perISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleعلی حسنی hassania@ripi.ir1سید علی مرتضوی 17.12.1@yahoo.com2Secondray and Tertiary recovery can lead to severe and Permanent reductions in permebility due to the interactions between injected fluids and the reservoir rock that is especially true in high clay content , low permebility , poorly consolidatel reservoir. After the fluid with a high PH value enters the reservoir , the texture of clay minerals and siliceous cement in the reservoir is destroyed due to the dissolution of clay minerals and cement and the release of fine particles produced, thus causing reservior plugging. Formation damage could be both temporarily due to the precipitation of reaction products caused by interaction between high PH fluids and reservior rock which will result in pore plugging .In this study , a series of core flooding experiments have been carried out to determine the critical PH of Alkaline fluids for plug samples of Fahlyian carbonate formation. Alkaline fluids with different PH (7, 8.5, 10 and 12) were injected into plug samples and the alkaline sensitivity of the carbonate formation has been measured in both qualitative and quantitative forms by a new applicable method .using this approach will result in the accurate estimation of the degree of formation damage .result indicate that used plugs show different behavior when exposed to fluids with different alkalinity and the degree of resulted formation damage varies form zero to serious and in certain cases are noticeable and Ireversible.therefore ,PH of injecting fluids must be kept less than its threshold value to prevent formation damage. http://journal.ispg.ir/Article/33752sensitivity measurement critical PH core flooding Formation damage carbonate formation perISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleهانیه نیکو گفتار hanienikoo@yahoo.com1University of TehranReconnaissance and interpretation of underground heterogeneity, particularly litho-facies,always plays an important role in evaluation and management of hy dro carbon resources.between various methods presented for modeling discrete characteristics of hydrocarbon reservoies such as litho-facies ,One with a more proper con formity with actual condition of reservoie facies is of great ad vantage . formed on basis of pro bability and presenting transition matrix, markov method is widely applied as a powerful tools for modeling the facies .In the present study , first the method is introduced in details; then, in order to optimize it, suggestion is made based on changing the type of the move of chain in simulation procedure. the case study is a 12 km long 110 m thick section of Anhydrite and three major members of asmari Formation from an oil field, South-West Iran.This section is modeed through Markov procedure and proposed solution .The models set indicated that on basis of using the deta from two wells and five seis mic horizons, best result ,with 90% accuracy , is for reciprocatng motion. http://journal.ispg.ir/Article/33753Markov chain Litho-facies Trasition mtrix hydrocarbon reservoirs Conditional simulationperISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleهانیه نیکو گفتار hanienikoo@yahoo.com1بهزاد تخم چی94.12.1-b@yahoo.com2عباس بحرودی12.17.bahrod@yahoo.com3غلامحسین نوروزی12.17.gh.n@yahoo.com4University of TehranUniversity of TehranUniversity of TehranUniversity of TehranReconnaissance and interpretation of underground heterogeneity, particularly litho-facies,always plays an important role in evaluation and management of hy dro carbon resources.between various methods presented for modeling discrete characteristics of hydrocarbon reservoies such as litho-facies ,One with a more proper con formity with actual condition of reservoie facies is of great ad vantage . formed on basis of pro bability and presenting transition matrix, markov method is widely applied as a powerful tools for modeling the facies .In the present study , first the method is introduced in details; then, in order to optimize it, suggestion is made based on changing the type of the move of chain in simulation procedure. the case study is a 12 km long 110 m thick section of Anhydrite and three major members of asmari Formation from an oil field, South-West Iran.This section is modeed through Markov procedure and proposed solution .The models set indicated that on basis of using the deta from two wells and five seis mic horizons, best result ,with 90% accuracy , is for reciprocatng motion. http://journal.ispg.ir/Article/33754Markov chain Litho-facies Trasition mtrix hydrocarbon reservoirs Conditional simulationperISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleReconnaissance and interpretation of underground heterogeneity, particularly litho-facies,always plays an important role in evaluation and management of hy dro carbon resources.between various methods presented for modeling discrete characteristics of hydrocarbon reservoies such as litho-facies ,One with a more proper con formity with actual condition of reservoie facies is of great ad vantage . formed on basis of pro bability and presenting transition matrix, markov method is widely applied as a powerful tools for modeling the facies .In the present study , first the method is introduced in details; then, in order to optimize it, suggestion is made based on changing the type of the move of chain in simulation procedure. the case study is a 12 km long 110 m thick section of Anhydrite and three major members of asmari Formation from an oil field, South-West Iran.This section is modeed through Markov procedure and proposed solution .The models set indicated that on basis of using the