Observation Well Monitoring Defined Well Proximities and Optimized ...
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CASE HISTORY
Observation Well Monitoring Defined Well Proximities and Optimized Production Installed real-time PT electronic gauges to enable reservoir modeling and field development Benefits Reservoir
modeling
–– Defined zonal contributions –– Communicated between formations –– Showed pressure decline trends Production optimization –– Defined producing well’s transient P/T relationship with observation wells Field-development well proximity study –– Defined pressure changes with fracture transients –– Defined pressure changes with proximity production –– Determined future well spacing
Well Background An operator requested that Baker Hughes configure monitoring systems that could define the production potential of individual zones in four close-proximity wells. The multiple observation wells would provide real-time data from each isolated zone, enabling the operator to define optimal well proximity, identify zonal communication, study transient pressures, and drive production optimization for future field development. The client selected Baker Hughes as a total-solution provider for the project and requested an integrated package of technologies and services across multiple product lines. The integrated technologies included specially modified Advantage™ Series HS™ packers with feed-through capability and SureSENS™ pressure/ temperature (P/T) electronic gauges with
quartz transducers and gauge carriers. The gauges were preplumbed with tubing encapsulated conductor (TEC) cable, and delivered to the well sites pre-assembled, resulting in deployment efficiencies and significant reduction in rig time during installation. The four observation wells are located approximately 500 ft (152 m) from a central production well. These observation wells are spaced at 90° intervals and each well has eight zones isolated by eight hydraulicset feed-through packers. Each zone has a dedicated high-resolution single-point P/T gauge that monitors how production from the central well affects the pressure of individual zones. The packers in each well were set in series with a single wireline retrievable plug. Because the P/T gauges were actively
Background and challenges Close-proximity
wells in Permian Basin
Operator
needed individual zone monitoring per well with high accuracy and resolution
Multiple
gauges on one TEC cable
per well Specialized
feed-through packer design required for TEC cable
One
surface data acquisition unit to retrieve and relay all gauge data
Baker Hughes solution and results Deployed
SurSENS 175 real-time electronic P/T gauges on one ¼-in. control line
CASE HISTORY monitoring during the packer setting, each packer’s engagement was confirmed through notable pressure spikes in the individual zones. All 32 SureSENS P/T gauges are functioning in their isolated zones. Their data are routed into a single, centralized surface data acquisition (SDA) unit that transmits real-time data to the operator’s network via the field’s SCADA system.
well’s productivity. Reservoir pressure declines can be trended, and long-term productivity can be forecasted based on this information. Pressure build-up testing can be done by shutting in a producing well while monitoring proximity wells. These tests can define transient pressures through formations and can ultimately determine ideal well spacing and long-term production optimization potential.
Benefits of Real-Time Data Real-time data from isolated zones during the life span of wells defines how one well’s production or fracture affects a neighboring
Observation/ Monitoring Well
Observation/ Monitoring Well Surface Data Acquisition Unit/SCADA
Producing Well
Data collected using SureSENS 175 gauges helped determine production potential.
Observation/ Monitoring Well
Observation/ Monitoring Well
P/T data was retrieved from eight zones in four individual wells and sent to a centralized surface data acquisition unit, and then routed through a SCADA system to the operator network.
Disclaimer of Liability: This information is provided for general information purposes only and is believed to be accurate as of the date hereof; however, Baker Hughes Incorporated and its affiliates do not make any warranties or representations of any kind regarding the information and disclaim all express and implied warranties or representations to the fullest extent permissible by law, including those of merchantability, fitness for a particular purpose or use, title, non-infringement, accuracy, correctness or completeness of the information provided herein. All information is furnished “as is” and without any license to distribute. The user agrees to assume all liabilities related to the use of or reliance on such information. BAKER HUGHES INCORPORATED AND ITS AFFILIATES SHALL NOT BE LIABLE FOR ANY DIRECT, INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE.
