International Journal of Petroleum and Gas Engineering

International Journal of Petroleum Engineering ISSN 5675-0715 Vol.  2 (3) pp. 089-094, March, 2015.  © International Scholars Journals

Full Length Research Paper

Continuous Expert seismology by non-direct oil reserves Expert framework

Leonidas E. Onassis

Department of Petroleum Engineering, Faculty of Engineering, Hellenic Open University, Patras, Greece.

Email: [email protected]

Accepted 03 February, 2015

Abstract 

A non-linear 3-D elastic waves real - time expert system is proposed for the exploration of land and marine oil reserves, according to the new theory of "Real-Time Expert Seismology". This Generic Technology will work under Real Time Logic for searching the land and marine petroleum developed on the continental crust and on deeper water ranging from 300 to 2000 m, or 3000 m, or even more. Hence, the proposed real - time expert system will be the best device for the exploration of the continental margin areas (shelf, slope and rise) and the very deep waters, too. Furthermore, the above expert system will be suitable for the exploration of land oil reserves, as well. The objectives for exploration of marine and land oil resources are to locate, characterize and evaluate the size of such reserves. Hence, there is a research and development responsibility for the acquisition and analysis of geophysical, geological and reservoir engineering data for the land and the seas all over the world, in order to be explored their petroleum and gas reserves. Thus, through the new technology of "Real-time Expert Seismology", will be effected the exploration of a significant part of marine and land oil reserves very fast and by a low cost.

Key words: Real-time expert seismology, land oil reserves, marine oil reserves, non-linear real - time expert system, real- time logic, generic technology.

International Journal of Petroleum Engineering ISSN 5675-0715 Vol.  2 (2) pp. 071-082, February, 2015. © International Scholars Journals

Full Length Research Paper

Examination concerning the rheological and filtration properties of boring mud constructed with Clay from Northern Nigeria

Omokiniovo V. Adams¹, Dedeji E. Adeleye²*, Okoro E. A¹, J. P. George ³ and Akpoguma V. A³

¹Petroleum Engineering Department, University of Uyo, Uyo, Nigeria.

²Petroleum Engineering Department, Federal University of Petroleum Resources, Effurun, Nigeria

³Department of Mechanical Engineering, Petroleum Training Institute, Effurun, Nigeria.

E-mail:[email protected]

Accepted 26 January, 2015

Abstract

Rheological properties of drilling mud formulated from ten samples of Nigerian clay and treated with sodium carbonate (Na₂CO₃) were determined. Four different formulations were made: A (22.5 g / 350 ml of mud + 0% Na₂CO₃), B (22.5 g / 350 ml of mud + 10% Na₂CO₃), C (25 g / 350 ml of mud + 10% Na₂CO₃) and D (28 g / 350 ml of mud + 10% Na₂CO₃). None of the samples tested in their natural state exhibited remarkable improvement in rheological properties. However, as the concentration of sodium carbonate in 22.5 g / 350 ml of mud increased to 10% in all the samples, the highest percent increase of 525% in shear stress at 1022 s^-1 was observed. As clay concentration increased to 25 and 28 g / 350 ml at 10% sodium carbonate concentration, an additional increase in shear stress of 32 and 29% was observed respectively. This resulted in an increase in the apparent viscosity, plastic viscosity and yield point of the mud by 298, 32 and 29% in B, 205, 10 and 7% in C, and 9500, 90 and 61% in D respectively (on average basis for all samples). Four of the samples (NWY 013, 028, 033 and 053) showed strong promising flow properties and can be further improved to qualify as substitute for imported bentonite clay.

Key words: Clay, viscosity, sodium carbonate, beneficiation, flocculation, yield point, drilling, mud.

International Journal of Petroleum Engineering ISSN 5675-0715 Vol.  2 (2) pp. 065-070, February, 2015. © International Scholars Journals

Review

Viewpoint of connecting related gas through natural gas hydrate (NGH) technology in Nigeria

Nwonsu Chijoke

Department of Petroleum Engineering, Federal University of Petroleum Resources Effurun, Effurun, Nigeria.

