Notes on Introduction

After you have reviewed the four parts of ( introduction to oil field processing) , i think you realized the basic ideas of answering why & what questions 

Now it would be good to focus on some points before we proceed to the next section of oil field processing 

1) The equipment between the wells and the pipeline, or other transportation system, is called
an oilfield facility.

2)  An oilfield facility is different from a refinery or chemical plant in a number of ways.
 The process is simpler in a facility, consisting of phase separation, temperature changes, and pressure changes, but no chemical reactions to make new molecules. In a refinery, the feed-stream flow rate and composition are defined before the equipment is designed.
For a facility, the composition is usually estimated based on drillstem tests of exploration wells or from existing wells in similar fields. The design flow rates are estimated from well logs and reservoir simulations. Even if the estimates are good, the composition, flow rates (gas, oil, and water), pressures, and temperatures change over the life of the field as wells mature and new wells are drilled. Facilities have a design rate that is a best-guess maximum flow based 

3) the lighter molecules, such as methane and ethane, tend to boil off into the vapor phase, taking some of the midrange components with them. The remainder of the midrange and most of the heavier molecules stabilize as liquid.

4) Basic sediment and water (BS&W) is the percent by volume of water and solid impurities in the oil. Oil pipeline specifications range from 0.1 to 3%, with a typical Gulf of Mexico pipeline requirement of 1% by volume.

5) The hydrocarbon dewpoint is the point at which hydrocarbon liquid first condenses from a gas sample when the temperature is lowered or the pressure is increased, and it depends on the composition of the gas. The water dewpoint is often specified for gas pipelines for hydrate and corrosion control.

6) The first separator in a facility that receives fluid from the wells is called a production, or high-pressure (HP), separator. If the production is at high pressure, (e.g., 500 to 1,200 psig)

7) A typical separation train might have a well producing into an HP separator at 1,100 psig, with the oil to an IP separator at 450 psig, an LP separator at 150 psig, and possibly an oil treater at 50 psig  before storage in an atmospheric tank

to be continued ......