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  • Journal article
    Dilib FA, Jackson MD, 2013,

    Closed-Loop Feedback Control for Production Optimization of Intelligent Wells Under Uncertainty

    , SPE PRODUCTION & OPERATIONS, Vol: 28, Pages: 345-357, ISSN: 1930-1855
  • Journal article
    Legler B, Johnson HD, Hampson GJ, Massart BYG, Jackson CA-L, Jackson MD, El-Barkooky A, Ravnas Ret al., 2013,

    Facies model of a fine-grained, tide-dominated delta: Lower Dir Abu Lifa Member (Eocene), Western Desert, Egypt

    , Sedimentology, Vol: 60, Pages: 1313-1356, ISSN: 0037-0746
  • Journal article
    Agar S, Geiger S, Leonide P, Lamarche J, Bertotti G, Gosselin O, Hampson GJ, Jackson MD, Jones G, Kenter J, Matthai SK, Neilson J, Pyrak-Nolte L, Whittaker F, Agar S, Geiger S, Leonide P, Lamarche J, Bertotti G, Gosselin O, Hampson GJ, Jackson M, Jones G, Kenter J, Matthai S, Neilson J, Pyrak-Nolte L, Whitaker Fet al., 2013,

    Summary of the AAPG–SPE–SEG Hedberg Research Conference on “Fundamental Controls on Flow in Carbonates”

    , AAPG Bulletin, Vol: 97, Pages: 533-552

    A joint AAPG–Society of Petroleum Engineers–Society of Exploration Geophysicists Hedberg Research Conference was held in Saint-Cyr sur Mer, France, on July 8 to 13, 2012, to review current research and explore future research directions related to improved production from carbonate reservoirs. Eighty-seven scientists from academia and industry (split roughly equally) attended for five days. A primary objective for the conference was to explore novel connections among different disciplines (primarily within geoscience and reservoir engineering) as a way to define new research opportunities. Research areas represented included carbonate sedimentology and stratigraphy, structural geology, geomechanics, hydrology, reactive transport modeling, seismic imaging (including four-dimensional seismic, tomography, and seismic forward modeling), geologic modeling and forward modeling of geologic processes, petrophysics, statistical methods, numerical methods for simulation, reservoir engineering, pore-scale processes, in-situ flow experiments (e.g., x-ray computed tomography), visualization, and methods for data interaction.

  • Journal article
    Solano JMS, Jackson MD, Sparks RSJ, Blundy JD, Annen Cet al., 2012,

    Melt Segregation in Deep Crustal Hot Zones: a Mechanism for Chemical Differentiation, Crustal Assimilation and the Formation of Evolved Magmas

    , Journal of Petrology, Vol: 53, Pages: 1999-2026, ISSN: 1460-2415

    Mantle-derived basaltic sills emplaced in the lower crust provide amechanism for the generation of evolved magmas in deep crustal hotzones (DCHZ).This study uses numerical modelling to characterizethe time required for evolved magma formation, the depth and temperatureat which magma formation occurs, and the composition ofthe magma.The lower crust is assumed to comprise amphibolite. Inan extension of previous DCHZ models, the new model couples heattransfer during the repetitive emplacement of sills with mass transfervia buoyancy-driven melt segregation along grain boundaries.The resultsshed light on the dynamics of DCHZ development and evolution.TheDCHZ comprises a mush of crystals plus interstitial melt,except when a new influx of basaltic magma yields a short-lived(20^200 years) reservoir of melt plus suspended crystals (magma).Melt segregation and accumulation within the mush yields two contrastingmodes of evolved magma formation, which operate over timescalesof c. 10 kyr-1 Myr, depending upon emplacement rate andstyle. In one, favoured by emplacement via over-accretion, or emplacementat high rates, evolved magma forms in the crust overlying theintruded basalt sills, and is composed of crustal partial melt, and residualmelt that has migrated upwards out of the crystallizingbasalt. In the other, favoured by emplacement via under- orintra-accretion, or by emplacement at lower rates, evolved magmaforms in the intruded basalt, and the resulting magma is composedprimarily of residual melt. In all cases, the upward migration ofbuoyant melt yields cooler and more evolved magmas, which arebroadly granitic in composition. Chemical differentiation is thereforedriven by melt migration, because the melt migrates through, andchemically equilibrates with, partially molten rock at progressivelylower temperatures. Crustal assimilation occurs during partial melting,and mixing of crustal and residual melt occurs when residualmelt migrates into the partially molten crust, yielding

