Operating costs are but a fraction of the price per barrel of oil or cubic feet of gas we sell. In sucker rod pumping, this fraction is extremely critical and can quickly mean the difference between gain or loss to your company or yourself. Your wage or profit is derived from operating expense and gross income; therefore, it behooves each of us to properly manage operating costs so that the returns will not only come to our company but also to ourselves. A constant program of well analysis employing understanding, prudent practices and applied techniques is necessary. Presented herein is a program of managing pumping wells with case history results. Even though, a specific program is discussed, it will apply with certain modifications to any company.

The control of pumping well failures at an optimum level requires access to equipment failure and maintenance records which adequately describe performance. It is necessary to know where failures and maintenance are occurring, what equipment is involved, the location and cause of failure, the nature of maintenance and costs. Problem wells can thus be isolated and corrective measures initiated. Further, it is possible to evaluate new materials, producing practices and inhibition methods to generally improve the performance of downhole equipment in all wells. Electronic data processing is a means of providing operating personnel with a complete failure and maintenance record in a form which permits accurate, continuous analysis of equipment performance.

This paper contains a brief description of the component parts of submergible pump to wells of various conditions is discussed. Operation results are reported for both oil wells and water supply wells.

In these days of budget constraints due to unstable oil and gas prices, many companies have begun purchasing more and more used production equipment, including pumping units. In some cases they have been able to reduce "up-front" capital expenditures only to later find that there can be significant costs in repairs to this same equipment. This paper will examine the precautions and considerations that should be made before the purchases are finalized. We will review what we consider the six (6) major areas of concern: 1) the age and history of the pumping unit, 2) the gear reducer, 3) the unit's structural integrity, 4) the structural bearing assemblies, 5) additional equipment included in the purchase and, 6) the reputation of the used equipment supplier. While we recognize that there are many used equipment dealers supplying quality reconditioned equipment, the purpose of this paper is to educate the buyer about what to look for when preparing to make this capital expenditure.

In order to get the maximum benefit from dynamometer well studies, it is essential that all of the factors involved in the pumping problems on each individual well be viewed as a complete picture. Each factor involved should be brought into focus and fitted into the picture as a whole. Fig. 1 illustrates a mechanical polished rod dynamometer.

A successful approach to oil and gas reservoir development requires knowledge of reservoir fluid
properties. It is therefore essential to determine the fluid's Pressure-Volume-Temperature (PVT)
behavior in order to obtain the necessary parameters for proper reservoir management as well as satisfy
regulatory classification requirements. Experience has demonstrated that PVT data obtained in a
laboratory is the preferred approach to fluid property description. When laboratory data are not available, correlations or equation of state computations are often used to estimate reservoir fluid behavior. Correlations are approximations to specific regional properties, and untuned equation of state calculations can produce erroneous results. Using case histories, we compare the inherent limitations in the calculated approach to PVT data derived from laboratory studies, and re-acquaint reservoir engineers with field sampling procedures, laboratory testing, and data analyses.

This paper presents a computer based tool for those wanting to use the wave equation in their beam pumping design activities, but do not require the needs of a more sophisticated, full featured program. This program properly handles the problems faced by a person responsible for designing what could be termed normal rod pumped installations. The output of the program includes pump size, rod string, surface unit size, and motor size for an input depth and production rate. The author has found that accepted design practices are not used much of the time. Whether it is because they are too cumbersome and time consuming or that acceptable knowledge about proper design procedures are not widely understood, I do not know. The objective of this software is to help the designer implement state of the art beam pumping design technology without getting buried with details. The program is a WindowsTM program requiring Windows 3.x and a 386 class computer or better. All important input and output information is available on a single window displayed for the user. More detailed information including graphs may be optionally displayed. It uses a rapid solution method to the damped wave equation allowing the user to see immediately the effect of changing a parameter such as tubing anchor, stroke length, stroke rate, and pump diameter. Correlations are used for the motion of conventional, Mark llTM and air balanced units. allowing the program to determine the size of the pumping unit required. Tapered rod strings (API taper) and Fiber Glass Steel combination strings are allowed. A full featured context sensitive help file is available to the user. This means that whenever the main screen is active you can get help by simply pressing it. The program is suitable for use on a desktop or laptop computer with or without an attached printer. Provisions are made for results to be saved to files for later examination.

