina) | Qin, Nan (RIPED, PetroChina) | Wang, Chunming (RIPED, PetroChina) | Zeng, Tongsheng (RIPED, PetroChina)
Full-layer high-resolution velocity modeling in depth domain is essential for imaging deep complex oil and gas reservoirs in China. However, limited by economic cost, especially in land exploration areas, seismic survey usually uses big observation grid and short offset distance, resulting in insufficient illumination to the subsurface. Therefore, it is difficult to reveal velocity structures with small scale, large buried depth or hidden characteristics by conventional wavefield inversion methods. With geobody identification as the core theory and velocity fusion as the tool, this paper proposes a geobody-oriented velocity modeling framework on the attribute side to realize full-layer high-resolution velocity modeling in depth domain. Using the combined method of chaotic fixed-point classifier and K-means clustering, all geobodies in the entire strata from the surface to the subsurface are simultaneously identified and then classified as different geological labels. The separated geobodies are independent of each other and can be easily manipulated individually, which makes it possible to interpret the velocity values on each of geobodies so that velocity fusion processing becomes more flexible and interpretable. Taking the data of Sichuan basin in China as an example, three strategies illustrate how to use geobody-oriented velocity fusion to improve modeling resolution. These examples also demonstrate that integrating geophysical data into geology will effectively improve the reliability of the depth-domain velocity model.
- Geology > Geological Subdiscipline (0.74)
- Geology > Rock Type (0.49)
- Asia > China > Sichuan > Sichuan Basin (0.99)
- North America > United States > Louisiana > China Field (0.98)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic modeling (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
Horizontal Well Path Design with Seismic Inversion for a Shale Oil Reservoir in the Ordos Basin, China
Xinhai, Hu (Research Institute of Petroleum Exploration and Development) | Minghui, Lu (PetroChina Exploration and Development Research Institute) | Hong, Cao (Research Institute of Petroleum Exploration and Development) | Zhifang, Yang (RIPED, PetroChina) | Jianyong, Song (Research Institute of Petroleum Exploration and Development)
The shale oil reservoir of Chang 7 member, Yanchang Formation in Ordos basin has shown great potential. They are highly heterogeneous and relatively thin sand body interbedded with mudstone and siltstone. This proposes the demand for accurate and high-resolution inversion data. We propose a workflow to plan the horizontal well path with seismic interpretation. Basic interpretation is conducted, which included well tie, horizon interpretation, and fault interpretation. A time-to-depth conversion workflow based on full waveform inversion, is proposed to gain the precise seismic and inversion data. The velocity model of FWI shows more high wavenumber variations that reflect thin and localized geological features than that of conventional migration velocity analysis. The geological statistical inversion is applied to get the high-resolution reservoir models for the thin layers beyond the seismic resolution. A comprehensive index is computed with the inverted parameters to reflect the quality of reservoir and identify the sweet-spots. We define the coordinates, direction and length of horizontal section on the sweet-spot maps. After that, the sections of seismic and inversion data along the paths are extracted to define the depth of the paths. In the study, the optimal paths are close to the centerline of target oil sand layers. The effectiveness of the workflow was verified by the application practice in Qingcheng oil field, Ordos Basin.
- Asia > China > Gansu Province (1.00)
- Asia > China > Shanxi Province (0.91)
- Asia > China > Shaanxi Province (0.91)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.72)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling > Seismic Inversion (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Ellerslie Formation (0.99)
- Asia > China > Shanxi > Ordos Basin > Changqing Field (0.99)
- (7 more...)