Email: [email protected] 

Accepted 18 January, 2015

Abstract 

Natural gas hydrate (NGH) technology is a feasible alternative to capture associated-gas, which are usually difficult to harness in the stranded and/or marginal oil field. The importance of gas hydrates is related to its potential to be able to contain about 160 Sm³ of gas and 0.85 m³ of water in 1 m³ of gas hydrate at standard temperature and pressure. This feature of natural gas hydrate can be brought to bear in harnessing associated gas instead of being flared. This article examines the prospect of natural gas hydrate (NGH) technology as a sustainable means of capturing associated gas from stranded and marginal oil field of the Niger Delta. Such gas is ordinarily being flared due to lack of adequate facilities to harnessing it. The conversion of associated-gas to hydrate will contributes to the elimination of flared gas and reduces the environmental pollution associated with gas flaring, and also increases government revenues from the monetized gas.

Key words: Natural gas hydrate, associated gas, gas flaring, hydrate slurry.

International Journal of Petroleum Engineering ISSN 5675-0715 Vol.  2 (1) pp. 057-064, January, 2015. © International Scholars Journals

Full Length Research Paper

Variables that influence weight distribution of flat wells in a layered reservoir with concurrent gas top and base water drive

Idoro B. Festus

Department of Petroleum and Mining Engineering, Faculty of Engineering, Ambrose Alli University, Ekpoma, Nigeria.

Email: [email protected]

Accepted 28 December, 2014

Abstract

Understanding the behaviour of pressure distribution completed in two layered reservoir subject to both active gas cap and bottom water drive mechanisms is very important in reservoir management. To determine the factors that affect pressure distribution of horizontal wells in a layered reservoir subjected simultaneously with a gas-cap at the top and bottom water drives, well completion was carried out in a particular layer and one of the parameters was varied while the others were kept constant. The results show that the following factors: (i) Wellbore radius (ii) Well Length and (iii) Pay thickness affect pressure distribution in two-layered reservoir subject to both active gas cap and bottom water drive which affect pressure distribution.

Key words: Well, pressure, layer, reservoir, well.

International Journal of Petroleum Engineering ISSN 5675-0715 Vol.  2 (1) pp. 046-056, January, 2015.  © International Scholars Journals

Full Length Research Paper

Sensitivity investigation of low saltiness water infusion in Zichebashskoe Oilfield

Liam Rush Hemsworth

Department of Petroleum and Mining Engineering, Faculty of Engineering, University of Queensland, Brisbane, Queensland.

Email: [email protected] 

Accepted 19 December, 2014

Abstract 

Presently, low salinity waterflooding is considered one of the most promising and cost-effective EOR methods. Although the recovery mechanisms are still uncertain, decrease of residual oil saturation and alternation of rock wettability are considered to be main mechanisms of the incremental oil recovery. In addition, laboratory and mathematical studies conducted over recent years suggested that mobility control is also a possible mechanism for enhanced oil recovery during low salinity water injection. The mobility control effect is due to induced fines migration and consequent permeability reduction in water invaded areas. The laboratory studies show that the incremental recovery gained from low salinity fines-assisted water flooding strongly depends on end point relative phase permeability for formation and injection waters. Permeability reduction due to fines migration decreases injected water mobility and increases the reservoir sweep. In this study, 24 years of production data from Zichebashskoe field (Russia) including 7 years of low salinity waterflooding are used to study the effect of water relative permeability reduction during low salinity waterflooding on improved oil recovery. The results of 3D reservoir simulations show low incremental oil recovery by low salinity water injection mainly due to two reasons: first a significant amount of water produced before the water injection, that is, a significant mixture between formation and injected waters that decrease the effect of low salinity; and second already high sweep efficiency as a result of water injection into water zone. The sensitivity study shows that the incremental recovery increases for greater relative permeability reduction by low salinity water injection .However, with 20 times decrease of Krwor from formation water to injected water, the incremental oil recovery is still negligible (4%).

Key words: Low salinity waterflood, fines-assisted waterflooding, field case, sensitivity study, fines migration.