The major portion of domestic oil is produced by rod pumping systems. Of the total 527,000 domestic oil wells 403,000 are rod pumped. In 1971, $157.5 million was spent for labor and material for downhole repair of these wells. This amount does not include production losses while the wells were being serviced. In that the average pulling job cost was $418.63l it is possible that the production losses exceeded this direct maintenance cost. When the total cost for maintenance and the volume of oil produced are considered, it is evident that even a small decrease in maintenance or a small increase in producing efficiency can have a significant economic impact. This paper considers the development of a new concept for controlling and monitoring rod-pumped oil wells. The development of the hardware and the techniques for implementing the concept are an integral portion of the consideration.

Field performance of plastic coated tubular goods is directly related to the following critical factors: 1- Metal cleaning and surface preparation 2- Adhesion between coating film and metal substrate. 3- Proper curing of the coating film. 4- Continuity and uniformity of the coating film. This paper deals with the various quality control techniques that are used to assure that these critical factors are controlled within specified parameters.

The determination of the correlation between petrophysical data, and core data is essential in the determination of reservoir rock properties. The goal of this study was to design a computer algorithm, which will use the geophysical inverse theory to deduce different reservoir facies, from well log responses, by utilizing statistical relationships between the well logs and core derived lithofacies information. In most oil and gas fields only a minority of the wells are cored. As a result, determination of reservoir rock properties is mainly dependent on the interpretation of geophysical log data. An objective approach to analyze well log data to determine the reservoir rock properties, would speed up the interpretive process and would also enable the researcher to correlate information between wells and incorporate a-prior knowledge into their interpretation. Detailed core and petrographical analysis was conducted as the first step in establishing statistical relationships of lithological data from four cored wells. Petrographically sixteen major rock types (lithofacies) were identified. Secondly, a valid forward model, which is a requirement in any successful inversion process, was constructed by the usage of mathematical formulation of well logs, and the petrographical data obtained from cores. Well logs used for this study include Neutron, Spectral Density including Bulk Density and Photoelectric Absorption Index (Pe), and Borehole Compensated Sonic (Interval Transit Time) logs. A unity constraint was also used as a supplementary log data. Thirdly, an inversion method, which can incorporate the results of core analysis and petrographical information as apriori geologic information, as potential constrains in the inversion itself was determined. The facies observed between wells in a given oil and gas field are related to each another. Therefore, using the a-priori information from the cored wells, with reservoir facies control, to determine if results from selected well(s) can provide lithofacies information in the remaining wells would improve the reservoir management efforts. An inversion algorithm, using a-priori geologic information was tested on four cored wells. Inversion method was tested for different a-priori geologic information cases where the examined facies were grouped in sixteen, fourteen, eleven, and five lithofacies classes. The robustness of the inversion results was found to depend on the a-priori information provided. Lithofacies inversion, using five lithofacies classes, showed reliable estimations for the purpose of depicting possible reservoir versus non-reservoir zones. The method used was also able to reliable identify most of the eleven facies classes. Inversion, using sixteen and fourteen different facies, showed to be a valuable tool in determining the gross lithology.

New methods for quantifying pump leakage are described. These methods extend the effectiveness of dynamometer analysis and can lessen the dependence on well tests in determining the degree of pump leakage. Actual examples are included to illustrate the techniques. A detailed description of traveling and standing valve leakage checks is also included.

Environmental stewardship has been and continues to be a critical component of the oil and gas industry, as exploitation of shale and other unconventional gas reservoirs requires large volumes of water for economic and efficient production. Evaluating and communicating the hazards of chemicals is done in a highly variable manner across the world. However the recent adoption of the Globally Harmonized System of Classification and Labeling of Chemicals (GHS) by multiple Global regulatory bodies has brought international consensus to hazard criteria and definitions. This system is being implemented with REACH in the EU. In the US OSHA has just proposed the GHS criteria as the basis for modifying their hazard communication regulations. This standardization ensures information about hazards and toxicity of chemicals is more universally available, to enhance protection of human health and the environment during handling, transportation and use. It is this scheme that we are beginning to utilize as the basis for the ranking of products and systems. This paper will describe the evaluation and implementation of a practical and quantitative process of ranking well servicing products based on their safety, health and environmental impacts. The ranking allows operators to select and use products that best fit their environmental stewardship goals, and provides scientifically sound tools for better research and development, and educational efforts.

