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A series of tests measuring power consumption were conducted at the Texas Tech Red Raider Test Well. This test facility is located 5 miles northeast of the campus of Texas Tech University in Lubbock, Texas. This paper introduces the Red Raider Test Well and all of it's abilities for testing various components of a rod pumping artificial lift system to unprecedented level of accuracy. This test measured the power consumed by the beam pumping system with all variables held constant except the surface stroke length and rodstring design.

The enhanced oil recovery processes discussed in this paper fall in the general areas of recovery of oil by thermal, gas drives, polymer flooding, and chemical flooding processes. General descriptions of the most widely used processes are given. Also, the conditions under which each process has been found to be likely successful (screening criteria) are included for each process. This helps the engineer to match processes to specific reservoirs.

Multiphase flow in pipes is defined as concurrent movement of free gases and liquids in the pipes. Flow may be in any direction. The gas and liquid may exist as a homogeneous mixture, or the liquid may be in slugs with gas displacement (which is pushing behind slugs). The liquid and gas may flow parallel to each other, or other combinations of flow patterns may be present. The gas may be flowing with two liquids (normally oil and water), and the possibility exists that the two liquids may be emulsified.

Laboratory Screening Tests are suggested to evaluate potential enhanced oil recovery projects. Standardized procedures are used to study the feasibility of (1) miscible/CO2 projects, (2) thermal processes, and (3) chemical processes. The Screening Tests are divided into four sections: crude oil characterization, injection water studies, reservoir core characterization, and displacement studies in porous media. These Screening Tests augment geologic and engineering studies and supplement (but do not replace) the more commonly known core analysis programs.

The success or failure of secondary recovery efforts is largely dependent upon the proper analysis of downhole and reservoir fluid movement characteristics, and control of these conditions to maximum displacement efficiency. The indigent reservoir reactions under secondary efforts differ dramatically from normal primary production systems. These differences generate a need for individualized analysis and correction of each problem.

The widespread use of waterflooding has presented many new problems to the petroleum industry. Most of these problems are directly related to the physical process of pumping great volumes of water at high pressures into water injection wells. Until the past few years, methods of increasing or maintaining injectivity were limited to the conventional techniques of acidizing or fracturing. Within the past three or four years, however, stimulation techniques have been developed primarily for problems related directly to water injection wells.

Primary separation methods (such as free water knockouts, gun barrels and skim tanks) often leave substantial amounts of oil and solids in waterflood injection water. Removing oil and solids from produced and supply water streams by secondary separation techniques such as corrugated plate inceptors (CPI) and gas flotation units can provide four benefits: 1. Increased oil sales. 2. Improved water injectivity. 3. Improved waterflood sweep efficiency. 4. Lowered injection pump discharge pressure.

Inaccuracies in hydrocarbon measurements can cause significant revenue losses for a company. This paper will discuss the problems associated with hydrocarbon measurements and the preventive measures a company can take to correct the inaccuracies. Historically, exploration and production companies have adopted a casual attitude to the necessity of accurate hydrocarbon measurements. All too often this author has heard, "Our measurements are pretty close: anyway what's a few barrels between friends".

The Progressive Cavity (PC) Pump is being used in various types of applications worldwide, particularly because of its simplicity of operation and increased mechanical efficiency over other methods of artificial lift. As with all fluid lift methods, the proper selection of the pumping system's size and materials of construction is most important to ensure increased operating life and overall efficiency. The selection process for a pc pump system is relatively easy due its simple design. The down hole pump consists of only two parts: the single helix rotor and the double helix stator.

Maximum production from many tight gas and shale reservoirs is obtained through high volume, high rate hydraulic fracture stimulation. The base carrier fluids for these treatments are most often shallow water wells, streams or ponds. This water is often laden with bacterial growth and saturated with dissolved oxygen requiring the fluids be treated with biocides and oxygen scavengers during the fracture stimulation to prevent accelerated corrosion of the downhole tubulars and surface separation equipment once the wells are placed on production.

In selecting gas lift equipment; there are several factors which must be given careful consideration. As each field has individual and distinct characteristics which make it different from others, these factors should be considered in the following sequences: A. Type of well B. Problems of producing the well and the overall production cost C. Problems to be considered in installation, work-over, and work-over cost D. Over-all cost of gas lift equipment and work-over on a two-year basis.

The stimulation of wells to increase the productivity has had wide acceptance in the industry in the last few years. The results have generally been beneficial, but, as in most processes, the method is not a cure-all, since in many instances the remedial operation has failed to produce the desired results. It is the responsibility of field managers and engineers, at any time, to avoid spending money on projects which will not be profitable.

