| Title | Deep shale gas in the Ordovician-Silurian Wufeng-Longmaxi formations of the Sichuan Basin, SW China: Insights from reservoir characteristics, preservation conditions and development strategies |
| Authors | Nie, Haikuan Jin, Zhijun Li, Pei Katz, Barry Jay Dang, Wei Liu, Quanyou Ding, Jianghui Jiang, Shu Li, Donghui |
| Affiliation | State Key Lab Shale Oil & Gas Enrichment Mech & Ef, Beijing 102206, Peoples R China Sinopec Petr Explorat & Prod Res Inst, Beijing 102206, Peoples R China Peking Univ, Inst Energy, Beijing 100871, Peoples R China Chevron CTC, 1500 Louisiana St, Houston, TX 77002 USA Xian Shiyou Univ, Sch Earth Sci & Engn, Xian 710065, Peoples R China CNPC Engn Technol R&D Co Ltd, 5 Huanghe Rd, Beijing 102206, Peoples R China China Univ Geosci, Sch Earth Resources, Wuhan 430074, Peoples R China China Petr & Chem Corp SINOPEC, Petr Explorat & Prod Res Inst, 197 Baisha Rd, Beijing 102206, Peoples R China |
| Keywords | FORT-WORTH BASIN THERMAL MATURITY DISTRIBUTION PATTERN GEOLOGICAL CONTROLS BARNETT SHALE EXPLORATION ENRICHMENT LITHOFACIES MECHANISMS GENERATION |
| Issue Date | 1-Apr-2023 |
| Publisher | JOURNAL OF ASIAN EARTH SCIENCES |
| Abstract | Shale gas at a burial depth greater than 3500 m is an important potential strategic target for exploration and development in China. Due to the complex geological and engineering settings, our understanding of the enrichment and retention mechanisms of deep shale gas is limited, and large-scale commercial development has not yet been realized. In this study, deep shale gas in the Upper Ordovician Wufeng Formation and Lower Silurian Longmaxi Formation of the Sichuan Basin is systematically studied in terms of the spatial distribution of black shale, reservoir types and properties, preservation conditions, and gas content as well as exploration and development practices. The deep siliceous shale of the Dicellograptus complexus-Cystograptus vesiculosus biozone exhibits high quartz content, which is conducive to the formation and preservation of effective reservoirs, thus it is often recognized as the optimal interval for deep shale gas development. Compared with the shallower res-ervoirs, microfractures in deep shale gas reservoirs are not developed. Also, overburden pressure and high temperature bring about a 40 %-50 % reduction in porosity and an 80 %-90 % decrease in permeability. High formation temperature, large in-situ stress and high-stress difference between the horizontal stress and vertical stress in the deep shale gas reservoirs lead to elevated shale plasticity, making it difficult to form and extend fracture. Moreover, due to the high fracture closure pressure, proppant tend to easily break in addition to the reduction of effective hydraulic fractures and fracture conductivity, which explains why it is difficult to effec-tively fracture deep shale and to achieve high and stable gas production. It is recommended to establish a volume fracturing plan (such as a long horizontal well with an increasing number of stages and perforations) for certain deep shale gas reservoirs. Creating and optimizing reasonable production systems with excellent pressure management procedures are also crucial to maximize deep shale gas production and ultimately realizing the commercial development of deep shale gas. |
| URI | http://hdl.handle.net/20.500.11897/671058 |
| ISSN | 1367-9120 |
| DOI | 10.1016/j.jseaes.2022.105521 |
| Indexed | SCI(E) |
| Appears in Collections: | 待认领 |
