Product News

Confused about selecting the right API 11AX pump? Discover how well depth, fluid viscosity, and sand content influence your choice between Tubing and Rod pumps. Expert advice from a certified API manufacturer.

Discover how Dongsheng anti-sand sucker rod pumps utilize advanced scraping technology and Tungsten Carbide coatings to prevent plunger sticking and extend run-life in high-sand oil wells.

Once the well depth goes beyond 8,000 ft, standard pump setups often fail due to high hydrostatic pressure, rod stretch, and mechanical fatigue.

Abstract: In oil production, sand-heavy well conditions are the primary driver of premature subsurface pump failure. Standard API 11AX components often fall short when facing severe abrasive wear. As a factory with deep customization capabilities, Dongsheng Rod Pump explores how to break through the limitations of standard parts through optimized plunger groove designs, micron-level clearance control, and advanced metallurgy to maximize the Mean Time Between Failures (MTBF).

Introduction: The High Stakes of Deep Well Recovery In the lifecycle of an oil field, transitioning into deep-well or ultra-deep-well production is a high-stakes endeavor. When dealing with well depths exceeding 2,500 meters (approx. 8,200 feet), the choice of artificial lift equipment is no longer just about fluid volume—it is a critical calculation of Total Cost of Ownership (TCO). Many international procurement managers are often swayed by the lower initial CAPEX of a Tubing Pump, only to realize later that they have fallen into a "maintenance money pit" caused by high-frequency workovers. At Dongsheng (DS Rod Pump), with over 20 years of experience serving global oilfield giants, we believe that 80% of production losses in deep wells are predetermined at the selection stage. This guide provides a deep dive into the technical and economic realities of API 11AX Rod Pumps versus Tubing Pumps.

As oil producers enter another year of operating in mature and technically demanding reservoirs, artificial lift strategy is quietly undergoing a shift. Rather than pursuing short-term production gains, operators are increasingly prioritizing engineering accuracy, system reliability, and lifecycle cost control. At the center of this transition is the oil rod pump​, still the most widely installed artificial lift system in onshore oilfields worldwide. Industry experts note that its long-term performance depends less on the pump itself and more on how rigorously it is selected. In recent months, engineering teams across Asia, the Middle East, and parts of Latin America have revisited formal pump selection standards as failure rates in complex wells continue to rise.

As global oilfields mature and production conditions become increasingly complex, selecting the right artificial lift system is decisive for controlling operating costs (OPEX) and minimizing downtime. While Electric Submersible Pumps (ESP) dominate high-volume offshore and deep-well applications, Oil Rod Pumps (Sucker Rod Pumps) remain the undisputed king of onshore and mature field economics. In recent years, a strategic shift has emerged: operators are increasingly replacing ESPs with rod pumps in mid-to-late life wells. This article analyzes the technical and economic reasons behind this trend and explains why the oil rod pump remains the preferred choice for maximizing Total Cost of Ownership (TCO).

Beyond the Price Tag: A Technical Handbook for Engineering & Procurement. By the Manufacturing Team at Tieling Dongsheng Petroleum Machinery. Executive Summary: The "10x" Rule In the artificial lift industry, there is a brutal truth known as the "10x Rule": Saving $500 on a pump purchase usually costs $5,000 in early failure expenses. For procurement managers and engineers in 2025, the goal is no longer just "getting the best price." It is Total Cost of Ownership (TCO) Optimization. A pump that runs for 400 days is infinitely cheaper than a pump that runs for 90 days, regardless of the initial invoice amount. But how do you ensure longevity before the rod pump is even installed? You must upgrade your Purchase Specification. This guide provides 8 Field-Proven Buying Strategies—covering metallurgy, geometry, and quality assurance—to help you source rod pumps that survive the harshest downhole conditions.

The 2025 Expert Guide: From Engineering Logic to Field Realities. Authoritative Guide for Operators, Engineers, and Procurement Teams. Who is this guide for? This guide is designed for: Oilfield Operators who want to reduce pump failures and stabilize production. Artificial Lift Engineers who require deeper insight into material selection, tolerances, and downhole wear mechanisms. Procurement Teams looking to make smarter sourcing decisions and avoid hidden lifecycle costs. Maintenance Supervisors aiming to implement predictive maintenance instead of reactive repairs. Energy Service Companies that need up-to-date 2025 engineering standards and field-proven practices.

In the artificial lift sector, the Sucker Rod Pump (SRP) remains the dominant technology due to its reliability and flexibility. However, operational inefficiency and premature failure continue to cost the industry billions annually in workover expenses (OpEx) and deferred production. As we navigate through 2025, the maintenance of these pumps has evolved from a reactive "run-to-failure" model to a proactive, data-driven discipline. This comprehensive guide details the technical nuances of maintaining oil rod pumps, combining legacy field experience with modern API standards and digital monitoring technologies.