A basic decision faced by all oil field investors, since reserves are continually being depleted through production, is to either add reserves through drilling, enhancement and/or acquisition, or go out of business. The data available on finding costs indicate that it has usually been cheaper to buy rather than drill for reserves in recent years. This comparison may be distorted since the true finding cost is not known until the discovery is fully developed, which usually takes years. However, it is obvious from the data that the current decision is normally to buy, not drill. Hence, the drastic drop in rig count continues, while the number of acquisition transactions continues to be strong.

Electric Submersible Pumping Systems are being specified more frequently as the means of artificial lift for both new and existing wells. With this increased use, many operators may not understand the proper selection, installation, operation, maintenance and troubleshooting related to the Electric Submersible Pumping System. This understanding is important in assuring a successful Submersible Pump operation. The purpose of this paper is to give an overview of some of the recently published Recommended Practices on Electric Submersible Pump installations and also to comment on additional work currently being done in this area.

In recent years, the use of foam has proven to be successful in drilling underpressured formations where conventional drilling fluids have been unsatisfactory. On the E. 0. Reed Well No. I-A, foam was successfully used by Getty to drill and complete an underpressured formation at a depth of over 22,000 ft. This presentation includes a discussion on the background of the E. 0. Reed I-A and how foam was selected as a drilling fluid. Also discussed are foam characteristics, foam components, planning and design considerations, foam drilling operations, results of the well completion and conclusions of this study.

Failure control is a critical path to optimizing operations in today's petroleum industry. Failure control in its simplest form is failure analysis with the goal of achieving corrective action. Accurate records and meaningful reports are a key part of any failure control program This paper is the third in a series involving the data gathering and processing system used by Atlantic Richfield to optimize production operations and discusses the new PC system version. Application is demonstrated by identifying some rod pumping problems, suggested solutions, and results.

A full-scale, transparent, laboratory, instrumented sucker-rod pump has been constructed to aid in designing a downhole, instrumented pump. The laboratory pump has demonstrated that key to the understanding of sucker-rod pumping is compression-chamber pressure. Laboratory data will be used to demonstrate real-time analysis techniques that will be used with the downhole, instrumented pump to differentiate between a gas-locked or a pumped-off well using compression-chamber pressure. For a gas-locked well, the pressure is symmetric between the upstroke and downstroke; where as, for a pumped-off well there are high and low pressure plateaus when the valves are open. A method will be demonstrated to determine sucker-rod pump fillage by cross plotting (Pressure)-1/r versus stroke (g is the heat capacity ratio). The intercept of the compression line and stroke gives pump tillage. Theintersection of decompression and discharge pressure can be used to determine the residual gas trapped between the standing and traveling valves at the end of the downstroke.

The oilfield has long been known for doing things "the way we have always done it". This approach can change dramatically using new technologies and analysis methods. New technologies and analysis methods can be used to determine what is wrong with an artificial lift system; the operator no longer need to assume and take action based on a faulty assumption. Fluid level data is acquired throughout the patch, only proper analysis and use of the data allows the operator to exploit the well to its fullest potential. Typically dynamometer data is not requested until an operator has pulled and replaced the pump with no improvement. Acquisition and analysis of fluid level and dynamometer data can be used to determine if: 1) the well is producing to its maximum potential, 2) the down hole pump is operating as expected.
Examples well data collected on various wells will show opportunities for improvement, more production, more effective operation and fewer pulling jobs.

A common error in utilizing gas lift as a means of artificial lift is the failure to properly analyze the completed installation. This, of course, has resulted in low efficiencies, and poor operations. Quite often the operator finds that excessive gas is being used or that production is low on a particular lease. However, it may be that a complete analysis of required injection gas has never been made. A common tendency for the field operator is to increase injection gas rates in an attempt to move more oil from the well. This may actually result in decreased production.

