Arvandan Oil and Gas Company

Tehrān, Iran

Arvandan Oil and Gas Company

Tehrān, Iran
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Aalaie J.,Research Institute of Petroleum Industry RIPI | Hemmati M.,Research Institute of Petroleum Industry RIPI | Sajjadian V.A.,Arvandan Oil and Gas Company
Journal of Macromolecular Science, Part B: Physics | Year: 2012

Sulfonated polyacrylamide (SPAA) solutions were prepared and the effects of pressure, polymer concentration, and water temperature, pH and salinity on their rheological behavior were investigated using a concentric cylinder dynamic rheometer equipped with a high pressure cell. According to the rheological flow curves the shear stress of SPAA solutions increased less than in proportion to their shear rates; that is, a shear thinning effect occurred. For polymer solutions containing 15,000ppm of SPAA, shear viscosity, and stress were nearly insensitive to pressure. However, the shear viscosity and stress of SPAA solutions were affected by temperature and this effect was more evident at lower pressure. The flow curves indicated the shear viscosity and stress of the samples increased with increasing SPAA concentration and pH of the water, but were decreased with increasing water salinity and temperature. © 2012 Copyright Taylor and Francis Group, LLC.

Zeinalzadeh A.,Ferdowsi University of Mashhad | Moussavi-Harami R.,Ferdowsi University of Mashhad | Mahboubi A.,Ferdowsi University of Mashhad | Sajjadian V.A.,Arvandan Oil and Gas Company
Journal of Natural Gas Science and Engineering | Year: 2015

In south west Iran, in the Abadan Plain, there are several giant gas and oil reserves in Jurassic and Cretaceous carbonates, such as Darquain, where there are excellent source rocks in the Early Cretaceous and Jurassic successions. In present study, petroleum generation and migration from these source rocks were evaluated. Maturity state of organic matter was determined with Organic petrography and results were used for calibration of thermal model. Basin modeling was used for investigation of petroleum generation and migration history. Burial history and 3D thermal model were constructed for the study area using Temis suite and Genex software. Modeling shows source rocks of Jurassic, such as Sargelu and Neyriz are in gas maturity state, oil generation phase passed before Cenozoic. It appears that gas from Jurassic source rocks accumulated in Najmeh and did not reach to Cretaceous Fahliyan reservoir. Cretaceous reservoir in Fahliyan Formation has been charged by the Garau Formation. This source rock reached to oil window in Early Cretaceous time and began hydrocarbon expulsion at the end of Cretaceous when the Darquain structure formed. Migration paths of hydrocarbons shifted from NE to SW direction about 11Ma in response to changes in regional structural dip contemporary with the Zagros Orogeny. Modeling results indicate that the quantity of gas and oil generated in the kitchen area was more than the reservoirs' capacity. Therefore, the surplus hydrocarbon could have migrated laterally out of reservoir area. © 2015 Elsevier B.V.

Shadizadeh S.R.,Petroleum University of Technology of Iran | Zoveidavianpoor M.,Arvandan Oil and Gas Co.
Oil and Gas Journal | Year: 2010

A study compared the cement casing standards of intermediate and production casing strings with analogous cement casing operations in Iran. Cementing is not the only factor that protects casing. Other ways for protecting the casing include placing completion fluids around casing that has not been cemented cathodic protection, and using a well- head insulator. The cement for the production casing is far enough above the producing formations to provide additional support for subsurface equipment and to prevent casing buckling. Relevant engineering and geologic factors for the immediate vicinity, including the presence or absence of hydrocarbons, potential drilling hazards, and permafrost determine the cement design. Cementing of the producing string typically is with a pump and plug method or another method approved by regulators. Radial expansion at the cement- casing interface occurs due to increased pressure in the casing.

Rahbar M.,Shiraz University | Roosta A.,Arvandan Oil and Gas Company | Ayatollahi S.,Shiraz University | Ghatee M.H.,Shiraz University
Energy and Fuels | Year: 2012

The preferential attraction of fluid on the rock surfaces, known as wettability, has serious implication because of their impact on multi phase flow in the rock hence the recovery efficiency of petroleum reservoirs. However, the prediction of wetting and the mechanisms of wettability changes during the production are difficult because of the complex chemical composition of the crude oil and the formation brine as well as the interaction with the minerals very close to the rock surface. To understand these mechanisms one needs to investigate the interactions that take place between crude oil, brine and rock surfaces. The objective of this work is to present the results of developed model based on the rock/fluids interactions for the prediction of the wettability state in a solid/brine/crude oil system. In this model, a three-dimensional (3D) adhesion map and surface wettability are related to the film stability through disjoining pressure isotherm of the wetting phase film separating the solid and nonwetting phase. Besides, the mechanism of wetting changes and predominant surface forces is diagnosed through disjoining pressure. This model is especially designed to predict the wettability and its alteration for the tight rocks, which is seldom to be done through the laboratory measurements. © 2012 American Chemical Society.

