Electricity has become an essential commodity in the life and economy of the American people. In the home, it is used for illumination, refrigeration, cooking, cleaning, water heating, washing, ironing, for entertainment, and to an ever increasing degree for cooling and heating. Even more important is the indispensible part it plays in turning the wheels of industry and in supplying the power required for our national defense. Yes in industry

Clays are present in a majority of hydrocarbon-bearing formations and their presence can cause many problems in the production of oil and gas. The difficulties that are encountered are complicated by the fact that clay composition and location in the rock can vary extensively. In reality, the presence of clays in any part of the drilled hole can present a variety of problems in all phases of the life of the well. There are shales that show a high degree of deterioration when contacted by the common types of water-base drilling fluids. Fluid loss from cement slurries and certain water-base stimulation fluids are another source of potential damage to permeability. Clays may be found in all types of rock. Formations made up of such rocks have been called water sensitive and may be defined as formations where a reduction in effective permeability is noted when a foreign water invades the formation. Normally, sandstone formations exhibit the greatest degree of water sensitivity. Clays may also be present in carbonate rocks but are frequently encapsulated in the rock matrix. Thus, they are not in a position to be contacted by the invading fluids. Permeability damage is primarily caused by migration of clays and other fines with fluid flow. High pH fluids, particularly those with low salt content, can cause dispersion of clays which increases their possibility of migrating. Subsequent bridging of particles at flow restrictions in the rock flow channels causes a plugging action which results in a permeability reduction. This overall effect is primarily found during the flow of water.

Shot peening has long been used in many applications to provide increased fatigue performance. This paper will provide a short summary of surface treating processes including details related to shot peening. Additionally, presented is information related to special process controls developed by a sucker rod manufacturer and trade marked "NOR-PEENING."

In the mid-1950"s, the Mark II, a new, rotary counterbalanced, sucker rod type pumping unit was developed, employing a special Class III geometry and phased counterweights. This paper reviews some of the basic functional goals envisioned for this unit by its designers, and the degree to which they have been realized. Also discussed are several functional categories involved in sucker rod pumping and the influence the unit's unique geometry has upon each of them.

Little has been written regarding the effects of electric power integrity on submergible pumping systems. The remoteness of a site and/or the economics of the distribution system can result in power which affects equipment life and efficiency. Other installed electric devices or systems can also impact the quality of supply. The purpose of this paper is not to condemn the circumstances which lead to deficient power supply situations, but rather to address their effects and discuss practical means of correcting or minimizing their effects.

Limited information is available on the effects of pressure on the set properties of cements with respect to commonly used additives. This report presents compressive strength data on cement systems cured at temperatures of 170F 10 260F and at pressures of 3,000 to 10,200 psi. Of the cement systems studied, those designed, for a specific, bottom-hole static temperature (BHST) show little change in compressive strength with increased curing pressure at BHST. However, some systems, cured at temperatures lower than BHST, gave increased or decreased compressive strength with increased curing pressure. The use of" curing pressures that simulate more closely the pressures actually found in oil or gas wells gives a better understanding of additive performance and a more realistic waiting on cement (WOC) time for cement systems.

Sloan Petroleum, the operator, had previously attempted to remove intermittent plugs of salt and sand from the non-producing wellbore of a gas well completed through 2 7/8" tubing at 2800 feet. Unsuccessful clean out efforts were made by conventional methods, first by fresh water circulation and then by wireline impacting tools. The operator also considered using reverse equipment and small diameter drill pipe but the cost was prohibitive. The problem was solved by drilling the obstructions with 1 _" coiled tubing, a 1

Today in this environment of uncertain oil price and the drive to become more cost effective, a Petroleum Engineer must have all the help possible to work smarter and more efficiently. To this end, many excellent software packages devoted to such specific disciplines such Reservoir Engineering, Project Economics, sophisticated drafting programs, and varied programs to calculate everything from bottomhole pressure to pumping unit design have been created. However how does an engineer handle the much more mundane tasks that beset him everyday that these specific packages weren't designed for? In order to effectively and efficiently manage these varied tasks, a "Computer Toolbox" of off the shelf "generic" software needs to be utilized.

The Equalizer is a totally new concept in downhole drilling string accessories. The principle of the device is much like that of a hydraulic jack as it acts as a resilient coupling between the drill string and the rock bit. Unlike spring loaded shock subs, the tool does not store energy. A series of hydraulic pistons is energized by the pressure drop generated across the jet nozzles of a rock bit by the surface mud pressure system. The mud system pressure drop is then internally utilized by the tool to provide a fluid coupling or "fluid cushion" between the bit and the drill string. At the same time, a constant weight is being transmitted to the bit. The tool has increased bit life and penetration rates, while substantially reducing shock damage to drill string components.

