Total E and P UK Ltd

Aberdeen, United Kingdom

Total E and P UK Ltd

Aberdeen, United Kingdom

Time filter

Source Type

Mainguy M.,TOTAL EandP UK Ltd | Mainguy M.,Total S.A.
International Journal of Rock Mechanics and Mining Sciences | Year: 2016

Approximately thirty Multi-Finger Calliper (MFC) surveys have been acquired in Elgin and Franklin development wells between 2003 and 2013. These surveys reveal around one hundred shear deformation features characterized by a kink in the pipe. The calliper surveys were depth shifted against the open-hole reference depth used in Geoscience to accurately identify the interfaces along which the deformations occur. The deformations have been found to be distributed at the top of the Fulmar Formation reservoir, in the Late Jurassic shales, in the Early Cretaceous Cromer Knoll Group, and the Late Cretaceous Chalk Group. For each deformation feature, the relative displacement of the well was estimated using the calliper tool eccentricity resulting from the movement of the toolstring through the kink in the pipe. Maximum relative displacements were estimated at 3.7 in. in the 7 in. liner and at 1.2 in. in the 9 7/8 in. production casing. The analysis of the calliper surveys show that the deformation features result from slip displacements along various discontinuities such as bedding planes, reservoir faults extending in the overburden, and overburden faults. It is interpreted that these interfaces have been reactivated because of the strong reservoir depletion. This work clearly demonstrates that MFC surveys are an effective tool for monitoring shear deformations occurring above a compacting reservoir. © 2016 Elsevier Ltd.


Lawson B.,Total E and P UK Ltd.
Society of Petroleum Engineers - SPE/APPEA Int. Conference on Health, Safety and Environment in Oil and Gas Exploration and Production 2012: Protecting People and the Environment - Evolving Challenges | Year: 2012

This paper will explain the process and practices involved in managing Asset Integrity within the context of the UKCS, one of the most regulated environments of the world. The paper will explain the following main areas: 1 The workings of Asset integrity within an major oil and gas company operating in the N Sea, including illumination of the processes that we have developed over the last seven years to assess the risks of the threats that we face in order to validate and prioritise the works. 2 We have undertaken ageing and life extension studies and the paper will discuss the methodology used, the outcomes and the results in relation the UK regulators programme to assess the understanding of Oil and Gas companies in relation to ageing and life extension. The processes and tools explained in the paper will be transferable to any operator or duty holder looking to establish or improve an Asset Integrity function around the world. In terms of achievements, the processes that we have in place both demonstrates that we are managing the risks that we encounter as well as senior management involvement and leadership on the issues. With regard to life extension, as a result of the ageing studies that we undertook we have moved on from study and assessment into the implementation phase of the required works that will enable us to operate one of our facilities for 20 years in excess of the original design life. The author is a member of the Asset Integrity Workgroup in Stepchange in Safety and has presented on elements of Asset Integrity at numerous seminars in the UK in recent years. Most recently I was also invited to participate as a member of the panel session on Ageing and Life Extension at Offshore Europe 2011 in Aberdeen. Copyright 2012, SPE/APPEA International Conference on Health, Safety, and Environment in Oil and Gas Exploration and Production.


Purvis B.,Total E and P UK Ltd
Proceedings of the Biennial International Pipeline Conference, IPC | Year: 2010

This paper will discuss both the present situation and future developments in Pipeline Integrity Monitoring. It will also highlight how integrity monitoring is a vital part of any Pipeline Integrity Management System (PIMS). To give the true picture of a pipeline's condition, the integrity monitoring systems must identify those elements of the pipeline which are at most risk to any potential modes of failure. Pipeline integrity monitoring offshore tends to be the periodic monitoring of specified components above and below the water surface. This being in the form of long and short term monitoring programs, which are derived from threat identification, risk assessment and mitigation processes. These programs normally follow the relevant industry standards that define specific monitoring activities and frequencies, especially for the safety critical components. PIMS documentation review cycles can be long and complex, but should be undertaken on a regular basis. When these reviews are undertaken they don't always use new data sources that could give us more information about potential failure modes. At present these processes tend to be more reactive or lagging in nature. The future monitoring of pipeline integrity should be more forward-looking and be proactive as well as being reactive. Where are the next major developments? We need to make better use of the data we have by studying trends, changes and impacts wherever possible. Also, have a better understanding of the in-service behaviour and how this can change over the life cycle of a pipeline system. Copyright © 2010 by ASME.


