Evaluation of Water Coning Tendency to Support Full Field Development Plan: Analytical Predictive Techniques or Numerical Simulation Models?

2015 ◽  
Author(s):  
Hossein Ali Algdamsi ◽  
Ahmed Abdalslam Amtereg ◽  
Ammar Agnia
Keyword(s):  
Numerical Simulation ◽  
Simulation Models ◽  
Development Plan ◽  
Full Field ◽  
Field Development ◽  
Water Coning

Full Field Development Plan Optimization Integrating Subsurface reservoirs uncertainties for Green Field Offshore Abu Dhabi, UAE

2012 ◽  
Author(s):  
Said Meziani ◽  
Mohamed Sayed Ibrahem ◽  
Khalil Al-Hossani ◽  
Tarek Mohamed Matarid ◽  
Bader Saif Al Badi
Keyword(s):  
Development Plan ◽  
Abu Dhabi ◽  
Full Field ◽  
Field Development ◽  
Plan Optimization

Full-Field Development Plan "The Big Picture - Creating the Future from the Future and Success through Real Synergy !H

2009 ◽  
Author(s):  
Ashraf Al-Saiid Keshka ◽  
Jorge Salgado Gomes ◽  
Maher Mahmoud Kenawy ◽  
Hafez H. Hafez ◽  
Sharif Al Olama ◽  
...  
Keyword(s):  
Development Plan ◽  
Full Field ◽  
Field Development ◽  
The Future ◽  
Big Picture

Full-Field Development Plan “The Big Picture—Creating the Future from the Future and Success through Real Synergy”

2009 ◽  
Author(s):  
H.H. Hafez ◽  
M.M. Kenawy ◽  
A. Al-Saiid Keshka ◽  
K.A. Samad ◽  
S. Al-Bakr ◽  
...  
Keyword(s):  
Development Plan ◽  
Full Field ◽  
Field Development ◽  
The Future ◽  
Big Picture

scholarly journals Estimation of Water Breakthrough Using Numerical Simulation

2019 ◽  
Vol 26 (3) ◽  
pp. 73-81
Author(s):  
Almanar Faleh ◽  
Jalal A. Al-Sudani
Keyword(s):  
Numerical Simulation ◽  
Vertical Direction ◽  
Simulation Models ◽  
Breakthrough Time ◽  
Time Model ◽  
Specific Strength ◽  
Wide Range ◽  
Water Coning ◽  
Fluid Properties ◽  
Numerical Simulator

Water coning is one of the most important phenomena that affect the oil production from oil reservoirs having bottom water aquifers. Empirical model has been developed based on numerical simulator results verified for wide range variation of density difference, viscosity ratio, perforated well interval, vertical to horizontal permeability ratio and well to reservoir radius ratio; the effect of all these parameters on breakthrough time of raising water have been recorded for five different oil flow rate. Since, the model reflects the real situations of reservoir-aquifer zone systems; in which the aquifer has a specific strength to support the reservoir pressure drop depending on its characteristics and water properties. Moreover, the numerical model has been constructed using very fine grids near the wellbore especially in vertical direction, so that very accurate results can be obtained. and (625)runs were performed to generate the breakthrough time model using the numerical simulator verifying all parameters affecting on breakthrough time. The results show that water coning is complex phenomena that depends on all reservoir and fluid properties; the dynamic critical flow rates affected simultaneously by both of the displacing fluid zones. The results show that the breakthrough time of the presented formula provides extreme accuracy with many numerical simulator cases of same reservoir and fluid properties; thus, the suggested formula can be considered as an alternative, quick and easy use tool than numerical simulation models, which consumes time and efforts.

Dynamic Modeling Workflow for an Unconventional Biogenic Gas Reservoir with Multistage Hydraulic Fracture. A Case Study of Miocene Gachsaran Formation, Abu Dhabi, United Arab Emirates

2021 ◽  
Author(s):  
Abdelghani Gueddoud ◽  
Ahmed Al Hanaee ◽  
Riaz Khan ◽  
Atef Abdelaal ◽  
Redy Kurniawan ◽  
...  
Keyword(s):  
Hydraulic Fracture ◽  
Development Plan ◽  
Unconventional Reservoirs ◽  
Hydraulic Fractures ◽  
Flow Mechanism ◽  
Gas Reservoir ◽  
Full Field ◽  
Gas Concentration ◽  
Biogenic Gas ◽  
Field Development

