bluuebunny/crossref_metadata_2025_split huggingface dataset:
Wellbore Segmentation using Inflow Control Devices: Design and Optimisation Process
Authors: Al Marzooqi Ayesha , Helmy Hamdy , Keshka Ashraf , Elasmar Magdi , Shafia Shaiful 
Published: February 2011

Abstract
Inflow Control Devices (ICD) optimize production, delay water influx, eliminate / minimize annular flow, and ensure a uniform inflow along the horizontal wellbore at the cost of a small pressure drop. ICDs have brought promises to the industry’s efforts in horizontal wells inflow profile optimization which contributes to the economic success of horizontal wells.
Although the structure of different types of ICD varies from one design to another, the principle is the same - restrict flow, and therefore balance or equalize wellbore pressure drop to achieve an evenly distributed flow profile. In general ICD’s are not adjustable once installed in the well. The location of the device and the relationship between rate and pressure drop are fixed. This makes the design of a well completion and inflow control devices critical for production. Having knowledge of the pressure profile of a horizontal well, the ICD completion can be designed to achieve the required uniform influx. Therefore, the need for pressure profile prediction along horizontal wells’ inflow area is obvious. Reservoir conditions are dynamic during the wells’ life cycle; hence the impact of ICD varies over time.
Results to date within one of the onshore fields located in Abu Dhabi showed remarkable improvement in well performance, where gains in oil production with controlled water production have been achieved. Long-term reservoir simulation results also showed considerable recovery increase with ICD’s compared to the open-hole case.
The paper provides an integrated analysis method of dynamic inflow and outflow to generate the flow profile of a horizontal well. The additional frictional pressure drop created by inflow control devices is considered. Two conditions that result in production challenges, wellbore pressure drop and breakthrough of undesirable fluids are addressed. The focus will be on when and how water encroachment will hit the horizontal well bore and how inflow control devices will act to optimize production. A simulated example at field conditions will be used to illustrate that it is critical to understand the reservoir conditions and wellbore dynamics together when designing a completion with inflow control devices. Uncertainties in reservoir conditions are considered, and a business case for a passive shut-off ICD is discussed through cumulative oil gain predicted by simulation of different development options and completion design strategy.
This paper presents the evaluation and results of ICD technology, and how it is expected to become a game changer in this field development.
Optimum Separation Pressure for Heavy Oils Sequential Separation
Authors: AL-Jawad Mohammed S. , Hassan Omar F. 
Published: February 2011

Abstract
The estimation of quantity of liquid that is collected from gas/oil separation system is a very complex task because it requires the application of the flash calculations which needs to solve the cubic equation of state and to use some numerical techniques. These difficulties can be overcome by a computer model which requires a lot of experimental data, long time, and experience.
This paper adopts a new technique to simplify this problem. It suggests new correlations for optimum separator pressure for separation station of heavy oils. The correlations have been achieved for two- and three- stage separation systems.
The correlations have been created depending on many Iraqi oil samples. The optimum separator pressure of each individual separator was found at the maximum amount of liquid recovered with the minimum oil formation volume factor.
The Optimum Separator Soave – Redlich – Kwong model (OSSRK) has been adopted to estimate the optimum separator pressure, while the objective functions, like oil formation volume factor, are predicted by Separator Flash Soave – Redlich – Kwong model (SFSRK) (Hassan 2004).
The optimum separator pressures have been correlated with mole percent of hexane plus in the well stream fluid, mole percent of methane in the well stream fluid, temperature of the separator and the optimum pressure of the previous separator. Nonlinear multiple regression analysis has been applied to get the best correlation for each system.
Many statistical tests are used to check the validity of the proposed correlations.
The error percents of API, GOR, Bo between the optimal cases for each model and the relevant correlations show a maximum of 0.047%, 0.3% and 0.15% for two – stage systems, and 0.2%, 0.6% and 0.22% for three – stage systems. Also the cross plot method is applied to test the correlation validity. These checks are good indication to use these correlations with high degree of confidence.
Improving Well Completion via Real-Time Microseismic Monitoring: A West Texas Case Study
Authors: Ejofodomi E.A. , Yates M.E. , Downie R. , Itibrout T. , Catoi O.A. 
Published: February 2011

