scholarly journals A justification of the application of low-mineralized flooding at the later stage of offshore oil field development

2021 ◽  
pp. 265-270
Author(s):  
Д.С. Тананыхин ◽  
А.Д. Селимов ◽  
Л.А. Сайченко
Keyword(s):  
Water Injection ◽  
Oil Field ◽  
Water Flooding ◽  
Reservoir Pressure ◽  
Reservoir Water ◽  
Field Development ◽  
Stage Of Development ◽  
Oil Field Development ◽  
Mineralized Water ◽  
Offshore Oil

Известно, что для поддержания пластового давления используется вода совместимая по своему химическому составу с пластовой. В этом случае обеспечивается возможность сохранить присущую эксплуатируемому объекту поровую структуру. Данная работа посвящена обоснованию применения низкоминерализованного заводнения нефтяных месторождений на поздней стадии разработки. На основе изученного материала разработаны методические рекомендации для повышения эффективности системы поддержания пластового давления за счет закачки низкоминерализованной воды. Результаты теоретического анализа (литературная и патентная проработки) дополнительно были подтверждены проведенным гидродинамическим моделированием низкоминерализованного заводнения на примере нефтяного месторождения. It Has been known that the water used for reservoir pressure maintenance has to be compatible in its chemical composition with the reservoir water. In this case, it is possible to preserve the pore structure inherent in the exploited object. This article is devoted to the justification of applying low-mineralized water flooding at the later stage of offshore oil field development. Authors developed a method to improve the efficiency of reservoir pressure maintenance system with applying low-mineralized water injection. The novelty of this article is the mathematical determination of the optimal period for the start of the application of low-mineralized water flooding. Theoretical analysis results were also confirmed by hydrodynamic modeling of low-mineralized water flooding in an offshore oil field at a late stage of development. Based on the analysis results, authors identified requirements and recommendations for the low-mineralized water flooding.

Low Permeability Reservoir Water Displacing Oil and Water Flooding Characteristic Curve Theory

2014 ◽  
Vol 556-562 ◽  
pp. 4701-4704
Author(s):  
Chun Sen Zhao ◽  
Qing Lin Ren ◽  
Pei Jing Li
Keyword(s):  
Characteristic Curve ◽  
Water Injection ◽  
Oil Field ◽  
Water Flooding ◽  
Practical Significance ◽  
Low Permeability ◽  
Reservoir Water ◽  
Field Development ◽  
Recoverable Reserves ◽  
The Impact

The so-called water flooding characteristic curve refers to the oilfield water injection (or natural water drive) development process, a relationship between curve cumulative oil production, cumulative water production and accumulation of fluid production. These curves have been widely used for water injection development of dynamic and recoverable reserves forecast. After many years of practical application, summed up the four kinds of water drive characteristic curve, they have a good practical significance. Recoverable reserves are important indicators of field development is the main basis for planning and design, the application of waterflooding characteristic curve can be predicted oil recoverable reserves. Four water flooding characteristics discussed above curve is mainly applied in high-permeability oil field, which did not consider starting pressure, but should consider the impact of low permeability oilfield actuating pressure gradient on the moisture content.

Diagnostic Plots for Production Decline During the Transition of Oil Field Development From Depletion to Water Injection

2021 ◽  
Author(s):  
Vil Syrtlanov ◽  
Yury Golovatskiy ◽  
Ivan Ishimov
Keyword(s):  
Water Injection ◽  
Simulation Models ◽  
Oil Field ◽  
Production Data ◽  
Oil Reservoir ◽  
Field Development ◽  
Well Production ◽  
Diagnostic Plots ◽  
Oil Field Development ◽  
Analytical Approaches

Abstract In this paper the simplified way is proposed for predicting the dynamics of liquid production and estimating the parameters of the oil reservoir using diagnostic curves, which are a generalization of analytical approaches, partially compared with the results of calculations on 3D simulation models and with actual well production data.

