Imperial College London

Professor Gary Hampson

Faculty of EngineeringDepartment of Earth Science & Engineering

Professor of Sedimentary Geology
 
 
 
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Contact

 

+44 (0)20 7594 6475g.j.hampson

 
 
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Location

 

1.42Royal School of MinesSouth Kensington Campus

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Summary

 

Publications

Publication Type
Year
to

103 results found

Debbabi Y, Jackson MD, Hampson GJ, Fitch PJR, Salinas Pet al., 2017, Viscous Crossflow in Layered Porous Media, Transport in Porous Media, Vol: 117, Pages: 281-309, ISSN: 0169-3913

JOURNAL ARTICLE

Debbabi Y, Jackson MD, Hampson GJ, Salinas Pet al., 2017, Capillary Heterogeneity Trapping and Crossflow in Layered Porous Media, TRANSPORT IN POROUS MEDIA, Vol: 120, Pages: 183-206, ISSN: 0169-3913

JOURNAL ARTICLE

Hampson GJ, Howell JA, 2017, Sedimentologic and sequencestratigraphic characteristics of wave-dominated deltas, AAPG BULLETIN, Vol: 101, Pages: 441-451, ISSN: 0149-1423

JOURNAL ARTICLE

Hampson GJ, Premwichein K, 2017, Sedimentologic Character of Ancient Muddy Subaqueous-Deltaic Clinoforms: Down Cliff Clay Member, Bridport Sand Formation, Wessex Basin, U.K., Journal of Sedimentary Research, Vol: 87, Pages: 951-966, ISSN: 1527-1404

JOURNAL ARTICLE

Hampson GJ, Reynolds AD, Kostic B, Wells MRet al., 2017, Introduction to the sedimentology of paralic reservoirs: recent advances, Pages: 1-6

BOOK CHAPTER

Le Blevec T, Dubrule O, john CM, Hampson GJet al., 2017, Modelling asymmetrical facies successions using pluri-Gaussian simulations, Geostatistics Valencia 2016, Publisher: Springer, Pages: 59-75, ISBN: 978-3-319-46818-1

An approach to model spatial asymmetrical relations between indicators is presented in a pluri-Gaussian framework. The underlying gaussian random functions are modelled using the linear model of co-regionalization, and a spatial shift is applied to them. Analytical relationships between the two underlying gaussian variograms and the indicator covariances are developed for a truncation rule with three facies and cut-off at 0. The application of this truncation rule demonstrates that the spatial shift on the underlying gaussian functions produces asymmetries in the modelled 1D facies sequences. For a general truncation rule, the indicator covariances can be computed numerically, and a sensitivity study shows that the spatial shift and the correlation coefficient between the gaussian functions provide flexibility to model the asymmetry between facies. Finally, a case study is presented of a Triassic vertical facies succession in the Latemar carbonate platform (Dolomites, Northern Italy) composed of shallowing-upward cycles. The model is flexible enough to capture the different transition probabilities between the environments of deposition and to generate realistic facies successions.

BOOK CHAPTER

van Cappelle M, Ravnas R, Hampson GJ, Johnson HDet al., 2017, Depositional evolution of a progradational to aggradational, mixed-influenced deltaic succession: Jurassic Tofte and Ile formations, southern Halten Terrace, offshore Norway, MARINE AND PETROLEUM GEOLOGY, Vol: 80, Pages: 1-22, ISSN: 0264-8172

JOURNAL ARTICLE

Hampson GJ, 2016, Towards a sequence stratigraphic solution set for autogenic processes and allogenic controls: Upper Cretaceous strata, Book Cliffs, Utah, USA, JOURNAL OF THE GEOLOGICAL SOCIETY, Vol: 173, Pages: 817-836, ISSN: 0016-7649

