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National-Oilwell is the Distributor for a newly patented line of Insertable Progressing Cavity Pumps. This new technology allows the producer to install and remove both the rotor and stator with the sucker rod string. The tubing string contains a down-hole seating assembly attached to the bottom, which stays in place until the tubing is removed from the well. The improved efficiencies and state of the art elastomer materials are all combined to significantly reduce the lifting costs for today's producer.

The Downhole Dynamometer Database is a compilation of test data collected with a set of five downhole tools built by Albert Engineering under contract to Sandia National Laboratories. The downhole dynamometer tools are memory tools deployed in the sucker rod string with sensors to measure pressure, temperature, load, and acceleration. The acceleration data is processed to yield position, so that a load vs. position dynagraph can be generated using data collected downhole.

Despite preventive measures taken during the manufacture of oil field tubular goods some defective lengths are produced. Other lengths become defective as the result of damage occurring during shipment or handling, or because of service conditions to which they are subjected. Failure to detect and properly dispose of these defective lengths before failure occurs has and can become costly and dangerous.

Illustrates the installation of a free type tandem dual zone hydraulic pump. Presents operation and design of special equipment required.

A Reda pump is essentially a multistage centrifugal pump, the shaft of which is directly connected through a protector section to a submergible electric motor. The entire assembly, as a unit, is of such outside diameter that it can be installed in wells completed with standard size casing. In operating position, the unit is suspended on tubing, submerged in the well fluid, with a cable from the surface supplying electricity to the motor. The installation may be for any depth since the unit is designed to function under any submergence pressures encountered.

When it becomes necessary to put an oil well on the pump, the operator is usually faced with an investment of several thousand dollars in some means of artificial lift. By far the most successful and most generally accepted type of artificial lift is the beam type pumping unit. Many years of research and testing have gone into the design of the modern pumping unit. Advancements in metallurgy and the most up-to-date machine tools go into its manufacture.

In today's times of material shortages and spiraling material costs, it has become increasingly important to emphasize proper installation techniques and a comprehensive maintenance program to assure long equipment life with minimum maintenance. Of prime consideration will be a scheduled maintenance program to prevent untimely and expensive downtime, and to prevent expensive major maintenance.

The purpose of this paper is to show how the design and operation of pilot-controlled gas-lift valves have overcome many of the inherent problems of multiple completions. Within the production tubing string, multiple completed wells are no different than single completions. From a gas-lift standpoint, the main difference is that several wells producing from a common casing, have a common casing annulus gas supply. This fact eliminates the use of pressure in the annulus as the sole means for actuating the gas-lift valves.

In general, the well characteristics will govern the type of pumping completion and the selection of equipment. Various arrangements of equipment are discussed, such as two packer single string, single packer with either clipped or free running secondary string, hollow rod pumping, lower zone gas venting and triple completions. It is emphasized that attention to correct installation of all equipment will eliminate needless completion expense.

This paper will discuss the installation of High Density Polyethylene (HDPE) liners in existing cement-lined and bare steel water injection pipelines. Design criteria, economic evaluation, and HDPE liner installation details are included. Also, different types of HDPE liner systems, material properties, and internal corrosion protection will be discussed.

An instrument skid especially designed for fracturing data acquisition provides operator flexibility and choices that can help reduce costs of data acquisition and recording. The operator interface panel (OIP) associated with the skid can be viewed at the skid or can be remoted up to 250 ft distance from the skid. Information collected can be used by the on-board computer system and displayed on three screens of the OIP, or the digitized data can be communicated to other computer systems that may be on the job.

Shortly after the discovery of the Block 31 field in 1945, ARC0 Oil and Gas Company, then Atlantic Refining Company, started searching for ways to improve the ultimate recovery from the Devonian formation. Laboratory research showed that natural gas would become miscible with the crude at 3500 psi. Therefore, injection of the produced gas began in 1949. A processing plant was built in 1957 to extract liquids from the gas before reinjection. Eventually, the produced gas volume was not adequate to maintain miscibility pressure and additional gas was purchased to make up reservoir voidage.

The use of an intelligent ESP control unit (IESP) aids in remotely operated and "trouble" wells. Inputs from a number of end devices are used to determine the condition of the well bore and the equipment. Based on these inputs the mode of start-up or operation is "decided on" by the IESP. Control commands are then sent to the Variable Frequency Drive (VFD), switchboard controller, or back-pressure valve to achieve the desired mode of operation. This paper will discuss the concept and IESP design behind the initial project.

