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USING NMR TO CHARACTERIZE FLUIDS IN TIGHT ROCK UNCONVENTIONAL AND SHALE FORMATIONS


Date: February 15th, 2017

Location: Auditorium at 1500 Louisiana Street (Chevron building)

Time: 11:30 am -1:00 pm

Parking: https://www.parkme.com/lot/14203/1400-louisiana-garage-houston-tx or limited parking on the street side using Park&Pay (Cash only)

Room Capacity: 200

Lunch: Provided on 3x - 6ft Catering Tables

Cost: $20

Officer Contact: Rohollah A. Pour, 512-965-7248 Rohollah.A.Pour@alphapres.com

Speaker Boqin Sun, Chevron

Date: Wednesday February 15th , 2017

Abstract:

Petrophysical characterization and quantification of OOIP/OGIP and producibility in tight rock unconventional (TRU) and shale reservoirs remains challenging. The porosity system of these reservoirs is dominated by nano and micro pores, while the matrix system is formed by the mixture of regular shale and kerogen with different maturities. Therefore the total porosity in an unconventional reservoir is often less than 10PU (porosity unit, or percentage of total volume), and the permeability ranges from nano to micro Darcy. Storage and transport of hydrocarbon varies with the percentage and maturity of the organic material in TRU and shale formations, and impacts up to 20% of OOIP/OGIP. Evaluation of porosity, saturation, and matrix permeability from conventional logs becomes very difficult and often requires a large number of core measurements to correctly define the rock and pore system.

Routine NMR workflows for characterizing conventional reservoirs cannot directly be used to derive petrophysical properties in TRU formations. Through laboratory NMR core analysis and NMR logging field trials in various TRU and shale reservoirs, we have developed a new NMR shale interpretation workflow that focuses on (1) obtaining high-quality raw echo data by optimizing data activation sequences for TRU and shale formations, (2) improving the data processing scheme by enhancing T2 resolution to separate different fluid components in T2 distributions, (3) adapting a new fluid typing method that only involves clay-bound water and capillary bound fluids, part of which is also producible, and (4) using NMR core analysis to verify the cutoff and T1/T2 ratio trend to improve fluid identification in TRU and shale reservoirs. The workflow has been successfully applied to evaluate petrophysical properties in the Marcellus and Vaca Muerta formations. It reduces the uncertainty of total porosity and free fluid volume (FFV), and identifies fluid types and sweet spots.

Biography:

Boqin Sun has been a research consultant of Chevron Energy and Technology Co. since 2001. He has been working on various NMR applications in solution, solid, and petrophysics. He received a BS from Hanzhou Univ. in 1982 and a MS from Wuhan Inst. of Physics in 1985, both in Physics, and a PhD from UC Berkeley in 1991 in Chemistry. Previously he was with Schlumberger at Sugar-Land product center for four years. Before that, he was a Postdoctoral Associate at MIT.


 

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