Petrie G.,Total E and P UK Ltd. | Rosbrook A.,Total E and P UK Ltd.
Society of Petroleum Engineers - SPE Offshore Europe Conference and Exhibition, OE 2015 | Year: 2015

Although the importance of human failures in causing accidents is well known in the Oil & Gas industry, historically the focus in safety cases or site safety reports has been less on human failures than on technical failures in major accident hazards (MAH). In order to address this disparity the Company has developed a process to manage the risk of human error across their assets. This is primarily for mature tasks and activities that is things that are currently done and have been for some time, as well as new tasks and activities from projects and modifications. This involves developing a robust process to select specific activities where Major Accident Hazard (MAH) scenarios had been identified from the various safety studies. Progress at first has been slow but by developing sound foundations the company has started to show significant benefits in managing human failures that may lead to MAH scenarios. This paper describes and details how this process has gained momentum by the Company providing dedicated resources to support the assessment process and to facilitate updates to site procedures. This work involves both operators and maintenance technicians in the analysis and site walk- and-talk through of the task. The process has identified safety related risks that were not previously recognised and significant environmental risks, operational risks (equipment damage, process upsets) and potential downtime of plant. A key benefit of employee involvement is that employees are actively involved in human error analysis in their day-to-day activities and recognise where human error is critical as well as the true value of maintaining key recovery systems Key learning points and case studies are described in order that they can be used by other organisations to assist in any application of the process. This process is very much work in progress. However, foundations have been developed to ensure lessons are learned and to ensure a standard approach to using a human factors approach to manageging MAH across the organisation. © Copyright 2015, Society of Petroleum Engineers.


Blanchard T.D.,Total E and P UK Ltd | Delommot P.,Total E and P UK Ltd
Geophysics | Year: 2015

There is much theoretical and laboratory evidence for fluid-related mechanisms causing attenuation in the seismic bandwidth; however, the number of measurements made from seismic reflection data is limited. We measured attenuation changes in a reservoir undergoing depletion and, in some locations, water injection. Two different applications of these measurements were then found. First, we used the measured attenuation changes to perform a time-lapse Q correction to improve 4D inversion results in an underlying reservoir. Second, we attempted to integrate the measured attenuation changes with changes in traveltime to try to separate gas and water saturations in the reservoir. We determined that large and coherent time-lapse attenuation measurements can occur in reservoirs undergoing production and that the nature of this attenuation when averaged across a region of the reservoir was consistent with a constant-Q hypothesis. Measurements were of good quality and were coherent with the geologic (such as channels) and dynamic characteristics (such as gas coming out of solution) of the reservoir. Finally, we evaluated the possible implications of such data sets upon enhancing our understanding of the underlying mechanisms controlling attenuation in the seismic bandwidth by providing favorable conditions for canceling spectral contamination and the fact that we have knowledge of the physical changes occurring within the reservoir. © 2015 Society of Exploration Geophysicists.


Saha P.,Total E and P UK Ltd | Parsa A.,Total E and P UK Ltd | Abolarin J.,Total E and P UK Ltd
SPE Production and Operations | Year: 2014

The Northern Underwater Gas Gathering, Export, and Treatment System (NUGGETS) subsea development in the northern North Sea consists of five gas wells and a 40- to 70-km tieback to the Alwyn platform, with first gas in 2001 and peak gas production of 6 million std m3/d in 2004. Project life was expected to be 10 years, with the main constraints being methanol (MeOH) requirements for hydrate management and sealine minimum turndown. Because of increasing water production, the wells were shut in one after another, and the field was scheduled to be decommissioned in 2010. At that time, the minimum recommended MeOH concentration was approximately 28% (wt/wt; MeOH/water), which allowed for a maximum water production of 40 std m3/d. Because of a concerted effort to keep gas rates at targets that respected all constraints and to reduce MeOH use to zero, an additional 4.0 million BOE has been produced from NUGGETS. This represents an incremental recovery of approximately 3%. In addition, the field life has been extended, with the possibility of further prospects being tied into the existing facilities. With MeOH constraints removed, the new issues became subsea-system-life longevity and reservoir management. Current field-operations philosophy is optimized to respect the minimum gas rate per well with or without water production. It is also aimed to manage water coning in the reservoir. The reservoir has very high permeability with kv/kh≈ 1 and strong aquifer influx. Moreover, numerical and analytical methods were used to investigate the coning. This paper provides a critical assessment of the methods used from the flow-assurance, well-performance, and reservoir-management points of view. It concludes with a set of observations and recommendations for operators of dry-gas fields with strong aquifers and long subsea tiebacks. Copyright © 2014 Society of Petroleum Engineers.


Blanchard T.D.,Total E and P UK Ltd | Thore P.,Total E and P UK Ltd
75th European Association of Geoscientists and Engineers Conference and Exhibition 2013 Incorporating SPE EUROPEC 2013: Changing Frontiers | Year: 2013

The seismic inversion of 4D prestack amplitude information (AVO) can be very non-unique, leading to dubious estimates of dynamic properties. Here we demonstrate a workflow that simultaneously uses the 4D time shift, 4D amplitude and a novel dynamic constraint to invert for much more robust and reservoir consistent changes in elastic parameters. The conversion of these elastic parameters to pressure and saturation yields very promising results. Previously undetectable small-scale changes in pressure are now observed that are coherent with the completion zones of a water injection well. Copyright © (2012) by the European Association of Geoscientists & Engineers All rights reserved.


