First Ever Gas Simops Implementation In Abu Dhabi Offshore: A Success Story

2021 ◽  
Author(s):  
Majid Ismail Al Hammadi ◽  
Andreas Scheed ◽  
Hasan Alsabri ◽  
Hasan Al Ali ◽  
Yaqoub Al Obaidli ◽  
...  
Keyword(s):  
Gas Injection ◽  
Oil Production ◽  
Economic Benefits ◽  
Mitigation Measures ◽  
Co2 Emission Reduction ◽  
Gas Flaring ◽  
Drilling Rig ◽  
Concurrent Execution ◽  
Additional Control ◽  
Continuous Presence

Abstract Gas SIMOPS is a concurrent execution of two or more activities at same time, i.e., Drilling Operation, Oil Production & Gas Injection on an offshore wellhead tower thereby ensuring uninterrupted oil production and continuous reservoir pressure management from gas injection. The alternative to gas injection in this scenario was gas flaring, which has major environmental and financial impact. Considering continuous presence of personnel on drilling rig working over wellhead tower with high pressure gas injection; extensive Risk Analysis were conducted, and additional control/Mitigation measures were implemented. This initiative also contributed to the zero Gas flaring vision of the company by achieving a huge quantity of CO2 emission reduction. This successful Gas SIMOPS model is already being extended to other fields. To achieve this objective and keeping with 100% HSE, an in-house multi-disciplinary team collaborated and successfully executed Gas SIMOPS for the first time in UAE Offshore. Execution of Gas SIMOPS has brought major economic benefits to the company with additional Gas savings incurred.

scholarly journals A cost-effectiveness analysis of water security and water quality: impacts of climate and land-use change on the River Thames system

2013 ◽  
Vol 371 (2002) ◽  
pp. 20120413 ◽  
Author(s):  
P. G. Whitehead ◽  
J. Crossman ◽  
B. B. Balana ◽  
M. N. Futter ◽  
S. Comber ◽  
...  
Keyword(s):  
Water Quality ◽  
Land Use ◽  
Cost Effectiveness ◽  
Land Use Change ◽  
Algal Blooms ◽  
Economic Benefits ◽  
Point Sources ◽  
Mitigation Measures ◽  
Mitigation And Adaptation ◽  
River Thames

The catchment of the River Thames, the principal river system in southern England, provides the main water supply for London but is highly vulnerable to changes in climate, land use and population. The river is eutrophic with significant algal blooms with phosphorus assumed to be the primary chemical indicator of ecosystem health. In the Thames Basin, phosphorus is available from point sources such as wastewater treatment plants and from diffuse sources such as agriculture. In order to predict vulnerability to future change, the integrated catchments model for phosphorus (INCA-P) has been applied to the river basin and used to assess the cost-effectiveness of a range of mitigation and adaptation strategies. It is shown that scenarios of future climate and land-use change will exacerbate the water quality problems, but a range of mitigation measures can improve the situation. A cost-effectiveness study has been undertaken to compare the economic benefits of each mitigation measure and to assess the phosphorus reductions achieved. The most effective strategy is to reduce fertilizer use by 20% together with the treatment of effluent to a high standard. Such measures will reduce the instream phosphorus concentrations to close to the EU Water Framework Directive target for the Thames.

Evaluation of CO2 Gas Injection For Major Oil Production Fields in Malaysia - Experimental Approach Case Study: Dulang Field

2001 ◽  
Author(s):  
Zahidah Md. Zain ◽  
Nor Idah Kechut ◽  
Ganesan Nadeson ◽  
Noraini Ahmad ◽  
D.M. Anwar Raja
Keyword(s):  
Experimental Approach ◽  
Gas Injection ◽  
Oil Production ◽  
Co2 Gas

Pilot Project Evaluating WAG Efficiency for Carbonate Reservoir in Eastern Siberia

2021 ◽  
Author(s):  
Valentina Zharko ◽  
Dmitriy Burdakov
Keyword(s):  
Oil Recovery ◽  
Gas Injection ◽  
Oil Production ◽  
Pilot Project ◽  
Carbonate Reservoir ◽  
Recovery Factor ◽  
Eastern Siberia ◽  
Water Cut ◽  
Wag Injection ◽  
Injection Rates

