The Use and Application of Permanent Downhole Pressure Gauges in the Balmoral Field and Satellite Structures

Shepherd, Carlton; Neve, Patrick; Wilson, Douglas C.

doi:10.4043/6256-ms

Cited by 4 publications

(3 citation statements)

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“…Simultaneously, increased reservoir-characterization sophistication added new requirements for downhole reservoir data. Early in the 1990s, the North Sea became a leader in the use of data from PDGs for reservoir management, as described by Shepherd et al (1991), Unneland and Haugland (1994), and Unneland et al (1998). PDG applications have since become common worldwide [see Chorneyko (2006) for examples].…”

Section: Introductionmentioning

confidence: 99%

Listening to the Reservoir—Interpreting Data From Permanent Downhole Gauges

Horne

2007

Journal of Petroleum Technology

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The permanent downhole pressure gauge is a class of tool that has become popular in the industry. These tools are installed during the well completion and provide a continuous record of pressure changes during production. Permanent downhole gauges (PDGs) have potential to provide more information than is available with traditional well testing, which is carried out for a relatively short duration. PDGs may provide useful information regarding changes in reservoir properties or well conditions with time as the reservoir is produced.However, interpretation of PDG data is a new problem. Unlike the traditional well test in which "disturbances" in the reservoir (i.e., rate changes) are created and pressure and rates are both known, the changes in rates associated with the record from the PDG may not be known. Moreover, the dynamic changes in the reservoir, along with changes in the flowing temperature or changes in the gauge itself, make the data more complicated to interpret.

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Section: Introductionmentioning

confidence: 99%

Listening to the Reservoir—Interpreting Data From Permanent Downhole Gauges

Horne

2007

Journal of Petroleum Technology

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“…However, downhole technology development had to occur before the industry-wide usage began in the 1980's (Shepherd et al 1991;Bezerra et al 1992;Unneland and Haughland 1994). Various case studies (Unneland et al 1998;van Gisbergen and Vandeweijer 2001) point to the ever-increasing popularity today.…”

Section: Introductionmentioning

confidence: 99%

Placement of Permanent Downhole Pressure Sensors in Reservoir Surveillance

Izgec

Cribbs

Pace

et al. 2007

Proceedings of EUROPEC/EAGE Conference and Exhibition

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fax 01-972-952-9435. AbstractThis paper probes the gauge placement issue with regard to yielding quality formation parameters, unaffected by wellbore effects. Non-physical or biased results may result if the wellbore effects go unaccounted for.We used a wellbore/reservoir simulator, which conserves mass, momentum, and energy to develop a comprehensive understanding of the gauge-placement issue. First, we reproduced a field example from a deepwater asset to demonstrate the simulator's capabilities. In this example, we matched the bottomhole pressure, and pressure/temperature monitored about midpoint of the flow string during a multirate test sequence lasting some 60 hours. Calculations show that thermal effects are exacerbated by increasing flow rate and increasing gauge distance from the perforations.Second, we performed a detailed uncertainty analysis with experimental design. Variables included in this analysis were perforation-to-gauge distance, permeability, geothermal gradient, flow rate, fluid viscosity, thermal conductivity of annular fluid and formation, and mechanical skin. This analysis sheds light on relative importance of these variables on our ability to extract formation parameters. Simple correlations are developed for designing gauge placement in many environments.

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“…Along with a summary of the technical evolution of permanent downhole gauges over time, the authors published value metrics for permanent downhole pressure gauge installations in terms of increased production and reduced operating costs. Other fields with documented examples of permanent downhole gauge installations and applications include Balmoral (6) , Scapa (7) , Gullfaks (8) , Ivanhoe, Rob Roy, and Hamish (9) . The first downhole gauge was run in Balmoral and Scapa in 1985, in Gullfaks in 1987, and in Rob Roy in 1989.…”

Section: Introductionmentioning

confidence: 99%

Real-Time Reservoir Surveillance Utilizing Permanent Downhole Pressures - An Operator's Experience

Chorneyko¹

2006

Proceedings of SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractPermanent downhole pressure gauges supply important information for reservoir surveillance and management. Technology has evolved over the more than 40 years since the first installation. Service companies have made significant improvements to the components of a permanent downhole gauge installation for a well. The components include gauges, housing, cable, connections, and acquisition systems. Installation and use of these gauges has become routine in many situations because of the improved reliability and the value of information that the gauges provide. Pressures from permanent downhole gauges can be examined almost as soon as they are acquired, depending on communication speed. The data is used for many applications including pressure monitoring, interference testing, water and gas injection monitoring, transient well testing, evaluation of well performance, reducing the flowback time of new wells, monitoring hydraulic fracturing operations, and monitoring pump inlet and outlet pressures for pumping wells. On the practical side, there are issues associated with the data that these gauges collect. Vast amounts of data are being gathered continuously at intervals down to one second over numbers of years. This data must be communicated from the well to the office. Since the data is an asset, it must be stored and archived. Individuals require access to the data at different times, for different reasons, and at differing resolutions. Interpretation of the data poses new challenges as there is more hidden in the long term pressure record than just a collection of drawdowns and buildups. The data contains information about parameters changing during short and long time intervals both near the well and in the reservoir. As more and more permanent downhole gauges are deployed, maximizing the corporate benefits becomes an asset management issue. Companies are faced with stewardship of the investment, communicating learnings across the organization, developing or acquiring software tools for data management and analysis, proposing and supporting industrywide standards for consistent data capture and communication, and integrating data into work processes and into applications such as smart wells and smart fields.

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The Use and Application of Permanent Downhole Pressure Gauges in the Balmoral Field and Satellite Structures

Cited by 4 publications

References 0 publications

Listening to the Reservoir—Interpreting Data From Permanent Downhole Gauges

Listening to the Reservoir—Interpreting Data From Permanent Downhole Gauges

Placement of Permanent Downhole Pressure Sensors in Reservoir Surveillance

Real-Time Reservoir Surveillance Utilizing Permanent Downhole Pressures - An Operator's Experience

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