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An overview of the operational and financial benefits of optimizing production and field development with real-time downhole data
Abstract
Traditionally, analytical models and simulation forecasts are made up of many assumptions and have significant error factors. These uncertainties are due to a lack of reliable data on the specific wells and reservoirs which are being developed.
Permanent downhole gauges (PDG’s) provide reservoir and pump performance data which allows users to move away from approximations and assumptions in their models, to calculating based off true real-time downhole parameters. This allows users to mitigate development risk and optimize their return on the development of their asset. Often in the early stages of a fields development, simply by optimizing well spacing, millions of dollars can be saved as a result of the data provided by PDG systems.
The modern capabilities of permanent real-time downhole monitoring systems are such that operators now have access to greater spatial resolution, increased accuracy & resolution, and data integrity than ever before.
Introduction
Real-time downhole gauges (permanent down gauges PDG’s) provide several benefits to the efficient development of oil and gas resources including reservoir development, drilling, completions, and ongoing production operations. Reservoir development, which may include rate transient analysis, analytical equations, well testing and reservoir simulation is particularly benefited through access to accurate, repeatable and high resolution pressure data on a timely basis. With that data access, Reservoir Engineers and other technical disciplines can make much faster decisions regarding well spacing early in the development of the play. “Time is money” they say.
Why is it important to have physical parameter data early on?
Suppose there was a well in a reservoir in which the estimated volume contained was five MMBbl of oil. The well was on primary production and produced for six months. We estimate the well has a recovery factor of 6% Original Oil in Place (OOIP) the reserves are therefore estimated at 300 MSTB. The well declines fast in the first year but has not “plateaued in oil rates.”
If we look back 30 years, it was typical to estimate reserves by analogy (type curves), analytical models and/or simulation. For analytical models and simulation forecasts, the error bars are very large…
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