Waxes accumulate as obstructions to the normal flow of crude oil systems. They do this by attracting molecules of like character (e.g., normal paraffin hydrocarbons) and combining through intermolecular forces to form aggregates of a crystalline nature. The aggregates thus formed interact mechanically and accumulate in constricted flow regions, pipe surfaces, and quiescent storage areas. Once it has been determined that paraffin wax accumulation has restricted the normal production, transport, and/or storage of crude oil, measures should be quickly undertaken to remedy the problem.

Advances in enzyme technology and its application to hydraulic fracturing have brought enzyme breakers from low-temperature, low-pH applications to being used over a wide range of temperatures, pH's and fluid systems. Their potential as fracturing fluid breakers seems almost limitless as one obstacle after another has been swept away by advances in biotechnology. High-temperature enzymes, high-pH enzymes and controlled release enzymes have contributed to their widespread use as fracturing fluid breakers.

In most instances there will be no question as to whether or not a well should be placed on continuous flow or intermittent flow. However, there are cases of the so called "borderline well". Reference should be made to "The Power of Gas" by Mr. C.V. Kirkpatrick for a complete analysis of the borderline well. This procedure involves an analysis of injection pressure injection gas/oil ratio and horsepower requirements. The following types of intermittent flow installations utilized in the field today are: 1. Tubing flow with a packer only (semi-closed installation), Fig. 1; 2.

The purpose of this paper is to describe multipoint intermittent gas lift installation design. The application and advantages of this design technique are noted. The operating principal of multipoint gas injection, which includes fundamental valve mechanics, is presented. The maximum producing rates from the same high capacity well with a continuous flow installation and a multipoint intermittent installation are compared, and the reasons for the difference in producing capacity is reviewed.

Many of the thousands of wells produced by intermittent gas-lift experience similar problems. One problem is that the system is attempting to lift a static slug from the bottom of the well to the surface, which is quite inefficient. As the slug moves toward the surface, there is a frictional drag on the liquid slug along the inner walls of the tubing. That drag, coupled with the fact that the gas is travelling faster than the liquid, means that there is a tendency for the gas to outrun the liquid. The liquid that is outrun never reaches the surface, it falls back to the bottom of the well.

Cement-lined steel or iron pipe is not a new approach to corrosion prevention. In 1836 the French Academy of Science reported the successful use of cement-lined pipe. They reported that, "Hydraulic cement, applied about 2.5 mm (0.1 inches) thick, is of all compositions, combining facility of application and cheapness, that which adheres the best to the casting, is the most indestructible, and prevents most effectually all oxidation (Corrosion) and consequent formation of tubercles.

The use of internal protective coatings for oilfield pipe has greatly increased during the past few years. New coating systems and application techniques, quality control, engineered performance and successful field use have all contributed to this growth. This paper summarizes the history of the coating industry, surveys the present art, and defines the useful areas for coatings in oil and gas production.

Accelerated internal failures of gas gathering lines due to corrosion are creating more concern to operators. A review of the dissolved gasses which cause corrosion is significant from the standpoint of occurrence and prediction of corrosion. Dissolved oxygen when present with other corrosive gases causes severe corrosion. Experience shows that early detection of corrosion by the use of monitoring devices is essential. Corrosion in gas gathering lines can be effectively and economically inhibited with organic film forming amine corrosion inhibitors properly applied and monitored.

Paper may soon be eliminated from the well permitting process at the Railroad Commission of Texas ("Commission") by an electronic commerce system that captures, stores, and transmits oil or gas well permitting information. With a few computer keystrokes and mouse clicks, Burlington Resources filed and the Commission approved the first drilling permit electronically through the ECAP (Electronic Compliance and Approval Process) system in a demonstration on May 11, 2000. A collaboration among the U. S.

Stringent safety requirements imposed by major operators when fluid level measurements are performed offshore or in enclosed wellhead spaces such as in Alaska's North Slope create procedural complications, such as the requirement for hot permits, when performing fluid level measurements in producing wells. This need has been eliminated by the development of a small, self contained, fully digital, battery powered instrument that is approved for use in hazardous areas. The Echometer Model H electronics has been tested at various locations on the North Slope.

Safety in the workplace is one of the major considerations for selecting and applying instruments for use in conjunction with oil and gas operations. All companies, government and labor organizations have developed guidelines and regulations aimed at making the workplace as safe as possible. In particular, instruments that are used in a hazardous environment have to meet strict requirements and specifications and be certified for use in explosive atmospheres.

This paper will provide a basic understanding of the Multiport Selector Valve (MSV) also known as Rotary Selector Valve (RSV), Controller, Environmentally-Friendly Spill Prevention Skid, Design Analysis, Usage and Dynamic Fundamentals; Highlighting the technical capabilities to manifold multiple wells from a single unit. Automation