Conference New approaches in reserves estimation of hydrocarbon resources will take place in Tyumen 11-12 February 2015


for more information ask  Antonina Kozmina.


With great probability today we can say that hydraulic fracturing is not the only one of the methods for oil extraction intensification but is an effective instrument for oil field development process regulation in whole. The analysis of accumulated experience at hydraulic fracturing operations allows us to speak about its effectiveness almost at all oil field development stages.

The development of coalbed methane (CBM) has been limited to moderate- to high-permeability reservoirs (>1 md).  However, a significant resource of natural gas exists within low-permeability coals (<1 md).  Worldwide CBM resources are estimated to range from 3,500-7,000 Tcf, and EIA estimates >800 Tcf are technically recoverable.  As of 2010, however, only 60-70 Tcf of CBM reserves were proved.  Vast CBM resources are untapped.

Different geophysical methods and processing techniques are used for studying of pore space in carbonate rocks, but system analysis necessitates for an integrated approach to the study of rock properties. One of the most efficient suites of specialized logging methods to study reservoirs with the mixed-type porosity is a joint analysis of data from the micro-imager, cross-dipole acoustic logging and also the formation tester.

Monday, 24 November 2014

Pore scale modeling for heavy oil

This presentation is about flow in porous media at the smallest length scales from pore-to-core, and will point out some emerging opportunities of fluid flow simulations relevant to heavy oil.

Information about fluid properties is a required input for every stage in the oil and gas industry from the reservoir to the refinery. It is therefore of utmost importance for reservoir, facility and corrosion engineers to understand the volumetric behaviour and the transport properties of the produced fluid. These fluid properties can be obtained from PVT reports generated either in-house or in external labs. In both cases, engineers should be able to perform a consistency check on the data before including it in their respective tasks.

The field, located deep offshore Angola in Block 17, is composed of confined and unconfined unconsolidated turbidites sands aged from Miocene. The field was discovered in 1997 and production started in December 2006. On Block 17, seismic data are of very good quality with a vertical resolution of 7 metres.

Production of hydrocarbons from tight reservoirs has a long history and traces itself back to the end of 19th – beginning of 20th century, when the natural gas production came from low-pressured fractured shales in Appalachian Basin. However, the lack of technology during that time did not allow operators to produce it with the adequate flow rates. It took almost 60 years for the industry to take a second look at these types of reservoirs, when Mitchell Energy & Development Corporation showed an interest in exploration of Barnett shales for gas production.

One of the major challenges, currently facing the Russian oil industry, is the development of unconventional reserves, including the Bazhenov Formation sediments to maintain and possibly increase oil production in Western Siberia. During the May meeting of the Moscow SPE section, a technology of development complex reservoirs will be discussed. We are talking about well-established multi-stage hydraulic fracturing (frac), accompanied by microseismic monitoring (MSM).

Fractured reservoirs often exhibit interaction between production and effective permeability. Simple rules used to explain this relationship are based on assumptions that are physically impossible. Moving beyond this limitation requires a change of mind-set.