Abstract
This paper presents a case history of hydraulic fracture stimulation treatments performed on a vertical well completion in the Spraberry-Wolfcamp formations located in Midland County, Texas, in which real-time microseismic Hydraulic Fracture Monitoring (HFM) was utilized to “track” the development of the hydraulic fracture as it propagates through the formation thereby allowing for the implementation of corrective actions to improve the completion efficiency of the well.
The case history is presented in three main themes or sections: background, job execution, and post-job evaluation. The background section will provide an overview of the completion design as well as the HFM setup. The job execution section will then address how the real-time HFM observations and interpretations made during the treatment executions were used to identify undesired height growth, which prompted swift and concise actions to optimize the well completion by modifying the perforation scheme and treatment design. Finally the paper will present the results of the integrated HFM post-treatment evaluation and will discuss the observed differences between the planned and actual fracture geometries as observed from the microseismic monitoring results. Comparison of the microseismic fracture geometry to the anticipated fracture geometry showed that even in areas where we think that there might not be anything new to be learned, opportunities exist to apply new technology that can identify some of the complications and challenges involved, improve the success of stimulation treatments, and identify opportunities to improve operational efficiency.
Overall, this example clearly shows how real-time microseismic monitoring provides the data required to improve fracture modeling, identify fracture behavior that is not predictable by conventional means alone, and reveals several opportunities to improve completion efficiency.
Challenges for Coiled Tubing in Horizontal Well Intervention
Authors: Rohilla Pulkita , Shukla Himanshu 
Published: February 2011

Abstract
Most coiled tubing (CT) interventions are performed in a Rigless environment. Infact, this is one of the important drivers for the widespread acceptance and continued growth of the technique for well servicing. Now a days in most of the reservoirs with high water-cut wells are drilled horizontally. But its maintenance and work over jobs are challenging and needs the most advanced and precise technology. As a result CT units are employed to do the interventions in horizontal wells. But it faces the following problems during its operation Fill material can rapidly accumulate on the low side of the wellbore during production and during conventional removal operations. In some cases, the fluid velocity can carry fill along horizontal sections, but cannot lift it through the build angle into the vertical wellbore. Gravity causes the particles to accumulate and slide down the low side of the wellbore, especially at inclinations of 300 to 600. Once the fill has settled, it is difficult to re-establish particle transport. Turbulent flow significantly improves hole cleaning in a horizontal wellbore. However, in many cases, turbulent flow is not possible, due to the flow and pressure restrictions imposed by the CT work string, or the relative size of the completion tubular.
This paper describes the solutions to the above mentioned problems along with the description of the new tool used. which leads to the better functioning of the unit and stability of borehole.
Rigorous Water Chemistry Modelling in Reservoir Simulations for Waterflood and EOR Studies
Authors: Wei Lingli 
Published: February 2011

Abstract
Many waterflood projects now experience significant amount of water cut, with more water than hydrocarbon flowing between the injectors and producers. In addition to the impact on water viscosity and density from using different injection water sources during a field’s life, water chemistry itself may impact oil recovery as demonstrated by recent research on low salinity water injection schemes. It is also known that water chemistry has profound impact on various chemical EOR processes. Moreover, the effectiveness and viability of such EOR schemes is strongly dependent on reservoir brine and injection water compositions. In particular, the presence of divalent cations such as Ca+2 and Mg+2 has a significant adverse effect for chemical EORs. Utilising new developments in reservoir simulation, this paper outlines a method to account rigorously for water chemistry with only a small incremental computational cost compared to the same simulation model without geochemical reactions. The new modelling capability considers chemical reactions triggered by injection water and/or injected reactive gases such as CO2 and H2S, including mineral dissolution and precipitation, cation exchange and surface complexation.
For waterflood performance assessment, this paper demonstrates that rigorous modelling of water chemistry can significantly impact simulation results. In addition, interpretation of saturation logs requires inputs about brine composition. Thus, the new modelling capability makes possible a more optimum evaluation of petrophysical logs for well intervals where injection water invasion is suspected. By modelling transport of individual species in the aqueous phase from injector to producers, reservoir characterization can also be improved through the use of these natural tracers, provided the compositions of the actual produced water are used in the history matching. The simulated water compositions in producers can also be used by production chemists to assess scaling and corrosion risks. For CO2 EOR studies, we illustrate chemical changes inside a reservoir and in the produced water before and after CO2 breakthrough, and discuss geochemical monitoring as a potential surveillance tool. Alkaline flood induced water chemical changes and calcite precipitation is presented to illustrate applicability for chemical EOR with the new simulation capability.
Permanent Downhole Production Monitoring & Well-testing of Commingled Production Reservoirs
Authors: Kremenetskiy M. I. , Ipatov A. I. , Gorodnov A. V. , Chernoglazov V. N. 
Published: February 2011