Quantifying Economic Uncertainties and Risks in the Oil and Gas Industry

2021 ◽  
pp. 154-184
Author(s):  
Sorin Alexandru Gheorghiu ◽  
Cătălin Popescu
Keyword(s):  
Business Performance ◽  
Oil And Gas ◽  
Water Injection ◽  
Oil And Gas Industry ◽  
Oil Field ◽  
Gas Industry ◽  
Field Development ◽  
Drilling Rig ◽  
Oil Field Development ◽  
Oil Gas

The present economic model is intended to provide an example of how to take into consideration risks and uncertainties in the case of a field that is developed with water injection. The risks and uncertainties are related, on one hand to field operations (drilling time, delays due to drilling problems, rig failures and materials supply, electric submersible pump [ESP] installations failures with the consequences of losing the well), and on the other hand, the second set of uncertainties are related to costs (operational expenditures-OPEX and capital expenditures-CAPEX, daily drilling rig costs), prices (oil, gas, separation, and water injection preparation), production profiles, and discount factor. All the calculations are probabilistic. The authors are intending to provide a comprehensive solution for assessing the business performance of an oil field development.

DEVELOPMENT PLANNING FOR THE COSSACK AND WANAEA FIELDS

1994 ◽  
Vol 34 (1) ◽  
pp. 92
Author(s):  
G. B. Salter ◽  
W. P. Kerckhoff
Keyword(s):  
Cost Reduction ◽  
Water Injection ◽  
Development Planning ◽  
Oil Field ◽  
Oil Fields ◽  
Oil Reservoirs ◽  
Field Development ◽  
Oil Reserves ◽  
Oil Field Development ◽  
Significant Effort

Development of the Cossack and Wanaea oil fields is in progress with first oil scheduled for late 1995. Wanaea oil reserves are estimated in the order of 32 x 106m3 (200 MMstb) making this the largest oil field development currently underway in Australia.Development planning for these fields posed a unique set of challenges.Key subsurface uncertainties are the requirement for water injection (Wanaea only) and well numbers. Strategies for managing these uncertainties were studied and appropriate flexibility built-in to planned facilities.Alternative facility concepts including steel/concrete platforms and floating options were studied-the concept selected comprises subsea wells tied-back to production/storage/export facilities on an FPSO located over Wanaea.In view of the high proportion of costs associated with the subsea components, significant effort was focussed on flowline optimisation, simplification and cost reduction. These actions have led to potential major economic benefits.Gas utilisation options included reinjection into the oil reservoirs, export for re-injection into North Rankin or export to shore. The latter requires the installation of an LPG plant onshore and was selected as the simplest, safest and the most economically attractive method.

Optimal design and scheduling for offshore oil-field development

2019 ◽  
Vol 123 ◽  
pp. 300-316 ◽  
Author(s):  
Yuxi Wang ◽  
Segen F. Estefen ◽  
Marcelo Igor Lourenço ◽  
Cheng Hong
Keyword(s):  
Optimal Design ◽  
Oil Field ◽  
Field Development ◽  
Oil Field Development ◽  
Offshore Oil

Broadband experience on deep offshore oil field development: Angolan example, B17/CLOV project

2013 ◽  
Author(s):  
Celso Gomes ◽  
Loic Bovet ◽  
Christian Deplante ◽  
Sergio Tchikanha ◽  
Enrico Zamboni
Keyword(s):  
Oil Field ◽  
Field Development ◽  
Oil Field Development ◽  
Offshore Oil

scholarly journals Economic Analysis and Generic Algorithm for Optimizing the Investments Decision-Making Process in Oil Field Development

Energies ◽  
2021 ◽  
Vol 14 (19) ◽  
pp. 6119
Author(s):  
Catalin Popescu ◽  
Sorin Alexandru Gheorghiu
Keyword(s):  
Economic Analysis ◽  
Water Injection ◽  
Investment Decisions ◽  
Price Volatility ◽  
Oil Field ◽  
Generic Algorithm ◽  
Field Development ◽  
Drilling Rig ◽  
Discount Factors ◽  
Oil Field Development

Due to the substantial amounts of money involved and the complex interactions of a number of different factors, managers of oil and gas companies are faced with significant challenges when making investment decisions that will increase business efficiency and achieve competitive advantages, especially through cost control. Due to the various uncertainties of the current period, optimal investment strategies are difficult to determine. Thus, through an economic analysis that includes data analysis, quantitative risk analysis scenarios, modelling and simulations, a work framework, in the form of a generic algorithm, is proposed with the aim of generating a complex procedure for optimizing investment decisions in oil field development. A complex set of elements is considered in the analysis: costs (operational expenditures (OPEX) and capital expenditures (CAPEX), daily drilling rig costs), prices (oil, gas, separation and water injection preparation), production profiles, different types of taxes and discount factors. Above all, oil price volatility plays an essential role and creates uncertainty in relation to profitability and the strategic investment decisions made by oil exploration and production companies.

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