Water tracers in oilfield applications: Guidelines

Serres-Piole, C.; Preud’homme, Hugues; Moradi-Tehrani, Navid; Allanic, Cécile; Jullia, H.; Łobiński, Ryszard

doi:10.1016/j.petrol.2012.08.009

Cited by 114 publications

(74 citation statements)

References 141 publications

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“…In addition, interface surfaces play an important role as many physicochemical processes with industrial relevance take place on or across interfaces, e.g. the preferential adsorption at the o/w interface of tracer nano-particles (Ryoo et al, 2010) and other species (Serres-Piole et al, 2012), or the rate of dissolution of the non-wetting in the wetting phase (Sahloul et al, 2002) directly related to the surface area per unit p.m. volume, have a strong impact on the spreading of contaminants in groundwater aquifers, the storage of CO 2 in brine filled formations, the efficient operation of PEM fuel cells (Bazylak et al, 2008) or trickle-bed reactors (Van de Merwe and Nicol, 2009) and other industrial applications.…”

Section: Introductionmentioning

confidence: 99%

Oil Fragmentation, Interfacial Surface Transport and Flow Structure Maps for Two-Phase Flow in Model Pore Networks. Predictions Based on Extensive, DeProF Model Simulations

Valavanides

2018

Oil & Gas Science and Technology - Rev. IFP Energies nouvel

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-In general, macroscopic two-phase flows in porous media form mixtures of connectedand disconnected-oil flows. The latter are classified as oil ganglion dynamics and drop traffic flow, depending on the characteristic size of the constituent fluidic elements of the non-wetting phase, namely, ganglia and droplets. These flow modes have been systematically observed during flow within model pore networks as well as real porous media. Depending on the flow conditions and on the physicochemical, size and network configuration of the system (fluids and porous medium), these flow modes occupy different volume fractions of the pore network. Extensive simulations implementing the DeProF mechanistic model for steady-state, one-dimensional, immiscible twophase flow in typical 3D model pore networks have been carried out to derive maps describing the dependence of the flow structure on capillary number, Ca, and flow rate ratio, r. The model is based on the concept of decomposition into prototype flows. Implementation of the DeProF algorithm, predicts key bulk and interfacial physical quantities, fully describing the interstitial flow structure: ganglion size and ganglion velocity distributions, fractions of mobilized/stranded oil, specific surface area of oil/water interfaces, velocity and volume fractions of mobilized and stranded interfaces, oil fragmentation, etc. The simulations span 5 orders of magnitude in Ca and r. Systems with various viscosity ratios and intermediate wettability have been examined. Flow of the nonwetting phase in disconnected form is significant and in certain cases of flow conditions the dominant flow mode. Systematic flow structure mutations with changing flow conditions have been identified. Some of them surface-up on the macroscopic scale and can be measured e.g. the reduced pressure gradient. Other remain in latency within the interstitial flow structure e.g. the volume fractions of À or fractional flows of oil through À connected-disconnected flows. Deeper within the disconnected-oil flow, the mutations between ganglion dynamics and drop traffic flow prevail. Mutations shift and/or become pronounced with viscosity disparity. They are more evident over variables describing the interstitial transport properties of process than variables describing volume fractions. This characteristic behavior is attributed to the interstitial balance between capillarity and bulk viscosity. Mean mobilization probability of i-class ganglia S 2.3 IFP Energies nouvelles International Conference Rencontres Scientifiques d'IFP Energies nouvellesNumber density of i-class ganglia S (15)Number of pore unit cells occupied by each i-class ganglion P

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Section: Introductionmentioning

confidence: 99%

Oil Fragmentation, Interfacial Surface Transport and Flow Structure Maps for Two-Phase Flow in Model Pore Networks. Predictions Based on Extensive, DeProF Model Simulations

Valavanides

2018

Oil & Gas Science and Technology - Rev. IFP Energies nouvel

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“…Different fluorobenzoic acids are commonly used as non-radioactive passive tracers in petroleum exploration [1, 2]. Hence, there is a need for their sensitive analysis in oil reservoir waters, known for their highly dissolved organic matter and salt (NaCl, CaCl 2 ) content often exceeding 25% [3].…”

