Productivity Assessment and Evaluation of Water Coning Tendency to Support Full Field Development Plan Using Single Well Numerical Model

2017 ◽  
Author(s):  
Hossein Ali Algdamsi ◽  
Ammar Agnia ◽  
Ahemd Amtereg
Keyword(s):  
Numerical Model ◽  
Development Plan ◽  
Full Field ◽  
Assessment And Evaluation ◽  
Field Development ◽  
Water Coning ◽  
Single Well ◽  
Productivity Assessment

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

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.

Historical Overview and Future Perspective of Chemical EOR Project for Major Malaysian Offshore Oilfield: Case Study

2021 ◽  
Author(s):  
Ahmad Khanifar ◽  
Benayad Nourreddine ◽  
Mohd Razib Bin Abd Raub ◽  
Raj Deo Tewari ◽  
Mohd Faizal Bin Sedaralit
Keyword(s):  
Interfacial Tension ◽  
Field Trial ◽  
Oil Production ◽  
Residual Oil ◽  
Oil Saturation ◽  
Full Field ◽  
Residual Oil Saturation ◽  
Field Development ◽  
Well Spacing ◽  
Single Well

Abstract A major Malaysian offshore oilfield, which is currently operating under waterflooding for a quite long time and declining in oil production, plan to convert as chemical enhanced oil recovery (CEOR) injection. The CEOR journey started since the first oil production in year 2000 and proximate waterflooding, with research and development in determining suitable method, encouraging field trial results and a series of field development plans to maximize potential recovery above waterflooding and prolong the production field life. A comprehensive EOR study including screening, laboratory tests, pilot evaluation, and full field reservoir simulation modelling are conducted to reduce the project risks prior to the full field investment and execution. Among several EOR techniques, Alkaline-Surfactant (AS) flooding is chosen to be implemented in this field. Several CEOR key parameters have been studied and optimized in the laboratory such as chemical concentration, chemical adsorption, interfacial tension (IFT), slug size, residual oil saturation (Sor) reduction, thermal stability, flow assurance, emulsion, dilution, and a chemical injection scheme. Uncertainty analysis on CEOR process was done due to the large well spacing in the offshore environment as compared to other CEOR projects, which are onshore with shorter well spacing. The key risks and parameters such as residual oil saturation (Sorw), adsorption and interfacial tension (IFT) cut-off in the dynamic chemical simulator have been investigated via a probabilistic approach on top of deterministic method. The laboratory results from fluid-fluid and rock-fluid analyses ascertained a potential of ultra-low interfacial tension of 0.001 dyne/cm with adsorption of 0.30 mg/gr-of-rock, which translated to a 50-75% reduction in Sor after waterflooding. The results of four single well chemical tracer tests (SWCTT) on two wells validated the effectiveness of the Alkaline Surfactant by a reduction of 50-80% in Sor. The most suitable chemical formulation was found 1.0 wt. % Alkali and 0.075 wt. % Surfactant. The field trial results were thenceforth upscaled to a dynamic chemical simulation; from single well to full field modeling, resulting an optimal chemical injection of three years or almost 0.2 effective injection pore volume, coupled with six months of low salinity treated water as pre-flush and post-flush injection. The latest field development study results yield a technical potential recoverable volume of 14, 16, and 26 MMstb (above waterflooding) for low, most likely, and high cases, respectively, which translated to an additional EOR recovery factor up to 5.6 % for most-likely case by end of technical field life. Prior to the final investment decision stage, Petronas’ position was to proceed with the project based on the techno-commerciality and associated risks as per milestone review 5, albeit it came to an agreement to have differing interpretations towards the technical basis of the project in the final steering committee. Subsequently, due to the eventual plunging global crude oil price, the project was then reprioritized and adjourned correspondingly within Petronas’ upstream portfolio management. Further phased development including a producing pilot has been debated with the main objective to address key technical and business uncertainties and risks associated with applying CEOR process.

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.

Oil Reserves Evaluation and Field Development plan of Hakim Oil Field in Libya

2016 ◽  
Vol 18 (1) ◽  
pp. 39-53
Author(s):  
Omar Salih ◽  
Mahmoud Tantawy ◽  
Sayed Elayouty ◽  
Atef Abd Hady
Keyword(s):  
Oil Field ◽  
Development Plan ◽  
Field Development ◽  
Oil Reserves
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