Download Papers

The Wolfberry offers additional production opportunities as well as many operational downhole challenges.  This paper will cover a field study of "gas interference" challenges and the problems of free gas" at the pump. Gas interference creates costly expenditures for operators of Wolfberry and other oil wells with similar wellbore conditions.

Mathematical rod pump models are used in the design and optimization of lift systems. Most models are based on the damped wave equation, assuming steady state cyclic behavior and empirical damping factors. Such models cannot be used for fully transient analyses.

Theoretically, each Sharp Edged Seat has fully open stem travel based on the port and ball diameters. Gas lift valve 1.5” has 6 different port diameters (3/16”, ¼”, 5/16”, 3/8”, 7/16” and ½”). For each port the ball diameter is usually larger than the port diameter by 1/16”.

Technology has developed to integrate pump off control with variable speed drives to capture the secondary benefits of reducing equipment loads and increasing production through continuous drawdown.

Corrosion is a major issue in our industry and it is hard to predict its behavior. It depends on many factors, among which the most relevant are pressure, temperature, concentration, water, PH, chlorines and flow conditions. From the materials point of view, the most relevant parameters are the alloys (such as No, Cr, NB, MO,C), structure, UTS/YS, electronegativity, hardness and toughness.

There are multiple API Recommended Practices for the care and handling of tubing, sucker rods, and pumps.  Additionally, there have been several papers written in support of these practices and documenting how they reduce downhole failures.  However, in the past few years the field application of these practices has taken a step backwards for multiple reasons.

Lower lifting cost in the oil field is a never ending task. Over the years, many products from pump off controller to fiberglass rods have been used successfully to lower energy cost and extend the life of the well. MotorWise integrates the latest technologies, to substantially lower lifting costs even more. MotorWise combines two technologies: Soft Start and Power Synchronizing to deliver the precise amount of energy to the pump jack in real time. The technology has been deployed on over 2,000 wells in the Permian Basin.

Lower lifting cost in the oil field is a never ending task. Over the years, many products from pump off controller to fiberglass rods have been used successfully to lower energy cost and extend the life of the well. MotorWise integrates the latest technologies, to substantially lower lifting costs even more. MotorWise combines two technologies: Soft Start and Power Synchronizing to deliver the precise amount of energy to the pump jack in real time. The technology has been deployed on over 2,000 wells in the Permian Basin.

This article covers the actions taken and results obtained in controlling sucker rod pin failures in the period 1963-1983 at the Cerro Dragon Area, Comodoro Rivadavia, southern Argentina.

The term "hydraulic pumping system" as used herein, is taken to mean a particular method of lifting fluid from oil reservoirs, in which a power pump, distribution lines, subsurface pumps, and other auxiliary components are employed. Some of the most familiar manufacturers of this type of pumping equipment are Kobe, Inc., Sargent Engineering Corporation, and National Supply Company. Sometimes this system is referred to as "hydraulic rodless pumping", but in the strictest sense this is untrue because there is always a rod connection the engine and pump pistons.

It is probable that more effort has gone into a study of corrosion control in the Brown Bassett Ellenburger Field than in any other single gas field. This is as it should be, since the corrosion problems encountered are more severe than those generally encountered.

The Pressure Fluctuating Tool (PFT) utilizes a bi-stable, fluidic oscillator to create pulsating pressure for breaking down and/or cleaning up perforations in oil, gas and injection wells with or without stimulation fluids. The pressures generated by the PFT are from 1,500 psi above hydrostatic to 1,500 psi below hydrostatic at 140 to 150 cycles per second. This focused energy has been very successful in perforation tunnel clean up as will be indicated in the detailed case history review contained in this paper.

The cost of conventional methods of paraffin control in pumping wells is often high. This paper describes an experimental installation for the injection of butane on a pumping well in Carter County, Oklahoma, in 1958, and subsequent expansion of the process to eight other well. The frequency and quantity of injection varies with the prevailing surface temperature conditions, and to date only minor problems have been encountered using the butane injection process.

As with all industries, the fracturing industry has gone through many technological advances over the years, and with these come many successes. Using a low polymer energized fluid seems to provide a good solution for these types of problems. These new style treatments provide faster cleanup, better flow back, good sand placement, and better production than conventional or previous fracturing fluids. The case studies provided will show that this treatment fluid technique provides a positive response for these types of wells.