© 2013 Baker Hughes Incorporated. All rights reserved. 39732 12/2013
CASE HISTORY
Observation Well Monitoring Defined Well Proximities and Optimized Production Installed real-time PT electronic gauges to enable reservoir modeling and field development Benefits Reservoir
modeling
–– Defined zonal contributions –– Communicated between formations –– Showed pressure decline trends Production optimization –– Defined producing well’s transient P/T relationship with observation wells Field-development well proximity study –– Defined pressure changes with fracture transients –– Defined pressure changes with proximity production –– Determined future well spacing
Well Background An operator requested that Baker Hughes configure monitoring systems that could define the production potential of individual zones in four close-proximity wells. The multiple observation wells would provide real-time data from each isolated zone, enabling the operator to define optimal well proximity, identify zonal communication, study transient pressures, and drive production optimization for future field development. The client selected Baker Hughes as a total-solution provider for the project and requested an integrated package of technologies and services across multiple product lines. The integrated technologies included specially modified Advantage™ Series HS™ packers with feed-through capability and SureSENS™ pressure/ temperature (P/T) electronic gauges with
quartz transducers and gauge carriers. The gauges were preplumbed with tubing encapsulated conductor (TEC) cable, and delivered to the well sites pre-assembled, resulting in deployment efficiencies and significant reduction in rig time during installation. The four observation wells are located approximately 500 ft (152 m) from a central production well. These observation wells are spaced at 90° intervals and each well has eight zones isolated by eight hydraulicset feed-through packers. Each zone has a dedicated high-resolution single-point P/T gauge that monitors how production from the central well affects the pressure of individual zones. The packers in each well were set in series with a single wireline retrievable plug. Because the P/T gauges were actively
Background and challenges Close-proximity
wells in Permian Basin
Operator
needed individual zone monitoring per well with high accuracy and resolution
Multiple
gauges on one TEC cable
per well Specialized
feed-through packer design required for TEC cable
One
surface data acquisition unit to retrieve and relay all gauge data
Baker Hughes solution and results Deployed
SurSENS 175 real-time electronic P/T gauges on one ¼-in. control line
CASE HISTORY monitoring during the packer setting, each packer’s engagement was confirmed through notable pressure spikes in the individual zones. All 32 SureSENS P/T gauges are functioning in their isolated zones. Their data are routed into a single, centralized surface data acquisition (SDA) unit that transmits real-time data to the operator’s network via the field’s SCADA system.
well’s productivity. Reservoir pressure declines can be trended, and long-term productivity can be forecasted based on this information. Pressure build-up testing can be done by shutting in a producing well while monitoring proximity wells. These tests can define transient pressures through formations and can ultimately determine ideal well spacing and long-term production optimization potential.
Benefits of Real-Time Data Real-time data from isolated zones during the life span of wells defines how one well’s production or fracture affects a neighboring
Observation/ Monitoring Well
Observation/ Monitoring Well Surface Data Acquisition Unit/SCADA
Producing Well
Data collected using SureSENS 175 gauges helped determine production potential.
Observation/ Monitoring Well
Observation/ Monitoring Well
P/T data was retrieved from eight zones in four individual wells and sent to a centralized surface data acquisition unit, and then routed through a SCADA system to the operator network.
Disclaimer of Liability: This information is provided for general information purposes only and is believed to be accurate as of the date hereof; however, Baker Hughes Incorporated and its affiliates do not make any warranties or representations of any kind regarding the information and disclaim all express and implied warranties or representations to the fullest extent permissible by law, including those of merchantability, fitness for a particular purpose or use, title, non-infringement, accuracy, correctness or completeness of the information provided herein. All information is furnished “as is” and without any license to distribute. The user agrees to assume all liabilities related to the use of or reliance on such information. BAKER HUGHES INCORPORATED AND ITS AFFILIATES SHALL NOT BE LIABLE FOR ANY DIRECT, INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE.
© 2013 Baker Hughes Incorporated. All rights reserved. 39732 12/2013
