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SPE Annual Technical Conference and Exhibition, ATCE 2014

作者： Liow, E. Goorhuis, H. Nederlandse Aardolie Maatschappij B.V. Company Netherlands Shell Projects and Technology Netherlands

ISBN: (纸本)9781634398879

A Double End Driven Compression train with Active Magnetic Bearings (AMB), a novel concept on its own, has been chosen as the solution for the Groningen 2nd phase compression project. A development assurance program was followed by a team comprising of both shell and Siemens specialists with the intent of ensuring that technical risks were identified and addressed as far as possible prior to field implementation. A demonstrator compression train has been installed and tested on 1 of the 20 Groningen clusters to allow early operational experience to be gained and verify its reliability. It is currently in its first year of operation and has displayed high availability and reliability. The paper will describe: The concept evaluation and selection The creation of the development programme to assess technical risks Technical challenges and learnings Current status of the development and design maturity. Copyright © 2014, Society of Petroleum Engineers.

关键词： Risk assessment

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CFD based erosion analysis for design of subsea hardware in a high flow rate gas field

CFD based erosion analysis for design of subsea hardware in ...

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Offshore technology Conference Asia: Meeting the Challenges for Asia's Growth, OTC ASIA 2014

作者： Singh, Aditya Sarkar, Suranjan Spritzer, Jared M. Okeremi, Akinyemi O. Shell Projects and Technology India Sdn. Bhd. Malaysia Shell Nigeria Exploration and Production Company Ltd. Nigeria

ISBN: (纸本)9781632663870

shell is developing an offshore gas-condensate field in Asia-pacific. Sand is expected to be co-produced during the life of this project due to minimal downhole sand control, which combined with high gas flow rate potentially could have posed a significant threat to the integrity of the subsea hardware due to erosion. A Computational Fluid Dynamics (CFD) based erosion study has been carried out to identify the location of erosion hotspots and erosion rates in the piping of the subsea X-mas tree, well Jumper and Manifold. The study has been used to either determine Inconel 625 clad thickness to be provided on the inner wall of the piping or modify the design of the piping to bring the erosion within acceptable limits. The CFD models have been validated using experiments in controlled environment. Through this study, the risk of potential erosive failure of the piping in the subsea hardware, leading to loss of containment has been greatly reduced. In literature, CFD based erosion modeling has been used and validated on simple geometries (elbow, target tee, internal diameter reduction etc). In this work, erosion in the entire piping which is a combination of such simple entities has been calculated in an integrated manner. The results show that the required cladding varies between 3mm and 7mm. The knowledge about erosion acquired in the past through experimental and modeling exercises, has been utilized to create a technique to do assessment and management of sand erosion in the subsea hardware. This integrated modeling approach provides insights about the behavior of sand particles in complex piping geometries, which can help design the piping, especially at locations of change in flow direction. Copyright 2014, Offshore technology Conference.

关键词： Gas industry

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The Majnoon field - A case study of drilling operations in a remote area of Iraq

The Majnoon field - A case study of drilling operations in a...

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SPE/IADC Drilling Conference and Exhibition 2014

作者： Le Vesconte, Marc-Jan Tinkhof, Rob Hardman, Paul Halliburton Project Management United States Shell Projects and Technology United States REACH Group United States

ISBN: (纸本)9781632660831

Iraq presents many challenges to international oil and gas producers. This paper will discuss one such operation, the giant Majnoon oilfield. The field was discovered in 1975. Following the drilling of 20 wells, operations were suspended due to the Iran-Iraq war of the 1980's. After the war, production resumed, however drilling did not re-commence until 2011. The challenges of Majnoon are many: unexploded ordnance litters the field;(total) losses in the 12 "A" hole;logistics require extensive planning and all drilling is undertaken by rigs with less experienced crews. Operator's tendering guidelines required a turnkey arrangement between Operator and the main Contractor, leading to an intricate arrangement of sub-contracts. Limited offset data further challenged the drilling process, with a steep learning curve evident across the field. With different disciplines on the critical path to meet the production target date, associated simultaneous operations led to rescheduling and flexibility on the part of the drilling operations team. Major success factors include a focus on performance;contract management;having the ideal team in place from day one;upfront planning and competence assurance. The paper will discuss aspects of the drilling program, from the initial contracting strategy, through to the final well delivery. Following an assessment of learning from the early wells in the sequence, the evolution of the performance culture will be discussed. The working relationship between the operator's field team and that of the main Contractor will be examined, particularly given the turnkey nature of the operation. The realignment of the project objectives after the first three wells will also be addressed. The aim of the paper is to present a case study of the complexities that arise, from operating in a country recovering from a troubled period. The intent is to share learning that may enable future operations in Iraq to avoid some of the operational pitfalls seen in