The author describes factors contributing to poor water conditioning practices and the problems which have resulted.

The questions and issues surrounding sucker rod connection integrity and its effect on well failure rates has been around as long as the sucker rod itself.

Bosch Rexroth is a manufacturer of hydraulic drive systems and components including power units, cylinders, and electronic controls. The R7 pumping unit is a specially designed hydraulic artificial lift system for crude oil pumping or natural gas dewatering applications. It can be used in applications with rod loads between 15,000-35,000 lbs, and stroke lengths up to 236 inches. It consists of a hydraulic power unit, which is driven by an electric motor, and a hydraulic cylinder, which stands vertically on top of the well head. The power unit also contains an electrical control cabinet with a PLC and an operator touchscreen to input control parameters to the system. Additionally, the power unit contains a
mechanical flywheel, which is mounted directly on the shaft of the electric motor and is used to recover energy during the pumping process

Shortage of oil, rising prices and increased difficulty and expense in finding new reserves make it imperative to investigate techniques for further stimulation of wells, particularly wells with large open hole sections, or wells with poor cement jobs. With this in mind, a method was investigated that resulted in the control of the placement of stimulation fluids through the use of radioactive tracer material and Gamma ray detectors, which provided instant and continuous knowledge of the zone of entry during the entire stimulation process. This placement technique insures all zones of interest are stimulated without stimulating water bearing or other undesirable zones.

Detailed study of a field in the Slaughter area of Hockley County resulted in increased original-oil-in-place (OOIP) as compared to an earlier estimate from an internal company report (1975). An important aspect of the study was the inclusion of well logs drilled after the earlier estimate of OOIP. Log-core transforms for Compensated Neutron Logs (CNL) and Sidewall Neutron Logs (SNP) and Sonic logs were constructed. Three Old Neutron (ON) logs were normalized to improve the spatial control of the field. The normalization of the ON logs involved the correlating of the ON log data to a modern neutron log (CNL/SNP). Availability of more data made it feasible to obtain more accurate reservoir parameters for the field that was developed in 1930"s.This paper describes the methodology involved in the construction of the geologic model to calculate the net pay, average reservoir porosity, permeability and water saturation. The OOIP was calculated using the isovolume and parametric averaging methods. The OOIP was increased by two folds from the earlier estimate, but only 63% of the OOIP was movable.

For years we have known that "Long and Slow" is considered a Best Practice for rod pumped wells and that continuous running is best for ESP"s. In a perfect world we would have the ability to slow down or speed up a pump unit or ESP to match fluid inflow and to vary the speed of the up and down stroke of the rod pump system to minimize rod buckling. In reality, we design a rod pump system for 80 to 85% run time and minimize pump off pounding with a POC. Our ability to do this is often limited by pump unit or sheave size. Fluctuating production results in high fluids or cycling of the artificial lift system. For ESP's we usually adjust the operating frequency based on monthly fluid shots. The industry recently took a step toward that "Perfect World" with Adjustable Speed Drives (ASD"s).

The Upper Devonian Woodford Shale ranges from a thickness of 0 ft to 300 ft and is found at depths of 7,000 ft to 18,000 ft in the Delaware Basin. The Woodford is thermally mature over its entire extent in New Mexico: In the deeper parts of the Delaware Basin it is in the thermogenic gas and condensate window; on the Northwest Shelf and where present on the Central Basin Platform it is in the oil window. Southeastern New Mexico is subdivided into Regions I, II and III based on the intensity of the fracture networks, thermal maturity and Total Organic Carbon (TOC) (Comer 2005). Miller's (2010) gas shales ranking scorecard used parameters like total organic carbon, vitrinite reflectance, shale thickness, gas-filled porosity, clay content, quartz content, fluid compatibility, natural fracture intensity, tectonic stress and reservoir pressure gradient. The range of the scale of ranking is 0 to 100 points and for reference, the Barnett has 73 points. The better the total points, the better are the prospects of finding shale gas. Each of the regions (Regions I, II and III) were ranked for the prospects of shale gas using Miller's (2010) ranking scorecard and assigned a score of 68, 66 and 48 respectively. The results showed that Region I and II have better chances of finding shale gas. Finally an assessment was made to quantify the volumes of oil and gas in-place using Comer's (2005) Hydrogen mass balance method. The estimated volumes were 36 billion barrels of original oil in-place and 44.5 trillion cubic feet of original gas in-place (New Mexico) in comparison to 119 billion barrels of original oil in-place and 230 trillion cubic feet of gas in-place in the Woodford for the entire Permian Basin (Texas & New Mexico) (Figure 3). The assessment confirms that Woodford shale is a major unconventional source of both oil & gas in New Mexico.

