Directive 065 - Energy Resources Conservation Board
Directive 065 - Energy Resources Conservation Board
Directive 065 - Energy Resources Conservation Board
You also want an ePaper? Increase the reach of your titles
YUMPU automatically turns print PDFs into web optimized ePapers that Google loves.
Requirements Comments<br />
b) a statement of the proposed delivery<br />
point, together with a discussion of the<br />
reasons why you propose the location,<br />
c) analyses of the economics of the<br />
proposed delivery point and alternate<br />
delivery points, and<br />
d) a discussion of the development and<br />
probable future development in the area.<br />
13) If you are requesting, pursuant to Section<br />
51(4)(b) of the OGCA, that the ERCB, to<br />
give effect to the common purchaser<br />
declaration, direct the proportion of the<br />
common purchaser’s acquisitions of gas from<br />
the pool that it shall purchase from each<br />
producer or owner offering gas for sale,<br />
a) a discussion and documentation<br />
indicating what negotiations were carried<br />
out in regard to distributing production<br />
among wells in the pool and where the<br />
impasse lies, and<br />
b) a discussion of your proposal as to how<br />
the ERCB should distribute production<br />
from the pool, including a tabulation of<br />
the percentage of total production that<br />
each well or group of wells should be<br />
allowed to produce, together with details<br />
of how the proposed scheme was<br />
obtained.<br />
For each case, the economic analysis should<br />
include a detailed itemization of all costs<br />
(excluding sunk costs), forecasts of production<br />
and revenue streams, and tabulations of<br />
before-tax rate of return, payback, and present<br />
value analyses.<br />
The ERCB’s usual practice is to allocate<br />
production among wells in a pool on a<br />
percentage basis, rather than setting any<br />
specific rate or volume. The proportion of<br />
production allocated to each well is commonly<br />
based on the following formula:<br />
Percentage of pool production for specific well<br />
= 100 x (wellbore net pay x porosity x gas<br />
saturation x area of spacing unit or validated<br />
area for specific well)/(sum of wellbore net pay<br />
x porosity x gas saturation x area of spacing<br />
units or validated areas for all wells).<br />
<strong>Directive</strong> 032 and Decision 91-8 offer<br />
discussions of the ERCB’s commonly used<br />
allocation formula and the validated area<br />
concept. The ERCB has not commonly used<br />
mapping as a means to determine hydrocarbon<br />
pore volume in a spacing unit because in many<br />
cases such mapping is interpretive. The ERCB<br />
has not normally factored the deliverability of<br />
a well into an allocation formula to avoid<br />
disputes on what constitutes appropriate testing<br />
of wells. You may propose an allocation<br />
formula other than the commonly used one;<br />
however, you should include detailed<br />
justification as to why the ERCB should<br />
deviate from its usual practice in determining<br />
an allocation formula.<br />
In some cases it may be useful to set minimum<br />
rates, with a percentage allocation above the<br />
minimum rate. If a well falls below the<br />
minimum rate, other wells are restricted only<br />
to their minimum rates and not below.<br />
ERCB <strong>Directive</strong> <strong>065</strong>: <strong>Resources</strong> Applications / Common Purchaser (March 2012) • 1-11