关键词： Contractors

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Compressor map prediction tool

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IOP Conference Series: Materials Science and Engineering 2015年第1期90卷

作者： Arjun Ravi Lukasz Sznajder Ian Bennett Shell Projects and Technology Lange Kleiweg 40 2288GC Rijswijk The Netherlands

shell Global Solutions uses an in-house developed system for remote condition monitoring of centrifugal compressors. It requires field process data collected during operation to calculate and assess the machine's performance. Performance is assessed by comparing live results of polytropic head and efficiency versus design compressor curves provided by the Manufacturer. Typically, these design curves are given for specific suction conditions. The further these conditions on site deviate from those prescribed at design, the less accurate the health assessment of the compressor becomes. To address this specified problem, a compressor map prediction tool is proposed. The original performance curves of polytropic head against volumetric flow for varying rotational speeds are used as an input to define a range of Mach numbers within which the non-dimensional invariant performance curve of head and volume flow coefficient is generated. The new performance curves of polytropic head vs. flow for desired set of inlet conditions are then back calculated using the invariant non-dimensional curve. Within the range of Mach numbers calculated from design data, the proposed methodology can predict polytropic head curves at a new set of inlet conditions within an estimated 3% accuracy. The presented methodology does not require knowledge of detailed impeller geometry such as throat areas, blade number, blade angles, thicknesses nor other aspects of the aerodynamic design - diffusion levels, flow angles, etc. The only required mechanical design feature is the first impeller tip diameter. Described method makes centrifugal compressor surveillance activities more accurate, enabling precise problem isolation affecting machine's performance.

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CO 2 Fate Comparison for Depleted Gas Field and Dipping Saline Aquifer

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Energy Procedia 2014年 63卷 5586-5601页

作者： Jeroen Snippe Owain Tucker Shell Projects & Technology – Innovation Research and Development Kessler Park 1 2288 GS Rijswijk The Netherlands Shell Projects & Technology – Upstream Development. 1 Altens Farm Road Aberdeen AB123FY UK

An important metric for CO 2 storage is the CO 2 fate plot, which displays the partitioning of mobile/capillary trapped/dissolved/mineralised CO 2 as a function of time. The archetype version of this plot (Fig. 1, from the IPCC 2005 report [1] ) is idealised. While a simplification is a good way to illustrate physical mechanisms, the problem with this plot is that due to its popularity it is now easily misinterpreted to be a universal plot. However, for actual case studies the curves behave quantitatively and sometimes qualitatively differently from the archetype plot. The reason for this is that reservoir settings are different from case to case, having a profound impact on the characteristic times, shapes, and magnitudes of the CO 2 fate curves. The objective of this work is to generate a realistic range of CO 2 fate plots, derived from reservoir simulations on simple geometries but with realistic input parameters, expressing the impact of key control parameters. This new range of plots can be used for communication purposes to a wider audience, and also as a Quality Control tool for future modelling studies. Our results bring out major differences between a depleted gas field setting (more generally: structurally closed setting) and a dipping saline aquifer setting (more generally: structurally open setting). In a structurally closed setting the CO 2 dissolution and/or mineralisation takes orders of magnitude longer than in a structurally open setting. This result is quite robust under variation of other parameters such as vertical to horizontal permeability, reservoir thickness, reservoir dip angle, relative permeabilities and geochemical variations. Moreover, only a small subset of structurally open cases, and none of the structurally closed cases, leads to CO 2 fate plots that are similar to the one in the IPCC 2005 report. Therefore the CO 2 fate plot from the IPCC 2005 report should not be used for quantitative statements regarding the relative size and timi