  • Journal article
    Glover PWJ, Walker E, Jackson MD, 2012,

    Streaming-potential coefficient of reservoir rock: A theoretical model

    , Geophysics, Vol: 77, Pages: D17-D43, ISSN: 1942-2156

    The streaming potential is that electrical potential whichdevelops when an ionic fluid flows through the pores of a rock.It is an old concept that is recently being applied in many fieldsfrom monitoring water fronts in oil reservoirs to understandingthe mechanisms behind synthetic earthquakes. We have carriedout fundamental theoretical modeling of the streaming-potentialcoefficient as a function of pore fluid salinity, pH, and temperatureby modifying the HS equation for use with porous rocksand using input parameters from established fundamental theory(the Debye screening length, the Stern-plane potential, the zetapotential, and the surface conductance). The model also requiresthe density, electrical conductivity, relative electric permittivityand dynamic viscosity of the bulk fluid, for which empiricalmodels are used so that the temperature of the model may bevaried. These parameters are then combined with parametersthat describe the rock microstructure. The resulting theoreticalvalues have been compared with a compilation of data for siliceousmaterials comprising 290 streaming-potential coefficientmeasurements and 269 zeta-potential measurements obtainedexperimentally for 17 matrix-fluid combinations (e.g., sandstonesaturated with KCl), using data from 29 publications.The theoretical model was found to ably describe the main featuresof the data, whether taken together or on a sample by samplebasis. The low-salinity regime was found to be controlled bysurface conduction and rock microstructure, and was sensitiveto changes in porosity, cementation exponent, formation factor,grain size, pore size and pore throat size as well as specific surfaceconductivity. The high-salinity regime was found to be subjectto a zeta-potential offset that allows the streaming-potentialcoefficient to remain significant even as the saturation limit isapproached

  • Journal article
    Jackson MD, Vinogradov J, 2012,

    Impact of wettability on laboratory measurements of streaming potential in carbonates

  • Journal article
    Jackson MD, Leinov E, 2012,

    On the Validity of the “Thin” and “Thick”Double-Layer Assumptions When CalculatingStreaming Currents in Porous Media

    , International Journal of Geophysics, Vol: 2012, ISSN: 1687-8868

    We find that the thin double layer assumption, in which the thickness of the electrical diffuse layer is assumed small comparedto the radius of curvature of a pore or throat, is valid in a capillary tubes model so long as the capillary radius is >200 times thedouble layer thickness, while the thick double layer assumption, in which the diffuse layer is assumed to extend across the entirepore or throat, is valid so long as the capillary radius is >6 times smaller than the double layer thickness. At low surface chargedensity (<10 mC · m−2) or high electrolyte concentration (>0.5 M) the validity criteria are less stringent. Our results suggest thatthe thin double layer assumption is valid in sandstones at low specific surface charge (<10 mC · m−2), but may not be valid insandstones of moderate- to small pore-throat size at higher surface charge if the brine concentration is low (<0.001 M). The thickdouble layer assumption is likely to be valid in mudstones at low brine concentration (<0.1 M) and surface charge (<10 mC·m−2),but at higher surface charge, it is likely to be valid only at low brine concentration (<0.003 M). Consequently, neither assumptionmay be valid in mudstones saturated with natural brines.

  • Journal article
    Saunders JH, Jackson MD, Pain CC, Vinogradov J, Saunders JH, Jackson MD, Gulamali MY, Vinogradov J, Pain CC, Saunders JH, Jackson MD, Gulamali MY, Vinogradov Jet al., 2012,

    Streaming potentials in hydrocarbon reservoir conditions

    , Geophysics, Vol: 77, Pages: E77-E90
  • Journal article
    Jackson MD, Gulamali MY, Leinov E, Saunders JH, Vinogradov Jet al., 2012,

    Spontaneous Potentials in Hydrocarbon Reservoirs during Waterflooding: Application to Waterfront Monitoring

    , SPE Journal
  • Journal article
    Jackson MD, Butler AP, Vinogradov J, 2012,

    Measurements of Spontaneous Potential in Chalk with Application to Aquifer Characterisation in the Southern UK