JOURNAL ARTICLE

Jordan OD, Gupta S, Hampson GJ, Johnson HDet al., 2016, PRESERVED STRATIGRAPHIC ARCHITECTURE AND EVOLUTION OF A NET-TRANSGRESSIVE MIXED WAVE- AND TIDE-INFLUENCED COASTAL SYSTEM: THE CLIFF HOUSE SANDSTONE, NORTHWESTERN NEW MEXICO, USA, JOURNAL OF SEDIMENTARY RESEARCH, Vol: 86, Pages: 1399-1424, ISSN: 1527-1404

JOURNAL ARTICLE

Massart BYG, Jackson MD, Hampson GJ, Johnson HDet al., 2016, Effective flow properties of heterolithic, cross-bedded tidal sandstones: Part 2. Flow simulation, AAPG BULLETIN, Vol: 100, Pages: 723-742, ISSN: 0149-1423

JOURNAL ARTICLE

Massart BYG, Jackson MD, Hampson GL, Johnson HD, Legler B, Jackson CA-Let al., 2016, Effective flow properties of heterolithic, cross-bedded tidal sandstones: Part I. Surface-based modeling, AAPG BULLETIN, Vol: 100, Pages: 697-721, ISSN: 0149-1423

JOURNAL ARTICLE

Sahoo H, Gani MR, Hampson GJ, Gani ND, Ranson Aet al., 2016, Facies- to sandbody-scale heterogeneity in a tight-gas fluvial reservoir analog: Blackhawk Formation, Wasatch Plateau, Utah, USA, MARINE AND PETROLEUM GEOLOGY, Vol: 78, Pages: 48-69, ISSN: 0264-8172

JOURNAL ARTICLE

van Cappelle M, Stukins S, Hampson GJ, Johnson HDet al., 2016, Fluvial to tidal transition in proximal, mixed tide-influenced and wave-influenced deltaic deposits: Cretaceous lower Sego Sandstone, Utah, USA, SEDIMENTOLOGY, Vol: 63, Pages: 1333-1361, ISSN: 0037-0746

JOURNAL ARTICLE

Armitage JJ, Allen PA, Burgess PM, Hampson GJ, Whittaker AC, Duller RA, Michael NAet al., 2015, SEDIMENT TRANSPORT MODEL FOR THE EOCENE ESCANILLA SEDIMENT-ROUTING SYSTEM: IMPLICATIONS FOR THE UNIQUENESS OF SEQUENCE STRATIGRAPHIC ARCHITECTURES, JOURNAL OF SEDIMENTARY RESEARCH, Vol: 85, Pages: 1510-1524, ISSN: 1527-1404

JOURNAL ARTICLE

Gani MR, Ranson A, Cross DB, Hampson GJ, Gani ND, Sahoo Het al., 2015, Along-strike sequence stratigraphy across the Cretaceous shallow marine to coastal-plain transition, Wasatch Plateau, Utah, U.S.A., Sedimentary Geology, Vol: 325, Pages: 59-70, ISSN: 0037-0738

JOURNAL ARTICLE

Graham GH, Jackson MD, Hampson GJ, 2015, Three-dimensional modeling of clinoforms in shallow-marine reservoirs: Part 2. Impact on fluid flow and hydrocarbon recovery in fluvial-dominated deltaic reservoirs, AAPG Bulletin, Vol: 99, Pages: 1049-1080, ISSN: 0149-1423

© 2015. The American Association of Petroleum Geologists. All rights reserved. Permeability contrasts associated with clinoforms have been identified as an important control on fluid flow and hydrocarbon recovery in fluvial-dominated deltaic parasequences. However, they are typically neglected in subsurface reservoir models or considered in isolation in reservoir simulation experiments because clinoforms are difficult to capture using current modeling tools. A suite of three-dimensional reservoir models constructed with a novel, stochastic, surface-based clinoform-modeling algorithm and outcrop analog data (Upper Cretaceous Ferron Sandstone Member, Utah) have been used here to quantify the impact of clinoforms on fluid flow in the context of (1) uncertainties in reservoir characterization, such as the presence of channelized fluvial sandbodies and the impact of bed-scale heterogeneity on vertical permeability, and (2) reservoir engineering decisions, including oil production rate. The proportion and distribution of barriers to flow along clinoforms exert the greatest influence on hydrocarbon recovery; equivalent models that neglect these barriers overpredict recovery by up to 35%. Continuity of channelized sandbodies that cut across clinoform tops and vertical permeability within distal delta-front facies influence sweep within clinothems bounded by barriers. Sweep efficiency is reduced when producing at higher rates over shorter periods, because oil is bypassed at the toe of each clinothem. Clinoforms are difficult to detect using production data, but our results indicate that they significantly influence hydrocarbon recovery and their impact is typically larger than that of other geologic heterogeneities regardless of reservoir engineering decisions. Clinoforms should therefore be included in models of fluvial-dominated deltaic reservoirs to accurately predict hydrocarbon recovery and drainage patterns.