Main Controlling Factors of Water Invasion for Kela 2 Gas Field
Liu, Zhaolong (RIPED, PetroChina) | Zhang, Yongzhong (RIPED, PetroChina)
Abstract As one of the largest discovered gas fields in China, Kela 2 gas field has proven geological reserves of more than 200 billion cubic meters, with a maximum annual gas production of approximately 12 billion cubic meters. After 18 years development, Kela 2 gas field is now in the middle-late development period. At present, the gas field has experienced many development challenges, among which early water flooding and inhomogeneous water invasion are the main reasons for the production decline in Kela 2 gas field. Based on the abundant geological and performance data, a fine 3D geological modeling is built to accurately describe the structure, matrix properties and fracture in Kela 2 gas field, and then analyzes the characteristics and causes of water invasion. The research shows that faults, fractures, high permeability zone and interlayer are the main controlling factors of water invasion in Kela 2 gas field. And the water invasion can be divided into three patterns, (a) Vertical channeling-lateral invasion, (b) Edge water lateral invasion, (c) Bottom water coning. On the basis of water invasion study, development countermeasures are put forward to provide support for long-term stable production and efficient development of Kela 2 gas field.
- Geology > Structural Geology (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.30)
- Asia > China > Xinjiang Uyghur Autonomous Region > Tarim Basin > Kela-2 Field (0.99)
- North America > United States > Louisiana > China Field (0.97)
Research and Application of Big Data Production Measurement Method for SRP Wells Based on Electrical Parameters
Chen, Shiwen (RIPED, PetroChina) | Deng, Feng (RIPED, PetroChina) | Chen, Guanhong (RIPED, PetroChina) | Zhao, Ruidong (RIPED, PetroChina) | Shi, Junfeng (RIPED, PetroChina) | Jiang, Weidong (RIPED, PetroChina)
Abstract Well metering is an important part of daily oilfield management. For wells in a block, production metering can help reservoir managers fully understand the changes in the reservoir and provide a basis for reservoir dynamics analysis and scientific field development planning. For single-well metering, accurate producing rate can help oil well operators optimize the well production system, improve the efficiency of oil wells, and even discover abnormal conditions in oil wells based on changes in production. In order to obtain accurate well production, over 300 SRP wells in an experimental area of an oil field in northeastern China are tracked and measured in this paper. Easily available continuous electrical parameter data (including electrical power, current and voltage) and real-time output of the wells were selected as training parameters. We separated the SRP well electrical curves and corresponding real-time production data into a set of samples by one-stroke time, and obtained a total of 200,000 valid samples. The production status of the pumping wells was classified by deep learning, and the electric curves were Fourier transformed to extract statistical features. Then, we performed deep learning on these samples, using production parameters as input vectors and well fluid production as output results. Finally, good results were obtained by training and a model for calculating SRP well production based on big data was developed. The model was used to calculate the production of SRP wells in an experimental area of an oil field in northeastern China and compared with the actual production data. For low-producing wells with daily production less than 6 m3, the error of the model was less than 0.5 m3 /d, and for wells with daily production greater than 6 m3, the relative error of the wells was less than 10%, which met the expectation of managers. Compared with the methods mentioned in this paper, the currently used measurement methods, such as flowmeter measurement and volumetric measurement, have limitations in terms of instrumental measurement range and real-time measurement, respectively. In addition, both of these methods increase the construction cost of flow measurement systems. The big data production measurement model provides operators with a method for optimizing the production system of oil wells and also provides signals for early warning of oil well failures. This method can help managers achieve cost reduction and efficiency increase. The processing and application methods of electrical parameters in this paper can also provide ideas for production prediction of PCP o ESP wells.
