This paper discusses behavior and motivation patterns in the development of management personnel. The working relationships existing between managers and their subordinates is also presented. The need for individual recognition and mutual trust and appreciation is stressed.

A power/current transducer for measuring both power and apparent current permits an operator to obtain a more complete analysis of the performance of a motor powered pumping unit system. Power and apparent current are acquired and displayed during a single stroke to aid in the analysis of pumping unit efficiency, cost of electricity, proper balance and torque. Power measurement, for induction motors, showing both consumption and generation are much easier to analyze than apparent current data from a conventional clamp-on amp meter which does not distinguish between consumption and generation. Power transducers require the measurement of current in two legs of a 3-phase system. In addition, voltage probes must be attached to each of the three phases. The phase relationship between the current and voltage is processed electronically to obtain a voltage signal proportional to power. This signal is digitized at a rate of 20 times per second and displayed as a plot of power per single pumping unit stroke. Apparent current is also obtained and plotted for additional analysis. The power data is easily processed to obtain gearbox torque without the need for pumping unit geometry nor polished rod loads. Field data are given for examples of motor performance including cost of electricity with and without generation credit, an under balanced unit, an overbalanced unit, an under loaded motor and other conditions.

An increasingly energy conscious world is seeking not only alternate energy sources but also more efficient methods of production. The drive for energy independence has created an atmosphere conductive to innovations in oil recovery. Enhanced oil recovery methods, such as water flooding, chemical treatment, and steam injection are being used to increase the production of low yield wells, which were considered
non-profitable years ago. Along with new enhanced oil recovery methods is a new and innovative artificial lift method. The Moyno Downhole progressing cavity pump has been sucessfully applied to downhole pumping applications. The pump has only one moving part, the rotor, which attaches to and is driven by the sucker rod string, while the mating stationary part, the stator, is attached to the production tubing string. The rotor is a singleT;ireaded helical gear with a circular cross section and an off set or eccentricity. stator is a double threaded internal helical gear which has a diameter equal to the rotor, but an eccentricity and pitch twice of the rotor. When the rotor and stator are meshed together, a series of sealed cavities, 180" apart, are formed, that progress from suction to discharge as the single helix rotates. The result is a pulsationless positive displacement flow. This unique progressing cavity feature enables the pump to handle high gas-oil ratio crudes without gas locking. Due to inherent low internal velocities heavy crudes of high viscosity can be easily handled. An abrasion resistant elastomer stator and plated rotor offer long life in sand laden crudes. The rotary design lends itself to low profile surface equipment allowing better utilization of the land for agriculture. These futures give the production engineer another alternative method for artificial lift,

The Multi-Phase pump was designed in 1998 to attempt to pump wells that exhibited very foamy, compressible fluid mixtures which are inherently hard to pump with a conventional sucker rod pump. The design of this pump varies from traditional rod pumps whereby the standing valve is re-positioned at the top of the pump barrel. This factor, along with a specially designed set of seals and poppet assembly have led to the success of this pump. An area of west Texas was targeted to try this pump after a very successful introduction to the oil patch in western Canada.

The rapid expansion of horizontal drilling in unconventional gas plays such as shales and tight sandstones has lead to large increases in the number and size of fracturing treatments. Successful fracturing treatments on these wells require multiple stages and proper zonal isolation between the intervals being treated. Zonal isolation and completion techniques typically take the form of either a cemented casing/liner string and stage fracture treated using a perf and plug methodology or a system of packers and sliding sleeves fracture treated in a continuous
operation. Each completion technique has its own set of advantages and disadvantages and is typically viewed as mutually exclusive of each other. A case study showing a combination of these techniques being implemented in successful fracturing treatments in central and western Oklahoma will be shown. The application of these combined techniques on future remedial stimulations will also be discussed.

Use of new software for management of low volume oil and/or gas wells will be presented showing how graphical discovery tools and knowledge of field operating conditions, best practices and failure data can be used to efficiently manage large numbers of wells under stripper market conditions. A multi-well management system for a large stripper gas well field well be demonstrated.

