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Collaborating Authors
Tight gas
Oil and gas production from the Middle East region has been steadily increasing during the past decade to meet global consumption demands and to maintain the Middle East countries' market share. As reported in BP Statistical Review of World Energy 2021, the Middle East accounted for 31% of global oil production and 17.7% of natural gas production. In terms of reserves, on the other hand, it hosts 48% of proved oil reserves and 40% of proved gas reserves. This clearly shows the bias toward gas production. Gas can be considered relatively underdeveloped as only 17.7% of global gas is produced by Middle East countries, which illustrates the significant potential of currently underutilized gas production when 40% of gas reserves reside in the Middle East.
- Europe (1.00)
- Asia > Middle East > Saudi Arabia > Eastern Province (0.30)
- Asia > Middle East > UAE > Dubai > Ras al Khaimah Basin > Jebel Ali Field (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Arabian Basin > Jafurah Basin (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Reesh Field > Tuwaiq Mountain Formation (0.99)
- Asia > Middle East > Saudi Arabia > Northern Borders Province > Abraq al-Toloul Field (0.93)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Tight gas (1.00)
- Production and Well Operations (1.00)
- Management > Asset and Portfolio Management > Reserves replacement, booking and auditing (0.78)
Is Single Stage Vertical Well the Only Option for Khazzan/Ghazeer? Hydraulic Fracturing Design Optimization Coupled with Production Simulations Provide Insights on Different Completion Approaches to Maximize Recovery, Production and Economics
Parada, C. (BP, Houston, Texas, USA) | Ligocki, L. (BP, Houston, Texas, USA) | Varahanaresh, S. (BP, Houston, Texas, USA) | Casero, A. (BP, Houston, Texas, USA) | Al Harrasi, M. N. (BP, Muscat, Sultanate of Oman) | Motealleh, S. (BP, Muscat, Sultanate of Oman)
Abstract Barik Sandstone is a well know condensate reservoir developed in several fields across Central Oman between Ghaba Salt Basin and Fahud Salt Basin. Its particularity lays in the vertical and lateral heterogeneity resulting from the fluvial-deltaic depositional environment and an associated quite unusually high stress differential across the different mudstone and sandstone members. Barik Sandstone is classified as Unconventional Tight Gas due to the low average permeability and requires hydraulic fracturing (HF) to economically exploit the natural resources. Over the years, operators have applied different completion strategies, all including HF, spanning form vertical wells with multiple stages to vertical wells with single massive HF treatments and horizontal multistage wells, the paper will contain a literature review covering all these solutions including the rationale and areas overlapping. However, the common denominator to the success of the stimulation and completion strategy applied is the identification of an optimized HF design that maximizes recovery and economics, increases deliverability and reliability, while efficiently deploy capital expenditure. This paper is focusing on the work done in the Khazzan and Ghazeer fields to optimize the HF through a full circle process that start from reservoir and Mechanical Earth Model descriptions to hydraulic fracturing modeling and sensitivities on different options, then exporting frac geometries to reservoir model and run production predictions, to compare economic analysis, and finally applying the findings to field operations. In condensate gas reservoir, both length (geometry of fracture) and conductivity of fracture play important roles in gas rate and recovery. This study shows how dimensionless fracture conductivity design and increase in fracture length can be balanced to improve gas rate and recovery. Additionally, it provides guidance and sensitivities on the effect of permeability and number of frac stages on recovery and production uplift. This paper presents a method integrating different disciplines including geology, petrophysics, stimulation, petroleum, and reservoir engineering, while using static and dynamic data. Static data such as vertical heterogeneity and stress profile and dynamic data such as HF treatment rate and pressure, well production data (rate and BHP), pressure build up data are integrated to provide the optimal stimulation approach with different optionality depending on project specific objective and constrains.
