How Do We Optimize Well Performance (Reservoir Management
-How do we optimize well performance (reservoir management)? Gas
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Production Separator
Test
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Oil
Water
Wellhead
ANSWER
To optimize well performance is actually a difficult task because usually we faced the lack of data we needed and many unknown involves.
To overcome this problem, based from Erik Vikane, SPE, is Manager of Reservoir Management at StatoilHydro, he applying three stages method: * Stage 1—Historical Surveillance Data Compilation * Stage 2—Data Interpretation and Identifying Value Addition * Stage 3—Quantify Value To Justify the Need for the Acquired Data.
(Obtain from, www.spe.org/jpt/print/archives/2009/09/15RPMFocus.pdf, at 22nd November, 2012)
All in all, those stages come back to the basic which the needs of sufficient data to conduct an action plan. From what we learned at Emerson Process Management last week, a transmitter is a tool which usually installed in the controller, which use to transfer the data from the field-site indicator to the control room, let say we use a Distributed Control System (DCS). Then, based from the data gathered an action might be needed to optimize the well performance, this is when the Final Control Element (FCE) come in handy. Of course there is some mathematical model needed to be generated to transfer those data into valuable information, but without the data gathered on-field and the action taken by the FCE the well will not be optimize. Thus, basically to optimize this well performance the control valves must be installed on the pipeline.
This is the basic control valves installed to give the idea what we have learned at Emerson. There are actually many more complex control elements in the real reservoir but we only learned four basic element
Production Separator
Production Separator
Test
Separator
Oil
Water
Wellhead
ANSWER
To optimize well performance is actually a difficult task because usually we faced the lack of data we needed and many unknown involves.
To overcome this problem, based from Erik Vikane, SPE, is Manager of Reservoir Management at StatoilHydro, he applying three stages method: * Stage 1—Historical Surveillance Data Compilation * Stage 2—Data Interpretation and Identifying Value Addition * Stage 3—Quantify Value To Justify the Need for the Acquired Data.
(Obtain from, www.spe.org/jpt/print/archives/2009/09/15RPMFocus.pdf, at 22nd November, 2012)
All in all, those stages come back to the basic which the needs of sufficient data to conduct an action plan. From what we learned at Emerson Process Management last week, a transmitter is a tool which usually installed in the controller, which use to transfer the data from the field-site indicator to the control room, let say we use a Distributed Control System (DCS). Then, based from the data gathered an action might be needed to optimize the well performance, this is when the Final Control Element (FCE) come in handy. Of course there is some mathematical model needed to be generated to transfer those data into valuable information, but without the data gathered on-field and the action taken by the FCE the well will not be optimize. Thus, basically to optimize this well performance the control valves must be installed on the pipeline.
This is the basic control valves installed to give the idea what we have learned at Emerson. There are actually many more complex control elements in the real reservoir but we only learned four basic element