Research and Application of Big Data Production Measurement Method for SRP Wells Based on Electrical Parameters
Chen, Shiwen (RIPED, PetroChina) | Deng, Feng (RIPED, PetroChina) | Chen, Guanhong (RIPED, PetroChina) | Zhao, Ruidong (RIPED, PetroChina) | Shi, Junfeng (RIPED, PetroChina) | Jiang, Weidong (RIPED, PetroChina)
Abstract Well metering is an important part of daily oilfield management. For wells in a block, production metering can help reservoir managers fully understand the changes in the reservoir and provide a basis for reservoir dynamics analysis and scientific field development planning. For single-well metering, accurate producing rate can help oil well operators optimize the well production system, improve the efficiency of oil wells, and even discover abnormal conditions in oil wells based on changes in production. In order to obtain accurate well production, over 300 SRP wells in an experimental area of an oil field in northeastern China are tracked and measured in this paper. Easily available continuous electrical parameter data (including electrical power, current and voltage) and real-time output of the wells were selected as training parameters. We separated the SRP well electrical curves and corresponding real-time production data into a set of samples by one-stroke time, and obtained a total of 200,000 valid samples. The production status of the pumping wells was classified by deep learning, and the electric curves were Fourier transformed to extract statistical features. Then, we performed deep learning on these samples, using production parameters as input vectors and well fluid production as output results. Finally, good results were obtained by training and a model for calculating SRP well production based on big data was developed. The model was used to calculate the production of SRP wells in an experimental area of an oil field in northeastern China and compared with the actual production data. For low-producing wells with daily production less than 6 m3, the error of the model was less than 0.5 m3 /d, and for wells with daily production greater than 6 m3, the relative error of the wells was less than 10%, which met the expectation of managers. Compared with the methods mentioned in this paper, the currently used measurement methods, such as flowmeter measurement and volumetric measurement, have limitations in terms of instrumental measurement range and real-time measurement, respectively. In addition, both of these methods increase the construction cost of flow measurement systems. The big data production measurement model provides operators with a method for optimizing the production system of oil wells and also provides signals for early warning of oil well failures. This method can help managers achieve cost reduction and efficiency increase. The processing and application methods of electrical parameters in this paper can also provide ideas for production prediction of PCP o ESP wells.
CCUS Numerical Simulation Technology and its Application in a Carbonate Reservoir of the Middle East
Li, Qiaoyun (China University of Petroleum Beijing) | Wu, Shuhong (RIPED, PetroChina) | Jia, Han (RIPED, PetroChina) | Wang, Baohua (RIPED, PetroChina) | Deng, Xili (RIPED, PetroChina) | Li, Hua (RIPED, PetroChina) | Fan, Tianyi (RIPED, PetroChina) | Xu, Mingyuan (RIPED, PetroChina)
Abstract Carbon dioxide Utilization and storage technology (CCUS) plays an important role for oil and gas field to further improve oil and gas recovery and achieve the goal of "double carbon" in recent years. Numerical simulation is an essential means for reservoir engineers to study the flow mechanism of CO2 flooding and storage, screen the CCUS technical indicators, predict the enhanced oil recovery and evaluate storage potential. This paper discusses the multiphase and multicomponent mathematical model based on the seepage theory of carbon dioxide flooding and storage, the calculation method of gas-liquid equilibrium based on EOS equation, the miscibility determination technique and two phase P-T flash calculation method. Meanwhile the CCUS numerical simulator developed based on above theoretical model and calculation method. Applying the simulator to CO2 miscible flooding in a carbonate reservoir of the Middle East, the results show that the model and software accurately describes the CO2-EOR seepage mechanism and CO2 miscible displacement process. It effectively predicts the effect of CO2 injection on EOR and the storage potential after CO2 flooding. It can provide feasible technical guidance for the optimization of CO2 utilization and storage programs.
