Artificial Lift

Gas production is one of the main problems on ESP systems; causing premature failures and low efficiency, these are the reasons why many companies have developed a number of solutions to separate gas before reaches the pump. To solve this problem a New Downhole Gas Regulator has been developed in order to avoid large amounts of free gas flowing directly into the pump intake. This system regulates the amount of gas ingested by the pump so it will make easier for the pump stages to lift a fluid with a higher density (Less amount of gas in the multiphase flow).

Horizontal Unconventional declines have a rapidly declining hyperbolic decline section and a slower declining exponential decline section. Rapidly changing production volumes from the decline curve and more rapid changes from slugging gas as a result of undulations in the horizontal leg plus sand from massive frac jobs result in challenges in artificial lift selection. This paper will explore these challenges.

This paper discusses the principal of ball lifting systems (Lizard) for oil and gas wells and its possible applications. Typical applications are: 1. Acts as moving standing valve to minimize dry runs while reducing tubing wear. 2. Will continually operate in transition area; Lizard will move the to transition flow area to deliver ball to lifting sleeve, unloading wells and work itself to the bottom. 3. Increase lifting depth from 40 degrees to 75 degrees. 4. Stop yo-yo effect between two-piece plungers.

Harmonic Mitigation Challenges in Unconventional ESP Applications 1. OBJECTIVES/SCOPE: Modern oil field producers face increasing pressure from utilities regarding harmonic compliance, and harmonic-related penalties can be severe. A more effective approach for mitigating VSD-induced power harmonics is presented, in which the unique electrical requirements of unconventional ESP applications are considered.

A process for modeling multivariate Electric Submersible Pump data in a central host system is proposed in to support managing fields by exception by using artificial intelligence models to identify failure modes and operating conditions. The AI model enables operators to immediately identify failure modes and operational conditions, as it is continuously analyzing, facilitating quicker decision making. It also increases the number of wells an operator can effectively manage, and can be used as an educational tool, empowering users to interpret complex ESP trends.

Corrosion and fatigue are the primary causes of sucker rod failures in artificial lift systems. Harsh well fluid conditions lead to material loss and detrimental pitting which then lead to initiation points for fatigue fractures to occur.

Production in aggressive service environments with higher acid gas concentrations associated with increased levels of hydrogen sulfide (H2S) and carbon dioxide (CO2) requires good fatigue life associated with corrosion resistance. 

This paper proposes a new method to deal with sand and chemical problems in the ESP. The protection system consists of 1) ESP sand separation system that works in two stages assuring the best sand separation efficiency. The first separation stage is composed of a V-wire geometry screened designed based on production. The second stage is a centrifugal system formed by a sand cutting resistance sleeve and a helix that creates a Vortex Effect.

The technology is used to prevent damages in equipment by breaking the gas/sand slugs, creating homogeneous flow regime to allow proper motor cooling, eliminate the risk of gas locking and increase lifting efficiency.

Rod pumping in horizontal wells in the Permian Basin is extremely challenging. So much so that other forms are often considered as alternatives just because of the difficulty. Some of the major difficulties include, gas interference leading to poor pump efficiencies, and greater sand problems leading to premature wear, failures and sticking. When converting from ESP to Rod Lift it is typical to accept a reduction in total production. This conversion typically happens around the 200/300bbls/day +/- range.

This presentation will explore and discuss technology and operational factors that will reduce downhole friction in sucker rod pumping systems resulting in fewer failures and lowering Lease Operating Expenses (LOE) and Workover (W/O) costs.