Abstract The paper presents the results of a pilot project implementing WAG injection at the oilfield with carbonate reservoir, characterized by low efficiency of traditional waterflooding. The objective of the pilot project was to evaluate the efficiency of this enhanced oil recovery method for conditions of the specific oil field. For the initial introduction of WAG, an area of the reservoir with minimal potential risks has been identified. During the test injections of water and gas, production parameters were monitored, including the oil production rates of the reacting wells and the water and gas injection rates of injection wells, the change in the density and composition of the produced fluids. With first positive results, the pilot area of the reservoir was expanded. In accordance with the responses of the producing wells to the injection of displacing agents, the injection rates were adjusted, and the production intensified, with the aim of maximizing the effect of WAG. The results obtained in practice were reproduced in the simulation model sector in order to obtain a project curve characterizing an increase in oil recovery due to water-alternating gas injection. Practical results obtained during pilot testing of the technology show that the injection of gas and water alternately can reduce the water cut of the reacting wells and increase overall oil production, providing more efficient displacement compared to traditional waterflooding. The use of WAG after the waterflooding provides an increase in oil recovery and a decrease in residual oil saturation. The water cut of the produced liquid decreased from 98% to 80%, an increase in oil production rate of 100 tons/day was obtained. The increase in the oil recovery factor is estimated at approximately 7.5% at gas injection of 1.5 hydrocarbon pore volumes. Based on the received results, the displacement characteristic was constructed. Methods for monitoring the effectiveness of WAG have been determined, and studies are planned to be carried out when designing a full-scale WAG project at the field. This project is the first pilot project in Russia implementing WAG injection in a field with a carbonate reservoir. During the pilot project, the technical feasibility of implementing this EOR method was confirmed, as well as its efficiency in terms of increasing the oil recovery factor for the conditions of the carbonate reservoir of Eastern Siberia, characterized by high water cut and low values of oil displacement coefficients during waterflooding.

Optimum Oil Production Planning Using Infeasibility Driven Evolutionary Algorithm

2013 ◽  
Vol 21 (1) ◽  
pp. 65-82 ◽  
Author(s):  
Hemant Kumar Singh ◽  
Tapabrata Ray ◽  
Ruhul Sarker
Keyword(s):  
Evolutionary Algorithm ◽  
Production Planning ◽  
Oil Recovery ◽  
Optimization Problems ◽  
Nonlinear Function ◽  
Practical Interest ◽  
Oil Production ◽  
Economic Benefits ◽  
Financial Benefit ◽  
Single Objective

In this paper, we discuss a practical oil production planning optimization problem. For oil wells with insufficient reservoir pressure, gas is usually injected to artificially lift oil, a practice commonly referred to as enhanced oil recovery (EOR). The total gas that can be used for oil extraction is constrained by daily availability limits. The oil extracted from each well is known to be a nonlinear function of the gas injected into the well and varies between wells. The problem is to identify the optimal amount of gas that needs to be injected into each well to maximize the amount of oil extracted subject to the constraint on the total daily gas availability. The problem has long been of practical interest to all major oil exploration companies as it has the potential to derive large financial benefit. In this paper, an infeasibility driven evolutionary algorithm is used to solve a 56 well reservoir problem which demonstrates its efficiency in solving constrained optimization problems. Furthermore, a multi-objective formulation of the problem is posed and solved using a number of algorithms, which eliminates the need for solving the (single objective) problem on a regular basis. Lastly, a modified single objective formulation of the problem is also proposed, which aims to maximize the profit instead of the quantity of oil. It is shown that even with a lesser amount of oil extracted, more economic benefits can be achieved through the modified formulation.

Risk Assessment and Enhanced Oil Recovery Effect of Gravity Assisted Oxygen-Reduced Air Flooding

2021 ◽  
Author(s):  
Lijuan Huang ◽  
Zongfa Li ◽  
Shaoran Ren ◽  
Yanming Liu
Keyword(s):  
Natural Gas ◽  
Oil Recovery ◽  
Gas Injection ◽  
Oil Production ◽  
Air Injection ◽  
Oil Reservoirs ◽  
Displacement Efficiency ◽  
Risk Area ◽  
Recovery Method ◽  
High Risk Area