Aalaie J.,Research Institute of Petroleum Industry RIPI | Alvand E.,Research Institute of Petroleum Industry RIPI | Hemmati M.,Research Institute of Petroleum Industry RIPI | Sajjadian V.A.,Arvandan Oil and Gas Company
Polymer Science - Series A | Year: 2015

One of the main problems of polymer solutions in enhanced oil recovery applications is their properties losses after long term aging in electrolyte media. This paper reports preparation and rheological properties and thermal stability of novel weak hydrogels based on sulfonated polyacrylamide crosslinked in electrolyte solutions. Experimental results show that by increasing of crosslinker concentration, storage modulus dependency on frequency becomes weaker. At lower gelation temperature, gels with higher crosslinker concentrations exhibit lower storage modulus. Sharp decrease of viscosity value in viscosity-shear stress curves, approved existence of yield behavior for sulfonated polyacrylamide/chromium triacetate systems. There is a linear dependency of storage modulus, viscosity and yield stress value on polymer and crosslinker concentrations. Sulfonated polyacrylamide weakly crosslinked samples show higher viscosity than sulfonated polyacrylamide solution after thermal aging. Results of this research suggest the potentials of weakly crosslinked systems based on sulfonated polyacrylamide for oil recovery applications. © 2015, Pleiades Publishing, Ltd.

Karami M.,Arvandan Oil and Gas Company | Manshad A.K.,Petroleum University of Technology of Iran | Ashoori S.,Petroleum University Engineering
Petroleum Science and Technology | Year: 2014

One of the problems of producing wells is water movement to production oil zone and so decreasing in wellhead pressure. Water produced from oil and gas reservoirs is a problem encountered all over the world since last two decades. The water quantities produced along with oil and gas are large due to the depletion stage of the reservoirs. The costs in treating and disposing of this water are very high and usually a negative impact on the economics of the petroleum reservoir production then it is necessary to set a long time to plan for make facility for protection or separation water produce with oil so very important to know about water breakthrough time. Therefore, in order to prevent to appear this problem it is necessary to try to have production with a suitable flow rate. However, because of economical considerations production in critical rate (the maximum rate of oil production without concurrent production of the displacing phase by coning; the critical rate, the built-up cone is stable but is at a position of incipient breakthrough), it is not economical. It is necessary to know when conning reach to the well if producing is above the critical rate to following causes: (a) production in optimum rate to delay water breakthrough time as far as possible, and (b) predicting water breakthrough time to help engineers to plan appropriate schedule for wellhead facilities preparing and well completion methods in order to maximum in place oil production. After review of two available methods for predicting water breakthrough time, the authors present a water-coning correlation to predict critical rate and water breakthrough time with less error than others. Copyright © 2013 Taylor and Francis Group, LLC.

Namdarian F.,Arvandan Oil and Gas Company | Taghanaki M.A.,Arvandan Oil and Gas Company | Hashemi A.,Arvandan Oil and Gas Company
Society of Petroleum Engineers - SPE Reservoir Characterisation and Simulation Conference and Exhibition, RCSC 2015 | Year: 2015

Gas injection in an unsaturated carbonate reservoir which is located in south-west of Iran started in 2009, and based on the original dynamic model the gas breakthrough would not have happened earlier than 2017. However, the gas oil ratio (GOR) in some wells increased rapidly before the anticipated time; also the real field data shows different behaviors of gas breakthrough in different wells. The 3D Geocellular grid obtained from 3D seismic cubes was applied to dynamic model, and by making the size of the cells smaller, the heterogeneity was identified as the most important factor in modeling and monitoring the gas movement from the injected wells towards the production wells. Based on the new upscaling, two dynamic models were constructed. The original model had 267,000 grid cells and the new ones have 1,120,000 and 2,400,000 grid cells respectively. Running the new models illustrated the gas breakout from some wells mostly through one layer of the reservoir. Since effective porosity was estimated by collocated cokrigging of well data with seismic porosity, vuggy porosity distribution in this layer is correctly predicted, given that a karstic volume has been detected in some part of the reservoir which its boundary has been defined by seismic data and the cross-plots of neutron porosity with acoustic impedence validate the reliability of this karstic zone. The results show various types of vuggy porosity that mostly governs the productivity of the wells in this reservoir. As a result of this study, both dynamic and static models modified based on pseudo-porosity derived from seismic cubes as the best known distributed heterogeneity in this field to predict the gas movement in the reservoir. Based on this modeling, new maximum efficient rates were defined for wells and field development strategy was reconsidered. Copyright 2015, Society of Petroleum Engineers.

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