- Research Report > New Finding (0.68)
- Research Report > Experimental Study (0.54)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.76)
- Geology > Sedimentary Geology > Depositional Environment > Transitional Environment > Deltaic Environment (0.54)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.46)
- Asia > Middle East > Oman > Ghaba Salt Basin (0.99)
- Asia > Middle East > Oman > Fahud Salt Basin (0.99)
- Asia > Middle East > Oman > Central Oman > Barik Formation (0.99)
- (22 more...)
Abstract Barik Sandstone is a well know condensate reservoir developed in several fields across Central Oman between Ghaba Salt Basin and Fahud Salt Basin. Its particularity lays in the vertical and lateral heterogeneity resulting from the fluvial-deltaic depositional environment and an associated quite unusually high stress differential across the different mudstone and sandstone members. Barik is classified as Unconventional Tight Gas due to the low average permeability and requires hydraulic fracturing (HF) to economically exploit the natural resources. Understanding the reservoir parameters was a key success for successful stimulation of the Barik Sandstone in Khazzan and Ghazeer Fields in Oman. A massive surveillance campaign was carried out to understand the reservoir properties including detailed seismic and long-term flowing and build up data. building a calibrated Mechanical Earth Model MEM allowed the team to design the best fit frac design that made the successful results on frac placement and well performance. With the extension of the reservoir height, more data were used to update the Mechanical Earth Model that helped to refine the frac design. this paper describes the workflow of how additional data helped modifying frac design using DFIT injections & different frac design approaches across different barriers. The Mechanical Earth Model created at the early stage of the field development was generated using a detailed Microfracs stress test and reservoir properties using static and dynamic data. layers stresses confirmed using several frac injection to test the break down pressure of that layer which then helped into defining the best frac design for the reservoir. The successful stimulation treatments confirm the value of such detailed surveillance and details workflow that was continuously updated using frac injections. This has a major impact on frac performance and field development plan that reflect the outstanding performance of these wells.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.77)
- Geology > Sedimentary Geology > Depositional Environment > Transitional Environment > Deltaic Environment (0.54)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.49)
- South America > Colombia > Casanare Department > Llanos Basin > Cusiana Field > Mirador Formation (0.99)
- Asia > Middle East > Oman > Ghaba Salt Basin (0.99)
- Asia > Middle East > Oman > Fahud Salt Basin (0.99)
- (21 more...)
Hydraulic Fracture Design Evaluation Through a Robust Geo-Mechanical Model, Tested in a Tight Gas Reservoir, North of Oman
Al Senani, A. (Petroleum Development Oman) | Al Aamri, M. (Petroleum Development Oman) | Al Mahfudhi, M. (Petroleum Development Oman) | Al Dhanhani, F. (SLB) | Sarmadivaleh, M. (Curtin University) | Al Sheidi, A. (Curtin University)
Abstract Natural gas plays an essential role in providing the world with a cleaner energy for possibly the next 50 years. Conventional gas resources are quickly declining and many countries (e.g. Oman) are investing in tight gas extraction. Such natural gases are usually accumulated in tight sand or shale formations, which have extremely low permeability. Thus, they don't flow at a commercial rate without implementing a hydraulic fracturing, which is an expensive and complicated technique. Therefore, proper fracturing design is a must to enhance well productivity and connectivity. In this study, the petrol physical logs and real field test data were used to construct an intensive rock mechanical model (RMM) for a specific tight gas field to be used in an economical simulator, to optimize the hydraulic fracturing design and strategy for the field. In this study, a rock mechanical model (RMM) was constructed to calculate the rock mechanical properties of the Formations, such as Poisson ratio, Young's modulus, uniaxial compressive strength (UCS), pore pressure and situ stresses. This was achieved by using the drilling data, wireline logs and core data of two wells from the field. The calculated properties from RMM were calibrated by inputting them in a specific constructed geo mechanical equation at which its trend was matched with the field caliber log trend. Some revision and modification were applied using an economical simulator to optimize the hydraulic fracture treatment. The simulation was run twice. In