SPE 67273

Total Well Management II

A Methodology for Maximizing Oil Production and Minimizing Operating Costs.

A.L. Podio, University of Texas at Austin; J. N. McCoy, Dieter Becker, Lynn Rowlan and Bill Drake, Echometer Company

This paper was prepared for presentation at the SPE Production and Operations Symposium held in Oklahoma City, Oklahoma, 24-27 March 2001.

(The examples shown in this paper are acquired and analyzed using Windows software. Any Well Analyzer using DOS software can be update to TWM Windows if desired.)

Oilfield operators continually need to verify that their wells are being produced at the optimum capacity and in a cost effective manner. An integrated analysis of the pumping system is requiret to reduce operating costs, increase oil production and increase net income. The integrated analysis of the pumping system must include the performance and interaction of all the elements: the prime mover, surface equipment, well bore equipment, down hole pump, down hole gas separator and the reservoir. This analysis is made based on data obtained at the surface without entering the well bore and must yield an accurate representation of the conditions that exist on the surface, within the well bore and within the reservoir. This integrated methodology concept is called Total Well Management, TWM. Examples of rod pumped wells, ESP pumped wells, PC pumped wells and other well analyses are presented.

The following table lists a series of WELL PERFORMANCE QUESTIONS that an operator is must be able to answer to efficiently produce a well. An operator should know that the PBHP is low compared to the SBHP so that the maximum production is being obtained. An operator should know that the pump traveling and standing valves are OK. An operator should know whether the down hole gas separator is efficient or not, and how to correct an inefficient gas separator problem. An operator should know whether a pumping unit is out of balance or not. An operator should know whether the rods are overloaded or not. Using the TWM process to analyze a well's performance will answer WELL PERFORMANCE QUESTIONS and will allow an operator to maximize oil production and minimize operating costs.

Successful application of the TWM concept generally includes some training of the operating personnel. Training is especially necessary if effective application of modern data acquisition hardware and software is to be introduced in an operation that has been relying on limited computer resources. Please check our Training web page for a schedule of our free of charge two and five day seminars: http://www.echometer.com/seminars/index.html.

WELL PERFORMANCE QUESTIONS:

From Acoustic Surveys:

Does liquid exist above the pump? At what depth is the top of the liquid column?

Does the liquid in the casing annulus restrict production from the well?

What is the maximum production rate available from the well?

What is the casing-head pressure? Does it restrict production?

What is the percentage of liquid in the annular fluid column?

Is gas flowing up the annulus? At what rate? What is the gas gravity?

Are there any restrictions or anomalies in the annulus above the liquid level?

From Dynamometer Surveys:

Is the well pumped off? What is the pump intake pressure? What is the pump fillage?

Is the traveling valve or standing valve leaking? What is the pump displacement?

What is the effective pump plunger travel? What is the current pumping speed?

Are the maximum and minimum rod loads within allowable limits?

What is the polished rod horsepower?

Is the gearbox overloaded?

Is the unit properly balanced? What movement of the counterweights is required to balance the unit?

Is the downhole gas separator operating effectively?

From Motor Power Surveys

What is the overall electrical efficiency of the pumping system?

Is the overall electrical efficiency above 50%?

What is the power consumption, $/month, $/BBL, and power demand, KW?

What is the motor current? Does the motor overheat?

Does the motor generate electricity sometimes during the stroke? Is credit allowed for generation?

Is the gearbox overloaded?

Is the unit balanced? What movement of the counterweights is required to balance the unit?

From Transient Pressure Surveys:

What is the reservoir pressure? What is the producing bottom hole pressure?

What is the liquid/gas annular afterflow when the well is shut in?

Is there any wellbore damage? Does the formation need treatment? Is the well fractured?

From Predictive Dynamometer Design Programs:

Is the predicted dynamometer in agreement with accurately measured horseshoe dynamometer data?

Can the performance be improved by a change in pump size, polished rod stroke length, SPM, rod string configuration or other factors?

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