Foreign practice and domestic experience with oil and gas production on the continental shelf indicate that the technicoeconomic indicators of the rigging and operation of deep-water platforms should be improved in the following directions:an increase in the number of wells per group to reduce the overall number of platforms in the field; multistory arrangement of production equipment on the platforms for well drilling and the recovery, collection, and preparation for transport of well production; use of automated assembly-unit equipment and its arrangement in unit modules to industrialize and reduce the time required for construction-assembly operations; and, broad implementation of automation and telemechanization of production processes to improve the safety of working conditions and fire safety.The most expedient production scheme for installations used in the preparation and transport of production to shore structures (SS) is determined as a function of the individual characteristics of each gas, gas-condensate, and oil field -the geographical location, depth of water, distance to the shoreline, the initial stratal pressure, the composition and physicochemical properties of the raw material, and the natural-chemical conditions. Three stages of gas processing are carried out.First. The gas is partially treated on the platform; this consists in extracting water vapor and a portion of the heavy hydrocarbons from the gas. The gas and condensate flows are fed through separate lines to the shoreline, where their further treamaent is carried out. In that case, short distances from the shore and a relatively even bottom relief are desirable. The alternate scheme in question permits the formation of a liquid phase in the gas pipeline from platform to shore.Second. The gas is treated on the platform, i.e., deep extraction of water and heavy hydrocarbons from the gas. The dew point of the gas with respect to those of the water and hydrocarbons ensures operation of gas lines in a virtually dry regime.Third. Water is separated from the stratal production. The gaseous and liquid hydrocarbon phases are then transported together to the shoreline.The production schemes of these installations differ little from the schemes of similar installations operating in normal fields on dry land. Quality gas indicators are obtained using the minimum required number of production techniques for a certain operating regime.The extent to which the condensate is treated in these installations is determined by the method of its transport, which depends on the amount of condensate, the distance between the platform and shoreline, the production life of the fields, etc. Depending on these factors, the mixture of liquid hydrocarbons can be stabilized to commercial condensate in conformity with OST 51.65-80 or subjected to partial degassing.Considering the high cost of production areas on a standard off-shore platform (SOP), and also the large outlays for production processes involving preparation of the raw material for transport, production op...
Diethylene glycol (DEG) is presently used in the gas industry on domestic units for the preparation of gas by the absorption method. The use of DEG is due mainly to its availability from Russian manufacturers and its lower cost compared to triethylene glycol (TEG). At the same time, TEG is used on gas-lift units by the petroleum industry to dry casing-head gas, mainly due to the more exacting standards for the initial parameters of this drying operation. The leading foreign companies also used teeming almost exclusively for gas-drying. Among the principal advantages of teeming compared to DEG is the more thorough drying achieved with gases, the smaller loss of the drying agent with the dried gas, and better regenerability. For example, at a mass concentration of 99.5% "lEG, the dew point depression of the gas is roughly 7 ~ more than for DEG at the same concentration. The amount of TEG lost in droplet form with the dried gas is 2-3 times lower than the analogous loss of DEG. Here, it must be considered that such losses account for 70-75% of the total loss of glycol on the process unit. Triethylene glycol also begins to break down at a higher temperature (206~ than DEG (164~ making it possible to regenerate a TEG solution without the use of a vacuum up to concentrations of 98.7% (97% for DEG).The feasibility of using TEG was shown by an analysis of the cost-efficiency of changing over to operation with TEG on large gas-preparation units at West Siberian deposits, as well as by test calculations performed for equipment designed for operation on DEG. Triethylene glycol meeting the specifications of the standard TU 6-01-5-88 is currently produced at four plants in the Russian Federation (in Kazan, Dzerzhinsk, Nizhnekamsk, and Salavat).The above considerations were the basis for recommendations made to change over to TEG on gas-drying units at the West Tarko-Sale deposit. Figure 1 presents the flow diagram of the gas-processing unit (GPU). Gas from the wells enters the separator S-1 for separation of the liquid in drop form -water and condensed hydrocarbons. The separated gas is then sent to absorber A-1 for drying. The dried gas, now in commercial condition with respect to dew point, subsequently enters a commercial measurement unit before being sent through the main for distribution. Regenerated triethylene glycol (RTEG) fed into the top part of the absorber absorbs water vapor from the gas. The resulting saturated solution is sent to degasifier D-l, where the aerating gas is separated from the glycol. The saturated triethylene glycol (STEG) then enters three-phase fractionating column C-1 to remove the hydrocarbon condensate. The main product subsequently proceeds in succession through a coal filter F-I, a f-me-cleaning filter F-2, and a magnetic treatment unit M-1. Filter F-1 uses activated carbon to remove heavy hydrocarbons and decomposition products from the STEG. Filter F-2 captures particles of mechanical impurities larger than 20/am. Permanent magnets in the M-1 unit convert hard salts present in the STEG to...
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