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Measurement and Use of Formation Fluid, Saturate, and Aromatic Content, with Wireline Formation Testers

Speaker: Christopher Jones
Date: Sept. 8
Location: Kinder Morgan - First Floor Conference Room, 1001 Louisiana St Houston, TX 77002
Parking: Travis Garage across milam, in front of Kinder Morgan, Open Air parking between Kinder Morgan and Shell N 2
Time:11:30am-12:20 pm.  
Cutoff Date: Sep 7 2015.  

Title: Measurement and Use of Formation Fluid, Saturate, and Aromatic Content, with Wireline Formation Testers
Measurement of a formation fluids composition can provide great insight for petrophysical, geochemical, and phase behavior interpretation.  Laboratory analysis of bottomhole samples have historically provided much of this required compositional data.  The delay in providing this critical information for decision making can be weeks to months.  When evaluation occurs, opportunity to resolve ambiguities with additional information is lost.  Providing formation fluid characterization in situ and in real-time by means of wireline formation testers can enhance formation characterization and sampling programs.  However, direct single station fluid compositional analysis measurements by wireline formation testers have historically been limited to gas components C1-C5, and bulk oil C6+.  Although some multi-station extrapolation can provide information regarding asphaltene content, no direct assay of bulk oil C6+ into measured components has been available.  New measurement technology based on a multivariate optical computing technique have provided evidence of saturate and aromatics content.  A comparison of tool response to laboratory values for eight formation fluids validates measurements of gas oil ratio (GOR), C1, saturates, and aromatics concentration.  The bulk difference with measured density represents the polar fraction of the oil, ie resin and asphaltene fractions.  Because of the high associated aromatic character of fluids in and near tar mat zones, measurement of aromatic content can be useful for pinpointing the locations of such zones.
Christopher Jones manages Fluid ID, Pressure Testing and Sampling technology R&D group at Halliburton. He has 15 years' experience in fluid analysis sensor development specializing in optical analysis in addition to 7 years' of experience in exploration and petroleum geochemistry. Chris initially joined Halliburton in January of 2001 through Westport Technology, an integrated rock/fluids E&P laboratory.  As supervisor of a geochemistry team he consulted with oil companies and worked closely with the Westport PVT operations.  This lead to Chris overseeing the development of Laserstrat(tm), a chemo-stratigraphy analyzer and the ARMIS(tm) TDL Gas Isotopic Spectroscopy services. In December 2007 Chris joined the Halliburton Formation Evaluation research department. He currently manages four laboratories including petroleum fluids laboratories in the US and Brazil, a sensor prototyping laboratory, and an optical thin films research laboratory. Chris received his BS from the University of South Carolina in chemistry an MS in Physical Chemistry from the University of Houston with an additional 38 graduate hours in Geology, specializing in Geochemistry.  Chris Jones specialties include optical spectroscopy, chemometrics analysis techniques, and petroleum geochemistry.  He has a combination of 21 petroleum industry and photonics industry papers, presentations or posters, and has been granted over 40 US patents.