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Potential of a Locally Made ASP Formulation Ogbonor (Irvingia Gabonensis) in Enhanced Oil Recovery Processes
Koyejo Oduola,
Nyemachi Oriji
Issue:
Volume 5, Issue 3-1, May 2017
Pages:
1-9
Received:
29 March 2017
Accepted:
30 March 2017
Published:
11 April 2017
DOI:
10.11648/j.ajche.s.2017050301.11
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Abstract: The quest for techniques to recover the remaining 60–80% of the original oil in place (OOIP) left upon conventional oil recovery methods has become imperative. Alkaline–surfactant–polymer (ASP) flooding has emerged as one of the most promising and widely applicable techniques due to its significant improvement on the displacement and sweep efficiency. A number of the attempts has been devoted to investigating the combination of up to three substances to form the appropriate ASP system for a given application, which has been without a number of technical challenges. This paper reviews the possibility of employing an appropriately engineered synthesis of an ASP substance which incorporates all the three components in one. Research has been conducted into the suitability of an ASP system formulated using locally available and thus economically viable raw materials (Ogbonor seeds, Irvingia gabonensis, potash, and salt). The study shows the best level of salinity needed for the retention of the polymer gel viscosity is 30g/l and the maximum viscosity of the polymer solution is 1.086, in the absence of additives. This brought to a conclusion that the chosen additive (potash) does not have a significant effect on the polymer solution that will result in highest viscosity which enhances a good percentage of oil recovery. Polynomial models relating the resulting polymer viscosity with concentration and salinity have been developed, applicable for predicting polymer viscosity at different concentrations of salt and additive.
Abstract: The quest for techniques to recover the remaining 60–80% of the original oil in place (OOIP) left upon conventional oil recovery methods has become imperative. Alkaline–surfactant–polymer (ASP) flooding has emerged as one of the most promising and widely applicable techniques due to its significant improvement on the displacement and sweep efficien...
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Application of Starches from Selected Local Cassava (Manihot Exculenta Crantz) as Drilling Mud Additives
Tubotamuno F. Harry,
Koyejo Oduola,
Falitat T. Ademiluyi,
Ogbonna F. Joel
Issue:
Volume 5, Issue 3-1, May 2017
Pages:
10-20
Received:
30 March 2017
Accepted:
31 March 2017
Published:
11 April 2017
DOI:
10.11648/j.ajche.s.2017050301.12
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Abstract: Selected local cassava (Manihot esculenta Crantz) starches were investigated as additives for water-based drilling mud. Cassava cultivars, TMS 30572, TMS 98/0505, TMS 98/0581, M98/0068, TMS 92/0057, TMS 96/1632, NR8082, TME 419, TMS 97/4779 and TMS 01/1412 were processed to starches and used for drilling mud treatment at 0.5, 1.0 and 2.0 percent. Polyanionic cellulose (PAC), xanthan gum (XG) and industrial starch-modified drilling muds served as controls. Physicochemical analysis of the starches showed significant differences in their properties. Viscosity and fluid loss profiles revealed that some of the local cassava starches had comparable performance with the commercial polymers. The optimal concentration of the industrial starch in the mud system was 0.5 percent, while that of the local starches were between 0.5 and 1.0 percent. PAC and XG performed best at 1.0 and 2.0 percent respectively. The highest viscosities were shown by muds treated with TMS 98/0581, XG, TMS 96/1632, M98/0068, TMS 92/0057 and PAC, arranged in decreasing order. And the lowest fluid losses were exhibited by muds with PAC, industrial starch, XG, TMS 98/0581 and M98/0068 in increasing order. Viscosity and fluid loss models as functions of cassava starch physicochemical properties were developed. Increase in starch content, amylose content, solubility index would readily increase viscosity, while high starch content, amylopectin content, solubility index and pH would reduce the fluid loss. Local starches from TMS 98/0581, TMS 96/1632 and M98/0068 and TMS 92/0057 could be used as a substitute in drilling mud as viscosity enhancers and fluid loss control agents in Nigeria.
Abstract: Selected local cassava (Manihot esculenta Crantz) starches were investigated as additives for water-based drilling mud. Cassava cultivars, TMS 30572, TMS 98/0505, TMS 98/0581, M98/0068, TMS 92/0057, TMS 96/1632, NR8082, TME 419, TMS 97/4779 and TMS 01/1412 were processed to starches and used for drilling mud treatment at 0.5, 1.0 and 2.0 percent. P...
