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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.

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.

Balancing injection-withdrawal ratio on a pattern basis is essential in optimizing tertiary recovery projects, where high lease expenses tend to marginalize even the best of candidates. Advances in reservoir modeling techniques provide increasingly reliable predictions of long term field-wide production response; however, a gap frequently exists in supplying routine or short term individual well forecasts. This paper describes a simple allocation technique utilizing a modified version of Darcy's equation for linear flow within the setting of a field-wide pattern network.

Operating electric submersible pumps in a CO2 flood is challenging and requires applying new engineering and operational resources to be successful. Extremely high GLR"s, radically changing bottom hole pressures and changing fluid densities require more than just conventional methods for operating and troubleshooting ESP"s. An integrated control system was used to troubleshoot well conditions that consist of high concentrations of CO2.

By arranging the geometry of the beam type oilfield pumping unit as a non-symmetrical front-mounted lever system, it is possible, in most cases to fit more closely the counterbalance torque pattern to the well load torque pattern, with significant reductions in peaks. This system results in a relatively uniform loading of both prime mover and gear reducer; the loading in turn allows the operator to handle many applications with smaller equipment and reduced first cost.

The technology associated with the use of carbon dioxide as a component of oilfield stimulation fluids has evolved dramatically since its introduction in the early 1960's. Technology improvements in the mechanical, chemical, and applications areas will be discussed herein. This paper will be introduced with a brief review of the chemical and physical properties of carbon dioxide which are the basis for the utilization of CO2, in the stimulation industry.

MWD services have been commercially available for over ten years. The most entrenched application is that of directional services, where conventional methods such as wireline steering have all but been obsoleted. The only real advances in this application have been those influenced by software changes and data rate improvements. For example, faster tool face update rates while steering are now possible. A relatively recent sensor is one that provides weight on bit and torque in real time. The currently intended applications are estimation of bit wear and bearing failure.

From the earliest days of West Texas drilling, produced brines have been readily available. Drillers quickly realized, even in the early days, the advantages to be gained from drilling with clear brine. Today, good quality brine is conveniently available to most parts of the Permian Basin at a delivered cost of 25 cents to 50 cents per barrel. The advantages of using clear brine as a drilling fluid have been adequately documented.

In recent years the development of refractory materials has proceeded at a much faster rate than the ability of industry to utilize them effectively. This paper will discuss in detail some of the more interesting of these compounds, their potential for the petroleum industry and a process by which they may be uniformly applied to the surface of any object.

Use of liquefied gases as fracture fluids has been a commercially available service for more than a year and both results and experience have helped dictate new developments and define candidate reservoirs. Designed originally for gas well stimulation, the new service uses a fluid made up of liquefied CO2, LPG and methyl alcohol. The liquefied gases are mixed in such a proportion that they remain a liquid and behave as a liquid as long as they are under adequate pressure and below the critical temperature of the mixture.

This paper discusses the latest equipment and software developments in wellsite drilling monitor systems. Included is a discussion of data collection and analysis by on-site computer. Specific emphasis on data analysis for drilling optimization and pressure detection in hard rocks is presented. New analytical tools, such as mud temperature and conductivity logging, are discussed, An economic analysis of data collection units gives the operator a basis for judging the merits of available services.

A sound velocity sensor is described as a means for detecting interfaces between different hydrocarbons in products and crude oil pipelines. Temperature and pressure influences are described as systematic error sources that are amenable to automatic compensation by a microprocessor. The utility of the sonic technique is assessed for detecting difficult interfaces between hydrocarbons of similar API gravities and for those interfaces where substantially different gravities prevail. A new development involving a combination sonic interface detector and sonic flowmeter is also discussed.

This paper discusses the development and use of polyelectrolyte's as broad spectrum coagulant aids and/or coagulants in the clarification of oil field waters.

Many papers have emphasized the problems of obtaining efficient mud displacement by cement, causing channels, annular gas flow and other problems. Mud displacement in liner cementing is more difficult than in full-string cementing because of several factors. Some suggestions for obtaining better results in liner cementing through, the use of newly-developed rotation equipment are presented in this paper. Tools designed for these types of jobs are shown and recommended procedures given.