This paper presents results from a study to analyze the performance and failures of the sucker rod/sinkerbar string used in beam-pumping operations through metallography, structural finite element analysis, and detailed failure data collection. Metallography has demonstrated that the microstructure of the steel bar stock needs to be considered to improve the fatigue resistance of the sucker rod strings. The current specification based on tensile strength, or yield strength, may not be appropriate since failure occurs because of fatigue and not yielding, and tensile strength is not always a good measure of fatigue resistance. Finite element analysis of the threaded connection identifies stress and fatigue concentrations and quantitatively assesses the performance and failure of coupling designs under a variety of loading. conditions. Subcritical fractures observed in the metallography are also suggested by the calculated stress distribution in the threaded coupling. Failure data illustrates both the magnitude and frequency of the failures, as well as categorizing the suspected cause of failure. This detailed failure information alone can reduce failures by indicating specific problem areas where focused action can yield immediate results. Application of the results in each of these project areas is expected to yield improved choice of metal bar stock, thread design, and make-up practices which can significantly reduce the frequency of sucker rod failures. Sucker rod failures at the rates observed today are not inherent in the process, but can be minimized through the application of new technology and observation of common-sense practices.

This presentation discusses the major types of packaged vapor recovery techniques and their application. The bulk of the paper is concerned with methods of analyzing the economics for installation of each method.

In recent years, a mathematical technique has been developed to analyze pumping-well performance using a digital computer to determine load-displacement conditions at the downhole pump and at intermediate depths in the rod string. Subsurface dynagraphs generated by the computer program are used to evaluate: pump intake pressures; gas interference or fluid pound; mechanical malfunctions in the pump, packer or tubing anchor; stresses at junction points in tapered rod strings; to name a few applications. This paper describes the analysis of the subsurface dynagraphs and discusses several case histories where the technique has been successfully applied.

Methods for analyzing gas well performance are presented. Inflow, outflow, and tubing performance curves are defined and examples of each are given. The concept of "fIowpoint" and its importance is explained. How these gas well surveillance tools can be used to evaluate compressor installations and tubing size changes are covered. The determination of an accurate reservoir abandonment pressure is also discussed.

This paper addresses the widespread need of oil field operators to continually verity that wells are being produced as close to their optimum capacity as possible, and in the most cost-effective manner. The analysis is to be made based on data obtained at the surface without entering the wellbore and must yield an accurate representation of conditions that exist within the wellbore, at the bottom of the well, at the sandface and within the reservoir. As such it is not an easy task since fairly complicated processes are involved in the flow of gas, oil and water mixtures in wellbores and a number of operators are often confused by the apparently contradictory evidence which one may obtain. The objective of this paper is to present in simplified terms some of the basic concepts of well performance analysis and to recommend a procedure to be followed in obtaining, organizing and analyzing the data assisted by a user friendly software program: AWP98.

Analyzing well performance is an important step toward increasing profits by improving production techniques. Generally the analysis is made by field observations and examination of well data. The acoustic liquid level instrument offers valuable supplemental information since downhole pressures can be determined from the depth to liquid measurement.

Three significant conditions existed in the oil industry in 2000. First we had the best oil prices we had seen in years, second we didn't know how long they were going to last and third many of the major oil companies were investing in overseas growth opportunities leaving less capital for domestic projects. Aggressive operators, with the ability to respond quickly, wanted to take advantage of the high oil prices by increasing production (make hay while the sun shines). Discerning operators wanted to hedge their spending on projects that would payout before the price fell back. Many major oil companies had to use only "expense" type funding for the short-term production enhancing projects.The Aneth Unit is a 320 well waterflood/CO2 flood in Southeastern Utah. This paper discusses how Reliability Engineering was used on the Aneth Unit to select projects that increased production, paid-out in six months, used no capital funds and required no increase in the annual expense budget. The paper is intended for field engineers, field supervisors and operations technicians. The paper will cover how we assembled a team to define a mission statement that accounted for the uncertain oil prices and the lack of a capital budget. The paper steps us through the Reliability Engineering process of brainstorming for ideas, culling and prioritizing ideas, defining and assigning action items and assessing results. The paper discusses how our prudent spending resulted in increased cash flow, increased earnings, improved return on capital employed, increased production and decreased lifting costs.

A review of the many types of gas anchors and their principles should be of interest to those who are concerned with pumping oil wells. The fact that free gas reduces pumping efficiency was discovered early on. An obviously better way to produce most such wells was to flow the gas up the casing annulus and pump only the liquids (oil and water). Some down-hole equipment arrangements were found to be better than others. As a result, many operators began investigating ways to improve pumping. A U.S. patent for a gas anchor was issued in 1881 to Crowley. Many more patents on gas anchors have since been issued; however, not all of them necessarily increase pumping efficiencies. The name "gas anchor" is a misnomer -- it is actually a down-hole gas and liquid separator. There are many types and their use is often misunderstood.

