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Results
Creating a Secure IT Infrastructure for the Kuwait Intelligent Digital Field
Saleem, H.. (Kuwait Oil Company) | Al-Shammari, R.. (Kuwait Oil Company) | Zolotavin, A.. (Kuwait Oil Company) | Bonilla, J. C. (Schlumberger) | Ali, Z.. (Schlumberger) | Robert, H.. (Schlumberger) | Farid, A.. (Schlumberger)
Abstract As oilfields mature and new fields come into operation, real time asset management of reserves is providing ongoing challenges to Kuwait Oil Company (KOC). Fewer engineers are managing more wells under increasingly tougher environmental conditions and compliance regulations. The combination of these factors has driven the need for KOC to make a step change in its approach to operations by incorporating digital field concepts to transform the way engineers are working. The result is the Kuwait Intelligent Digital Field initiative. To enable KwIDF, new technologies were deployed in both mature and immature assets, creating issues in terms of interoperability and integration thereby increasing the strain on the legacy IT infrastructure. In addition, there was the requirement to isolate the SCADA industrial networks from the corporate business networks while automating traffic control with the various enterprise data systems. This โmanagedโ separation complicated the delivery of productivity tools to employees and posed the greatest challenge to creating a transparent, seamless KwIDF infrastructure. The KwIDF Jurassic project was particularly challenging since it had the most limited existing infrastructure, requiring the design and deployment of an entirely new architecture scattered over significant distances and business areas. This in turn created significant hurdles in terms of integration and compatibility with the remainder of KOCโs proprietary systems and technologies. Specific efforts were required to allow KOCโs network infrastructure to be capable of embracing such solutions and technologies with proper security measures in place. Developing a network infrastructure to enable real time solutions for KwIDF Jurassic involved analyzing the specific business drivers of the asset to ensure that the capital investment not only delivered results, but did so within a secure environment. This paper presents the methodology employed by KOCโs Corporate IT Group (CITG) to deliver the right network infrastructure, along with lessons learned, for enabling the Kuwait Intelligent Digital Field Jurassic project.
- Information Technology > Security & Privacy (1.00)
- Information Technology > Communications > Networks (1.00)
Young Technology Showcase Detection and monitoring are important prognostic means in preserving material integrity and reducing the life cycle cost of industrial infrastructure, ships, aircraft, ground vehicles, pipelines, oil installations, etc. Having better control of your infrastructureโs condition will enable you to optimize profitability and lower maintenance cost. Hence, monitoring an oil and gas pipeline will not only work as a precaution, but can also give information on when replacement or repair is necessary, thereby maximizing uptime. There is a huge need for reliable monitoring of pipe wall thickness, both topside and subsea. Even in topside applications, the conditions of operation may be hostile and problems such as large temperature variations, lack of space, fluid loading issues, and a host of other factors make development of such a tool a challenging task. Going subsea makes it even more demanding when you have to take into account factors such as high pressure and limitedย access. Over the past years, ClampOn has offered a corrosion/erosion monitor (CEM) for topside installations. Major advantages of this technology are its noninvasiveness, high repeatability, lack of any transducer movement, and high coverage. The measurement principle is based on dispersion of ultrasonic-guided wave modes, and by using electromagnetism, these waves are transmitted along the pipe wall without the sensor being in direct contact with the metallic surface. This makes it an excellent candidate for subsea use. It is installed on the outer pipe wall to produce real-time wall thickness information, not as a spot measurement, but as a unique average path wall thickness. With several successful installations topside, the ClampOn CEM has also found applications subsea, with the first unit installed at 2300 m in the Gulf of Mexico in February and another 10 units to follow in the future. Corrosion and erosion in subsea installations is detected by several methods. In topside applications, the alternatives are both more reliable and many. In subsea applications, the more hostile environment makes the detection of corrosion and erosion a more challenging task. Piggable pipelines are normally inspected at regular intervals and tracking of pipeline integrity is in general not problematic. Some unpiggable pipelines can be inspected using cable-operated tools, but such inspections are expensive and may require a shutdown of production. Subsea production templates, flow jumpers, manifolds, and flow lines can today only be inspected by preinstallation of corrosion/erosion sensors or by use of sensors controlled by remotely operated vehicles (ROVs).
- North America > Mexico (0.34)
- North America > United States (0.24)
Abstract Despite the compelling case for moving towards cloud computing, the upstream oil & gas industry faces several technical challengesโmost notably, a pronounced emphasis on data security, a reliance on extremely large data sets, and significant legacy investments in information technology (IT) infrastructureโthat make a full migration to the public cloud difficult at present. Private and hybrid cloud solutions have consequently emerged within the industry to yield as much benefit from cloud-based technologies as possible while working within these constraints. This paper argues, however, that the move to private and hybrid clouds will very likely prove only to be a temporary stepping stone in the industry's technological evolution. By presenting evidence from other market sectors that have faced similar challenges in their journey to the cloud, we propose that enabling technologies and conditions will probably fall into place in a way that makes the public cloud a far more attractive option for the upstream oil & gas industry in the years ahead. The paper concludes with a discussion about the implications of this projected shift towards the public cloud, and calls for more of the industry's services to be offered through cloud-based "apps."