Since the first foam fracturing treatment in approximately November of 1974, great strides have been made in both the technology of foam per se and the equipment to handle same. Countless numbers of papers, presentations and patents have been presented. A sampling of these is listed in the bibliography of this paper. The early foam fracturing treatments were conducted using water, foamer, and nitrogen injection trucks. The treatments were small and sand concentrations quite normally did not exceed two to three pounds per gallon downhole.

The recirculation electric submersible pump system was introduced to industry in 1995. Subsequently, the system's utility has been demonstrated in numerous installations; the vast majority of which have occurred in the Permian Basin area of west Texas / southeast New Mexico. The system can be used to: (1) minimize gas interference with the pump (2) maximize well drawdown (3) increase fluid flow past the motor in low volume wells, and (4) eliminate shrouds.

The routines of your daily work can be efficient only as they place demands on your lifting equipment that are in balance with its mechanical and metallurgical design. You of the petroleum industry who are engaged in artificial lifting do specify equipment. If your demands exceed its abilities, unfortunately you are then involved in an expensive servicing job and replacement of equipment. We should be able to mutually agree that you, in lifting, can do your job more easily and better if you understand the nature of your equipment

The difficulties in recognizing pay versus non-pay zones in the Permian Bell Canyon and Cherry Canyon sands in Reeves and Culberson counties are the result of: 1.) the presence of residual oil, 2.) the very fine grain size (Mz = 0.05 to O.10mm), 3.) the high Rw values (Rw = 0.15 to 0.25 ohm-m) and 4.) the presence of authigenic chlorite and mixed-layered illite-smectite clays. The fine grain size and the authigenic clays result in high irreducible water saturations.

Power to operate the unit is generally taken from the lines of public utility companies who furnish 3-phase, 60 cycle power at carious standard voltages. Where utility power is not available, an engine generator unit is used at the well. The motor, which is a squirrel cage, induction type, turns the pump at approximately 3450 R.P.M. Maximum motor horsepower ratings are controlled by casing size.

The downhole tubing caliper survey, as part of a preventative maintenance program, is an effective tool for reducing the number of future or repeat tubing failures that occur on rod-pumped wells. Preliminary field results of an investigation in the North McElroy Unit, Crane and Upton Counties, Texas indicate that downhole tubing caliper surveys may be the most economical and effective field method of eliminating worn or severely corroded tubing in a well and insuring against troublesome repeat tubing failures.

This paper describes a new tool and method for removing solids; such as sand, scale, and iron sulfide; from production fluids before the fluid's entry and passage thru a downhole pump. A downhole pump's life and efficiency may be significantly increased. Erosive wear and sticking of pump parts is greatly reduced. This new device, the "Sandtrap" Downhole Dasandar, is run on the production string below any type of downhole pump.

With more and more emphasis on reducing expenses for beam units, most operators are examining all areas to try to cut costs. One of the biggest costs in beam unit operations is the associated electrical charges. Examining the pumping units to determine and adjust to the optimum counterbalance will reduce the electrical bill. Several fields have been checked with a PC software program, which allows the operator to determine how far out of balance the units are and what it will take to properly balance them.

There are several ways that power consumers with large distribution systems can reduce their electrical cost. In this paper we will discuss two methods. The first method will be the application of capacitors and the second is the selection of the proper rate.

The downhole cushioning device can reduce fluid pound effects on sucker rod strings. The tool studied in this paper is compact and simple. It is placed in the rod string above the pump to absorb shock waves. This should help prolong equipment life and reduce operating expenses. The cushioning device uses a piston and sleeve that fill with well fluid. Fluid enters the chamber creating a buffer to absorb and dampen shocks. Field data available at present indicate the device to be effective. Case histories show a reduction in rod failures after installation in problem wells.

The need to effect water production through the use of relative permeability modifiers is becoming an everyday reality in the oil and gas industry today. Rising exploration and development costs, along with ever-increasing water management costs, require that cost-effective methods of reducing unwanted water production be developed and implemented. To address this issue, a new relative permeability modifier system has been developed. It is designed to be placed into the matrix of sandstone or carbonate formations.