JOURNAL ARTICLE

Graham GH, Jackson MD, Hampson GJ, 2015, Three-dimensional modeling of clinoforms in shallow-marine reservoirs: Part 1. Concepts and application, AAPG Bulletin, Vol: 99, Pages: 1013-1047, ISSN: 0149-1423

© 2015. The American Association of Petroleum Geologists. All rights reserved. Clinoform surfaces control aspects of facies architecture within shallow-marine parasequences and can also act as barriers or baffles to flow where they are lined by low-permeability lithologies, such as cements or mudstones. Current reservoir modeling techniques are not well suited to capturing clinoforms, particularly if they are numerous, below seismic resolution, and/or difficult to correlate between wells. At present, there are no modeling tools available to automate the generation of multiple three-dimensional clinoform surfaces using a small number of input parameters. Consequently, clinoforms are rarely incorporated in models of shallow-marine reservoirs, even when their potential impact on fluid flow is recognized. A numerical algorithm that generates multiple clinoforms within a volume defined by two bounding surfaces, such as a delta-lobe deposit or shoreface parasequence, is developed. A geometric approach is taken to construct the shape of a clinoform, combining its height relative to the bounding surfaces with a mathematical function that describes clinoform geometry. The method is flexible, allowing the user to define the progradation direction and the parameters that control the geometry and distribution of individual clinoforms. The algorithm is validated via construction of surface-based three-dimensional reservoir models of (1) fluvial-dominated delta-lobe deposits exposed at the outcrop (Cretaceous Ferron Sandstone Member, Utah), and (2) a sparse subsurface data set from a deltaic reservoir (Jurassic Sognefjord Formation, Troll Field, Norwegian North Sea). Resulting flow simulation results demonstrate the value of including algorithm-generated clinoforms in reservoir models, because they may significantly impact hydrocarbon recovery when associated with areally extensive barriers to flow.

JOURNAL ARTICLE

Holgate NE, Jackson CA-L, Hampson GJ, Dreyer Tet al., 2015, Seismic stratigraphic analysis of the Middle Jurassic Krossfjord and Fensfjord formations, Troll oil and gas field, northern North Sea, Marine and Petroleum Geology, Vol: 68, Pages: 352-380, ISSN: 0264-8172

JOURNAL ARTICLE

Jackson MD, Hampson GJ, Rood D, Geiger S, Zhang Z, Sousa MC, Amorim R, Brazil EV, Samavati FF, Guimaraes LNet al., 2015, Rapid reservoir modeling: Prototyping of reservoir models, well trajectories and development options using an intuitive, sketch-based interface, Pages: 829-845