This paper explains the contributing elements of a new formula developed for more accurately predicting the performance of those gas wells which include a high permeability zone interbedded with one or more low permeability zones. The theory assumes the existence of three conditions: that the well depletes without water encroachment; that each zone remains discreet from every other --that is, without cross flow among zones when the well is producing; and that each zone has either a hydraulic fracture or some skin effect. As a practical matter in using the model, however, only one of these reservoir conditions need be strictly met: freedom from water encroachment. The model developed herein does adapt to reservoirs that have limited cross flow between zones; it also adapts to those with a hydraulic fracture in only some of the zones. Finally, it includes equations which help to calculate matrix permeability whenever a known hydraulic fracture does exist. We illustrate the functions of this model by assuming the existence of a shaley-sand, six-zone reservoir and by ascribing to it certain characteristics. We examine how the model uses this data and then discuss the results.

Drilling multi-laterals is a preferred method to increase production from a single wellhead. Getting baack into these laterals can be difficult and costly. But without proper treatment, say for example acidizing the lateral, the well can not produce as well as it should. There are pressure activated tools that can get your coiled tubing back into the laterals and with different attached tools, cleaning or acidizing the lateral is very possible at reasonable pump rates. This paper will discuss how a tool works, the therory behind its use, case histories, successes, problems encountered and how to avoid problems in advance.

Drilling multi-laterals is becoming a preferred method to increase production from a single wellhead. Coiled tubing's role continues to grow as a well intervention system, but is limited in its capacity for selective entry into multi-lateral completions. Without a practical method to selectively enter multi-lateral completions to perform workovers and stimulation operations, these wells are not achieving their full production potential. A tool has been developed, tested and proven that allows CT to selectively enter each leg of a multi-lateral completion. The tool finds and enters the desired juncture or window and signals the operator at surface that it has done so. The Lateral Entry Guidance System is being used reliably for conventional CT stimulation or cleanout applications, and it has been adapted to run on the end of other specialized tools. This paper will discuss the tools development/testing and case histories of successful operations in the Permian Basin.

Multiphase Pumping has been gradually expanding its niche as a tool for coaxing additional production from wells. In the past it was seen as a discipline for saving capital costs, such as saving on additional subsea lines, or, in the case of Venezuela, reducing the surface treatment equipment needed to gather and move heavy, gassy crude. Today it has become a specialty tool that can lower back pressure of wells that otherwise have difficulty in producing into established production systems, or it can be used in conjunction with other down hole methods to optimize gas lift, jet pumping, and even augment the performance of PCP or ESPs. Confidence has grown among the users as they have learned how to apply this equipment effectively. This paper defines common terms used when sizing and applying multiphase equipment, and briefly describes the types of pumps available today, including the new reciprocating types of pumps that have met with recent successes. Some of the new techniques and applications are described along with considerations to keep in mind when installing such systems.

The competitive position in which oil companies now find themselves -- with other energy suppliers as well as in their own industry -- has demanded that they deliver, to the market, oil products as efficiently and cheaply as possible. This position has required a look at all phases of the industry: exploration, drilling, production, transportation, refining, manufacturing, and marketing. One factor which has received considerable study and development has been multiple zone completions. Because of its normal application in producing oil, hydraulic pumping has many desirable features as applied to multiple zone completed wells, when artificial lift is required. This paper will discuss some phases of this application.

This paper will provide a comparison between multistage horizontal pumping systems and reciprocating positive displacement pumping systems. We will compare their applications, costs and advantages and disadvantages.

