PUBLICATIONS RIGHTS RESERVED PUBLICATIONS RIGHTS RESERVED THIS PAPER IS TO BE PRESENTED AT THE INTERNATIONAL TECHNICAL MEETING JOINTLY HOSTED BY THE PETROLEUM SOCIETY OF CIM AND THE SOCIETY OF PETROLEUM ENGINEERS IN CALGARY, JUNE 10 TO 13, 1990. DISCUSSION OF THIS PAPER IS INVITED. SUCH DISCUSSION MAY BE PRESENTED AT THE MEETING AND WILL BE PAPER IS INVITED. SUCH DISCUSSION MAY BE PRESENTED AT THE MEETING AND WILL BE CONSIDERED FOR PUBLICATION IN CIM AND SPE JOURNALS IF FILED IN WRITING WITH THE TECHNICAL PROGRAM CHAIRMAN TO THE CONCLUSION OF THE MEETING.
STEAM SEPARATING SOLVES PHASE SPLITTING PROBLEMS PHASE SPLITTING PROBLEMS IN WET STEAM DISTRIBUTION SYSTEMS
Texaco operates several large steamflood projects in the Southern San Joaquin Valley in which individual wellhead mass flow rates and steam quality measurements are difficult to obtain. Uneven and unpredictable phase splitting at lateral and dead end tees is the problem (Hong, 1978.) In one instance, Texaco has solved this problem by utilizing a horizontal separator to separate 10,500 BPD of 70% quality cogeneration steam.
The separator is able to deliver saturated water and 96.5% quality steam. These two single phase flows can be divided into any number of flow streams and then measured using simple orifice plate, differential pressure, technology.
The steam flood distributing piping consists of two single phase trunk lines running the length of the field to serve phase trunk lines running the length of the field to serve small headers located near the steam injectors. The purpose of these headers is to measure and control water and steam for each well, using orifice meters and adjustable chokes. Because each injector is controlled separately, the injector mass flow rates and steam qualities are independent of one another. Not only does this solve the phase splitting higher or lower qualities than others. For instance, lower qualities may be warranted for patters experiencing steam breakthrough or the areas of the field in which the flood is more mature.
One of the problems associated with this type of operation is the chemical treatment of the dry steam line. A neutralizing amine needs to be added to combat the high pH caused by the formation of carbonic acid. The goal is to hold corrosion to 6.25 mpy (1/8" over 20 years).
This paper addresses the system design, flow measurement, and automatic control apparatus, as well as the details, results, and sampling techniques of the chemical program.
To satisfy part of the steam demand for thermal development in the Midway-Sunset field (Bakersfield, California) Texaco contracted to buy approximately 10,500 BPD of steam. The steam, which is supplied from a nearby cogeneration facility, was to serve the stimulation and displacement needs of several properties.
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