The Estimation of Oil and Gas

The following example essay on “The estimation of oil and gas” talks about a complex process which involves the integration of geological, geophysical, reservoir and production engineering data.

In order to arrive at the most likely reserves, the reserves are estimated by using deterministic and probabilistic methods as there are various uncertainties that are involved in the estimating the reserves. In defining the hydrocarbon, Reserves refers to the quantities of oil and gas which can be commercially recovered from a given date forward whereas Resources are the reserves plus additional oil and gas that cannot be produced due to techno-economic factors.

In the different stages of a field exploration and developments there are different reserves estimate methods that are generally used at the respective stages. One of the methods which is generally used from when the field is discovered up to when it is abandoned is the Oil and Gas-Len- Place method at surface conditions.

As usually only some of the oil and gas-in?place can be recovered, therefore the total oil and gas-in-place must be multiplied by a certain recovery factor which depends on the individual field.

Moreover, when oil and gas are brought to the surface it shrinks and expands respectively. Therefore if the surface volume of the in-place oil and gas were to be calculated, the Formation Volume Factor which accounts for the shrinkage and expansion factors, should be vided and multiplied respectively for the oil and gas.

At 1280 ms is the lowest tested oil. IP category is where there is 90% confidence.

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For UP Oil Reserve ‘so-pay, the Iso- pay value within the entire gas cap is mm and falls to zero at 1300 ms which is at ten 011-water contact penning on ten structural Tall. A a ten UP 011 Reserve has an ‘so-pay value of mm in the entire gas cap area and reduces to zero at 1380 ms which is at the last closed contour depending also on the structural fall. The UP and UP categories have 50% and 10% confidence associated with them respectively.

After the ‘so-pay contours are constructed, the area between two respective ISO-pay contours is estimated by means of drawing the contours on a tracing paper and by inspecting the area by means of an underlying graph paper in units of centimeter square (CM). Once the area between the two ISO-pay contours has been estimated ND converted into kilometer-square (km) according to the given scale, the rock volume is estimated by multiplying the area converted to meter-square (mm) by the average thickness in meters (m) between the two ‘so-Pay contour values.

The above is done for all the IP Gas Reserve ‘so-pay and the 1 P, UP and UP Oil Reserve ‘so-pays. An example of the above is as follows. The diagram above shows the 1 P ‘so-pay contour map of the Gas Cap. Figure 1: IP gas ‘so-pay contour map As explained before the ‘so-pay value ranges from zero to fifteen which depends on the structural gain which was from (1220 to 1205 ms). The three areas are divided into Area A, B and C respectively. Therefore in order to find the rock volume between the 15 and 10 ‘so-pay values (Area B), the area between them is first calculated.