the first run, the simulator calculated the mechanical properties of the formation automatically by the built-in correlations of the simulator. In the second run, the outcome of constructed RMM were input in the simulator. The results from simulator were compared with the real fracture height from the radioactive tracer measured from the field test. The simulator's result shows the error percentage in the first run, which was done without the RMM, was 112%. While in the second run, where rock mechanical properties were entered in the software, it was 11%. As expected theoretically, building a fracturing model with calibrated data from RMM provides accurate and precise results that are close to the real measurements. However, the minor difference between the second run and the actual measurements can be because of uncertainties in the rock formation, and unavailability of some test data. In addition, the accuracy of the radioactive tracer to measure the real fracturing treatment should be considered. The outcome of this project would help to enhance and optimize the fracturing design and ultimately enhance the productivity of the newly fractured wells. Further, this study is considered an excellent guideline for current and new hydraulics fracture design to reduce the OPEX of the well and optimize production.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.71)
- Asia > Middle East > Oman > Al Wusta Governorate > Arabian Basin > Rub' al-Khali Basin > Barik Field > Barik Formation (0.98)
- Asia > Middle East > Oman > Miqrat Formation (0.97)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Tight gas (1.00)
- (4 more...)
Fracturing and Production Characteristics of Tight Gas Reservoir: A Case Study from Thrace Basin, Turkey
Kilicaslan, U. (Turkish Petroleum Corporation, Ankara, Turkey) | Mengen, A. E. (Turkish Petroleum Corporation, Ankara, Turkey) | Ozcan, O. (Turkish Petroleum Corporation, Ankara, Turkey) | Sevinc, S. (Turkish Petroleum Corporation, Ankara, Turkey) | Belhoucine, S. (Turkish Petroleum Corporation, Ankara, Turkey) | Boudissa, R. (Turkish Petroleum Corporation, Ankara, Turkey) | Mironov, V. S. (Turkish Petroleum Corporation, Ankara, Turkey) | Khlopkov, A. V. (Turkish Petroleum Corporation, Ankara, Turkey)
Abstract During the last three years, Turkish Petroleum Corporation, state owned oil company of Turkish Republic, has put significant efforts to develop its shaly sandstone reservoirs located in the Thrace Basin by-utilizing hydraulic fracturing technology. In this paper, a comprehensive review of operational and modelling aspects in the development of tight gas reservoirs were presented as a real field case study. Fracturing an over-pressured tight gas reservoir deeper than 3,000 meters (true vertical depth), in a tectonically active area, was the main challenge of the project. The initial priority was performing fracturing operations in a safe, proper, environmentally friendly way. In the post-frac phase, substantial difference observed in the individual well performances and post-frac assessment of estimated ultimate recovery (EUR) have become the main criteria in evaluation of the success of the current stimulation campaign as well as the identification of possible potential infill opportunities. Diagnostic fracture injection tests showed high closure stresses (up to 1 psi/ft gradient), which resulted in high treating pressures. To prevent screen-out, proppant concentration was increased by 0.25 ppg at each step and considerable sweeps between main stages were carried out. Different type of proppants were employed during the treatments in order to ensure having better fracture initiation and conductivity. The created fracture properties estimated from stimulation software as well as the values from rate-transient analysis were not well aligned. EUR predictions from the decline curve analysis and history matched simulation model only agreed for the first well, after having 2 years of production history, but not for other more recent wells. Image logs were also very helpful to explain different initial flow rates seen in the wells, due to the inferred presence of natural fractures. This case study summarises the efforts to overcome challenging hydraulic fracturing conditions and to analyse varying production behaviours between the hydraulically fractured wells by means of different methods; to assist the efficient development of the company's tight gas reservoirs in the Thrace Basin, Turkey. It was observed that natural fracture intensity increases as the well locations approach major faults, at which point the complex stress regime may then begin to expose the fracturing operations to a risk of early screen-out. Therefore, any proposed infill wells should be located in those areas at a safe proximity from faults for enhanced production.