Abstract
Commingling differentiated control providing is actual problem for multi-layer oil fields in the Russian Federation. There are multiple economic benefits of commingling reserves that can provide very large increases in incremental project NPV for all types of oil and gas field developments. The benefits of commingling production from separate reservoirs are: ability to produce hydrocarbon from multiple reservoirs which may not be economic to produce on their ownfewer wells, less infrastructure - lower capital expenselower operating expensesless environmental impact, fewer locationsa sustained production plateau
The regulations for the commingling of down-hole production are typically set by government agencies responsible for oil and gas developments. There are very few areas of the world that permit commingled flow from different reservoir intervals without approved means of control, testing of segregation, and flow estimation and allocation. Russian government regulators limit commingling by continuous monitoring stringent requirement for each reservoir. This opportunity allows a license holder to both manage and control of oil field development and water oil displacement processes.
Separate monitoring and development management task has been technically solved nowadays at pilot level by a number of national oil companies. For instance, GazProm Neft specialists tested the technical side of the problem and its possible solutions at the Yuzhno-Priobskoe oil field in 2009. The work has been continuing in 2010. [1].
Modeling of Acid Treatment in Oil Reservoirs
Authors: Volnov . A. , Kanevskaya . D. 
Published: February 2011

Abstract
The mathematical model of two-phase displacement of oil by an acid aqueous solution in the neighborhood of a well and a hydraulic fracture is created. It takes into account the kinetics of acid dissolution of a carbonate rock. The proposed model allows us to investigate the penetration of the active admixture and the changing of the reservoir characteristics during the solution injection and after well shut-in for reaction.
The effect of well acidizing and acid fracturing are estimated. It is shown that neglecting the two-phase nature of the flow leads to the underestimation of the treatment effect. At given process parameters the needed length of the shut-in period for reaction and dimensions of the acid penetration zone are estimated.
The control of such parameters as the injection rate and the chemical reaction rate makes possible to reach the maximum treatment effect at the given solution volume. Calculations showed that in the case of the acid fracturing the significant slowing of the reaction rate may lead to large leakage of unreacted acid into the reservoir, extending the penetration zone, but also reducing the effects near the fracture and thus worsening the result of treatment.
The created model was applied to numerical calculations for real cases. Field and calculated data are in good agreement.
Dynamic SAGD Well Flow Control Simulation
Authors: Stone T. W. , Guyaguler B. , Bailey W. J. , Damas C. E. , Naccache P. F. , Morton A. 
Published: February 2011

Abstract
An investigation is presented on the use of Flow Control Valves (ICVs, FCVs) to control steam placement in the early stages of a Steam Assisted Gravity Drainage (SAGD) process. The two parts of this process that are examined in this paper are the steam circulation preheating period and the early stages up to one year of injection/production in which the steam chamber is beginning to form. Steam injection and production in this and other thermal processes can be difficult to control because steam has a high mobility ratio and tends to establish flow paths that may be difficult to break once established. This is especially pronounced in heterogeneous reservoirs. Two SAGD case studies have been designed that accurately model the initial preheating period in which both wells circulate steam through an inner tubing and outer annulus in order to conductively and, to a lesser extent convectively, heat the region around the well pair in order to establish communication. After this initial circulation period, the wells switch to injection and production. Both cases have the same base configuration but differ in the degree of reservoir heterogeneity. In the injection well, ICV devices are placed to control steam/water flow through the outer screens. In the producer, FCV valves are used to flatten the production profile along the well. Two methods are examined to change valve apertures. One uses proportional-integral-derivative (PID) controllers while the second applies an optimization algorithm directly on each individual connection productivity index. A preliminary investigation is presented here into using feedback controllers and optimization with instantaneous reservoir parameters to improve a SAGD process in the presence of reservoir heterogeneity.
Adaptive Technology for Waterflood Management
Authors: Kostrigin I.V. , Khatmullin I.F. , Khatmullina E.I. 
Published: February 2011

Abstract
Reliable estimation of the deposit energy/volume dynamics is the key to ad-hoc decision-making in managing waterflooding operations.
The paper describes the key elements of a single-layer waterflooding proxy-model. The pressure and saturation field calculations are performed by means of a two-phase streamline simulator developed by the authors.
The proxy model simulation includes an iterative adaptive matching procedure for the saturation/productivity data field, the actual bottom-hole/reservoir pressure data, and the actual injection/production rates. The fitness of inferred areal distribution of the reservoir parameters and the current recovery is by matching the calculated dynamic reservoir pressures and rate values with the available production history and well test data.
Systematic Approach Ensuring Asset Integrity, Equipment Reliability and Process Safety
Authors: Derevyakin . M. 
Published: February 2011

