Application of Field of the Future to BP's North American Gas Operations

Sisk, Carl; Knox, David; Branch, Deborah D.; Williams, Gerard T.; Fanty, Scott

doi:10.2118/106938-ms

Cited by 5 publications

(1 citation statement)

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“…Geography matters and one format does not fit all. Instead of looking for a single blueprint for an ideal bank office (Sisk, 2009), the branch strategy should place bank offices in an entire banking network and design office functions to cater to varying hierarchical positions in a central place system, different community (sub-market) sizes, and unique community demographic characteristics. In other words, there should be a strategy for the entire office network and a design of a hierarchy of bank offices instead of designing a bank office in isolation.…”

Section: Summary and Concluding Remarksmentioning

confidence: 99%

Does Geography Matter?

Zhou

2014

International Journal of Applied Geospatial Research

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This study investigates the role of geography in shaping the average bank office size in Illinois banking. “Geography” here refers to a host of socioeconomic, demographic, and local community characteristics at the bank market level. The study finds that larger bank markets, higher levels of market concentration, higher percentages of whites within the total population, and less physical fragmentation within a geographical bank market contribute to larger average bank office sizes. The use of technology, represented by higher percentages of physical capital and premises in the total assets, is found to reduce the bank office size. This tendency is further reinforced by a lack of economies of scale at the bank office level. At the same time, the study finds that the greater adoption of internet banking is associated with larger bank offices. These findings provide indirect evidence that market structure has an impact on the adoption of alternative banking technologies. A study of bank office size has practical implications in providing insights into the future branch strategy, as well as the inadequate nature of measures of market power currently used in antitrust regulation.

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Section: Summary and Concluding Remarksmentioning

confidence: 99%

Does Geography Matter?

Zhou

2014

International Journal of Applied Geospatial Research

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Successful Application of Integrated Digital Automation System for Production Optimization in the North San Juan Basin

Oyewole

Scull²,

Downey³

et al. 2007

All Days

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An integrated digital automation system has been used successfully to efficiently optimize tubing flow control and plunger lift installations in North San Juan basin. This paper presents description, application, and significant results achieved by using an intelligent closed looped digital integrated automation system. Results included increased gas production, equipment reliability, also, efficient and inexpensive deliquification method through almost exclusively remote-controlled operations. The smart digitally enhanced system consists of two parts; the Remote Terminal Unit (RTU) and the SCADA-host. The common RTU application is deployed across all well sites and utilizes a common application load. Where and when needed, new feature selections have been added however complete backwards compatibility has been maintained. This is made possible mainly by abstracted I/O and a modular programming technique. The SCADA-host which is also a common unifying system provides interface to all wells for surveillance, monitoring and control capability. The system displays the current system layout graphically. Historical trends are also easily retrievable. Gas production increment of over 4MMcfd has been achieved and sustained in less than 40 plunger lift installations mainly due to availability of high quality digital automatic control system coupled with effective utilization of plunger lift data. By itself, the system adjusts plunger arrival time, after flow and shut-in time based on pre-set operating range to maximize gas production. Thirty tubing flow control installations have resulted in an average gas production uplift of 130Mcfd per well. In tubing flow control application, the casing valve is automatically controlled based on well conditions. This allows a well to flow gas through tubing above critical gas rate while releasing friction and backpressure on the formation by producing additional gas through the tubing-casing annulus. It is a simple process that includes a combination of surface equipment and control logic that could not perform faultlessly without intelligent automation system. This is a significant departure from the traditional means of operating gas wells where highly expensive full rig intervention is required to continuously optimize tubing size and artificial lift installation. As expected, improved business performance has been achieved through an intelligent integrated digital automation system. Introduction Gas wells tend to show a decrease in production over time as a result of depleting reservoir pressure. The liquids that are associated with the produced gas accumulate in the gas well. The liquid column that is built up in the well creates hydrostatic backpressure on the well which further reduces the gas flow rate. Turner et al1 and Coleman et al2 models, give the minimum gas flow rates required to lift the entrained liquid droplets to the surface at a specific wellhead pressure. There are several artificial lift and de-watering methods available to lift liquid from the bottom of the well to the surface, one such method being plunger lift. In some of the marginal gas wells, neither gas production nor anticipated production uplift from wells could justify installing more costly artificial lift systems such as a sucker-rod pump to de-water wells. In some other application, given the consideration of low rates, economic feasibility, well characteristics and mechanical integrity - plunger lift became the obvious choice. Plunger lift is an intermittent form of artificial lift, which utilizes the natural energy of the reservoir to lift the liquids out of the well bore. Plunger lift like other forms of artificial lift has benefited from improved digital technology. The entire system is completely monitored and optimized. Unlike conventional natural gas reservoirs in which gas production rates tend to be greatest at the onset, then steadily decline over the life of the well, coal bed methane produced in North San Juan progressively increases in gas production rate to a maximum flow rate years or several days after the first production. It has always been a great challenge to match and optimize tubing and well bore conduit with the ever changing production rate. Application of optimized Tubing-Flow Control is helping to mitigate these challenges.

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Deploying Field of the Future on Major Projects

Thomson¹,

Law²

2008

All Days

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BP has achieved considerable success in developing and deploying FIELD OF THE FUTURE technologies into existing, operating assets around the world. BP wants to ensure that new field developments will benefit from the FIELD OF THE FUTURE programme from first oil or gas. BP has developed a consistent process, which all major projects must follow from discovery through to first oil or gas. This paper will describe the sub-processes and tools that have been developed within this overall framework to ensure FIELD OF THE FUTURE technologies are part of each major project and how the operating philosophy is developed to exploit them. In the early stages of the project, the value that the FIELD OF THE FUTURE programme can bring must be understood as field development options are created, analysed and ranked. Some technologies may enable innovative solutions particularly where there are complex reservoirs or difficult locations and logistics. The selection of the preferred option must take into account a range of reservoir, commercial and technical considerations, many of which are impacted by FIELD OF THE FUTURE technologies. As the chosen development option is worked up, the necessary infrastructure must be included in the project scope. Furthermore, as the Operations' team start to develop operating and maintenance strategies, their processes and organisation must be designed around the FIELD OF THE FUTURE technologies. Various tools have been developed to assist the project team in identifying value and developing the project scope and these will be described in the paper. The paper will conclude with case studies showing how these new project processes have been used in major projects. Introduction The BP initiative to implement a digital oilfield is called the FIELD OF THE FUTURE programme. Tools and processes developed as part of this programme have been successfully deployed in a number of existing assets, demonstrating and returning real value to BP (Dudley 2006), (Oyewole, 2007), (Pannett 2007), (Sisk 2007). Within BP, a global technology team develops the FIELD OF THE FUTURE technologies and provides assistance to operating units to implement them in the field. BP has a significant portfolio of Major Projects that will be executed and come on line over the next 5 - 10 years. Clearly, BP wants to maximize the value of these MPs by exploiting the technologies we have available, including those from the FIELD OF THE FUTURE programme.

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Application of Field of the Future to BP's North American Gas Operations

Cited by 5 publications

References 1 publication

Does Geography Matter?

Does Geography Matter?

Successful Application of Integrated Digital Automation System for Production Optimization in the North San Juan Basin

Deploying Field of the Future on Major Projects

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