Petrie G.F.J.,Total e and P UK Ltd | Rosbrook A.,Total e and P UK Ltd
Institution of Chemical Engineers Symposium Series | Year: 2015

Although the importance of human failures in causing accidents is well known in the Oil & Gas industry, historically the focus has been less on human failures than on technical failures in major accident hazards (MAH). In order to address this disparity, TOTAL Exploration & Production (E&P) UK (TEPUK) has developed a process to manage the risk of human error across their assets. This is primarily for mature tasks and activities i.e. things that are currently done and have been for some time, as well as new tasks and activities from projects and modifications. This involves developing a robust process to select specific activities where Major Accident Hazard (MAH) scenarios had been identified from the various safety studies. Progress at first has been slow but by developing sound foundations the company has started to show significant benefits in managing human failures within MAH scenarios. This paper describes progress to date across TEPUK and details how the process has gained momentum by providing dedicated resources to support the assessment process and to facilitate updates to site procedures. This work involves both operators and maintenance technicians in the analysis and site walk- and-talk through of the task. The process has identified safety related risks that were not previously recognised and significant environmental risks, operational risks (equipment damage, process upsets etc) and potential downtime of plant. A key benefit of employee involvement is that employees are actively involved in human error analysis in their day-to-day activities and recognise where human error is critical as well as the true value of maintaining the key recovery systems such as hose registers, locked open/locked closed process, line walks etc. The challenges along the way include the following points; • Organisations need to be 'intelligent customers' (ONR Guide 2013) • A clear and agreed strategy and common methodology as a prerequisite • Focus on major risks (different to industry approach) • Closing the loop (from MAH scenarios linked to procedures and through to training & competency) • Integrating human factors into the business, ensuring that the workforce and management have sufficient knowledge of Human and Organisational Factors (HOF) • Involving (i.e. beyond 'engagement') the employees (in every aspect of the human factors work-scope; awareness, ownership and accountability) • Fully integrating the human factors agenda into projects and modifications This process is very much work in progress however foundations have been developed to streamline the process. A large number of employees are now involved in human factors work-scopes through training, analysis and updates to procedures. TEPUK's focus is to continue addressing high risk tasks which could lead to a MAH across operational sites until these have been fully understood and measures implemented to mitigate issues identified. Only then will there be progress on safety critical task analysis which are identified as medium or low risk. © 2015 Amec Foster Wheeler.


Kachuma D.,Total EandP UK Ltd
ECMOR 2010 - 12th European Conference on the Mathematics of Oil Recovery | Year: 2010

The use of complex corner point systems in field flow reservoir simulators allows the modelling of a wider variety of cell geometries and hence a better representation of faulted reservoirs. If faults are involved, then a cell face may be next to two or more cell faces. This phenomenon can also be observed in situations where the cells in a particular region have been refined to improve accuracy. This creates complex connections between cell faces which require special attention and representation within the simulator. Conventionally, this is handled by the use of the so-called non-neighbour connections (NNC) whereby the simulator includes, on top of the regular neighbour fluxes, the fluxes between the extra cell connections. We present a robust technique which is applicable regardless of the flow configuration. Our technique involves subdividing each cell with non-neighbour fluxes into a local regular subgrid. Using this grid the local streamfunction is constructed numerically. By reducing the size of the local subgrid, the accuracy of the traced streamlines improves. We demonstrate this technique first on a detailed 2D synthetic example that is designed to show the robustness of the technique. The practical utility of our algorithm is then demonstrated in a structurally complex and heavily faulted full model of a North Sea field which includes cells with several nonneighbour configurations in different faces. This treatment is contrasted with the usual approach and also other techniques designed to trace streamlines in heavily faulted systems.


Thore P.,Total E and P UK Ltd
75th European Association of Geoscientists and Engineers Conference and Exhibition 2013 Incorporating SPE EUROPEC 2013: Changing Frontiers | Year: 2013

I present a classification of Seismic Inversions in two categories; Data Driven and Model Based. Based on examples I show that no inversion is purely data driven and that the user has to provide prior information which constrains the solution to a certain behavior. On the other hand, Model Based Inversion can provide very appealing results (an example breaks the traditional view of seismic resolution) provided that the underlying model is sound. I conclude by proposing a workflow which tries to get the best from both approaches. Copyright © (2012) by the European Association of Geoscientists & Engineers All rights reserved.

Loading Total E and P UK Ltd collaborators
Loading Total E and P UK Ltd collaborators