A new surface energy mechanism, based on recent joint industry-university research using nanoparticle dispersions (NPD) is now available to the oil and gas industry, and is being laboratory and field tested for improving stimulation fluid recovery, remediating wellbore damage issues such as paraffin, waterblock and deep induced imbibition, as well as for enhancing the recovery of oil, gas and water following their application by a variety of intervention methods. Also being readied for implementation, is the use of NPDs to provide increased hydrocarbon production
and injection efficiency from waterflooding and other improved hydrocarbon recovery operations. Increasing injectivity into saltwater disposal wells (SWD) has been accomplished in beta test field trials. Graphic experimental demonstrations of these mechanisms will be shown and discussed, with emphasis on their current and potential field treatment applications, and with comparisons to another successfully utilized additive technology.

A net oil meter has been developed that provides accurate measurement of the water and oil fractions and production rates of oil/water emulsions. The net oil meter incorporates integral mass flow rate, density and temperature measurements in a single package, coupled to a powerful microprocessor based transmitter. This transmitter is designed for easy installation in the oil field and on off-shore platforms. The net oil meter provides both improved productivity and precision. The equipment simplifies net oil measurement with more results, and includes automatic well testing. Calculations are obtained for the following: % water cut emulsion flow rate water flow rate oil flow rate total oil production total water production test time total emulsion emulsion density temperature The net oil meter operates on the basis of the Coriolis principle. The basic flowmeter and theory of operation is discussed below.

Past field history has proven the effectiveness of internal plastic coatings as a primary tool for the control of corrosion in secondary and tertiary recovery programs. In recent times, new coating materials have been developed that have been found to enhance the previous performance of coatings by providing materials with greater flexibility and impact resistance. This paper discusses the basics of these new materials as they apply to the various corrosion mechanisms found in enhanced oil recovery. In addition, current industry standards for the application of internal plastic coatings is discussed in detail, including recommended field handling procedures.

Efficient oil recovery by waterflooding requires that certain fluid and reservoir properties lie in an appropriate range. The mobility ratio of the oil being produced to the water being injected is one such parameter which fortunately can be adjusted by one technique or another to obtain satisfactory recoveries. The most recent technique for adjusting the water oil mobility ratio is to dissolve small amounts of a water soluble polymer in the injection brine. It has been found that very small quantities of polymer greatly reduce the mobility of injection fluid thus increasing oil recovery. The increased recovery is due to a more effective sweep of the reservoir and can be quantitatively predicted in advance of the flooding operation. Laboratory and field tests of the process have previously been reported. lf the present discussion concerns the new commercial applications of this process.

Injection profiles of West Texas waterflood projects have been improved by the application of sequential zirconium complexed polymer treatments. Alternating stages of polymer and a new zirconium complexor were applied using specially designed skid mounted injection units. These units automatically monitor waterflood rate and adjust chemical pumps to maintain constant chemical concentrations. A small scale injection unit has been built to imitate the larger unit. This unit enables on-site, pre-treatment adjustments to design concentrations, to account for the effects of injection water variables. Mechanisms behind sequential metal complexed polymer treatments are discussed, along with field variables which affect these mechanisms, and the advantages of the new zirconium complexor. Treatment design theory is presented, as well as the change from theoretically to empirically based job designs. Design of the skid mounted injection unit is described recording capabilities, the automatic tracking feature, and shut-off controls, including monitoring and pressure activated Field results of 100 sequential zirconium complexed polymer treatments are summarized, with results of three treatments presented in detail.

A compact cyclone multiphase meter (CCM meter) developed by Statoil and Kvizrner Process Systems utilizes a compact gas liquid cyclone to separate liquid and gas, before individual measurement of the two phases by conventional single phase instruments, followed by re-mixing downstream of the measurement section. The most unique feature of this cyclone is the simple control scheme which provides for large turn down ratios. The instrumentation has been implemented into the water cut analyzer electronics to provide for a complete stand alone system. Field test data will be presented along with its impact on reservoir management.

Variable Speed Drive technology has been adapted to work with rod pumping to increase run life, decrease failures and reduce operation costs. This paper will show the technology being used and show several examples of systems installed and the benefits from this technology.