Section: Introductionmentioning

confidence: 99%

Rapid ion-exchange matrix removal for a decrease of detection limits in the analysis of salt-rich reservoir waters for fluorobenzoic acids by liquid chromatography coupled with tandem mass spectrometry

et al. 2016

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A matrix removal procedure with ion-exchange resin prior to analysis for 18 fluorinated benzoic acids (FBAs) tracers in saline (>25% salt) reservoir water was optimized. The elimination of >98% of salt and the simultaneous matrix sample cleanup allowed the direct analysis using the supernatant by liquid chromatography coupled with tandem mass spectrometry (LC-MS/MS). This resulted in a gain in detection limits for most of the tracers in comparison with the reference method (direct analysis after minimum required dilution). The limits of detection (LODs) were in the range of 0.01–0.15 ng/ml and compared to other studies the developed method provided comparable limits of detection and advantage of simplified and shorter sample preparation. The presented method offers a considerable gain in simplicity and analysis time. Recoveries for all the tracers reached 80–100%, except for 2-FBA and 2,6-dFBA for which they were ca. 60%. The low recoveries were corrected by the use of five isotopically labeled internal standards. The method was validated by the analysis of spiked samples and by an independent comparison of the results with those obtained by solid-phase extraction LC-MS/MS method.Electronic supplementary materialThe online version of this article (doi:10.1007/s00216-016-0060-5) contains supplementary material, which is available to authorized users.

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“…At present, there are many methods being used to determine breakthrough channels in the process of water flooding, such as injecting tracer material, analyzing well test data, applying fuzzy recognition of expert system based on interpretation results of logging information (Serres-Piole et al 2012;Liu and Liang 2004;Meng et al 2007). Some similar technologies have also been used to judge steam breakthrough performance (Closmann 1984;Masse et al 1991).…”

Section: Introductionmentioning

confidence: 99%

A new profile control design based on quantitative identification of steam breakthrough channel in heavy oil reservoirs

Liu

Pang

et al. 2013

J Petrol Explor Prod Technol

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Steam breakthrough has a great negative influence on the development of steam flooding in heavy oil reservoirs. In this article, a new profile control design based on quantitative identification of steam breakthrough channel is introduced. Firstly, dual-sandpack experiments are conducted to study the characteristics and influencing factors of steam breakthrough. Then based on the experimental results as well as pretreatment and combination of geological parameters and production data, comprehensive identification parameter (CIP) is achieved through the analytic hierarchy process to quantitatively describe the degree of steam breakthrough. Afterward, the breakthrough types of production wells are determined by CIP and the volume of breakthrough channels and profile control parameters among the injector and the producers are calculated according to the tapering distribution of steam breakthrough in the process of steam flooding in heavy oil reservoirs. The experiment results show that there exists a large difference between breakthrough channels and nonbreakthrough areas in temperature and oil recovery. Permeability contrast is an important factor, which influences the direction of steam breakthrough, and temperature has a great correlation with oil recovery under the heterogeneous condition. The determination of CIP is an attempt to quantify the degree of breakthrough and it combines many factors, which show the difference between the injector and the producer, as well as the difference between producers. All producers of the steam flooding well group can be divided into complete breakthrough wells with CIP over 0.5 and incomplete breakthrough wells with CIP below 0.5 for calculating conveniently. Based on the tapering distribution of the steam breakthrough channel, blocking parameters considering oil drainage radius around the injector, temperature distribution between the injector and the producer and the demand of blocking effect and field reality are obtained to calculate the blocking volume for complete breakthrough wells and incomplete breakthrough wells. This method could be used as a tool to judge breakthrough degree and design profile control parameters for oilfields with heavy oil reservoirs.

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Water tracers in oilfield applications: Guidelines

Cited by 114 publications

References 141 publications

Oil Fragmentation, Interfacial Surface Transport and Flow Structure Maps for Two-Phase Flow in Model Pore Networks. Predictions Based on Extensive, DeProF Model Simulations

Oil Fragmentation, Interfacial Surface Transport and Flow Structure Maps for Two-Phase Flow in Model Pore Networks. Predictions Based on Extensive, DeProF Model Simulations

Rapid ion-exchange matrix removal for a decrease of detection limits in the analysis of salt-rich reservoir waters for fluorobenzoic acids by liquid chromatography coupled with tandem mass spectrometry

A new profile control design based on quantitative identification of steam breakthrough channel in heavy oil reservoirs

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