In 1992 the US market began to focus on the efficiency and solids handling capabilities of the Conventional Progressive Cavity Pump System (PCP). The Canadian Market. during this time frame. had already installed approximately 4000 of these units replacing conventional rod pump units. Because of the simple design and commonalties with the Rod pump conversions were made easy. (Please see figure 1. I) As the PCP

Most energy professionals must focus on a specific activity. For example, you the attendees at this Southwestern Petroleum Short Course focus on petroleum production in this region of Texas. Energy professionals also have a both personal and professional responsibility to objectively share information regarding the broad aspects of energy utilization - "The Essentials of Essential Energy Utilization" the title of this paper. This information should be provided our legislative representatives, although many local representatives have a realistic understanding regarding energy matters. A more difficult task is to provide factual energy related information to misinformed persons. A combination of wishful thinking, and false information makes these persons very difficult to approach regarding energy matters. A major purpose of this paper is to provide you a context in which energy matters may be discussed.

Well completion, in the Permian Series of West Texas, is complicated in many instances because of: 1) poor knowledge of reservoir rock, 2) improper log analysis and 3) misinterpretation of core analysis. The first completions were almost exclusively from open hole sections; however, as the years went by the need for stimulation became apparent and several methods were employed

Stuck pipe has been identified as the largest single contributor to non-productive drilling time. The use of resonant vibration as a means of freeing stuck tubulars from a well bore has been demonstrated to be effective in both Drilling and Workover environments and has the potential to provide almost immediate results in many day-to-day applications. The challenge for the future is to further explore both proven and potential applications of this technology in order to evaluate the benefits and reduce the unknown associated with the technology. The long term industry benefit will be a different approach to stuck tubular recovery available in the form of superior technology that addresses real needs while substantially reducing costs. The technology offers the benefits of being quick and easy to apply, operations are conducted from surface with no downhole intervention, and results may be achieved very quickly. Demonstrated successes in both cased and open hole applications has prompted the industry to embrace the technology as a viable and often preferred means of stuck pipe recovery.

The materials and the workmanship for the present day oil well requirements have changed greatly from those 20 to 30 years ago. Both the materials and the workmanship have been improved to meet the requirements presented to us in deep well pumping.

A number of major oil companies have begun -field tests of the lightweight, non-corrosive fiberglass sucker rods, The tests were generally made using steel sucker rods in a well for a specific time period and replacing the steel rod string with one designed with fiberglass rods. Specific detailed records were kept on these "before and after" studies by most companies. Other companies employed an independent testing firm to provide test results, This paper will compare steel sucker rods with two brands of fiberglass sucker rods manufactured by Company A and Company B. The wells in this study are divided into groups of similar depths with comparable fluid levels, pumping units and bottom-hole pumps. Four standards were developed to compare and evaluate sucker rod performance. 1. Equipment loading 2. Energy consumption 3. Fluid production 4. Failure frequency Each of these four standards was studied in depth in similar wells to compare each group of sucker rods.

The practice of lifting fluid from subsurface levels with gas pressure is not new; it has been in use for many years and is now recognized as a major method of artificial lift in petroleum production. Until recent years a detailed study of gas lift operating principles was relatively unimportant because of the low value of natural gas. With increasing gas value a study of the principles became imperative. This study has led to much advancement in development of the practice, principles and equipment.

The application of correct methods for determining the effect of pressure and temperature on the behavior of natural gas is essential in projects involving gas measurement. The gas compressibility factor may be neglected in gas calculations only at low pressures and high temperatures. This paper presents the basic equations, with example solutions, for determining the gas compressibility factor, the volumes occupied by a gas at different pressures and temperatures, and the flow of gas through pipelines as measured with an orifice meter.

Since the beginning of oil production, salt water handling has presented problems. However, recent years have brought about significant changes in attitudes and approaches to gathering, pumping and injecting large volumes of salt water. Political implication, landowner relations. And regulatory decrees have demanded increased controls on salt water disposal. The lack of, or inhibited use of, fresh water have forced greater dependence on salt water sources for waterflood. In combination, these factors have created new concepts. Water handling is no longer regarded as a side-line necessity. It is often a controlling factor in profitable oil producing operations. Efforts are constantly being directed to finding better and cheaper ways to handle large salt water volumes. New technology has joined old experiences in overcoming serious problems. This paper reviews some of the primary problems and presents methods of approach toward their solution. Caution and danger conditions are discussed. Symptom signals and control measures are described. Emphasis is placed on the systematic acquisition of appropriate data. A simplified chemical material balance concept, utilizing standardized data presentation techniques, is suggested as a way for the production engineer to derive a quantitative expression of "water quality".

Recent improvements in the Borehole Televiewer logging field have enabled oil operators to determine the presence of natural fractures and their orientations in the Spraberry and Dean Formations. Running modern open hole logs over the Spraberry and Dean zones is rarely done when these zones are the primary target zone of a well. However, the need for determining the natural fracture direction is important to the oil operator so he can optimize his offset locations with respect to the trend of the natural fracture system. Defining the trend of the fracture system is particularly important since many Spraberry/Dean wells are drilled on 40 acre spacing and are candidates for waterflood projects in many areas. The following examples document the utility of the Borehole Televiewer in both evaluating the subject formations for hydrocarbon production and optimizing the hydraulic fracture stimulation design for achieving maximum oil production.

