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For both wells, injection and withdrawal rates per well are 1.47 and 0.375 MMSM3/day, respectively.
Accordingly, similar to that in scenario 5.1 (taking a constant working gas volume into account), injection and withdrawal rates per well are 1.3 and 0.5 MMSCF3/D, respectively.
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In North Dakota's Bakken, for instance, Sandrea observes that despite robust production growth, "the average production rate per well is not increasing as before and the amount of new wells it takes to obtain a similar increase in overall production is rising".
After the treatments, the average fluid production rate per well increased by 41%, and the average oil production rate per well increased by 46%.
In addition, the potential injection rate per well is another key factor for the injection cost.
Based on the determined duration of injection and withdrawal operations, injection rate per well is 750 MSM3/D.
During optimization, the volumetric flow rates for the injection and production were controlled by the EnKF with the imposed constraint of a maximum allowable injection/production rate per well set at 130 m3/day.
In the beginning, target production rate is set based on per well withdrawal objective for peak season (2 MMSM3/D).
Figure 15 shows gas production rate (per one well) from these three well-spacing systems, whereas Fig. 16 shows total cumulative gas production from the 450-acre reservoir.
To measure cell growth rates, 1000 cells per well were seeded onto 96-well plates in triplicates.
It is in the gulf, more than anywhere else, that the rate of production per well is declining most sharply each year, at a rate of as much as 40percentt, adding to the industry's hunger to gain access to more drilling sites.
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CEO of Professional Science Editing for Scientists @ prosciediting.com