We will look at the advantages of the vee-wire sand screen, which is a well known as well as popular in the filtration industry. It is easily adapted for down-hole rod pumps. We will look at it use on the Pump itself as well as it's use on the tubing. In rod pumps it is used in replacement of the gas anchor, which can reduce sand failures by eliminating the heavier frac sand from our production tubing. The Vee-wire screen can be manufactured in different lengths, sizes and slot sizes.

A new type of anti-biofoulant corrosion inhibitor (ABF) has been developed that lays down a unique, smooth film that resists the adhesion of sessile bacteria and iron sulfide, thereby reducing the formation of biomass that initiates under deposit corrosion cells. This inhibitor, formulated with special surfactancy, can help penetrate existing biomass and lay down an inhibitor film. The ABF corrosion inhibitors coupled with a practical methodology can control corrosion due to sulfate reducing bacteria.

If gas and particulates (sand & iron-sulfide) are becoming a problem for your API Pump, consider the rugged Two- Stage Hollow Valve Rod Pump. Which is the most popular and successful pump ever produced. This pump has several benefits and can be designed for numerous pump configurations. This paper will give a basic understanding of the sequence of operation of the Two-Stage Hollow Valve Rod Pump and its application.

Presents latest API standard 11E. Explanation is given of ratings on structure as well as gear reducers. Design considerations and safety factors included in current designs are presented.

American Petroleum Institute (API) proposed Recommended Practices (RP)' present standards of performance to be used in testing of floating equipment that is used in oil and gas well completions. Extensive laboratory testing has been done following API proposed procedures. Testing at levels beyond API standards have also been accomplished. A paper has been prepared to present data resulting from API tests conducted. Procedures used and test results gained from testing at more stringent standards are also presented. Data reported include (1) impact and pressure force tests exerted through the cementing plugs to floating equipment, and (2) flow tests in which a large volume of lost circulation material was passed through floating equipment. Subject paper also presents statistical data from an extensive body of cementing work performed in domestic operations in the United States. Many pipe sizes are represented in this information. Data include pipe size, flow rates, circulation times, and cementing times. Results presented justify the need for and the severity of the standards in the API proposed RP.

The successful application of threaded and coupled rods (i.e. sucker rods, drive strings, etc) to provide power to lift downhole fluids is critically dependent on using proper makeup procedures. This is applicable whether the pump is a reciprocating, positive displacement, subsurface pump or a rotary driven, progressing cavity pump. Torque by itself has been discredited with being able to provide consistent connection pin preload stress or pre-stress due to a variety of factors related not only to the setup procedures but also due to the equipment that is used to provide the power to the power tongs. This presentation will review the various parameters that affect proper connection pin preload and provide a discussion of the new revisions to the industry's API recommended practices for sucker rod driven pumps as well as newly developed draft recommendations for progressing cavity pump installations.

This paper discusses the techniques used to size available submersible pumping equipment to pump in a variable speed, constant head mode. Effects of variable speed, constant head operation on the pump and motor are described with their relation to optimum system performance. Energy-usage calculations for a conventional, constant-speed submersible pump and a variable-speed, constant-head submersible pump are compared. Finally, the economics of the variable speed submersible system are analyzed.

While not applicable to all existing well conditions and requirements, submersible pumps, properly selected and applied, offer a useful tool to the oil industry. Ultimate economic efficiency

A non-intrusive flow meter which directly measures mass has been commercially available for seven years. This meter, sometimes known as a Coriolis or gyroscopic flow meter, measures the force imparted to a vibrating tube by the mass of a fluid as it passes through the tube. This allows the measurement of mass flow without compensation for fluid properties. This paper will present the operating principles of this device and its applicability to the measurement of carbon dioxide, with methods and techniques for mass calibration.

The Mesa Verde formation is highly naturally fractured and varies in depth from 5500" to 6200". Low recoverable reserves make wells in this area marginally economical. The lower hole is air drilled and cemented back to the intermediate at 3700 feet. Historically, the production casing has been cemented with a 50/50 Poz/H blend mixed at 13.2 ppg. Bond logs were often marginal and fall back was a problem. This paper reviews the development of a lightweight cement system with the ability to develop high compressive strength to enhance the mechanical seal. This slurry needed to have plating lost circulation material (LCM) to prevent fall back and minimize node buildup due to high fluid loss. Compressive strength, fluid loss and rheological properties for various formulations are presented. The results of over forty jobs are summarized with operation and bond log results reviewed in detail from two typical wells.