Abstract The technology of air injection has been widely used in the second and tertiary recovery in oilfields. However, due to the injected air and natural gas will explode, the safety of the gas injection technology has attracted much attention. Gravity assisted oxygen-reduced air flooding is a new method that eliminates explosion risks and improves oil recovery in large-dip oil reservoirs or thick oil layers. The explosion limit data of different components of natural gas under high pressure were obtained through explosion experiments, which verified the suppression effect of oxygen-reduced air on explosions. The influence of natural gas composition and concentration on explosion limits was also investigated. In addition, a rotatable displacement device was used to study the feasibility of gravity assisted oxygen-reduced air injection for improving the heavy oil reservoirs recovery. Under pressure and temperature conditions of 20MPa and 371K, the sand-filled gravity flooding experiments with different dip angles were carried out using oxygen-reduced air with an oxygen content of 8%. The results show that with the increase of the reservoir dip, the pore volume of the injected fluid at the gas channeling point, the efficient development time of gas injection, and the final displacement efficiency of gas injection development all increase through gravity stabilization caused by gravity differentiation. In the presence of a dip angle, the cumulative oil production before the gas breakthrough point exceeded 80% of the oil production during the entire production process, indicating that gravity assisted oxygen-reduced air flooding is an effective and safe improving oil recovery method. Finally, the explosion risk of each link of the air injection process is analyzed, and the high-risk area and the low-risk area are determined.

Global Optimization of Gas Allocation to a Group of Wells in Artificial Lift Using MATLAB

2001 ◽  
Author(s):  
Gabriel A. Alarcón ◽  
Carlos F. Torres-Monzón ◽  
Nellyana Gonzalo ◽  
Luis E. Gómez
Keyword(s):  
Production Rate ◽  
Optimization Technique ◽  
Gas Injection ◽  
Nonlinear Function ◽  
Oil Production ◽  
Oil Well ◽  
Artificial Lift ◽  
Total Oil ◽  
Gas Lift ◽  
Injection Rates

Abstract Continuous flow gas lift is one of the most common artificial lift method in the oil industry and is widely used in the world. A continuous volume of gas is injected at high pressure into the bottom of the tubing, to gasify the oil column and thus facilitate the extraction. If there is no restriction in the amount of injection gas available, sufficient gas can be injected into each oil well to reach maximum production. However, the injection gas available is generally insufficient. An inefficient gas allocation in a field with limited gas supply also reduces the revenues, since excessive gas injection is expensive due to the high gas prices and compressing costs. Therefore, it is necessary to assign the injection gas into each well in optimal form to obtain the field maximum oil production rate. The gas allocation optimization can be considered as a maximization of a nonlinear function, which models the total oil production rate for a group of wells. The variables or unknowns for this function are the gas injection rates for each well, which are subject to physical restrictions. In this work a MATLAB™ nonlinear optimization technique with constraints was implemented to find the optimal gas injection rates. A new mathematical fit to the “Gas-Lift Performance Curve” is presented and the numeric results of the optimization are given and compared with results of other methods published in the specialized literature. The optimization technique proved fast convergence and broad application.

Reducing Gas Flaring in Oil Production from Shales

2016 ◽  
Vol 30 (9) ◽  
pp. 7524-7531 ◽  
Author(s):  
Richard Roehner ◽  
Palash Panja ◽  
Milind Deo
Keyword(s):  
Oil Production ◽  
Gas Flaring ◽  
Reducing Gas

scholarly journals Potential to increase condensate oil production by huff-n-puff gas injection in a shale condensate reservoir

2016 ◽  
Vol 28 ◽  
pp. 46-51 ◽  
Author(s):  
James J. Sheng ◽  
Fersheed Mody ◽  
Paul J. Griffith ◽  
Warren N. Barnes
Keyword(s):  
Gas Injection ◽  
Oil Production ◽  
Condensate Reservoir

Stability of Gas Injection Using Lateral Wells in Layered Oil Reservoirs

2007 ◽  
Vol 18-19 ◽  
pp. 271-276
Author(s):  
E. Steve Adewole ◽  
B.M. Rai
Keyword(s):  
Pressure Distribution ◽  
Gas Injection ◽  
Oil Production ◽  
Bottom Layer ◽  
Oil Reservoirs ◽  
Mobility Ratio ◽  
Fluid Velocities ◽  
The Stability ◽  
Gas Cycling ◽  
Gas Properties

The stability of gas injection in a layered reservoir drilled with lateral wells, is studied using a generalized pressure distribution-dependent mobility ratio expression. Stable injection guarantees clean oil production. The mobility ratio compared layers’ fluid velocities across a common permeable interface. Studies were based on injected gas compressibilities and viscosities only. Results show that injection stability is affected by (1) injected gas properties, and (2) injection layer; i.e., whether gas cycling (bottom layer injection) or gas injection (top layer injection). Gas cycling tends to exhibit more instability than gas injection operation.

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