Abstract
Today for oil industry can be characterized as “the time of problems”, and not in terms of the global financial crisis and slump in oil prices but in terms of equipment age. The issue of outdated equipment stock is acute for Russia and the whole world as well. What should be done with it and how should it be used safely? How should technogenic disasters and accidents be avoided? What is the way to do it effectively so as to be sure that facilities are safe and thus do not endanger lives of people and do not entail severe financial losses?
Oil companies, carrying out equipment maintenance, believe that all problems are solved; however, actual state of play proves it not true.
To settle the said issues a common approach has been developed, which is aimed at ensuring of safety of industrial facilities and, simultaneously, at optimization of preparation, planning and performance of work for equipment maintenance. This approach is based on clear understanding of risks related to each particular equipment type, establishment of equipment performance/integrity criteria and implementation of the systems for monitoring of compliance with these criteria, which also influences equipment integrity.
Implementation of the new process of preparation, planning and performance of work enables to ensure equipment reliability and integrity due to the possibility of timely performance of more critical maintenance work as well as enables to improve efficiency and reduce expenditures on this kind of work.
The author of this work shares his experience and explains the need for integration of HSE systems and processes, maintenance and personnel development processes, in order to assure equipment integrity and safety of operations.
A Case Study of Smart Well Deployment for Arctic Offshore Subsea Field Development
Authors: Khrulenko A. A. , Zolotukhin A. B. 
Published: February 2011

Abstract
This work deals with the efficiency of smart (or intelligent) wells, i.e. wells equipped with inflow control valves (ICV) and bottomhole pressure and temperature sensors in a moderate in size oil field, located on the Arctic shelf and developed using subsea technologies.
The assessment was performed by comparing results of calculations of various stochastically generated geostatistical models of a hypothetical field using two development options - with and without smart completion. The latter can be considered as an alternative to traditional water shutoff works. The ECLIPSE simulator supplemented with the software add-in has been used for calculations. This add-in enabled us to perform reactive control of two-position (on/off) ICV during the model computations.
The field model is based on the following principles:
Elastic water drive, high stored elastic energy in the water-bearing area, enabling to develop the field without the reservoir pressure support system; Underexplored reservoir properties, expressed in several equally probable stochastic realizations of the porosity and permeability distributions; Uncertainty of fluids' properties and of the reservoir′s type (wettability mode), realized using various options of relative phase permeabilities (RPP).
For each realization of the reservoir model (combination of phase permeabilities and petrophysical parameters) two options of the field development were calculated:
Uncontrolled commingled production from two reservoirs using conventional wells; Commingled development of oil reservoirs with production control using two-position inflow control valves;
In the flow models, the following limitations specific for subsea production were realized:
▪ Wells shall flow with wellhead pressures higher than specified minimum allowed pressures; this makes possible the multiphase flow through the subsea pipelines to the nearest offshore platform. When the wellhead pressure drops below the specified limit, the well shall be decommissioned. ▪ For the option B, the inflow from individual perforation intervals shall be adjusted in order to extend the period of well flowing and thus, to increase oil production.
Comparison of calculated production profiles for options A and B for the each model realization showed a significant economic benefits due to ICV usage. Generally, results of the work demonstrate that smart wells help to improve the economic and technological parameters of the project and to reduce risks of its realization due to uncertainties.
Influence of the Multi-Layered Reservoir on the Production Dynamics of the Gas Condensate Well During Multi Rate Testing
Authors: Shandrygin A. , Rudenko D. , Kuzmichev D. 
Published: February 2011

Abstract
The paper considers the problem of gas condensate production from a multilayered reservoir. Sufficient influence of the individual layer properties was demonstrated by the analysis of a 2-layer formation where synthetic properties were varied over a wide range. Analysis of a field case supplements the results. The study demonstrates a sensitivity of the inflow performance relationship (IPR) curve to the formation layer parameters, and authors propose a model for IPR curve analysis for estimation of the parameters and evaluate it using synthetic IPR curves.
Multi-Phase Flow Meters for Well Testing – Field Experiences in an Offshore Field, Abu Dhabi
Authors: Santhanam Kalakad S. , Al-Marri Faisal M. , Attas Ali , Al-Zarooni Nabil , Khan Ayyaz , Ehmaid Bassam , Kumar Kotha Ravi , Basak Gautam , Ladmia Abdelhak 
Published: February 2011

Abstract
This paper presents the field trial testing of three brands of Multi-Phase Flow Meters (MPFM) in a matured offshore field, being operated by ADMA-OPCO in Abu Dhabi. The purpose of the MPFM installation was to enhance the well testing in order to efficiently manage the reservoirs and production. ‘Trial Tests’ were conducted successfully with simultaneous measurements through Test Separator (TS) mounted on boat Test Vessel (TV) for verification and performance evaluation. All 3 MPFMs were permanently installed on 3 different Towers to acquire independent operational experiences and assess vendor’s technical and maintenance supports. The paper includes experiences & performances of MPFMs, which led to the field implementations that are currently in progress.