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Hydrate Occurrence in Multiphase Flowlines

When hydrocarbons are extracted from the earth, three phases, oil, gas, and water, usually flow out of the well. The practice in the past was to locate a separator as close to the well as possible; to remove almost all traces of water from the gas phase; to transport the oil and gas to market separately; to clean up the water phase; and finally to dispose of the water by dumping it overboard or by injecting it into a deepwater well. As production operations move further offshore, the cost of constructing platforms solely for separation becomes prohibitively expensive. A cost-effective alternative is to produce the reservoir using subsea wells and to transport the fluids in multiphase production flowlines to either existing platforms in shallow water or to the shore base. There are a number of technical challenges in producing in this manner, and one of the biggest is the potential for hydrate formation. If a hydrate plug forms in one of these subsea flowlines, then it is very difficult to unplug the flowline because one usually has easy access to only one end of the flowline. This paper will be divided into three parts. The first part will describe the HYDRATE prediction model that is used to estimate the hydrate formation temperature/pressure formation line. Next, the temperature, pressure, and quantity of liquid in a gas pipeline will be presented. We will demonstrate how these variables control hydrate formation in wet gas pipelines. The last part of the paper will show how transient operation of a subsea oil/gas pipeline can result in hydrate formation.