Hybrid journal (It can contain Open Access articles) ISSN (Print) 1754-8888 - ISSN (Online) 1754-8896 Published by Inderscience Publishers[439 journals]
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Authors:Qingxin Song, Tianyue Li, Xianyong Liu Pages: 1 - 17 Abstract: The sand control problems of multiple cyclic steam stimulation (CSS) mainly include destruction of the sand barrier, failure, and short validity period of sand control. Uncompaction of packing layer and loose arrangement of filling sand may cause sand migration or even collapse in the formation, which results in plugging and reducing seepage capacity in the near-wellbore zones. Some bottleneck problems limit the development, such as short effective period of sand control, rapid production decline, casing deformation, and casing damage. Sand plugging or sand burial at the bottom hole mainly causes these problems. To solve the above problems, fibre consolidation with high-temperature resistance is developed. Additionally, the layered sand control and steam injection string are used. Finally, the technology of balanced dense filling and sand control is developed, which can effectively increase the strength of the sand barrier, extend the validity period, and realise high-efficiency development of the wells after multiple CSS. Keywords: cyclic steam stimulation; heavy oil; high temperature resistance; cementitious materials; layered sand control Citation: International Journal of Petroleum Engineering, Vol. 4, No. 1 (2022) pp. 1 - 17 PubDate: 2022-11-28T23:20:50-05:00 DOI: 10.1504/IJPE.2022.127196 Issue No:Vol. 4, No. 1 (2022)
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Authors:Kingsley E. Abhulimen, Temi Okesanya Pages: 18 - 64 Abstract: This paper presents a novel water-based mud (WBM) that utilised certain environmentally friendly bioenhancers additives to improve its overall effectiveness of mud properties (pH, mud weight, corrosion tendencies, and viscosity) in drill fluid system. The primary base bio-additives in the WBM used in our research are banana peels ash (BPA), orange peel ash (OPA), and a mixture of OPA/BPA. Thus, different formulations of the drilling fluid systems were treated with bio-additives (OPA, BPA and BPA/OPA) and caustic soda. The test samples (samples A to E) were formulated at different concentrations of BPA, OPA, BPA/OPA mixture, and caustic soda. Sample A was taken as the control sample. The investigations were carried out in line with the American Petroleum Institute (API) standards to check for improvement in pH and other fluid properties' specifications such as laxity, yield, suspensions, and viscosity on the initial empirical pilot experimentation. Keywords: corrosion; banana peels ash; BPA; orange peel ash; OPA; mud enhancers; viscosity; drilling; pH control Citation: International Journal of Petroleum Engineering, Vol. 4, No. 1 (2022) pp. 18 - 64 PubDate: 2022-11-28T23:20:50-05:00 DOI: 10.1504/IJPE.2022.127201 Issue No:Vol. 4, No. 1 (2022)
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Authors:Josephine Fleur Matateyou, Lionel Tapsia Karga, Madeleine Nitcheu, Ornella Gwladys Djouwa Kom, Luc Leroy Mambou Ngueyep, Sifeu Takougang Kingni Pages: 65 - 79 Abstract: This paper aims to design a gas lift that not only activates a non-eruptive well but also and above all, optimises the recovery of hydrocarbons at the surface while using a very less and limited gas quantity per day. The data are reservoir data, fluid data, well architecture properties, and also injection targets. To achieve the objective, it is necessary to carry out a nodal analysis of the non-eruptive well, and design the gas lift system by finding the gas injection pressure in the well, the number of valves, the optimal heights of injection, and the flow rates received by each valve. The evaluation of the system performance, as well as the sensitivity analysis, allows the selection of an optimal production rate. All the simulation operations and the well diagram are carried out with PIPESIM 2017.1. The results obtained show for the continuous injection of gas at 0.73 and 0.23 mmscf/d respectively. For valves 1 and 2 in the well, i.e., 1 mmscf/d for the two valves and using pressure at the head of the well of 100 psia, an optimal flow rate of 262.9 STB/d can be produced and the payback period is one year and two months. Keywords: non-erupting well; gas lift; step-up; production; sensitivity analysis; payback period Citation: International Journal of Petroleum Engineering, Vol. 4, No. 1 (2022) pp. 65 - 79 PubDate: 2022-11-28T23:20:50-05:00 DOI: 10.1504/IJPE.2022.127212 Issue No:Vol. 4, No. 1 (2022)
Hybrid journal (It can contain Open Access articles)
[439 journals]