关键词： CCS trapping geochemistry Reactive Transport Modelling

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Quality control of porosity changes predicted by geochemical modelling in CCS case studies

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Energy Procedia 2014年 63卷 2861-2869页

作者： Jeroen Snippe Shell Projects & Technology – Innovation Research and Development Kessler Park 1 2288 GS Rijswijk The Netherlands

Assessment of long-term stability of injected CO 2 for geological storage requires a certain level of dynamic modelling, including geochemical modelling of fluid-rock interactions triggered by the injected CO 2 in geological formations. One of the key outcomes of a geochemical simulation is the predicted porosity changes. Decreasing porosity implies an overall plugging of the pore system and therefore probably a reduction in permeability, while increasing porosity implies the possibility of the opening up of flow paths. Therefore the predicted porosity change is an important indicator for self-healing versus self-accelerating behaviour of potential CO 2 leak paths. Based on project studies and natural analogue comparisons, several easy-to-use metrics and cross-correlations are developed in this paper. This is done by starting from a mass balance analysis, and re-writing it as a volume balance analysis plus correction terms. In this way porosity changes can be rigorously split up in distinct contributions from salinity changes, density changes and (de)mineralisation of CO 2 and H2O. By cross-correlating the porosity changes to these contributions, using 11 CCS case studies and natural analogues examples (covering a wide range of settings such as aquifer/gas field, geographic location, geochemical reaction paths, salinity, temperature), distinct patterns and rules of thumb emerge. The methodology and resulting cross-correlations can be applied as a quick and powerful sanity check on geochemical modelling results. The key conclusions that can be drawn from this work are: • The amount of mineralised CO 2 is a reasonable predictor for the porosity change • The amount of mineralised H2O and the density change can be significant contributors to the porosity change, but (without taking into account mineralised CO 2 ) are poor predictors for the porosity change The salinity change is only a minor contributor to the total porosity change. The main conclusion is that the poros

关键词： CCS geochemistry Reactive Transport Modelling porosity

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The Peterhead-goldeneye Gas Post-combustion CCS Project

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Energy Procedia 2014年 63卷 6258-6266页

作者： Bill Spence Denise Horan Owain Tucker Shell UK 1 Altens Farm Road Aberdeen AB123FY UK Shell Projects & Technology – Upstream Development. 1 Altens Farm Road Aberdeen AB123FY UK

Full scale demonstration projects are the key to gaining policy acceptance for CCS. They also form the vital first step towards reducing the cost of clean power: only when a project is built can engineers examine it and identify improvements and savings opportunities. A number of projects are currently in development for coal CCS, but carbon capture on gas is also important if the world is to make the depth of cuts in emissions required by the current scientific consensus. shell and SSE plan to deliver the world's first full scale CCS project on gas in Scotland. Up to 10 million tonnes of carbon dioxide (CO 2 ) emissions could be captured over a 10-year period from flue-gas from a 400MW combined cycle gas turbine at the existing Peterhead Power Station in Aberdeenshire, Scotland and then transported by pipeline and stored, approximately 100 km offshore in the depleted Goldeneye gas reservoir, at a depth of more than 2 km under the floor of the North Sea. This would provide enough clean electricity to power the equivalent of 500,000 homes per year. The project is one of two preferred bidders in the UK Government's CCS Commercialisation Programme and is currently in the midst of a front end engineering and design (FEED) phase. Subject to positive final investment decisions by shell and the UK Government, and the receipt of all relevant permits and consents, the project is expected to be up and running by the end of the decade.

关键词： CCS trapping geochemistry Reactive Transport Modelling

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A high capacity floating LNG design

A high capacity floating LNG design

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17th International Conference and Exhibition on Liquified Natural Gas 2013, LNG 2013

