Chalk–fluid interactions with glycol and brines

Risnes, Rasmus; Haghighi, Hossein Kamran; Korsnes, Reidar Inge; Natvik, O.

doi:10.1016/s0040-1951(03)00187-2

Cited by 85 publications

(68 citation statements)

References 5 publications

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“…However, chemomechanical compaction of fine-grained carbonates has been successfully reproduced during experiments under low temperature conditions, proving the importance of water composition (Wang et al 2016), as well as the effect of the presence of oil v. water on compaction, pressure solution and porosity loss (Risnes et al 2003). Much work has recently been undertaken on the experimental simulation of reactions between CO 2 and host rocks to determine the effects of carbon capture and storage on reservoir and caprock quality, utilizing realistic low temperatures and relatively long-duration experiments (Armitage et al 2013a).…”

Section: Experimental Simulation Of Diagenesismentioning

confidence: 94%

Petroleum reservoir quality prediction: overview and contrasting approaches from sandstone and carbonate communities

et al. 2018

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Abstract:The porosity and permeability of sandstone and carbonate reservoirs (known as reservoir quality) are essential inputs for successful oil and gas resource exploration and exploitation. This chapter introduces basic concepts, analytical and modelling techniques and some of the key controversies to be discussed in 20 research papers that were initially presented at a Geological Society conference in 2014 titled 'Reservoir Quality of Clastic and Carbonate Rocks: Analysis, Modelling and Prediction'. Reservoir quality in both sandstones and carbonates is studied using a wide range of techniques: log analysis and petrophysical core analysis, core description, routine petrographic tools and, ideally, less routine techniques such as stable isotope analysis, fluid inclusion analysis and other geochemical approaches. Sandstone and carbonate reservoirs both benefit from the study of modern analogues to constrain the primary character of sediment before they become a hydrocarbon reservoir. Prediction of sandstone and carbonate reservoir properties also benefits from running constrained experiments to simulate diagenetic processes during burial, compaction and heating. There are many common controls on sandstone and carbonate reservoir quality, including environment of deposition, rate of deposition and rate and magnitude of sea-level change, and many eogenetic processes. Compactional and mesogenetic processes tend to affect sandstone and carbonate somewhat differently but are both influenced by rate of burial, and the thermal and pressure history of a basin. Key differences in sandstone and carbonate reservoir quality include the specific influence of stratigraphic age on seawater composition (calcite v. aragonite oceans), the greater role of compaction in sandstones and the greater reactivity and geochemical openness of carbonate systems. Some of the key controversies in sandstone and carbonate reservoir quality focus on the role of petroleum emplacement on diagenesis and porosity loss, the role of effective stress in chemical compaction (pressure solution) and the degree of geochemical openness of reservoirs during diagenesis and cementation. This collection of papers contains case study-based examples of sandstone and carbonate reservoir quality prediction as well as modern analogue, outcrop analogue, modelling and advanced analytical approaches.Gold Open Access: This article is published under the terms of the CC-BY 3.0 license.Porosity and permeability (reservoir quality) exert fundamental controls on the economic viability of a petroleum accumulation (Blackbourn 2012).They need to be quantified from basin access and exploration, via appraisal and field development through secondary and tertiary recovery in order to

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Section: Experimental Simulation Of Diagenesismentioning

confidence: 94%

Petroleum reservoir quality prediction: overview and contrasting approaches from sandstone and carbonate communities

et al. 2018

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“…Simplified brines with seawater ionic strength (0.219 M MgCl2 and 0.657 M NaCl) were used. Since mechanical properties measured under isotropic compression are less scattered and highly repeatable as shown from previous studies (Risnes et al, 2003;Heggheim et al, 2005;Korsnes et al, 2006bKorsnes et al, , 2008Zangiabadi et al, 2009;Madland et al, 2011), this type of test is chosen. Microscopic studies by Scanning Electron Microscopy (SEM) are included.…”

Section: Introductionmentioning

confidence: 99%

Mechanical and physical behavior of high-porosity chalks exposed to chemical perturbation

Megawati

Madland

Hiorth

2015

Journal of Petroleum Science and Engineering

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Extensive study on the effect of dissolution-precipitation on mechanical behavior of various high-porosity outcrop chalks (Liége, Aalborg, Kansas, Stevns Klint, and Mons) flooded with simplified aqueous chemistry at 130 °C under isotropic stress beyond the yield is performed.Chemical effects induced by injection of 0.219 M MgCl2 solutions into impure chalks (Liége, Aalborg, Kansas) lead to an immediate enhancement on the macroscopic creep with more than a factor of 2 larger than that of exposed to 0.657 M NaCl solutions. In pure chalks The chemical effects are also demonstrated by marked reduction in the permeability. The porosity-permeability relationship measured at the end of creep test is shifted down from the initial correlation, indicating a dramatic increase in the chalk specific surface area.

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“…Since the early eighties, the effect of the nature of the pore fluids, of their mutual interaction and of their interaction with the rock skeleton were examined to better interpret the origin of compaction (Newman, 1983;Monjoie et al, 1985;Piau & Maury, 1994;Schroeder et al, 1998;Risnes et al, 2003). It was proposed to adopt a coupled hydro-mechanical framework taken from the mechanics of unsaturated soils (containing water and air as a non wetting fluid) and to adapt it to reservoir chalks (containing water and oil as a non wetting fluid) Collin et al, 2002;De Gennaro et al, 2003).…”

Section: Introductionmentioning

confidence: 99%