The selection of a proper application of hydraulic pumping for any set of conditions is only as accurate as the information available. The adaptability of hydraulic pumping, however, minimizes any unusual expense by wrong assumption or incorrect information. This paper will handle two phases of hydraulic pumping: the selection of size and type of installation and the analysis of various operating characteristics.

The two basic groups of pumps covered in the A.P.I. Standard 11-A are tubing and insert pumps. From these, various combinations can be made for particular well conditions by rearranging existing equipment and substituting a few fittings. A third group of pumps, which could be referred to as miscellaneous or special, use mostly standard fittings from the basic groups and are usually designed to overcome one particular difficult well condition.

In the past several years, there have been many advancements in the coating industry. The overall performance of all coatings has increased with the introduction of epoxies, urethanes and polyesters, which have better adhesion, abrasion and chemical resistance, along with increased gloss retention for high quality paints. The selection of a paint or coating system for any given situation will require certain considerations: (1) the environment, (2) degree of surface preparation, (3) economics.

Often the oil operator fails to recognize the importance of a careful study of the prime mover, yet each well that does not flow involves a problem in the selection and application of a suitable prime mover. Many formulas have been derived to determine the prime mover size. Basically, these formulas give essentially the same results when the same allowances have been made. An overall multiplier is generally applied without much thought as to the exact factors involved. Sometimes, very important factors are overlooked in obtaining an efficient, economical prime mover installation.

Presents explanations of different types of bottom-hole pumps available to produce gaseous wells. Case histories indicating increases gained by various operators with proper pump installation will be given.

Many pump designs and combinations of metals have been developed to meet the various problems (or conditions) found in an oil well. In presenting our thoughts on "The Proper Selection of an Oil Well Pump" we will, therefore, first classify the problem found in the well and then present our suggestions as to the proper design and combination of metals to be used in building the pump to meet the specific conditions of the well.

This paper discusses the primary factors to consider in the sizing of ANSI standard centrifugal pumps for production and plant applications. Practical information on selecting equipment for present and future requirements will be discussed. Material selection, mechanical seal selection, and pump modifications will be covered as part of the selection process. Explanation and calculations of NPSH and its relation to cavitation and pump sizing will be briefly mentioned. A basic overview of electric driver selection will also be touched upon.

The proper selection of an artificial lift system for a waterflood project will greatly influence the overall economics of the project. To achieve the most favorable economics, the lift system should have sufficient flexibility to handle the predicted range in producing rates, under the anticipated operating conditions, with minimum investment and operating costs.

As the use of special fluids to complete or workover wells has become accepted practice, the number of completion and workover products on the market has increased considerably. Because of this, the selction of the fluid which will provide the best performance at the most efficient cost is a critical question. A review of the basic functions of a completion or workover fluid is presented. In addition, a discussion of the various types of completion and workover fluids is included. A decision chart is presented in order to systematize the selection process.

There have been many papers presented and many discussions about producing multiple completion wells. In fact, two papers were presented last year at the 5th Annual Short Course. We do not intend to cover the entire field of pumping multiple completion wells but must, of necessity, review some of the past history and accomplishments in this field. Dually completed wells first came into being during the early 1940s for two reasons: 1) shortage of steel (tubular goods) 2) Increased demand and price of oil.

Prior to a sound selection of injection pumps for waterflood service many factors are to be considered. With the consideration of plunger pumps versus centrifugal pumps the basic advantages of each must be carefully taken into account. When choosing one of these pumps for an individual flood project, the anticipated initial and future injection conditions for that system are of primary importance in determining the most economical type installation.

API Standard 11 AX, Subsurface Pumps and Fittings, sets forth specifications covering sucker rod pumps and establishes dimension requirements to assure interchangeability of component parts. No material specifications or guidelines for the proper application of the various API pumps are given. This report was prepared by NACE Task Group T-lF-12 and is intended to serve as a supplement to API 11 AX. It presents general recommendations of metallic materials for the construction of sucker rod pumps for service in a hydrogen sulfide environment.

The proper selection of metallic materials often makes the difference between a successful water injection program and an economic failure. Poor selection can often necessitate early abandonment or may limit the quantity of water injected by causing excessive shut-down time. In some floods, even a temporary stoppage of injection can cause oil to be bypassed in the formation and, if nothing worse, decrease the profit from the operation. For these reasons, much care in the selection of metallurgy throughout the water-handling operation is essential.