作者： Pek, Barend Van Der Velde, Harry Shell Projects and Technology Netherlands

ISBN: (纸本)9781629935331

The Prelude FLNG solution is capable of processing rich gas. Developments with rich gas using similar facilities may also benefit from the considerable amount of revenue possible from condensate and LPG. However, some fields have gas that is significantly leaner, and will not have the benefit of condensate and LPG revenue streams. To ensure robust and economic development of gas fields with lean gas compositions, shell has developed FLNG Lean. FLNG Lean is an FLNG concept with a nominal LNG production capacity of 6 million tonnes per annum and reduced functionality for other liquids. FLNG Lean is a natural development of the shell FLNG design selected for Prelude. The substructure design with its utilities, the accommodation, the operating and the safety philosophies, the flare and blow-down system, the cooling water systems, the LNG containment systems, the LNG off loading system, and the turret and mooring system design are all the same, enabling repeatability gains. Lessons learnt and the latest technology developments have also been implemented. Some utilities are relocated to the substructure to create sufficient deck space for the liquefaction trains and process equipment. Modern aero-derivative gas turbines will drive the liquefaction compressors and power generators. All process heating requirements will be met by waste heat recovery units. This paper will describe the FLNG Lean design and its application area. We will first describe the economic drivers, then highlight the approach followed, explain the main features of FLNG Lean, compare it with Prelude, and conclude with an outlook on the future of FLNG.

关键词： Waste heat

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Two-phase flow behaviour for a single flowline with a non-symmetric splitter to a dual riser

Two-phase flow behaviour for a single flowline with a non-sy...

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16th International Conference on Multiphase Production technology 2013

作者： Prickaerts, P. Haandrikman, G. Henkes, R.A.W.M. Delft University of Technology Netherlands Shell Projects and Technology Netherlands Delft University of Technology Shell Projects and Technology Netherlands

ISBN: (纸本)9781629932958

We have carried out laboratory experiments for the phase split of a gas-liquid flow from a single flowline to a dual riser. The facility used for the experiments is the air-water loop at the shell technology Centre in Amsterdam. The 2″ diameter loop consists of a 100 m long flowline followed by a dual 15 m high vertical section. The two risers arc connected to the same separator at a platform that is operated at atmospheric pressure. The set-up includes a non-symmetric side-branch T-splitter, of which both the side arm and the run arm result in a vertical riser (Riser 1 and Riser 2, respectively). All experiments were conducted with slug flow conditions in the incoming flowline. It has been observed in the experiments that the liquid phase preferentially flows into Riser 2, while the gas phase is predominantly diverted through Riser 1. However, due to the vertical orientation of the risers, this maldistribution can result in gravity dominated flow in Riser 2. As a result, quasi-stable modes form in the dual riser system. These can imply extreme situations, like a fully liquid-filled Riser 2 or partial separation of the phases over the two risers. Each mode has a typical riser base pressure. It was observed that manual choking can influence the phase split (albeit to a limited extent), and is capable of switching the system between the quasi-stable modes. For specific combinations of valve openings and flow rates, Riser 2 experiences a severe slugging cycle. As a result, the phase split shows strong transient behaviour, either with constant cycle times or with an irregular time dependence. Also here manual choking can influence the characteristics of the cycle and is capable of completely suppressing it. Examples of the flow modes and the measured pressure transients at various locations will be shown. © BHR Group 2013.

关键词： Liquids

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Areal field surveillance - Applying the right solutions for each asset

Areal field surveillance - Applying the right solutions for ...

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SPE Middle East Intelligent Energy Conference and Exhibition 2013, IEME 2013

作者： Engbers, Peter Zwaan, Marcel Grandi, Samantha Shell Projects and Technology United States

ISBN: (纸本)9781613992760

As part of Smart Fields, deployment of surveillance solutions adds a lot of value to further field development and well and reservoir management by providing insight into the reservoir behaviour and therefore enabling timely decisions. Solutions need to be tailored for the specific field, production type, purpose, or environment. We have developed a framework to ensure that we deploy the right Field Surveillance solutions for each type of field and asset. In this paper, we describe how we screen, decide applicability, and deploy integrated Field Surveillance solutions for the shell portfolio. As guidance, we make use of a newly build Solutions Advisory. This advisory, for example, highlights which solutions are standard in which environment, meaning that you would have to justify why not to implement. We will describe how this assessment and deployment works with a field example from an onshore EOR field. Substantial value has been added as a result of the optimized, fit for purpose surveillance program, linked to a decision-logic with identified control measures. Copyright 2013, Society of Petroleum Engineers.

关键词： Reservoir management

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