- Asia > Middle East (0.85)
- Europe > Middle East (0.61)
- Africa > Middle East (0.61)
- Research Report > New Finding (0.34)
- Research Report > Experimental Study (0.34)
A Case Study of Miscible CO2 Flooding in a Giant Middle East Carbonate Reservoir
Wu, Shuhong (RIPED, PetroChina) | Fan, Tianyi (RIPED, PetroChina) | Zhao, Lisha (RIPED, PetroChina) | Peng, Hui (RIPED, PetroChina) | Tong, Min (RIPED, PetroChina) | Wang, Ke (RIPED, PetroChina) | Wang, Cong (RIPED, PetroChina)
Abstract Miscible CO2 flooding is a proven field development technology, which has been widely applied to many fields to enhance the oil recovery. It can efficiently expand oil volume, reduce oil viscosity and eliminate oil-gas interfacial tension. In this paper, a case study is detailed on CO2 flooding in a giant low-permeability (2-5md) and low-viscosity (0.3mpa.s) carbonate oil reservoir in Middle East, which has been extensively developed since 1990's with natural depletion, water flooding, and hydrocarbon gas (HC) flooding as well as HCWAG. The demand for further enhancing oil recovery and reducing greenhouse gas emission requires to assess the potential of CO2-EOR flooding. In this paper, production history is firstly reviewed as well as the CO2 pilot test, including production performance, gas/water injection profile and remaining oil distribution in a five-point high-angle horizontal well pattern. MMP of hydrocarbon gas and CO2 is compared in the carbonate reservoir with the miscibility with oil, miscible area, residue oil and also, the gas intake profile as well as gas breakthrough. The density difference between gas/CO2 and oil results in a gravity override, gas/CO2 channeling, and early breakthrough and poor vertical conformance problems. Therefore, CO2-alter-Water injection with optimized WAG cycle as well as tapered WAG are detailed to improve production performance and increase the oil recovery, which is considered as a potential way with high swept efficiency of water flooding (70-80%) in a low-viscosity and high displacement efficiency of CO2 miscible flooding (85-90%). The discussions of simulation schemes in this study can be applied to determine the optimal strategy for the future development of this large carbonate reservoir in the Middle East.
- North America > United States (0.29)
- Europe > Middle East (0.24)
- Asia > Middle East (0.24)
- Africa > Middle East (0.24)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation (0.99)
- North America > United States > Montana > Williston Basin > Bakken Shale Formation (0.99)
- North America > Canada (0.89)
A Scalable Parallel In-Situ Combustion Reservoir Simulator for Large Scale Models
He, Ruijian (University of Calgary) | Wu, Shuhong (RIPED, PetroChina) | Chen, Zhangxin (University of Calgary) | Yang, Bo (University of Calgary) | Liu, Hui (University of Calgary) | Shen, Lihua (University of Calgary)
Abstract As a competitive recovery method for heavy oil, In-Situ Combustion (ISC) shows its great potential accompanied by technological advances in recent years. Reservoir simulation plays an indispensable role in the prediction of the implementation of ISC projects. With the computational complexity, it is imperative to develop an effective and robust parallel in-situ combustion simulator. In this paper, a mathematical model for ISC is proposed, which takes full consideration of ISC related physical phenomena, including multi-dimensional multi-component three-phase flow, heat convection and conduction, chemical reactions, and mass transfer between phases. In the mathematical model, different governing equations and constraints are involved, forming a complicated PDE (partial differential equation) system. For physical and chemical behaviors, some special treatments for the ISC simulator are discussed and applied. Also, a modified PER (Pseudo-Equilibrium Ratio) method is proposed in this paper. A fully implicit scheme is applied, and discretization is implemented with the FDM(Finite DifferenceMethod). In solving nonlinear systems, the Newton Method is introduced, and both numerical and analytical Jacobian matrices are applied. Due to the complexity of an ISC problem, an appropriate decoupling method should be considered for which the Gauss-Jordan transformation is developed. Then, with certain preconditioners and iterative solvers, a numerical solution can be obtained. The results of different models are presented, which are validated with the results by CMG STARS. Also, the scalability of parallelization is shown, indicating the excellent performance of parallel computing. This accurate, efficient and parallel ISC simulator applies to complex reservoir models.
- Asia (1.00)
- North America > Canada > Alberta (0.46)
- North America > United States > Texas (0.28)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.67)
- North America > Canada > Saskatchewan > Athabasca Basin (0.99)
- North America > Canada > Alberta > Athabasca Basin (0.99)