Real-Time Determination of Filtrate Contamination During Openhole Wireline
Sampling by Optical Spectroscopy

Mullins, Oliver C.; Schroer, Jon

doi:10.2523/63071-ms

Cited by 22 publications

(3 citation statements)

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“…The optical densities in the longer wavelength channels were quite small for all six of these crude oils, suggesting that light scattering is not important. Nevertheless, wavelength-dependent light scattering can occur in DFA absorption spectra, for instance, from clays in the drilling mud; consequently, it is desirable to perform confirming measurements. It is well-known that crude oils are in the high-concentration limit with regard to fluorescence intensity. , Thus, an increase in chromophore concentration in crude oils results in a decrease in fluorescence intensity.…”

Section: Resultsmentioning

confidence: 99%

“…The drilling muds serve many purposes such as preventing blow outs by virtue of their adjusted high density, preventing excess fluid loss into the formation by forming mud cakes on the borehole face of permeable zones, lubricating the drilling process, lifting the rock cuttings to the surface, and so forth. To differentiate OBM base fluids that leak into permeable formations from formation hydrocarbons, the fluid “color” and GOR , are measured. Unlike crude oils, the base fluids contain no appreciable dissolved gas nor heavy ends such as asphaltene which give rise to fluid color.…”

Section: Introductionmentioning

confidence: 99%

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Oil Reservoir Characterization via Crude Oil Analysis by Downhole Fluid Analysis in Oil Wells with Visible−Near-Infrared Spectroscopy and by Laboratory Analysis with Electrospray Ionization Fourier Transform Ion Cyclotron Resonance Mass Spectrometry

et al. 2006

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In the first study of its kind, we analyze heavy ends of crude oils to characterize oil reservoirs by both in situ downhole fluid analysis (DFA) in oil wells along with heavy-end fingerprinting utilizing ultrahigh resolution mass spectrometry. One of the biggest problems in the exploitation of oil reservoirs in high-cost settings is the difficulty of characterizing flow connectivity or compartmentalization of the various permeable zones. Standard industry methods to determine compartmentalization either fail or are prohibitively expensive. A relatively new method of performing DFA on crude oils has identified compartmentalization on a regular basis and is rapidly becoming an industry standard. Here, compartmentalization is established in an oil-containing vertically stacked sand-shale sequence by performing visible-near-infrared spectroscopy on crude oils in situ in the oil well. These crude oils are then fingerprinted by electrospray ionization-Fourier-transform ion-cyclotronresonance mass spectroscopy. This novel analysis protocol can lead to a more detailed understanding of the reservoir and provides a new utility for advanced methods of analytical chemistry; this charter fits within the new field of petroleomics.

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Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Oil Reservoir Characterization via Crude Oil Analysis by Downhole Fluid Analysis in Oil Wells with Visible−Near-Infrared Spectroscopy and by Laboratory Analysis with Electrospray Ionization Fourier Transform Ion Cyclotron Resonance Mass Spectrometry

et al. 2006

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“…Figure 4 shows a graph of pump rate, pressure, GOR and optical density (OD) at Station E. The test sequence consists of a pre-test followed by a shut-in (PBU1), a second flow, a sampling, an additional flow of 5 minutes followed by a second shut-in (PBU2). To determine when a representative fluid is flowing through the tool, Mullins and Schroer (2000) recommended monitoring filtrate contamination. Filtrate monitoring is best suited when trying to recover a lab quality PVT sample, because it typically requires a very long pumping time to produce a "clean" fluid and was not found to be cost effective here.…”

Section: Case 1 (Oil)mentioning

confidence: 99%

Identification of Bypassed Pays in Low-Resistivity, Thinly-Bedded, Sand-Shale Sequences in the Ghdames Basin of North Africa Through Use of the Wireline Formation Tester

Chu

Welch

2008

SPE Annual Technical Conference and Exhibition

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This paper presents a discussion on the use of the Wireline Formation Tester (WFT) to identify oil-bearing intervals in a reservoir section that contains thinly-laminated, lowresistivity pay sections in the Ghadames Basin of southern Tunisia. Pay zones previously bypassed by conventional log analysis have been conclusively determined as oilbearing through use of the tool.Three field examples are discussed on the use of the Downhole Fluid Analyzer (DFA) to determine hydrocarbon type and in-situ GOR for three different hydrocarbon phase environments.The paper also discusses, again through use of field examples, how analysis of the post-DFA pressure response could be used to determine zonal producibility. This zonal producibility from the WFT is then compared to conventional well-test productivity. A close agreement exists between the WFT and conventional well-test productivity estimates. Thus, it eliminates the need for zones to be conventionally tested to determine productivity.Finally, the paper provides a method to significantly reduce the time necessary to collect representative fluid samples through proper monitoring of the DFA data stream.

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Uncertainty Analysis of Visible and Near-Infrared Data of Hydrocarbons

et al. 2006

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Measurement of physical and chemical properties of hydrocarbons plays an important role in the exploration and production of oil wells. In situ measurement of chemical properties of hydrocarbons makes use of visible and near-infrared (vis-NIR) absorption spectra of hydrocarbons. Uncertainty analysis of these fluid properties is central to developing a fundamental understanding of the distribution of hydrocarbons in the reservoir. In this manuscript, we describe an algorithm called the fluid comparison algorithm (FCA), which provides a statistical framework to quantify and compare hydrocarbon fluid properties and associated uncertainties derived from vis-NIR measurements. The inputs to FCA are the magnitude and uncertainty of vis-NIR spectroscopy data of two hydrocarbons. The output of FCA is a probability that two fluids are statistically different. FCA lays the foundations for subsequent optimization and capture of representative reservoir hydrocarbons. Furthermore, in some circumstances, it can also enable real-time decisions to identify reservoir compartmentalization and hydrocarbon composition gradients in natural oil reservoirs.

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Real-Time Determination of Filtrate Contamination During Openhole Wireline Sampling by Optical Spectroscopy

Cited by 22 publications

References 0 publications

Oil Reservoir Characterization via Crude Oil Analysis by Downhole Fluid Analysis in Oil Wells with Visible−Near-Infrared Spectroscopy and by Laboratory Analysis with Electrospray Ionization Fourier Transform Ion Cyclotron Resonance Mass Spectrometry

Oil Reservoir Characterization via Crude Oil Analysis by Downhole Fluid Analysis in Oil Wells with Visible−Near-Infrared Spectroscopy and by Laboratory Analysis with Electrospray Ionization Fourier Transform Ion Cyclotron Resonance Mass Spectrometry

Identification of Bypassed Pays in Low-Resistivity, Thinly-Bedded, Sand-Shale Sequences in the Ghdames Basin of North Africa Through Use of the Wireline Formation Tester

Uncertainty Analysis of Visible and Near-Infrared Data of Hydrocarbons

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