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This paper discusses the information obtained from 22 mixed string sucker rod tests in sour crude (Arbuckle) production. The discussion includes field experience previous to the tests, reasons for conducting the tests, results of the tests and the benefits derived from the application of these data to field operations. The obvious advantage of mixed string sucker rod testing over other methods of sucker rod comparison is discussed.

This paper describes an Excel spreadsheet used to solve 3 challenging transient heat transfer problem for a well. A large number of unknown temperatures are solved numerically as a function of time on an R-Z grid. Time steps are controlled by a macro and the formulation is fully implicit for numerical stability. The situation modeled is hot oil injection into a well annulus in attempt to warm the tubing, thus melting wax and allowing its removal. Often the tubing is pumped while it is heating. Hot water or wax solvents are sometimes used in place of hot oil.

The most important feature of an inhibitor protection program is how well the compound used matches the method of introduction into the system. This paper discusses those features of corrosion inhibitor compounds which are important for protection programs in producing oil and gas wells, in water floods, in gas-gathering lines, and in fire floods. In the process, the discussions will include the pros and cons of heavy inhibitors, of inhibitors for mixed-water systems and mixed air-hydrogen sulfide systems, and of vapor-phase inhibitors.

As late as 1940, the method of pulling rods and tubing utilizing a horse-drawn single line over an A-frame mounted on wagon wheels, was in common use in shallow areas. For those who are not acquainted with this early operation we have provided an illustration to point out basically the simplicity of performance which has become a major part of our industry. One of the next steps in the progress of providing portable equipment to cover larger areas, was the Rumley tractor unit. This equipment served the Oklahoma, Eastland and the East Texas fields in the early stages.

Vogel's inflow performance relationship relates the flowing well pressure to production rate for solution-gas drive reservoirs. Because two-phase flow exists, the graph of bottom-hole flowing pressures versus oil production rate results in a curved line. This trend accounts for the decrease in production as more gas comes out of the solution. Vogel assumes the initial reservoir pressure is the same as the bubble point pressure for the starting point of the IPR curve. This implies no gas has initially come out of the solution, i.e. the reservoir is at bubble point pressure.

Over a number of years, the reference tool developed by Grant, White, Smith & Miller" and commonly referred to as "White's Injection Scale" has been widely accepted as a useful mechanism for planning and execution of cement squeeze processes in shallow and low pressure formations worldwide.

In rod pumping wells, the downhole data can be computed from the surface data by solving the one dimensional damped wave equation. Currently, the modified Everitt-Jennings method uses finite differences and an iteration on the damping factor to solve the one dimensional damped wave equation. The iteration on the damping factor allows for an automatic damping factor adjustment, which can be a valuable tool when dealing with large fields of wells. The damping factor pertaining to this method is a common damping factor for both the upstroke and downstroke.

Currently, API specs on 7/8" couplings allow for a wide variation in coupling face widths. The face width is critical when trying to achieve good rod makeup. For example, a larger face width is less likely to rotate due to the larger surface area i.e. more friction. As a result of the high number of rod pin-coupling failures, especially in the 718" section, a coupling with a more effective face width was developed.

Fiberglass sucker rods have proven to be an economical solution to many sucker rod beam pumping problems. Two important parameters that contribute to the effectiveness of FRP sucker rods are effective modulus of elasticity and fatigue life. Using established computer predictive techniques, it has been shown that FRP sucker rod installations can benefit from using rod designs with a lower modulus of elasticity. Fatigue life of sucker rods is an important consideration for any sucker rod pumped oil well, for both steel and fiberglass rods.

Money saving ideas can be initiated by the analytical study of a dynamometer card obtained from a pumping well. This is illustrated by presenting methods of calculating polish rod horsepower, peak torque, and volumetric efficiency from typical dynamometer cards obtained from wells in West Texas and New Mexico. A brief discussion of the basic fundamentals of a dynamometer card in relation to the pumping cycle is presented and followed by the analysis of cards that have resulted in money saved.

When the money requirements for drilling and production for the petroleum industry are considered, the sums involved are indeed staggering. According to information compiled by a joint effort of the American Petroleum Institute, The Independent Petroleum Association of America and the Mid-Continent Oil and Gas Association, the average cost per well in 1953, including drilling, casing, tubing, and well head connections, but not including tanks, flow lines, separators, treaters or other surface equipment, was approximately $78,700 for wells drilled in the Texas portion of the Permian Basin.

Pump off controllers have earned a place in the technology of rod pumping. Many methods exist for sensing when a well has pumped off. Most widely used are techniques based on the surface dynamometer card or motor speed or production rate. This paper describes several methods for sensing pump off using the downhole pump dynamometer card. These include areas inside of the pump card, areas outside of the pump card, set point and liquid fillage, among others. Procedures for calibrating the controllers are described together with provisions for high fluid level recovery.

Computer programs are being developed to identify wells that are not responding to the current chemical corrosion control program. Computer corrosion monitoring programs are a method to quickly and effectively process large volumes of data that are necessary to document changes in well conditions and chemical inhibitor programs. Decision support software is also being used to competently select corrosion inhibitors by correlating existing system parameters with a data base of inhibitors and their associated characteristics.

The monitoring of injection, disposal, and produced waters involves complex preparation, studies, evaluations, and interpretations. This paper presents the objectives and requirements of an effective monitoring program. Those aspects of monitoring that most frequently result in misleading data are covered and the means to prevent such data and misinterpretations that are drawn there from. The presentation is made of over 50 categories of conditions that deserve careful observation and consideration in a continuous monitoring program.

Because of the susceptibility of the Morrow Sandstone formation to fluid damage, improved completion techniques have been demanded by industry. A new look at old ideas has resulted in the development of unique procedures especially adapted to well completions in sensitive dry-gas sandstone reservoirs. In this paper is presented a historical account of the development of completion practices in Morrow wells located chiefly in Eddy and Lea Counties, New Mexico. Special emphasis is given to the Tubing Conveyed and the Maximum Differential techniques developed by Vann Tool Company.

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.

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 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.

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.

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.

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.

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.