- Geology > Structural Geology > Fault (1.00)
- Geology > Sedimentary Geology > Depositional Environment (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.69)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (0.66)
- Asia > China > Shanxi Province (0.32)
- Asia > China > Shaanxi Province (0.32)
- Asia > China > Gansu Province (0.32)
- Asia > China > Shanxi > Ordos Basin (0.99)
- Asia > China > Shaanxi > Ordos Basin (0.99)
- Asia > China > Gansu > Ordos Basin (0.99)
Fracture Geometries and Breakdown Pressures of Multi-Branch Radial Borehole Fracturing Influenced by Horizontal Stress Difference
Yong, Yuning (China University of Petroleum ) | Guo, Zhaoquan (CNPC Engineering Technology R&D Company Limited) | Tian, Shouceng (China University of Petroleum) | Wang, Tianyu (China University of Petroleum) | Sheng, Mao (China University of Petroleum) | Liao, Lulu (Sinopec Research Institute of Petroleum Engineering / China University of Petroleum)
ABSTRACT Multi-branch radial boreholes can be drilled and combined with hydraulic fracturing to efficiently stimulate tight gas reservoirs. This paper experimentally investigates how horizontal stress difference affects fracture geometry and breakdown pressure in multi-branch radial borehole fracturing by a true triaxial fracturing device. Six artificial rocks (395 mm ร 395 mm ร 395 mm) were cast for the experiments, which are divided into two groups by the azimuth of the radial borehole. The results show that fracture geometries are controlled by the rectification of a single radial borehole, the extrusion between the adjacent radial borehole row, and the deflection of the maximum horizontal stress. Fracture propagation is affected by the dynamic variation of the three effects. Decreasing the stress difference is favorable for fracture propagation along the radial borehole axis, while it lifts the breakdown pressure. Decreasing the azimuth lifts fracture extension distance parallel to the radial borehole axis and reduces the breakdown pressure. This research sheds light on the feasibility of radial borehole fracturing for reservoirs under various stress differences. INTRODUCTION Horizontal wells combining multi-stage hydraulic fracturing technology are commonly used to extract tight gas reservoirs. However, it still has the challenge that is the insufficient stimulation. Radial borehole fracturing is proposed recently, which combines the horizontal radial borehole with hydraulic fracturing (Huang et al., 2020a; Huang et al., 2020b; Kamel, 2016; Landers, 1998). This technology has the following procedure. Firstly, several radial boreholes, with diameters of no more than 50 mm, are drilled perpendicular to the axis of the vertical well. The fracturing fluid is then injected into the radial boreholes via the main well. After fracturing, the complex fracture network is generated in the reservoir finally. It has been applied in many fields with good effect (Bruni et al., 2007; Cinelli and Kamel, 2013; Cirigliano and Blacutt, 2007; Li et al., 2000; Maut et al., 2017; Ragab and Kamel, 2013). The multi-branch radial boreholes are favorable to communicating several sweet spots in the tight gas reservoir, which is also more economical than horizontal wells. So, radial borehole fracturing is anticipated to efficiently develop tight gas reservoirs or other unconventional reservoirs.
- Asia > India > Tripura > Assam-Arakan Basin (0.99)
- North America > United States > Louisiana > China Field (0.97)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- (3 more...)
