Oil and gas production handbook An introduction to oil ... - ABB Group
Oil and gas production handbook An introduction to oil ... - ABB Group
Oil and gas production handbook An introduction to oil ... - ABB Group
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the bot<strong>to</strong>m. Salt is a thick fluid, <strong>and</strong> if deposited under the reservoir, it will<br />
flow up in heavier rock over millions of years. This process creates salt<br />
domes with a similar reservoir-forming effect. These are common e.g. in the<br />
Middle East.<br />
This extraordinary process is ongoing. However, an <strong>oil</strong> reservoir matures in<br />
the sense that an immature formation may not yet have allowed the<br />
hydrocarbons <strong>to</strong> form <strong>and</strong> collect. A young reservoir generally has heavy<br />
crude, less than 20 API, <strong>and</strong> is often Cretaceous in origin (65-145 million<br />
years ago). Most light crude reservoirs tend <strong>to</strong> be Jurassic or Triassic (145-<br />
205/205-250 million years ago), <strong>and</strong> <strong>gas</strong> reservoirs where the organic<br />
molecules are further broken down are often Permian or Carboniferous in<br />
origin (250-290/290-350 million years ago).<br />
In some areas, strong uplift, erosion <strong>and</strong> cracking of the rock above have<br />
allowed hydrocarbons <strong>to</strong> leak out, leaving heavy <strong>oil</strong> reservoirs or tar pools.<br />
Some of the world's largest <strong>oil</strong> deposits are tar s<strong>and</strong>s, where the volatile<br />
compounds have evaporated from shallow s<strong>and</strong>y formations, leaving huge<br />
volumes of bitumen-soaked s<strong>and</strong>s. These are often exposed at the surface<br />
<strong>and</strong> can be strip-mined, but must be separated<br />
from the s<strong>and</strong> with hot water, steam <strong>and</strong><br />
diluents, <strong>and</strong> further processed with cracking<br />
<strong>and</strong> reforming in a refinery <strong>to</strong> improve fuel<br />
yield.<br />
101 kPa<br />
10 °C<br />
The <strong>oil</strong> <strong>and</strong> <strong>gas</strong> is pressurized in the pores of<br />
the absorbent formation rock. When a well is<br />
drilled in<strong>to</strong> the reservoir structure, the<br />
hydrostatic formation pressure drives the<br />
hydrocarbons out of the rock <strong>and</strong> up in<strong>to</strong> the<br />
well. When the well flows, <strong>gas</strong>, <strong>oil</strong> <strong>and</strong> water<br />
are extracted, <strong>and</strong> the levels shift as the<br />
reservoir is depleted. The challenge is <strong>to</strong> plan<br />
drilling so that reservoir utilization can be<br />
maximized.<br />
20 MPa<br />
100 °C<br />
40 MPa<br />
200 °C<br />
Gas exp<strong>and</strong>s<br />
<strong>and</strong> pushes <strong>oil</strong><br />
downwards<br />
Seismic data <strong>and</strong> advanced 3D visualization<br />
models are used <strong>to</strong> plan extraction. Even so,<br />
the average recovery rate is only 40%, leaving<br />
60% of the hydrocarbons trapped in the<br />
reservoir. The best reservoirs with advanced enhanced <strong>oil</strong> recovery (EOR)<br />
allow up <strong>to</strong> 70% recovery. Reservoirs can be quite complex, with many folds<br />
<strong>and</strong> several layers of hydrocarbon-bearing rock above each other (in some<br />
areas more than ten). Modern wells are drilled with large horizontal offsets <strong>to</strong><br />
25<br />
Reservoir hydrostatic pressure<br />
pushes <strong>oil</strong> <strong>and</strong> <strong>gas</strong> upwards.