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SUBSURFACE FLUID CHARACTERIZATION USING DOWNHOLE AND CORE NMR T1T2 MAPS COMBINED WITH PORE-SCALE IMAGING TECHNIQUES


Subsurface fluid characterization using downhole and core NMR t1t2 maps combined with pore-scale imaging techniques
Margaret Lessenger


Date – Tuesday, April 26th from 11:15 am-1:30 pm. Lunch Served at 11:15 am, talk starts at 11.45. Location: Repsol 2455, Technology Forest Blvd, The Woodlands Tx 77381. Cost Regular $25 and Students $10 (Lunch Included). Please register/pay via the website ASAP as the catering cut-off is the 22nd.

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ABSTRACT

Characterization of the subsurface fluid types, porosity, saturations, and wettability are critical for understanding the type and volumes of fluids that will be produced during primary completions and secondary waterflood recovery. The oil reserves within the Green River Formation of the Uinta Basin (Utah, USA) in the Greater Monument Butte Unit (GMBU) have variable fluid volumes, saturations, and wettability. Within a potential pay section of over 2000 feet are over twenty defined producing sandstone reservoir intervals within the Green River Formation with variable depositional environments, mineralogy, and rock quality. Traditional core analyses for saturations and wettability are time-consuming and expensive because of variable reservoir properties within discontinuous sands and high-paraffinic oil containing asphaltenes and resins. Similarly, the variable wettability complicates standard analyses of NMR (nuclear magnetic resonance) data for fluid type and volume estimations.
 
Newfield has approximately a dozen wells with NMR T1, T2, and diffusion data in the producing section of Monument Butte Field. We have identified patterns of NMR, dielectric, and standard triple-combo log data that are associated with differences in estimation of clay-bound water volumes from NMR and XRD data. We present results from pore-scale imaging, NMR core-flood experiments, USBM (United States Bureau of Mines) measurements of wettability, and 2.5D inversion of NMR data used to characterize the variable wettability of GMBU sandstone reservoirs.
 
We found that the sandstone reservoirs are mixed-wet at the micro- and macro-pore scales, including presence of oil-wet clays. Mixed-wettability complicates estimation of fluid types and volumes from NMR data using standard interpretation techniques. An analysis protocol involving pore-scale imaging, core-flood NMR experiments, and 2.5D NMR processing and analyses permit reduction of interpretation ambiguity of the NMR data.
 
 
Margaret Lessenger is a consulting petrophysicist at Rimrock Petrophysics and Analytics in Denver with over 30 years of experience as a geophysicist, geologist and petrophysicist working in various basins in the Rockies, North Sea and Gulf of Mexico. She has worked for the Superior Oil Company, ARCO Oil and Gas, Platte River Associates, the Colorado School of Mines Department of Geology, Williams Exploration, and Newfield Exploration. Lessenger holds a BS in Geophysical Engineering, MS in Geophysics, and PhD in Geology from the Colorado School of Mines. She is a member of SPWLA, AAPG, SPE and SCA.
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