Numerical Investigation on Field-Scale Fracture Propagation of Multi-Layered Formations Based on Unconventional Fracture Model
Jing, Meiyang (China University of Petroleum) | Yang, Ruiyue (China University of Petroleum) | Huang, Zhongwei (China University of Petroleum) | Cong, Richao (China University of Petroleum) | Chen, Jianxiang (China University of Petroleum) | Wen, Haitao (China University of Petroleum)
ABSTRACT The investigation of fracture propagation in multi-layered formations can assist in determining the optimal hydraulic fracturing pumping schemes for unconventional tight gas reservoirs. The option of multilayer-commingled fracturing or separate-layer fracturing technologies, based on geological and engineering conditions, is crucial for the commercial development of oil and gas in multi-layered formations. This paper presents a field-scale interbedded sandstone-mudstone fracturing model that employs an unconventional fracture modeling method based on logging interpretation data of the Upper Shihezi Formation in the Ordos Basin. The study examines the effects of in-situ stress, interlayer spacing, injection rate, and fluid viscosity on the fracture propagation of layered formations. The research findings suggest that the in-situ stress difference among multiple layers and interlayer spacing are the primary factors affecting the stimulated reservoir volume (SRV). A larger interlayer spacing and in-situ stress difference can lead to a greater SRV in separate-layer fracturing. On the contrary, the multilayer-commingled fracturing technology is suggested. In this scenario, higher fluid viscosity and lower injection rate are recommended. Based on numerical results, a separate-layer fracturing/multilayer-commingled fracturing selection chart was established for layered formations. The key findings are expected to provide a basis for selecting separate-layer fracturing/multilayer-commingled fracturing in tight layered reservoirs. INTRODUCTION With the sustained growth of China's economy and society, the consumption of fossil fuels has increased, resulting in a steady annual increase of CO2 emissions. In 2020, China's CO2 emissions reached approximately 10.3 billion tons, with coal, oil, and natural gas accounting for over 90% of the total emissions, at 9.5 billion tons. At the 75th United Nations General Assembly, China pledged to achieve peak CO2 emissions by 2030 and carbon neutrality by 2060 (Jin et al., 2023), representing a positive step towards China's global climate governance and fulfilling the Paris Agreement. Thus, the low-carbon utilization of fossil fuels is vital to ensuring energy security and achieving the "dual carbon" goal. Tight gas, a clean and efficient energy source with vast reserves, presents an opportunity to alleviate energy shortages and environmental pressures. Accelerating the development and utilization of tight gas resources can help China achieve the "dual carbon" goal sooner. Unlike the thick sand bodies found in the United States, tight gas reservoirs in China typically exhibit thin thickness and multi-layer characteristics. Multi-layered reservoirs often contain multiple sets of vertically stacked gas-bearing strata, which exhibit low permeability and strong heterogeneity, resulting in lower single-layer production (Wang, 2017). The Ordos Basin, China's second largest gas-bearing basin, is a key area for developing layered tight gas reservoirs, which are characterized by low reserves abundance, multiple sets of thin interbeds in the longitudinal direction, and common occurrences of sand-sand and sand-mud interbeds. The number of gas-bearing layers is usually between 9 and 11, with single-layer thickness ranging from 3 to 5 meters. The single-layer production capacity is low, and the contribution of each layer to gas production varies significantly. The sand body is generally small in size (Yang et al., 2016 and Li et al., 2012).