This paper is a case study of the selection procedure for the various types of artificial lift equipment utilized in the Reinecke Unit, Reinecke Field, Borden County, Texas. The considerations involved in choosing a Jet pump, Submersible pump, or Rod pump for maintaining optimum production performance in a high capacity reservoir are reviewed and evaluated.

The rapid expansion of the petroleum industry has caused a shortage of experienced field personnel. Even though there are volumes upon volumes written regarding specific stimulation techniques and processes, one finds that many of the routine aspects of performing these treatments are overlooked. We will look specifically at a study of optimized perforation costs in relation to hydraulic horsepower requirements, optimization of stimulation fluids - first in terms of unit cost, and then take a particular fluid and look at treatment cost compared to productivity increase.

Hot oil treatment of flowline and downhole paraffin problems is still common in the oilfields of North America. The use of chemical programs has been growing but often the industry is unsure which type of treatment should be done and if these programs are more cost effective than hot oiling. This paper will attempt to show, based on the paraffin problems being experienced, which type of chemical treatment would be most cost effective. Case histories of economic treating programs will be presented.

Matrix acidizing is often undertaken to improve the permeability of reservoir rock. When excessive quantities of ferric (Fe+++) ions are taken into solution by matrix acidizing, iron deposition and permeability reductions can occur after acidization. Sources of iron include (1) iron oxides from tubular goods, (2) pipe scale and (3) iron in mineralogical form such as siderite, pyrrhotite, magnetite, hematite and pyrite. Preventing iron deposition in matrix acidizing is essential to a successful acid treatment.

This paper presents a discussion of fracture height measured with gamma ray and temperature surveys and fracture height predicted with a real-time model during the pumping of a fracture treatment. The San Andres formation was fracture stimulated ii; six West Texas wells. Each treatment was pumped down the annulus with open-ended tubing in the hole. The open ended tubing pressure was monitored to obtain direct measurement of bottom-hole treating pressure. Throughout each treatment a real-time quasi 3D fracture model was run to predict fracture geometry.

Many times a certain prime mover is selected because that particular make and size is known to the purchaser. Little or no consideration is given to the various types of engines available, one of which may be best for the particular installation. To make an intelligent comparison of slow and high speed engines and be able to make a proper selection of a prime mover for a particular installation it is necessary to understand the definition, the principle of operation, the mechanical construction, and the advantages and disadvantages of each type of engine.

Rod pumping units historically used a crank driven walking beam to provide a reciprocating motion for oil and gas production. Several geometries have evolved over the years to produce desirable polished rod motion profiles and gearbox torque loads. These mechanical systems are limited in their ability to manipulate the motion profile and the profile is forever fixed by the selected geometry. Hydraulic cylinder linear actuators became available a number of years ago for reciprocating rod pumping of oil and gas wells.

In lieu of pending EPA and NRC regulations covering the monitoring of ground water supplies of drinking water as it relates to the public health, both private and municipal water districts, and utilities will be required to monitor for naturally occurring radioactive materials, NORM, and their constituents, ie... Radon, Radium, and Thorium. This monitoring will require the utility districts to utilize and employ "BAT", best available technology.

The variation of centrifugal pump performance curves with liquid viscosity is a well-known fact and is usually properly accounted for when selecting such pumps for oilfield service like artificial lifting by ESP units, pipeline transport, etc. Thus, several theoretical and empirical methods are available for correcting performance curves (conventionally measured with water) to other liquids.

Before we start to discuss "Optimum Pumping Conditions" let us first see what Webster's Dictionary gives as the real meaning of "optimum": "The best or most favorable degree. Best, most favorable or most conducive to a given end, especially under fixed conditions." The first and most important key to optimum pumping is the establishment of fixed conditions. As we all well know, the basic purpose of any pumping installation is to pump fluid from the well to the surface.

A comparison was made between four commercially available sucker rod string design programs: Rod Star, S-Rod, Q-Rod, LoadCal B and a proprietary, modified API RP11L based program. These programs used the same input requirements, where applicable, and their outputs compared dynamometers cards from five different producing wells. The results show differences in the anticipated major design loads along with differences in the output information. Recommendations are made on potential changes to these programs and comments are made on things to consider when these programs are used.