One of the most helpful and convenient aids in the successful application of conventional beam pumping units is the American Petroleum Institute bulletin, 11 L-3, "SUCKER ROD PUMPING SYSTEM DESIGN BOOK". Expanding the work of Sucker Rod Pumping Research Inc. and the Midwest Research Institute, the API produced this set of tables (11 L3) containing literally thousands of different precalculated pumping options, or modes, generated by using a model of the wave equation applied to sucker rod pumping when using conventional beam units. These API tables have been widely accepted, and though certain sections have been questioned, and in some cases revised - in general, they have made a substantial contribution to the petroleum industry in facilitating the application of conventional pumping units. According to these tables, there are twenty API approved sucker rod sizes, eighteen approved stroke lengths, and ten different API plunger diameters. Thus, in lifting a given amount of fluid from a particular depth, with a conventional pumping unit, theoretically there could be some 3600 beam and sucker rod system options, or pumping modes, for a single, artificial lift application - not considering variation in pumping speed.

Reservoir simulation has typically been applied to only the larger and more complicated reservoirs. The cost of performing such studies in a Unix/Workstation environment is high and most fields are not analyzed using reservoir simulation. Highpower inexpensive PCs, and software with a powerful, user-friendly interface that does not require a simulation expert has changed the economics of performing such studies to such an extent that engineers and geologists are now using PC-based reservoir simulation to evaluate exploration plays on a teal-time basis. This paper documents the process and results of a study that involved mapping, gridding, geostatistics and reservoir simulation of an exploration prospect while the drilling rig was on-site. The paper demonstrates the feasibility of using PC-based reservoir simulation as a routine part of reservoir management, beginning with the exploration well.

The openhole drillstem test (DST) has changed little in the last 30 years; however, pressure-transient analysis recently has made significant advancements. Modern electromagnetic telemetry systems are the basis for an economical method of transmitting pressure and temperature readings in real time." Improvements in information technology now allow advanced on-site analysis. This paper provides an overview of an openhole test, describes the components used during real-time analysis, and discusses the case history for a real-time job in Andrews County, TX.

The experience gained from many years of computerized analysis of dynamometer records combined with very powerful portable computers, advanced modeling software, advanced graphical user interface and wireless datab acquisition systems allow the visualization of the operation of the rod pump in real time. The operator directly observes and determines at a glance whether the pumping system is operating efficiently or requires modification or remedial intervention. The majority of the analysis is performed automatically and does not require evaluation of numerical results by the user. When unusual conditions are observed the user has access to advanced tools that facilitate detailed diagnostic analysis.

The concept of predictive modeling for "What if?" and contingency analysis is well established for electric power dispatching. We are currently completing the first such system for gas pipeline network dispatching. The model accounts for fully transient flow of gas through pipelines and equipment. Based on flow forecasts, 16 hour predictions of pressure, horsepower, and fuel are made. The system continually tracks the SCADA data base so that the linepack distribution is current. In addition to answering "What if?" questions, the system supports risk analysis, leak detection, and strategy evaluation. The model can be used for pack and draft analysis, compressor fuel optimization, and operator training.

Sucker rods performance greatly impacts fluid lifting efficiency, and rod failure lead to lost production. Therefore, proper attention to the condition of new and used rod strings can assure optimum operating efficiency and reduce total production costs. The performance of the string depends on the proper integrity of each individual rod. These rods are subjected to severe operational conditions and down hole conditions such as corrosion, cyclic loading, and stresses which can ultimately lead to material break down. It is of utmost importance to investigate the condition of new and used rods to ensure the absence of stress raisers and manufacturing imperfections. Nondestructive testing (NDT) is used in this application. It will be our intent to show pictures of what defects we have found in new and used sucker rods. And not to point a finger at any rod manufacture. We will evaluate both manufacturing and service induced flaws in sucker rods and couplings. That would cause premature rod failures and thereby avoiding the time and labor costs associated with work-over operations.