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|Modifying the system to improve production||Model the system for reservoir to delivery point. Forecast and create multiple scenarios to determine optimum solutions.|
|New facilities requirements||Predict pressure loss, corresponding flow rates, and liquid drop out.|
|Unconventional gas wells production||Model horizontal gas wells with a definite number of fractures or artificial lift.|
|Flow system blockages||Identify bottlenecks in the production gathering system.|
|Analyzing existing ESP installations||Compare the ESP performance with actual operations parameters to predict failure before it happens.|
An exploration and production company faced developing a gas field in an environmentally sensitive region. The goals were to save capital but also to ensure that today’s pipeline infrastructure would not restrict tomorrow’s expected production. The region requires that pipelines be planned with minimal disturbance, so line looping at a later date was not an option.Solution
IHS helped the customer model the system from reservoir to delivery point in order to understand current operating conditions and how the system would respond to changing conditions. Inputting the expected drilling program determined pipeline and compression requirements.Result
The customer was able to negotiate better pricing on pipelines and compression as requirements were known well in advance. A system produces optimally for a longer period of time when pipelines and compression have been sized to expected flow rates and required pressures.
The client did not understand why a particular well was not producing as expected.Solution
IHS used production history to estimate reserves and determine inflow capability, and then determined if there was any way of increasing production.Result
Tubulars were identified as the cause of the restriction. Switching production to casing flow doubled production and greatly increased the economics of the well.