    , Quarterly Journal of Engineering Geology and Hydrogeology
  • Journal article
    Jackson MD, Vinogradov J, Saunders JH, Jaafar MZet al., 2011,

    Laboratory Measurements and Numerical Modeling of Streaming Potential for Downhole Monitoring in Intelligent Wells

    , SPE JOURNAL, Vol: 16, Pages: 625-636, ISSN: 1086-055X
  • Journal article
    Gulamali MY, Leinov E, Jackson MD, 2011,

    Self-potential anomalies induced by water injection into hydrocarbon reservoirs

    , GEOPHYSICS, Vol: 76, Pages: F283-F292, ISSN: 0016-8033
  • Journal article
    Gulamali MY, Leinov E, Jackson MD, 2011,

    Self-potential anomalies induced by water injection into hydrocarbon reservoirs

    , Geophysics, Vol: 76, Pages: F283-F292, ISSN: 1942-2156

    The injection of cold water into a hydrocarbon reservoir containingrelatively warmer, more saline formation brine may generateself-potential anomalies as a result of electrokinetic,thermoelectric, and=or electrochemical effects. We havenumerically assessed the relative contributions of these effectsto the overall self-potential signal generated during oil productionin a simple hydrocarbon reservoir model. Our aim was todetermine if measurements of self-potential at a production wellcan be used to detect the movement of water toward the well.The coupling coefficients for the electrochemical and thermoelectricpotentials are uncertain, so we considered four differentmodels for them. We also investigated the effect of altering thesalinities of the formation and injected brines. We found thatthe electrokinetic potential peaked at the location of the saturationfront (reaching values of 0.2 mV even for the most salinebrine considered). Moreover, the value at the production wellincreased as the front approached the well, exceeding the noiselevel ( 0.1 mV). Thermoelectric effects gave rise to largerpotentials in the reservoir (10 mV), but values at the wellwere negligible ð Þ .0:1 mV until after water breakthroughbecause of the lag in the temperature front relative to the saturationfront. Electrochemical potentials were smaller in magnitudethan thermoelectric potentials in the reservoir but were measurableð Þ > 0:1 mV at the well because the salinity front wasclosely associated with the saturation front. When the formationbrine was less saline (1 mol=liter), electrokinetic effects dominated;at higher salinities (5 mol=liter), electrochemicaleffects were significant. We concluded that the measurement ofself-potential signals in a production well may be used to monitorthe movement of water in hydrocarbon reservoirs duringproduction, but further research is required to understand thethermoelectric and electrochemical coupling coefficients in partiallysatu

  • Journal article
    Deveugle PEK, Jackson MD, Hampson GJ, Farrell ME, Sprague AR, Stewart J, Calvert CSet al., 2011,

    Characterization of stratigraphic architecture and its impact on fluid flow in a fluvial-dominated deltaic reservoir analog: Upper Cretaceous Ferron Sandstone Member, Utah

    , AAPG Bulletin, Vol: 95, Pages: 693-727, ISSN: 0149-1423
  • Journal article
    Choi K, Jackson MD, Hampson GJ, Jones ADW, Reynolds ADet al., 2011,

    Predicting the impact of sedimentological heterogeneity on gas–oil and water–oil displacements: fluvio-deltaic Pereriv Suite Reservoir, Azeri–Chirag–Gunashli Oilfield, South Caspian Basin

    , Petroleum Geoscience, Vol: 17, Pages: 143-163, ISSN: 1354-0793
  • Journal article
    Vinogradov J, 2011,

    Multiphase streaming potential in sandstones saturated with gas/brine and oil/brine during drainage and imbibition

    , Geophysical Research Letters
  • Journal article
    Jackson MD, 2010,

    Multiphase electrokinetic coupling: Insights into the impact of fluid and charge distribution at the pore scale from a bundle of capillary tubes model

  • Journal article

    High-resolution stratigraphic architecture and lithological heterogeneity within marginal aeolian reservoir analogues

    , Sedimentology, ISSN: 0037-0746
  • Journal article
    Glover PWJ, Jackson MD, 2010,

    Borehole electrokinetics

    , The Leading Edge, Vol: 29, Pages: 724-728
  • Journal article
    Leinov E, Vinogradov J, Jackson MD, 2010,

    Salinity Dependence of the Thermoelectric Coupling Coefficient in Brine-Saturated Sandstones

    , Geophysical Research Letters

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