Water flooding of the Oseberg Øst oil field, Norwegian North Sea: Application of formation water chemistry and isotopic composition for production monitoring

Munz, I. A.; Johansen, H.; Huseby, Olaf; Rein, Elin; Scheire, O.

doi:10.1016/j.marpetgeo.2009.12.003

Cited by 11 publications

(2 citation statements)

References 35 publications

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“…The length of this pore salt dissolution step was optimized to avoid the dissolution of more slowly reacting detrital and diagenetic minerals. The samples were evaporated and the residues were measured utilizing a Finnigan MAT 261 thermal-ionization mass spectrometer (Munz et al 2010). Repeated measurements of the SRM 987 standard at the time of analysis yielded an average 87 Sr/ 86 Sr of 0.710260 with the reference value being 0.710254.…”

Section: Strontium Residual Salt Analysis (Sr Rsa)mentioning

confidence: 99%

The Longyearbyen CO 2 Lab: Fluid communication in reservoir and caprock

Huq

Smalley

Mørkved

et al. 2017

International Journal of Greenhouse Gas Control

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The Longyearbyen CO2 Lab of Svalbard, Norway was established to estimate the potential for geological carbon sequestration at Spitsbergen. Several monitoring wells were drilled in and around the planned CO2 injection site. These revealed a Triassic to Cretaceous stratigraphy consisting of (from top to bottom) a zone of permafrost, the aquifer, the caprock shale, and the upper, middle and lower reservoir. This paper uses two tools to investigate fluid communication within and between these entities: 87 Sr/ 86 Sr of formation waters extracted from cores using the residual salt analysis (RSA) method, and the δ 13 C of gases, principally methane and CO2, degassed from core samples. The Sr RSA data reveal that the upper reservoir rocks have very constant formation water 87 Sr/ 86 Sr in wells several kilometres apart, suggesting good lateral communication on a geological timescale. However, there is a distinct barrier to vertical communication within the middle reservoir, indicated by a step change in 87 Sr/ 86 Sr, corresponding to thin but presumably laterally extensive (>1.5 km) lagoonal mudrocks. The aquifer, which shows a gradient in 87 Sr/ 86 Sr, is also interpreted to have some degree of vertical internal communication on a geological time scale. The caprock shale shows large-scale (over 350 m) smooth vertical gradient in 87 Sr/ 86 Sr. This is indicative of an ongoing mixing process between high-87 Sr/ 86 Sr waters within the caprock and lower-87 Sr/ 86 Sr waters in the underlying reservoir. Diffusion and flow modelling of the Sr data suggest that at some time in the past shale, fluid transport properties were enhanced by the formation of temporary pressure escape features (fractures or chimneys) during deep burial and uplift or cycles of glaciation. Nevertheless, the smooth compositional gradient in the caprock indicates that fluid mixing has subsequently taken place slowly, dominated by diffusion. This 3 interpretation is supported by the gas isotope data, where systematic variations in gas δ 13 C values also indicate slow and incomplete diffusional fluid mixing. These are positive indicators for caprock effectiveness during a CO2 injection project.

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Section: Strontium Residual Salt Analysis (Sr Rsa)mentioning

confidence: 99%

The Longyearbyen CO 2 Lab: Fluid communication in reservoir and caprock

Huq

Smalley

Mørkved

et al. 2017

International Journal of Greenhouse Gas Control

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“…Ferrous ions and chloride ions are common constituents of subsurface brines (e.g. see Munz et al, 2010) and, hence, this particular flow-battery chemistry is environmentally benign. Iron chlorides are also low cost and widely available at industrial volumes since they are used for sewage treatment.…”

Section: Theoretical Performancementioning

confidence: 99%

Subsurface Flow Batteries: Concept, Benefits and Hurdles

Waltham¹,

Holt²,

Kuenzel³

et al. 2022

Preprint

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We introduce a novel concept for storage of electrical energy in the subsurface—storage of flow-battery electrolytes in porous rock. Flow-batteries operate by electrochemical transformations of electrolytes, rather than of electrodes, and their energy capacity can therefore be increased indefinitely by using larger electrolyte tanks. Saline aquifers may be the cheapest way to provide large-scale storage for this purpose. Storage would be within high-porosity, high-permeability reservoirs sealed by impermeable layers but—in contrast to hydrocarbon, H2 or CO2 storage—electrolytes would be trapped at the base of such formations as a consequence of their high density compared to natural brines.Calculations show that the resulting devices may be able to charge/discharge safely, cheaply, efficiently and continuously for weeks at 100’s of MW. Hence they are a possible solution to the problem of long-term renewable energy intermittency. We discuss a range of electrochemical, geochemical, microbiological and engineering hurdles which must be overcome if subsurface flow-batteries are to become a practical technology. No insurmountable problems were found in our preliminary assessment but further laboratory studies are needed.

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