Each year more and more wells go on the pump. The Oil and Gas Journal predicts that in 1957 over 29,000 wells will be placed on artificial lift. In addition, this publication comments on a trend of a 7% increase in the number of wells put on the pump each year. The decision of whether or not to place a particular well on the pump is based entirely on the economics involved. This evaluation includes estimates of the expected production, the cost of the equipment needed, and the expected annual maintenance costs. Many of the components on a pumping unit have been studied and annual costs have been estimated, based on loads, bearing size, gear-face width, and so on. One component which has previously defied attempts at prediction of annual costs has been the V-belt drive.

The steel API sucker rod connection design used in beam and progressing cavity pumping systems has been an industry standard since the 1920"s. During these many years of continuous use, improvements have been made both large and small, yet this three part connection system is responsible for the majority of rod string connection failures. After 31/2 years of development, we now bring to the industry a new API modified four-part design with a method and system for precise make-up which expands load bearing capabilities and extends the working life of sucker rod connections. This paper describes development and testing work performed, information acquired, systems and methods created, and how the new API modified connection solves problems, eliminates or greatly extends time between failures, keeping work over and associated costs to a minimum. {See Figure - 1 }

Carbon/Oxygen (C/O) logging applicable in cased wellbores measures energy and intensity of inelastic and capture gamma rays resulting from pulsed neutron irradiation of subsurface formations. Continuous C/O logs therefore define the relative abundance of elements, such as C, 0, Si, Ca, H, etc., which in turn relates to lithology, porosity, and hydrocarbon saturation distribution in potential reservoir rocks independent of formation water salinities. Basic concepts and environmental correction will be reviewed with special emphasis being placed on practical field experiences both in sandstone and carbonate reservoirs. Such field applications include exploration for bypassed oil in old wells, location and monitoring of oil in low or unknown formation water salinities, monitoring sweep and displacement efficiency of waterfloods and EOR projects, residual oil determination, evaluation of heavy oil and tar sand reservoirs, etc.

To anyone who has been associated with the operation, selection, or purchasing of production equipment over the past 20 to 30 years, it is obvious that in the beginning oil producers made money in spite of operating equipment, and methods, rather than because of them. In the very early days of cable tool rigs, the well was drilled and pumped with the same engine, and surface equipment. Upon completion the rope, jars, and drilling bits were pulled out, and sucker rods and common barrel were installed. Very seldom, if ever, was any type of counterbalancing used. It was thought that if erratic motion of the walking beam was good enough to drill the well, then it was good enough to produce it. Of course, even with such crude and unsuitable equipment producers were able to sell of the oil they could produce at prices as high as $5.00 per barrel. Naturally they made money. With the advent of proration, deeper wells, taxes, engineers, and banks, in to the production field it became necessary that close attention be paid to the equipment used so as to produce the well efficiently. Only in this way could the loan be paid off, the taxes kept up-to-date, and a little profit left for the man who had stuck his neck out. At the present time production equipment is pattern, which has been decided upon after thorough consideration of many, many, factors affecting economics of oil production. In order to discuss new developments in pumping it is only proper to begin with the bottom hole pump because this is the item of equipment that starts the cash register ringing for the producer.

Along with the development of new tools there are continuous improvements of existing tools and techniques. It is the purpose of this paper to review some of the new radioactivity tools that have been developed and also review some of the existing tools that have undergone significant improvements. The following major subjects are discussed: The casing potential profile, the densilog, small diameter radioactivity instruments, radioactivity tracer injector, and the perforating-formation collar chart. The interpretation of radioactive tracer surveys and porosity determinations from the neuron curve will also be discussed. Because of the number of subjects covered, the explanations are brief and confined to the theory of operation, the significant improvements, results obtained and the advantages to be derived from their use.

Over 400,00 oil wells are now produced by rod drawn pumps. These vary in depths from "post holes" of less than a hundred feet to some of the deepest wells drilled, where the setting depth of the pump may be as much as 12,000 feet. The volume output of these pumps is just as varied as their setting depth. It may range from less than a barrel a day in small stripper wells to more than 2,000 barrels a day in wells where large bore pumps and high operating speeds are employed.