- Asia (1.00)
- North America > United States > California (0.29)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.46)
- Asia > Indonesia > Sumatra > Aceh > North Sumatra Basin > B Block > Arun Field (0.99)
- North America > United States (0.89)
- Europe (0.89)
- Information Technology > Communications > Web (1.00)
- Information Technology > Cloud Computing (1.00)
- Information Technology > Communications > Networks (0.93)
Abstract Two of the biggest drivers in Middle East oil & gas operations today are the continued development and upgrade of existing facilities (Brownfield Projects) and the challenges involved in developing high pressure, high temperature (HP/HT) fields. These developments come with very different piping and pipeline challenges. In the case of Brownfield projects, it is the ageing piping installations with increased corrosion and leaks, and the need to carry out piping modifications while continuing production. And in the case of HP/HT developments, the challenges include the need to develop robust and effective instrumentation, reliable connections, reduce subsea intervention costs, and operate around existing infrastructure. This paper will look at how cold-work piping connection solutions can accommodate the challenges involved in Brownfield projects and HP/HT applications, as well as alleviating concerns over traditional methods, such as welding. Such concerns include time, cost, resources, and safety implications. Referring to the experience gained from installing over 3,000 cold-work connections worldwide, this paper will examine how cold-work solutions generate a simple mechanical connection; the technology of using hydraulic pipes to flange expansion in developing leak-free connections; the importance of no gasket, seals or moving parts in the connection; and the flexibility needed to handle a range of piping diameters. The paper will provide an example of a recent topside cold-work installation offshore Abu Dhabi - on a field in production for more than 40 years, where the cold-work piping technology was found to significantly reduce the traditional work scope. It will also provide an overview of the choices in taking the technology subsea and applications for critical, high pressure applications through recent testing with Petrobras in Brazil The paper will provide an important technical contribution to Middle Eastern operators in the form of i) a low impact and flexible piping solution that reduces production shut-down time; ii) increased safety; and iii) introduce significant financial savings.
- Europe (1.00)
- Asia > Middle East > Saudi Arabia (1.00)
- Africa > Middle East > Egypt (1.00)
- (5 more...)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government (0.46)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Zakum Concession > Zakum Field > Upper Zakum Field > Thamama Group Formation (0.99)
- Asia > Middle East > Saudi Arabia > Red Sea > Red Sea Basin (0.89)
- Asia > Middle East > Israel > Mediterranean Sea > Levantine Basin (0.89)
Abstract Downstream Refineries and Chemical Plants have benefited from real time optimization systems (RTO) for the last 30 years. Downstream RTO is a well established and permanent fixture in many plants โ the "way we do things โround here!". Upstream E&P operations have "come to this party" much more recently and are using RTO more sparingly, even though the economic and HSSE benefits can be very significant. There are key differences between downstream and upstream. For example, downstream facilities do not deal with sub-surface uncertainties, multiphase flow and isolated/harsh environments; while upstream operations do not usually have to deal with complex chemical processes. Integrated Oil Companies run upstream and downstream operations and integration of tools/practices across both regimes is often perceived to be of significant value. Hence, the purpose of this paper is to compare and contrast downstream and upstream RTO learnings with a view to identifying and describing: similarities in production unit operations e.g. fluid separation, compression etc.; key differences between production unit operations; cultural differences between operations; RTO activities from a technical perspective; RTO business benefits and how these might be leveraged and sustained in both directions. What will emerge from this analysis will be a comparison, highlighting points of commonality and differences, leading to a better understanding of how RTO can be more effectively exploited in the upstream business โ the cheapest oil available! Specifically, it is concluded that RTO in upstream operations is feasible and lucrative, but is relatively rare with sustainability a challenge. Downstream RTO is more common and sustainable, significantly less lucrative, but a "must do" to compete in a highly competitive, margin constrained business.
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Downstream (1.00)
- Africa > Middle East > Tunisia > Mediterranean Sea > Gabes Basin > Miskar Field (0.99)
- Africa > Equatorial Guinea > Gulf of Guinea > Rio Muni Basin > Okume Complex > Oveng Field > Block G > Oveng Field (0.99)
- Africa > Equatorial Guinea > Gulf of Guinea > Rio Muni Basin > Okume Complex > Oveng Field > Block G > Okume Field (0.99)
- (71 more...)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Downhole monitoring and control (1.00)
- Health, Safety, Environment & Sustainability (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
Asset integrity management encompasses the design, operation, and maintenance of an asset to preserve its integrity at an acceptable level of risk throughout its operating life. Protection of health, safety, and the environment is a critical component of the processes and procedures used to monitor the conditions of offshore surface and subsea facilities and structures.
