Maximizing Production Rate
A west Texas E&P producing a well with traditional gas lift was still getting 1,400 bpd after producing for more than two-and-a-half years. To accelerate revenue, at high commodity prices, without hampering the well’s economic return, the operator wanted to see how best to employ an ESP.
Note: The well had a water cut of approximately 95 percent, so there would need to be a significant increase to boost income.
THE PROBLEM:
Focused on finding the right partner, the E&P asked five ESP providers, including us, to bid on pump sizes and procedures to do this in the most efficient manner. The other four simply recommended an ESP size that approximated current gas lift production, a 2000 barrel per day unit.
Focused on finding the right partner, the E&P asked five ESP providers, including us.
We took a different approach and employed our XSIZE software to compare ESP sizes, discovering the well’s true potential. This method revealed that a 3000 bpd pump, double what was coming from gas lift and 50 percent higher than other recommendations, would be the right choice.
THE PROCESS:
Even with the small oil cut, 3000 bpd equaled more than $100,000 per month of additional revenue. This rate appeared to be sustainable through continuation until the well would be depleted to 50 percent, a period estimated to be more than 12months based on the prolific large size of the reservoir—more than $1 million for the year.
Conclusion
As more and more E&Ps embrace the benefits of big data in decision making, XSIZE does exactly that. It incorporates and manages THE CONCLUSION extensive well data, then compares that with its deep database of pump information to show operators a range of options, from which they can then make an informed decision.