- Asia > China > Shanxi Province (0.45)
- Asia > China > Shaanxi Province (0.45)
- Asia > China > Gansu Province (0.45)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.50)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.35)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Horn River Basin > Horn River Shale Formation (0.99)
- Asia > China > Shanxi > Ordos Basin (0.99)
- Asia > China > Shaanxi > Ordos Basin (0.99)
- (5 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Tight gas (1.00)
- Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
Abstract Drawdown and choke management is an important process in production control and reservoir performance, primarily in unconventional and tight gas fields, where a well may produce with a high wellhead pressure for a long period. Under critical conditions, the gas or liquid rate is a function of upstream pressure, gas-liquid ratio and choke aperture diameter. The analysis of well decline behavior and production performance has an added complexity when there are problems in terms of fluid rate measurement and different production conditions related to choke changes. Then, there is a need of finding a model for a two-phase flow to understand the choke size selection effects, analyze production limitations and performance, normalize production data, and simulate different operating conditions. A data-driven method was explored aiming at providing a formulation approach for a production choke performance model in different fields. Filtered 4000 points after data analysis from seven fields were incorporated to calibrate a two-phase flow model, grouping the data in three main datasets (unconventional oil, unconventional gas, tight gas). Empirical correlations and coefficients were obtained from a multivariable regression model, using a Gilbert-type formula for each group of fields. Confidence and validation tests indicate the observed parameter is very well explained by the independent variables, resulting in the maximization of prediction accuracy and determination coefficients. The comparison and deviation of estimated parameters with real data confirms the robustness of the modeling. The evaluation of the results demonstrates that the two-phase choke model obtained with the multivariable regression methodology allows: - validation of production data in the allocation process (e.g., estimated variable vs real variable). - incorporation of predicted data in production datasets when a variable is missing or not measured. - production normalization: evaluation of previous or future production, modifying or assuming different production conditions (e.g., choke aperture diameter). - analysis of production under different operating conditions (i.e., initial decline behavior). - comparison of wells with the same production conditions. - simulation of the flow rate through chokes for specific conditions to better understand production strategy and forecasts. The results of this study stablish the framework to deal with choke management aspects in early-time production of unconventional wells and tight gas wells from seven fields, where both linear flow production in early-time stage, and further ultimate recovery of the well, are affected by the choke size selection and the resulting drawdown. The proposed choke model for two-phase flow is a precise and appropriate methodology which provides the elements to evaluate production and reservoir performance, normalize data, adjust drawdown and operating conditions, estimate production forecast, and optimize final recovery in these green fields with strong growth and aggressive development plans.
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (0.88)
A Systematic Approach to Fracture Propagation Simulation with the Integrated Natural Fracture and Geomechanical Model
Guan, Xu (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Zhu, Deyu (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Tang, Qingsong (PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Wang, Xiaojuan (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Wang, Haixia (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Zhang, Shaomin (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Deng, Qingyuan (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Yu, Peng (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Yu, Kai (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Huang, Xingning (Downhole service company of Xibu Drilling Engineering Company Limited, Karamay, China) | Xu, Hanbing (CNPC, International HK LTD Abu Dhabi, Abu Dhabi, UAE)
Abstract In recent years, tight sandstone gas as one of the important types of unconventional resources, has been rapid explored and developed. There are large-scale tight sandstone gas production in Sichuan Basin, Ordos Basin, Bohai Bay Basin, Songliao Basin and other basins, and it has become a key part in the area of increasing gas reserves and production in China. Due to the influence of the reservoir characteristics, tight gas reservoirs have low porosity and permeability, and the tight gas can only be effectively developed by improving the conductivity around the wellbore. Therefore, it is required to perform hydraulic fracturing after the completion of horizontal well drilling to improve the permeability of reservoir. It can be seen that hydraulic fracturing is the core technology for efficient development of tight gas resources. The implementation of hydraulic fracturing scheme directly determines the horizontal well production and EUR. This paper describes the workflow of 3D geomechanical modeling, technical application for Well YQ 3-3-H4 reservoir stimulation treatment, and carries out hydraulic fracture propagation simulation research based on 3D geomechanical model. This paper also compares the micro-seismic data with the simulation results, and the comparison results show that the propagation model is consistent with the micro-seismic monitoring data, which verifies the accuracy of the model. This paper clarifies the distribution law of hydraulic fractures in the three-dimensional space of horizontal wells in YQ 3 block, and the research results can be used to provide guidance and suggestions for the optimization of fracturing design of horizontal wells in tight gas of Sichuan Basin.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.46)
- Asia > China > Shanxi > Ordos Basin (0.99)
- Asia > China > Shaanxi > Ordos Basin (0.99)
- Asia > China > Gansu > Ordos Basin (0.99)
- (5 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Tight gas (1.00)
- (2 more...)