Abstract BP Trinidad and Tobago LLC (bpTT) has grown from an oil to a large gas based company over the last 50 years. The companyโs discovery of large volumes of gas in the mid 90โs contributed significantly to the rapid development of a thriving Trinidad and Tobago gas based industry, including petrochemical and LNG industries. BP continued to focus on gas based exploration, appraisal and production activities through the decade and has now grown to be in the privileged position of being the largest gas resource holder and producer in Trinidad and Tobago, supplying circa. 2.1bcf/day of daily gas demand. As the industry finding rate, in particular large fields, decreased over the last decade BP has had to look for ways of leveraging its incumbency to increase value for Trinidad and Tobago and BP. Sustaining resource progression and production at current rates is a very challenging and exciting proposition. The opportunities that present themselves both from a technology and incumbency viewpoint along with the required competency, skills and capability make for a challenge that requires new ways of working. BP has embarked on a multi staged approach; optimizing recovery from the base, applying new technology, commencing an aggressive appraisal program and continuing to explore on existing and new acreage. Clearly the future wells and developments need to be economic and add value to both to Trinidad and Tobago and BP. Given the time required to progress resources through to production, the pace required to prove resources to continue to support Trinidad and Tobagoโs existing gas business provides an exciting and challenging sense of urgency, which demands a different approach to Resource development as compared to what was done in the past. In this paper we will describe the approach, as we define long term sustainability of the gas business for BP and the opportunities and challenges that present themselves.
- North America > Trinidad and Tobago > Trinidad > North Atlantic Ocean > Columbus Basin > Immortelle Field (0.94)
- North America > Trinidad and Tobago > Trinidad > North Atlantic Ocean > Columbus Basin > East Mayoro Block > Mahogany Field (0.94)
- North America > Trinidad and Tobago > Trinidad > North Atlantic Ocean > Columbus Basin > Amherstia Field (0.94)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Production and Well Operations (1.00)
- Management > Strategic Planning and Management > Exploration and appraisal strategies (0.87)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (0.69)
Over the past 30 years, geophysical methods have assumed a much more prominent and integral role in many investigations where subsurface features have environmental and engineering importance. In fact, the field once referred to as โenvironmental and engineering geophysicsโ has broadened to include other applications (e.g., archeology, forensics), and is now commonly referred to more generally as โnear-surface geophysics.โ It is difficult to precisely define near-surface geophysics, and the definition will likely depend on whom you ask. However, we define it as the use of geophysical methods to investigate the zone between the surface and hundreds of meters into the Earth's crust. Applications include, but are not limited to, potable water management, engineered infrastructure and construction, site clearance, gas storage, natural-hazard mitigation, mining, forensics, and archaeology. Although the same physical principles are relevant for any target depth, the high degree of near-surface heterogeneity, rapid change in physical properties, and proximity to the free surface often dictates that dominant processes and therefore key assumptions differ between the near-surface and deeper investigations. While near-surface geophysics shares many technical and cultural attributes of oil and gas exploration, the majority of near-surface geophysicists practice under different economic drivers and conditions.
- North America > United States (1.00)
- Asia (0.94)
- Geology > Structural Geology > Tectonics > Plate Tectonics (0.68)
- Geology > Rock Type (0.68)
- Geophysics > Magnetic Surveying > Magnetic Acquisition (0.68)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.68)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.46)
- Law (1.00)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract The oil and gas industry has a need for reliable monitoring of changes in wall thickness both topside and subsea. It is important to detect and monitor the effect of corrosion and erosion as this may reduce the life-cycle cost and increase the lifetime of industrial infrastructure, ships, aircrafts, ground vehicles, pipelines, oil installations, etc. Even topside the conditions of operation can be extremely hostile, facing problems like surface roughness, fluid loading issues, temperature variations, and a host of other factors that make development of a robust wall thickness assessment tool a challenging task. Deploying a monitoring system subsea makes the application even more demanding when you have to take into account factors like high pressure and limited access. Over the last years ClampOn have offered a topside corrosion-erosion monitor (CEM) for monitoring changes in the wall thickness of such infrastructure. Major advantages of this technology have been its non-invasiveness, high repeatability, high coverage and the lack of any transducer movement, also making it an excellent candidate for subsea use. The measurement principle is based on dispersion of ultrasonic guided wave modes, and by using electromagnetism these waves can be transmitted through the pipe wall without the sensor being in direct contact with the metallic surface. It is installed on the outer pipe wall to produce real-time wall thickness information, not as a spot measurement, but as a unique average path-wall thickness. With several successful installations topside, the technology has now also been made available for subsea installation.
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (0.94)
Abstract This paper aims a solution to improve dynamic connectivity between regions in compartmentalized reservoirs. The proposal is to drill horizontal wells whose main objective is to communicate the zones where compartmentalization has been detected. The fluid flow between compartments will occur due to the potential difference existing between them. The flowrate will depend on the petrophysical properties of reservoir, physicochemical properties of fluids and the design of horizontal well. The work develops a mathematical model that represents the potential behavior of each compartment over time when they are communicated through a horizontal well. It considers the special application for gas cap systems and it presents an example, which demonstrates the impact and benefits of this solution. The implementation of this proposal will help exploiting the hydrocarbons reservoir through the existing infrastructure in adjacent regions, thus, reducing or eliminating the requirement of new infrastructure and extending the lifespan of existing infrastructure, thereby maximizing the value and recovery of the fields, which can represent great economic benefits for many oil companies.
- North America > United States (0.69)
- North America > Mexico (0.48)