The presence of natural fractures in hydraulic fracturing candidates can present an array of well completion
problems. Natural fractures can be very difficult if not impossible to model without adequate pre-job diagnostic
testing to calibrate simulation. Left undetected natural fractures can cause premature screen-out as well as gel damage. In tight gas sand formations, natural fractures can be the predominate production mechanism in the reservoir. If polymer residue is left in the natural fractures after drilling, stimulation or work-over, a substantial amount of potential production may be left behind. Often this type of damage may be documented by the sheer fact that production may decrease after these types of operations.mTechniques have been perfected to determine the impact on leakoff due to natural fractures. In many cases production may exceed the predictive capability of production simulators without the introduction of permeability numbers that might be considered high for that area. This could lead one to believe that some portion of the production is dominated by natural fractures. A better understanding this type of leakoff could help in the development of methods to predict production results or economics of a well based on pre-job testing. It is the intention of this paper to discuss methodology to predict the presence of natural fractures and show key considerations when trying to simulate their behavior. This paper will also investigate damage mechanisms and describe methods that may be used to help minimize their impact.

This paper deals with the various kinds of taxes, other than income, which affect the oil industry. The material is directed to first level supervisors and engineers who are concerned with taxation problems in the industry.

A true gas lock is really just a pocket of gas trapped between the standing valve and the traveling valve. It has enough pressure when the pump is extended (on the upstroke) to keep the standing valve from opening and admitting new fluid. But does not compress tightly enough when the pump is closed (on the downstroke) to lift the traveling valve off its seat. Since coming to the oilfield in 1975 I have seen, and dealt with a great number of sucker rod pumps that appeared to be gas-locked. I have also inspected, and listened to the sales pitch for, many devices that the inventors claim will solve this problem once and for all. I have had the opportunity to evaluate several of these "gadgets" in the field and found them wanting. Most often the devices fail prematurely, and several had no discernible effect. The claims for others bordered on the absurd. Yet, these devices persist and I have seen at least three inventors and or salesmen in the last six months. At least two of the ideas have merit, although not necessarily for the reasons that the inventors' claim. As a well technician for Texaco I have been involved in the company

Supervisor is a vital function in the modern organization. It is the link between decision and action and both are ineffective without it. Therefore, the supervisor is the "man in the middle" with responsibilities to the management and to his men. His position and authority in the organization should be carefully defined and his duties, responsibilities and rights clearly understood. What is a supervisor and what should he do?

Extensive Jet Pump field operating experience has shown that the Jet Pump is a viable method of deep well pumping. Properly applying this pump to a given well installation involves 14 factors relating to the well and its production characteristics, and involves determining the optimum pump nozzle and throat size required to do the most effective job. Since many of the production characteristics of a well are interdependent, many reiterative calculations are required to determine the proper nozzle and throat size for each producing condition. The computer is the only practical method for using the producing conditions to make the many calculations that are required to generate an accurate and easily understood Jet Pump Operating Chart. This paper shows the factors involved and their effect upon Jet Pump operation.

Printed technical references to jet pumps can be traced as far back as 1852 England. However, consistent mathematical formulas were not published until 1933, when J. E. Gosline and M. P. O"Brien of the University of California at Berkley published The Water Jet Pump. In the same time period, the Jacuzzi Company received a patent for a jet pumping system that was successfully used to lift shallow water wells. Over the years, jet pumps have also been used as vacuum sources in applications such as steam ejectors on large, condensing steam turbines or on a wide variety of process industry vacuum requirements. Low to moderate lift water wells, and process and steam ejectors remain today as common industrial applications of jet pump technology. These applications, however, use liquid as a power source to move liquid, or gas as a power source to move gas. The initial problem in applying jet pumps to lift oil wells was based on the fact that a typical oil well contains a mixture of oil, water, and gas. The mathematical formulas of the 1930's did not produce accurate results in predicting pump performance and, consequently, required considerable modification. Also, jet pump performance calculations require a cycle of a number of repeat calculations, each one "zeroing in," as it were, more closely on the desired result. Making these calculations manually is very time consuming. It was not until the widespread availability of computers and the ability to properly program calculations of this type that the proper application of jet pump lift to oil wells became a practical reality. The first really successful applications were put in service in 1970. The use of this method of artificial lift has grown quite steadily since then. It is not the intent of this paper to discuss in detail the theory of operation or the calculation methods employed to accurately predict jet pump performance. It is suggested that those interested in a detailed presentation of those topics refer to the 1987 edition of The Petroleum Engineering Handbook, published by the Society of Petroleum Engineers. Chapter 6 of this publication, authored by Hal Petrie of National-Oilwell, contains a wealth of excellent information on hydraulic pumping, including both jet and reciprocating pumps. However, in order to discuss the versatility of jet pumping oil wells, a basic discussion of the Hydraulic Lift System and the jet pump's design characteristics is in order, since these are the basis of the jet pump's versatility.