Sucker Rod Pump

Modern controllers are required to estimate various parameters from field data to provide effective diagnostics and control of sucker rod pumping installations. In some cases, however, the data are not only corrupted by noise but also contain outliers that are in gross disagreement with the postulated model. If included, outliers can distort the fitting process so dramatically that the fitted parameters become arbitrary. 

The ability to have host software autonomously optimize control artificially lifted oil and gas wells has obvious upsides for operators looking for productivity gains both for their workforce and their assets. In recent years, many strides have been made to develop such algorithms to allow operators to maximize performance on their artificially lifted assets. One of the most significant challenges that remains is how to optimize dynamic wells.

Effectively managing fluid production with high sand content poses a common challenge in various forms of artificial lift, whether it be addressing formation fines or handling proppant flowback from hydraulically fractured zones. This challenge is particularly pronounced in reciprocating rod lift applications, where the entry of sand and solids into the barrel/plunger interface emerges as a primary cause of pump failures.

The use of rod rotators is key to extend the life of sucker rod string couplings in all intentionally and not intentionally deviated wells. Its applicability has proved to be a low-cost solution, giving an even wear on sucker rod couplings, extending considerably their run time.
One of the major issues with conventional cable actuated rod rotators is the integrity of the cable, its installation and proper maintenance. It’s common to heard from operators losing the cable connection and ending up on a premature failure on sucker rod couplings due to localized wear.

The Downstroke Pump and Special or Unusual Sucker Rod Pumps Explained This paper will explain the author’s theory of operation of the pump that lifts fluid on the downstroke, using the weight of the rods, and its loading of the sucker rod string and pumping unit. Other special sucker rod pumps will be likewise explained, using the author’s understanding, including the family of double displacement type pumps, compound compression ratio pumps, traveling barrel pumps, and others.

Mechanical rod rotators have been used as part of the beam lift artificial lift system since the concept was first patented in the late 1930’s. By rotating the rods, the frictional wear surface can be distributed around the circumference of the rod, versus on a single side of the rod. By distributing the wear surface, the rod life will be significantly extended. In the same way, the industry has used tubing rotators to derive this same benefit on the tubing, distributing the wear around the inner circumference of the tubing.

Understanding rod loading is vital to reducing failure rates in reciprocating rod lift systems. By changing the minimum stress and using the modified stress analysis instead of the modified goodman diagram, manufacturers are “tricking” you into using high tensile strength and/or premium sucker rods in your rod designs. This presentation will attempt to explain rod loading why most rod lift applications do not require or need  high strength and/or premium sucker rods.

When rod pump wells are operated in corrosive environments, corrosion induced sucker rod parts can lead to premature well failure and expensive, repeat workovers. Many corrosion mitigation solutions exist to combat this type of failure, including metallurgy, chemical inhibitor, and epoxy coatings, but they can be costly and not all solutions are appropriate for all types of wells.

Sucker rod pumping is largely regarded as the final artificial lift method in a well’s lifecycle. Until now, the industry standard application of sucker rod pumping systems has been up to 400 barrels per day fluid production. With the industry advancing towards deeper wells and increasingly aggressive production targets, the challenge of meeting these application parameters while decreasing costs has become forefront to an operator’s requirements for profitability and in some cases, survival.

Abstract In 2019, we presented the early results of a design change on our insert sucker rod pumps in the Highway 80 field. The information presented previously was eighteen months of data after this change was made. We also included over seven years of data prior to the change. Today we will discuss the forty-eight months of data collected after the design change and more than 11 years reviewing sucker rod pumps stuck in tubing in this field. When an insert rod pump gets stuck in tubing, increases in well-servicing events drive costs and safety risks.