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Evaluating The Effect of Temperature and Polymer Concentration on Properties of Hydroxyethyl Cellulose Gravel Pack Fluid
Anthony Okon John,
Ogbonna Joel,
Franklin Chukwuma
Issue:
Volume 5, Issue 3-1, May 2017
Pages:
21-27
Received:
29 March 2017
Accepted:
31 March 2017
Published:
15 April 2017
DOI:
10.11648/j.ajche.s.2017050301.13
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Abstract: The commercial success of petroleum wells depends greatly on the type of completion, especially the choice of gravel packing fluid system for wells with gravel pack completions. Currently several polymers are in use to viscosify gravel pack fluids. These polymers are expected to exhibit acceptable properties such as good solubility, viscosity yield, rheology, sand carrying capacity, thermal stability, break profile, low residue content and others, to match the job requirements, in order not to jeopardize the sand control process or cause hydrocarbon production impairment. Hydroxyethyl cellulose (HEC), one of the most commonly used polymers used in formulating gravel pack fluids has so many good qualities, such as very low solid residues and easy clean out. In this paper, gel break time was investigated for 40lbs/1000gal and 60lbs/1000gal HEC polymer concentrations at 140°F, 160°F and 180°F, using Sodium Persulfate as gel breaker at concentrations of 1.0lbs/1000gal, 5.0lbs/1000gal, 10.0lbs/1000gal and 20.0lbs/1000gal. The proppant carrying capacity at different temperatures was also investigated. Test results indicated that gel break is a function of temperature, breaker and polymer concentrations. At higher temperatures and higher breaker concentrations, gel break is faster, but slower for higher polymer concentration.
Abstract: The commercial success of petroleum wells depends greatly on the type of completion, especially the choice of gravel packing fluid system for wells with gravel pack completions. Currently several polymers are in use to viscosify gravel pack fluids. These polymers are expected to exhibit acceptable properties such as good solubility, viscosity yield...
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Design, Fabrication and Validation of a Laboratory Flow Loop for Hydrate Studies
Odutola T. O.,
Ajienka J. A.,
Onyekonwu M. O.,
Ikiensikimama S. S.
Issue:
Volume 5, Issue 3-1, May 2017
Pages:
28-41
Received:
3 March 2017
Accepted:
4 March 2017
Published:
27 April 2017
DOI:
10.11648/j.ajche.s.2017050301.14
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Abstract: The peculiar nature of the offshore environment has necessitated the need for the Oil and Gas industry to develop durable subsea technologies and better hydrate inhibitors to prevent hydrate formation and assure flow. This paper discusses the design, fabrication and validation of a laboratory flow loop for hydrate studies. The laboratory loop is a closed loop of 12meters, fabricated using 0.5inch 316 stainless steel pipe enclosed in an insulated 4inch Polyvinylchloride (PVC) pipe. The skid mounted loop was fitted with pumps, temperature gauges, pressure gauges, differential pressure transmitters, a gas mixing vessel, an inhibitor mixing vessel, and a Natural Gas cylinder. Hydrate formed in the loop when natural gas was contacted with water under suitable hydrate forming temperature and pressure conditions and was indicated by an increased loop temperature, an increased differential pressure and a decreased loop pressure. Loop Validation was done by flowing a single phase fluid of water, a single phase fluid of gas and a 2 phase fluid of gas and water in three different experimental runs respectively. Each experimental run lasted 2 hours during which temperatures and pressures around the loop were recorded every minute. Hydrate formation was observed in the experimental run conducted with the two phase fluid (gas and water) and the experimental run conducted with gas alone due to water condensing out of gas during cooling. Hydrate did not form in the experimental run conducted with single phase fluid of water. The laboratory flow loop adequately predicts hydrate formation and has been used in screening and selection of Kinetic Hydrate Inhibitors (KHI).
Abstract: The peculiar nature of the offshore environment has necessitated the need for the Oil and Gas industry to develop durable subsea technologies and better hydrate inhibitors to prevent hydrate formation and assure flow. This paper discusses the design, fabrication and validation of a laboratory flow loop for hydrate studies. The laboratory loop is a ...