Abstract The Miocene Gachsaran Formation across Onshore Abu Dhabi and Dubai possesses high potential of generating shallow biogenic gas. A dynamic model and field development plan generated based on a detail G&G analysis to understand and evaluate its capability as promising gas resources. Specific approaches and workflow generated for volumetric and dynamic reservoir model capable of defining the most viable development strategy of the field from both an economic and technical standpoint. The proposed workflow adapts also the development plan from single pad-scale to full field development plan. A fine-grid field-scale with more than hundreds of Pads covering the sweet spot area of three thousands of square kilometers including structure, reservoir properties built based on existing vertical wells, newly drilled horizontal wells and seismic interpretation. In this paper, a robust workflow for big and complex unconventional biogenic gas reservoir modeling and simulation technique have been developed with hydraulic fracture and stimulated area created through LGR. Independent workflows generated for the adsorbed gas in place calculation, desorption flow mechanism, and Pads field development plan. An accuracy on in place calculation, desorption flow mechanism and Pseudo steady state flow through direct and indirect total gas concentration measured using (1) Pressurize core and sorption isotherm capacity experiment, (2) Langmuir /BET function and Vmax scaling curves for each grid cells, and (3) Gas concentration versus TOC relationship. Field development plan for unconventional shallow biogenic gas reservoirs is possible only if a communication network created through hydraulic fractures connects a huge reservoir area to the wellbore effectively. A complete workflow presented for modeling and simulation of unconventional reservoirs, which in-corporates the characterization of hydraulic fracture and their interaction with reservoir matrix. Dual porosity model has been constructed with accurate in place calculation through scaling the Langmuir function and calculation Vmax for each grid cell of the full field model, The single Pad design approach in the development plan has exhibited great advantages in terms of improvement in the quality and flexibility of the model, reduction of working time with the same Pad model design which is adapted for the full field development plan. The proposed unconventional modeling and field development plan workflow provides an efficient and useful unconventional dynamic model construction and full field development planning under uncertainty analysis. Minimizing the uncertainty in place calculation and production forecasting for unconventional reservoirs necessitates an accurate direct and indirect data measurement of gas concentration and flow mechanism through the laboratory measurement. Field development plan for unconventional reservoirs is possible only if fracture network can be created through hydraulic fractures that connects a huge reservoir area to the wellbore effectively through pad completion.

Solving the Problem of Operational Accounting of Well Drilling Results in a Full-Scale Model of Unique Gas Condensate Fields

2021 ◽  
Author(s):  
Andrey Viktorovich Poushev ◽  
Ruslan Railievich Mangushev ◽  
Sergey Anatolievich Yakimov
Keyword(s):  
Decision Making ◽  
Oil And Gas ◽  
Flow Simulation ◽  
Simulation Models ◽  
Gas Production ◽  
Scale Model ◽  
New Production ◽  
Full Field ◽  
Field Development ◽  
Field Static

Abstract Today, strategic planning of field development is based on full-field static and flow simulation models which are regularly updated as part of field surveillance programs and by integrating the actual results of drilling and testing of new production and exploration wells and integrated interpretation of seismic surveys and reservoir core and fluid laboratory analyses. One of the key factors for the success of investment projects is how quick and flexible the decision-making process is. Therefore, in modern conditions, prompt integration of new data into full-field flow simulation models followed by their processing, analysis, and decision-making on adjusting the strategic goals is of particular relevance for oil and gas production companies. For unique multi-reservoir fields containing dozens of reservoirs, hundreds of accumulations and wells, it is hardly possible to promptly update full-field static and flow simulation models within less than 6-12 months, therefore, the decisions are made in the absence of up-to-date models, which may lead to poor quality of production forecasts. The purpose of the study was to develop an approach to the modeling of unique fields, which would allow prompt integration of new data in a full-field flow simulation model while keeping the level of detail without significant time input.

scholarly journals An efficient approach for optimizing full field development plan using Monte-Carlo simulation coupled with Genetic Algorithm and new variable setting method for well placement applied to gas condensate field in Vietnam

2016 ◽  
Vol 35 (1) ◽  
pp. 75-102 ◽  
Author(s):  
Jongyoung Jun ◽  
Joomyung Kang ◽  
Daein Jeong ◽  
Haeseon Lee
Keyword(s):  
Genetic Algorithm ◽  
Monte Carlo Simulation ◽  
Monte Carlo ◽  
Optimization Procedure ◽  
Gas Condensate ◽  
Dew Point ◽  
Development Plan ◽  
Well Placement ◽  
Full Field ◽  
Field Development

This paper presents an efficient technique to optimize a gas condensate field development plan under economic uncertainties. Many studies have been conducted to optimize development plan but mostly limited to oil field under fixed economic environments and required huge number of simulation runs. It is proved that black oil model can be a reasonable alternative of compositional model to complete field development optimization within acceptable period when reservoir pressure is higher enough than dew point pressure. This study implements Monte-Carlo simulation to Genetic Algorithm to assess economic uncertainties while optimization procedure is being performed and to avoid duplicating whole optimization procedure by changing economic assumptions. An idea for setting optimization variables for well placement is also introduced to reduce required number of simulation runs. A real field application confirms that the technique can be applied to optimize a gas condensate field with contractual gas sales obligation, and the idea plays a key role to find the optimized solution with limited resources by reducing the number of simulation runs required during the optimization procedure. The proposed technique can be applied to optimize not only full field development plan but also reservoir management plan and it will be helpful to improve economics of all kinds of E&P projects under lots of uncertainties.

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