Copyright © 2015 Society of Petroleum Engineers. Constructing or refining complex reservoir models at the appraisal, development, or production stage is a challenging and time-consuming task that entails a high degree of uncertainty. The challenge is significantly increased by the lack of modeling, simulation and visualization tools that allow prototyping of reservoir models and development concepts, and which are simple and intuitive to use. Conventional modeling workflows, facilitated by commercially available software packages, have remained essentially unchanged for the past decade. However, these are slow, often requiring many months from initial model concepts to flow simulation or other outputs; moreover, many model concepts, such as large scale reservoir architecture, become fixed early in the process and are difficult to retrospectively change. Such workflows are poorly suited to rapid prototyping of a range of reservoir model concepts, wel l trajectories and development options, and testing of how these might impact on reservoir behavior. We present a new reservoir modeling and simulation approach termed Rapid Reservoir Modeling (RRM) that allows such prototyping and complements existing workflows. In RRM, reservoir geometries that describe geologic heterogeneities (e.g. faults, stratigraphic, sedimentologic and/or diagenetic features) are modelled as discrete volumes bounded by surfaces, without reference to a predefined grid. These surfaces, and also well trajectories, are created and modified using intuitive, interactive techniques from computer visualization, such as Sketch Based Interfaces and Modeling (SBIM). Input data can be sourced from seismic, geocellular or flow simulation models, outcrop analogues, conceptual model libraries or blank screen. RRM outputs can be exported to conventional workflows at any stage. Gridding or meshing of the models within the RRM framework allows rapid calculation of key reservoir properties and dynamic behavior

CONFERENCE PAPER

Patruno S, Hampson GJ, Jackson CA-L, 2015, Quantitative characterisation of deltaic and subaqueous clinoforms, Earth-Science Reviews, Vol: 142, Pages: 79-119, ISSN: 0012-8252

JOURNAL ARTICLE

Patruno S, Hampson GJ, Jackson CA-L, Dreyer Tet al., 2015, Clinoform geometry, geomorphology, facies character and stratigraphic architecture of a sand-rich subaqueous delta: Jurassic Sognefjord Formation, offshore Norway, Sedimentology, Vol: 62, Pages: 350-388, ISSN: 0037-0746

JOURNAL ARTICLE

Villamizar CA, Hampson GJ, Flood YS, Fitch PJRet al., 2015, Object-based modelling of avulsion-generated sandbody distributions and connectivity in a fluvial reservoir analogue of low to moderate net-to-gross ratio, Petroleum Geoscience, Vol: 21, Pages: 249-270, ISSN: 1354-0793

JOURNAL ARTICLE

Agar SM, Hampson GJ, 2014, Fundamental controls on flow in carbonates: an introduction, Petroleum Geoscience, Vol: 20, Pages: 3-5, ISSN: 1354-0793

JOURNAL ARTICLE

Deveugle PEK, Jackson MD, Hampson GJ, Stewart J, Clough MD, Ehighebolo T, Farrell ME, Calvert CS, Miller JKet al., 2014, A comparative study of reservoir modeling techniques and their impact on predicted performance of fluvial-dominated deltaic reservoirs, AAPG Bulletin, Vol: 98, Pages: 729-763, ISSN: 0149-1423

Multiple techniques are available to construct three-dimensional reservoir models. This study uses comparative analysis to test the impact of applying four commonly used stochastic modcling techniques to capture geologic heterogeneity and fluid-flow behavior in fluvial-dominated deltaic reservoirs of complex facies architecture: (1) sequential indicator simulation; (2) object-based modeling; (3) multiple-point statistics (MPS); and (4) spectral component geologic modeling. A reference for comparison is provided by a high-resolution model of an outcrop analog that captures facies architecture at the scale of parasequences, delta lobes, and fades-association belts. A sparse, pseudosubsurface data set extracted from the reference model is used to condition models constructed using each stochastic reservoir modeling technique. Models constructed using all four algorithms fail to match the facies-association proportions of the reference model because they are conditioned to well data that sample a small, unrepresentative volume of the reservoir. Simulated sweep efficiency is determined by the degree to which the modeling algorithms reproduce two aspects of fades architecture that control sand-body connectivity: (1) the abundance, continuity, and orientation of channelized fluvial sand bodies; and (2) the lateral continuity of barriers to vertical flow associated with flooding surfaces. The MPS algorithm performs best in this regard. However, the static and dynamic performance of the models (as measured against facies-association proportions, facies architecture, and recovery factor of the reference model) is more dependent on the quality and quantity of conditioning data and on the interpreted geologic scenario(s) implicit in the models than on the choice of modeling technique. Copyright ©2014. The American Association of Petroleum Geologists. All rights reserved.

JOURNAL ARTICLE

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