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Models for Environmental and Business Management in the Oil and Gas Industry
Olajide Festus,
Joel Ogbonna,
Amadi-Echendu Joe
Issue:
Volume 5, Issue 3-1, May 2017
Pages:
42-48
Received:
20 March 2017
Accepted:
20 March 2017
Published:
27 April 2017
DOI:
10.11648/j.ajche.s.2017050301.15
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Abstract: To meet the United Nations 2030 Agenda for Sustainable Development and the United Nations Frame Work conventions on climate change, there is need to develop new business and environmental management models to mitigate the impact of the emission of Carbon (IV) Oxide (CO2) into the environment by the Oil and Gas industry taking into consideration the advantage provided by the digitalization of technology. This research presents new models for environmental management and Carbon taxation within the frame work of environmental sustainability. This study focused on the sources of the Hydrocarbon rather than the sink for its analysis and modelling. Every Oil and Gas producing country is viewed as an Isolated Thermodynamic system in space whose emission of CO2 must be sustainable. An Isolated thermodynamic system is one in which no transfer of mass or energy occurs across its boundary. Hence, Oil and Gas producing countries that benefit from the revenues of Oil and gas production are held directly responsible for the unfavourable impact of CO2 emission rather than the sink (consumers) in accordance with the “Polluter Pays Principle”. Viewing every country as an Isolated Thermodynamic system ensures that each country strives to live sustainably. The model for computing the CO2 Ecological Footprint (EF) was developed with MATLAB 7.5.0 Software based on the total Oil and Gas production from the Oil and Gas producing country (Nigeria was used as a case study). Based on the Computed CO2 EF, model for the size of the forest required for sequestering all the emitted CO2 was developed for environmental sustainability. Two of the available technologies for CO2 sequestration (Ocean Fertilization and Ocean Injection of CO2) were used to develop environmental cost models as a basis for taxation. The result of the research shows that by viewing each Oil and Gas producing country as an Isolated Thermodynamic System that will be held accountable for CO2 emission, the attainment of the UN 2030 Agenda for sustainable development and the UN conventions on Climate change are easily achieved. Empirical analyses of data obtained with regard to CO2 released during Oil and Gas production in Nigeria suggests that the CO2 release by the Nigerian Oil and Gas Industry is unsustainable. Digitalization technologies will rely on the new models developed in this research to develop new business tools for national and inter-country trading of CO2 emissions and management of Forests for CO2 sequestration.
Abstract: To meet the United Nations 2030 Agenda for Sustainable Development and the United Nations Frame Work conventions on climate change, there is need to develop new business and environmental management models to mitigate the impact of the emission of Carbon (IV) Oxide (CO2) into the environment by the Oil and Gas industry taking into consideration the...
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Enhancement of High-Density Polyethylene Properties by Impregnation with Inorganic Alumina Filler
Koyejo Oduola,
Fabian Ozioko
Issue:
Volume 5, Issue 3-1, May 2017
Pages:
49-54
Received:
10 April 2017
Accepted:
11 April 2017
Published:
27 April 2017
DOI:
10.11648/j.ajche.s.2017050301.16
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Abstract: The influence of filler size and content on the mechanical and rheological properties (thermal conductivity, impact strength, hardness and melt flow index (MFI) of Al2O3/high-density polyethylene (HDPE) composites have been studied. Concentration of alumina was varied up to 30% by weight. The composites were prepared using a two-roll mill and then test specimens were prepared by injection molding. Thermal conductivity, hardness, impact strength and melt flow rate of the composites increased with decreased particle sizes and increased particle content with exceptions at certain concentrations due to non-uniform distributions of particles and agglomerates formed by the particles. As an example, the best integrated thermal conductivity was shown by a 75 micron-Al2O3/HDPE composite at 15% wt. alumina content, while the 212 micron- Al2O3/HDPE composite at 20 wt.% alumina content. For the same alumina content of 15% concentration by weight out of the three particle sizes. 75, 212 and 850 microns, the 75 micron-Al2O3/HDPE composite gave the highest thermal conductivity, which was nearly 50% higher than that of pure HDPE. Enhancement in impact strength and Hardness Rockwell were up to 300% and 400% as compared to the pure HDPE respectively. The Al2O3 with small particle size is generally more efficient for the enhancement of the impact strength.
Abstract: The influence of filler size and content on the mechanical and rheological properties (thermal conductivity, impact strength, hardness and melt flow index (MFI) of Al2O3/high-density polyethylene (HDPE) composites have been studied. Concentration of alumina was varied up to 30% by weight. The composites were prepared using a two-roll mill and then ...
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