These include natural gas from traditional sources liquefied natural gas (LNG) and synthetic natural gas (SNG) from coal, tar sands, solid waste, liquid waste, biomass, and liquid petroleum feedstocks. This fact has caused a redirection by many of the nation's gas companies, including SoCal Gas, to concentrate more effort in obtaining new supplies of gaseous fuels. Since the late 1960's the supply of gas nationwide has not been sufficient to meet the demand for this premium fuel. SoCal Gas, like other major gas distribution utilities, has undergone a dramatic change during the past decade. This study provides useful reference and operation guidelines on offshore water-injection and completion design consideration.Ībstract The Southern California Gas Company is responsible for providing gas service to 12 million southern Californians. A check valve set at the bottomhole could stop the backflow in less than 1 second.
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This cyclic process continues with reduced amplitude in each cycle because of friction. Water hammer in the wells and pipeline system experiences (1) after-flow with reduced bottomhole pressure (BHP) and flow rate into formation, (2) backflow when BHP becomes less than reservoir pressure, and (3) resumption of water flow into reservoir when BHP starts to increase. Unlike the classic water hammer in pipelines, water hammer in injection wells is much less in surge amplitude because the high-injectivity reservoir behaves like a cushion to absorb the water-hammer impact on the downhole completion and sandcontrol infrastructure. With the surface-controlled subsurface safety valve (SCSSV) closing when backflow is felt, the water-hammer fluctuation can be reduced to 200 psi. For Scenario II, pressure fluctuation because of topside shut-in is 300 psi.
#Arma 3 dynamic simulation skin
With increasing skin because of cumulative injectivity damage by water-particle plugging and thermal-induced fracture closure at shut-in, the water-hammer-pressure fluctuation can be as high as 1,200 psi. Backflow for the opening well could be close to 10,000 STB/D. The third well, which stays open for injection, experiences an even larger pressure surge (approximately 450 psi at bottomhole). Water-hammer sensitivity on different parameters, such as valve-installation position, stroke time, water-backflow conditions, and the hydraulic characteristics, has been performed.įor Scenario I, the pressure change because of the wellhead shut-in is approximately 200 psi at bottomhole, which is much lower than the amplitude seen at the wellhead (3,400 psi). The other scenario is that the topside pump is stopped while the injection wells are still kept open. One of the scenarios is that two wells are shut in and the third well is kept open. Two different shut-in scenarios for an offshore injection system have been investigated. This study seeks to provide an operational reference for the well-injection operation and valve installation to mitigate backflow and maintain the downhole- sand-control-device integrity and thus good water injectivity. Over time, injectors that undergo repeated rapid shut-ins often have significantly reduced injectivity and show evidence of sanding and even failure of the downhole completion. Water-hammer effects resulting from the shutting in of water-injection wells have a considerable impact on injection-well performance and longevity. Summary In water injectors, rapid shut-in creates a water hammer.
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