Xinggui Yang
Doctoral Student
Southwest Petroleum University
Mr. Yang is a doctoral student of Southwest Petroleum University. He is mainly engaged in the exploitation of unconventional oil and gas resources such as shale gas and tight gas, as well as the numerical simulation of multi-scale fracture propagation process of hydraulic fracturing. He has participated in the fracturing design and field implementation of ultra-deep tight gas wells in Tarim Basin for many times.
Participates in
TECHNICAL PROGRAMME | Primary Energy Supply
Opportunities for Oil & Gas Supply Growth - Shales, Oil Sands, New Basins Other Unconventionals
Forum 02 | Digital Poster Plaza 1
28
April
12:30
14:30
UTC+3
The Kuqa Foreland Basin accounts for over 70% of the total proven natural gas reserves in the Tarim Oilfield. Due to complex reservoir conditions, primarily characterized by large thickness and well-developed natural fractures, hydraulic fracturing for production enhancement faces multiple challenges. First, matrix-type tight sandstone reservoirs typically aim to create long fractures, while the stimulation strategies for fractured tight sandstone reservoirs are still in the exploratory phase. Secondly, the large thickness and high closure stress make it difficult to achieve long-distance proppant transport and efficient placement across the entire fracture domain. Thirdly, high formation pressure and gel back-production increase the risk of proppant flowback, making it challenging to maintain proppant pack stability.
Extensive G-function pressure decline analysis of wells in the block indicates that the low-permeability matrix and natural fractures form an equivalent high-permeability composite system, requiring high main fracture conductivity. Therefore, for fractured tight sandstone, it is crucial to increase the fracture length to maximize connectivity with natural fractures and optimize proppant placement to enhance fracture conductivity. To achieve this stimulation objective, a fiber-assisted proppant high-efficient placement technology was developed and successfully applied in Well A with a depth of over 7000 m. Building on the stimulation parameters of adjacent wells in the same block (with fluid intensity of 12.5 m³/m, proppant intensity of 0.58 m³/m), the introduction of fiber and structural stabilizers (with fiber concentration of 0.4%, structural stabilizer concentration of 0.2%) was implemented to increase the proppant-supporting area and improve the conductivity of the whole fracture domain post-hydraulic fracturing.
Compared with conventional fracturing wells, Well A showed significantly improved hydraulic fracture conductivity and effective mitigation of proppant flowback after implementing proppant high-efficiency placement technology. Based on post-fracturing flowback data and proppant flowback statistics, the concepts of flowback intensity and flowback proppant production index were introduced. Flowback intensity represents the daily flowback volume per meter during the flowback phase, indicating the hydraulic fracture conductivity. The flowback proppant production index is defined as the ratio of cumulative proppant flowback to flowback intensity, reflecting the severity of proppant flowback. Compared to adjacent wells, Well A exhibited a 1.5-fold increase in flowback intensity and a 70% reduction in the flowback proppant production index after using fiber-assisted proppant transport. These results demonstrate that the proppant efficient placement technology is successful in ultra-deep fractured tight sandstone reservoirs.
Under the same proppant volume, the proppant high-efficiency placement technology can effectively enhance post-fracturing production, indicating that this technology can also reduce the required proppant volume while meeting single-well production targets. This technology provides a viable solution for the economic and efficient development of ultra-deep and naturally fractured reservoirs.
Co-author/s:
Yuxuan Liu, Associate Professor, Southwest Petroleum University.
Extensive G-function pressure decline analysis of wells in the block indicates that the low-permeability matrix and natural fractures form an equivalent high-permeability composite system, requiring high main fracture conductivity. Therefore, for fractured tight sandstone, it is crucial to increase the fracture length to maximize connectivity with natural fractures and optimize proppant placement to enhance fracture conductivity. To achieve this stimulation objective, a fiber-assisted proppant high-efficient placement technology was developed and successfully applied in Well A with a depth of over 7000 m. Building on the stimulation parameters of adjacent wells in the same block (with fluid intensity of 12.5 m³/m, proppant intensity of 0.58 m³/m), the introduction of fiber and structural stabilizers (with fiber concentration of 0.4%, structural stabilizer concentration of 0.2%) was implemented to increase the proppant-supporting area and improve the conductivity of the whole fracture domain post-hydraulic fracturing.
Compared with conventional fracturing wells, Well A showed significantly improved hydraulic fracture conductivity and effective mitigation of proppant flowback after implementing proppant high-efficiency placement technology. Based on post-fracturing flowback data and proppant flowback statistics, the concepts of flowback intensity and flowback proppant production index were introduced. Flowback intensity represents the daily flowback volume per meter during the flowback phase, indicating the hydraulic fracture conductivity. The flowback proppant production index is defined as the ratio of cumulative proppant flowback to flowback intensity, reflecting the severity of proppant flowback. Compared to adjacent wells, Well A exhibited a 1.5-fold increase in flowback intensity and a 70% reduction in the flowback proppant production index after using fiber-assisted proppant transport. These results demonstrate that the proppant efficient placement technology is successful in ultra-deep fractured tight sandstone reservoirs.
Under the same proppant volume, the proppant high-efficiency placement technology can effectively enhance post-fracturing production, indicating that this technology can also reduce the required proppant volume while meeting single-well production targets. This technology provides a viable solution for the economic and efficient development of ultra-deep and naturally fractured reservoirs.
Co-author/s:
Yuxuan Liu, Associate Professor, Southwest Petroleum University.
