On May 25, Sinopec Southwest Petroleum Engineering Company's Downhole Operation Division successfully completed its first ultra-high-pressure sand fracturing operation at the Xinsheng 214H well using 175 MPa fracturing equipment. The operation reached a peak pressure of 140 MPa, setting a new high for Sinopec’s fracturing pressure record. Additionally, the operation established three new records for the Xujiahe Formation in western Sichuan: highest single-stage fluid injection (4,311 m³), highest single-stage sand volume (246.82 m³), and highest operational displacement (20 m³/min), marking a major breakthrough in ultra-high-pressure fracturing technology.

The Xinsheng 214H well, located in the western Sichuan Basin, is a vertical exploratory well with a depth of 5,042 meters. The main objective of the operation was to assess reservoir development, collect parameters for reserve calculation, and validate the performance of 175 MPa equipment, providing technical support for further exploration and development.

The 175 MPa fracturing equipment and associated technology are strategically significant for natural gas development in southwest China. They enable effective stimulation of deep tight reservoirs and ultra-deep shale gas formations, especially those buried deeper than 4,500 meters. Ultra-high-pressure fracturing allows for the creation of denser fracture networks, significantly improving single-well output and recoverable reserves.

To ensure the success of this first attempt, the company assembled a multidisciplinary expert team to conduct comprehensive tabletop simulations. They repeatedly refined the process design, equipment connectivity, and pressure transmission mechanisms, culminating in a well-rounded operational plan. Equipment was customized for the 175 MPa requirements, including rigorous material selection and performance testing for critical components such as high-pressure pumps, seals, and pipeline joints. Fatigue strength and sealing precision were meticulously verified, with engineers stationed onsite during manufacturing to ensure compliance with design standards.

The challenging reservoir featured low porosity, poor natural fractures, and high in-situ stress. To tackle these issues, the team employed a “high-rate + fine proppant + extreme intensity” fracturing technique, executed in two stages. The first stage used 140 MPa medium-scale fracturing to quickly evaluate gas content. The second stage adopted large-scale, ultra-high-pressure sand fracturing at 175 MPa, successfully connecting faults and microfractures around the well. The team also introduced “dry method” proppant injection for the first time, solving issues such as proppant settling and low transport efficiency. This was paired with tail-end flow-limiting technology for precise fracture control, enhancing reservoir stimulation results.

Throughout the operation, the team prioritized safety and efficiency. They optimized resource allocation and refined procedures to ensure integrated execution. High-standard technical protocols were strictly followed, and all materials—fracturing fluids and proppants—were thoroughly tested. Real-time microseismic monitoring tracked fracture propagation, allowing for dynamic parameter adjustments and risk prevention.

In light of the 175 MPa pressure risks, full inspection and quality assessment were conducted on wellhead assemblies, high-pressure pipeline installation, connections, commissioning, and pressure testing. Emergency response plans were developed and rehearsed to handle potential issues such as sand blockages or pipeline leaks. During fracturing, comprehensive safety inspections monitored wellhead pressure, high-pressure zones, and equipment conditions. After each stage, pipelines and pump trucks were maintained to ensure operational integrity. A comprehensive safety management network was established to ensure safe and smooth operations.

Ultimately, the Xinsheng 214H well successfully completed six stages of sand fracturing, with a maximum displacement of 20 m³/min, peak pressure of 140 MPa, total sand injection of 721 m³, and total fluid volume of 14,892 m³—achieving a one-time successful operation. The success validated the 175 MPa equipment and technical system, offering valuable experience for future ultra-high-pressure fracturing operations and strong support for building a 100-billion-cubic-meter natural gas production base in southwest China.