Wyniki wyszukiwania - Biblioteka Nauki

1

Economics of combined CO2-EOR and CCS projects based on the example of a Polish multilayered oil field

100%

Kosowski P.

Archives of Mining Sciences

|

2020

|

tom Vol. 65, no. 2

241--254

EN

The article presents a comprehensive economic analysis of a CO2 injection project in one of the Po-lish oil fields for both increased production (CO2-EOR) and underground storage (CCS). An interesting differentiator of this work is the use of a multilayered reservoir, which is actually not one reservoir but several located in the same place, as an example. It allows the optimization of the processes of injection, production and storage. Such projects are becoming more and more important because recently, after a period of long-term stagnation, costs of carbon allowances have started to rise which affects e.g. the electricity market in Poland. This can be an important incentive for the development of CCS technology, especially in combination with CO2-EOR. In the case of very high costs of carbon emissions rights CCS may turn out to be a cheaper solution. Economic efficiency is the main determinant of the EOR project’s success, as well as a very significant factor influencing the potential development of CO2 underground storage. Results are based on the numerical simulation of a combined CO2-EOR and CCS project. This analysis has been divided into two parts. The first uses a standard, deterministic approach, based on the DCF method and NPV indicator. It also provides a detailed sensitivity analysis, with particular reference to the impact of oil prices and the cost of carbon emissions rights on a project’s profitability. The second part of the economic analysis is probabilistic and involves estimating the maximum amount of CAPEX using the Monte Carlo method. Two cases were taken into account. The first assumes that the CO2 emitter pays for CO2 storage and the price is equal to 80% of the emissions rights price (with storage revenue). In the second one the emitter does not pay for storage (without storage revenue).

2

Modeling of ground subsidence in oil fields

100%

Szostak-Chrzanowski A. , Chrzanowski A. , Ortiz E.

Technical Sciences / University of Warmia and Mazury in Olsztyn

|

2006

|

tom nr 9

133-146

EN

A method of integrated analysis and prediction of ground subsidence in oil fields is being developed at the Canadian Centre for Geodetic Engineering. The method utilizes the in-situ data such as location and geometry of the oil reservoir, geology, pressure in oil wells, production data, and surface deformation monitoring results. The data is used in forward analysis of deformation analysis of the rock mass. The reservoir compaction and subsidence modeling is based on the functional relationship between production, change of pressure in underground oil reservoir and measured ground subsidence. As a first stage of the study, various methods of ground subsidence modeling have been implemented and compared in modeling the effects of oil extraction in oil fields along La Costa Oriental del Lago de Maracaibo (COLM) in Venezuela. A method of "nucleus strain", Knothe's influence function, and finite element method have been used in the comparison.

PL

Metoda zintegrowanej analizy i przewidywania osiadania powierzchni górotworu wywołanego wydobyciem ropy naftowej została opracowana przez Kanadyjskie Centrum Geodezji Inżynieryjnej. Metoda ta jest oparta na wykorzystaniu takich informacji, jak geometria zbiornika roponośnego, budowa geologiczna górotworu, stan ciśnienia w otworach wiertniczych, dane wydobycia ropy naftowej oraz dane pomiarowe osiadania powierzchni górotworu. Dane te są wykorzystywane w modelowaniu osiadania powierzchni górotworu na podstawie obliczonej kompakcji zbiornika roponośnego. W analizie wykorzystano relacje między zmianami ciśnienia w zbiorniku, produkcji i pomierzonym osiadaniem powierzchni. Porównano trzy modele obliczania osiadania powierzchni, wykorzystując dane z eksploatacji pól naftowych w La Costa Oriental del Lago de Maracaibo (COLM) w Wenezueli. Modelami tymi były model "nucleus strain", metoda Knothego oraz metoda elementów skończonych.

3

Reservoir Properties of the Jurassic Khatatba Formation: Tut Oil Field, NW-Desert, Egypt

80%

El Sayed A. M. A. , El Sayed N. A. , Radwan A. A.

Inżynieria Mineralna

|

2024

|

tom Vol. 1, no. 1

105--113

EN

The Tut oil field is in the North-western part of the Western Desert. This work aims to study the reservoir characteristics, to evaluate the hydrocarbon potentiality of the Upper and Lower Safa Members based on the available subsurface data obtained from open-hole well log records of four wells distributed in the study area. Numerous isopach and lithofacies maps have been constructed. The petrophysical evaluation, in terms of determining reservoir net-pay thickness, shale content (Vsh), effective porosity (∅eff), water saturation (Sw) and hydrocarbon saturation (Sh), were estimated. The vertical and the lateral distribution of the reservoir characteristics, in the form of litho-saturation cross-plots, iso-parametric maps and lithologic-matrix cross-plots were constructed. Three hydrocarbon charged zones in the Khatatba Formation were defined and represented by the Upper Safa-Top, Upper Safa-Bottom and Lower Safa-Top. The upper most part of Upper Safa Member (Upper Safa-Top) reservoir represents an oil producing zone where it consists of shallow marine to alluvial sediments. The Lower most part of Upper Safa Member (Upper Safa-Bottom) reservoir represents gas producing zone where it consists of a thick alluvial sand body. Finally, the upper most part of Lower Safa Member (Lower Safa-Top) reservoir represents an oil-gas producing zone consisting of shallow marine sediments with high terrestrial input. The iso-parametric maps show that Northern and central parts of the study area are the most favorable parts for hydrocarbon accumulation due to the increase in net-pay thickness and average effective porosity and decrease in water saturation toward these parts.

4

Reservoir Characterization of The Baharyia Formation, Neag-1, 2 &3 Oil Fields, Western Desert, Egypt

80%

El Sayed A. M. A. , El Sayed N. A. , El Bagoury M. A.

Inżynieria Mineralna

|

2024

|

tom Vol. 1, no. 1

87--95

EN

An integration was achieved between different bore holes and laboratory measured data using several petrophysical parameters of the Baharyia Formation encountered in Neag-1,2&3 oil fields. It illustrates the key control factors affecting the Baharyia reservoir quality. The obtained petrophysical relationships could be used widely in both exploration geophysics and hydrocarbon reservoir production. It provides and demonstrates solutions for both geological and geophysical engineering problems. The measured porosity and permeability are ranging from 2.5 to 32 % and 0.005 to 874 mD respectively. The influence of diagenesis on both reservoir porosity and permeability has been investigated. Pore filling minerals has been classified into four classes by XRD- analysis technique. A reliable regression equation was reached between reservoir permeability and mineral pore fillings. Several relationships among rock permeability, porosity and density obtained from open hole logs were recognized. The pore throat distribution has been laboratory measured by use of MICP technique for some selected samples. The calculated reservoir storage and flow capacity indicate four major fluid flow types which are controlled by the variations in reservoir pore space framework. Formation resistivity factor – porosity relation was accomplished under reservoir conditions, while the Archie’s 2nd equation was outlined. The Archie’s parameters (a, m &n) were calculated for shaly and clean sandstones of the Baharyia Formation. Both cation exchange capacity (CEC), Mounce potential (MP) and mercury injection capillary pressure (MICP) were measured to distinguish reservoir facies.