deta from two wells and five seis mic horizons, best result ,with 90% accuracy , is for reciprocatng motion. http://journal.ispg.ir/Article/33755Markov chain Litho-facies Trasition mtrix hydrocarbon reservoirs Conditional simulationperISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleعلی حسنی hassania@ripi.ir1سید علیرضا مرتضوی94.12.24.1@yahoo.com2 Secondary and Tertiary recovery processes can lead to severe and permanent reductions in permeability due to the interactions between injected fluied and the reservoir rock that is especially true in high clay content , low permeability, poorly consolidated reservoirs.After the fluid with a high PH value enters the reservoir,the texture of clay minerals and siliceous cement in the reservoir is destroyed due to the dissolution of clay minerals and cement and the release of fine particles produced ,thus causing reservoir plugging. Formation damage could be bith temporarily due to the precipitation of reaction products caused by interaction between high PH fluids and reservoir rock which will result in pore plugging .In this study ,aseries of core flooding experiments have been carried out to determine the critical PH of Alkaline fluids for plug samples of Fahlyian carbonate formation. Alkaline fluids with different PH (7,8.5, 10 and 12) were injected into plug samples and the alkaline sensivity of the carbonate formation has been measured in both qualitative and quantitative forms by a new applicable method .Using this approach will result in the accurate estimation of the degree of formation damage .result indicate that used plugs show different behavior when exposed to fluids with different alkalinity and the degree of resulted formation damage varies from Zero to serious and in certain cases are noticeable and irreversible. Therefore, PH of injecting fluids must be kept less than its threshold value to prevent formation damage. http://journal.ispg.ir/Article/33756Sensitivity measurement critical ph Core flooding formation damage carbonate formation perISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110article Secondary and Tertiary recovery processes can lead to severe and permanent reductions in permeability due to the interactions between injected fluied and the reservoir rock that is especially true in high clay content , low permeability, poorly consolidated reservoirs.After the fluid with a high PH value enters the reservoir,the texture of clay minerals and siliceous cement in the reservoir is destroyed due to the dissolution of clay minerals and cement and the release of fine particles produced ,thus causing reservoir plugging. Formation damage could be bith temporarily due to the precipitation of reaction products caused by interaction between high PH fluids and reservoir rock which will result in pore plugging .In this study ,aseries of core flooding experiments have been carried out to determine the critical PH of Alkaline fluids for plug samples of Fahlyian carbonate formation. Alkaline fluids with different PH (7,8.5, 10 and 12) were injected into plug samples and the alkaline sensivity of the carbonate formation has been measured in both qualitative and quantitative forms by a new applicable method .Using this approach will result in the accurate estimation of the degree of formation damage .result indicate that used plugs show different behavior when exposed to fluids with different alkalinity and the degree of resulted formation damage varies from Zero to serious and in certain cases are noticeable and irreversible. Therefore, PH of injecting fluids must be kept less than its threshold value to prevent formation damage. http://journal.ispg.ir/Article/33757Sensitivity measurement critical ph Core flooding formation damage carbonate formation perISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleعلی حسنی hassania@ripi.ir1سید علی مرتضوی94.12.25@yahoo.com2 Secondary and Tertiary recovery processes can lead to severe and permanent reductions in permeability due to the interactions between injected fluied and the reservoir rock that is especially true in high clay content , low permeability, poorly consolidated reservoirs.After the fluid with a high PH value enters the reservoir,the texture of clay minerals and siliceous cement in the reservoir is destroyed due to the dissolution of clay minerals and cement and the release of fine particles produced ,thus causing reservoir plugging. Formation damage could be bith temporarily due to the precipitation of reaction products caused by interaction between high PH fluids and reservoir rock which will result in pore plugging .In this study ,aseries of core flooding experiments have been carried out to determine the critical PH of Alkaline fluids for plug samples of Fahlyian carbonate formation. Alkaline fluids with different PH (7,8.5, 10 and 12) were injected into plug samples and the alkaline sensivity of the carbonate formation has been measured in both qualitative and quantitative forms by a new applicable method .Using this approach will result in the accurate estimation of the degree of formation damage .result indicate that used plugs show different behavior when exposed to fluids with different alkalinity and the degree of resulted formation damage varies from Zero to serious and in certain cases are noticeable and irreversible. Therefore, PH of injecting fluids must be kept less than its threshold value to prevent formation damage. http://journal.ispg.ir/Article/33758sensitivity measurement Critical PH Core flooding Formation damage Carbonate formation perISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleهانیه نیکو گفتار hanienikoo@yahoo.com1عباس بحرودی94.12.25.2@yahoo.com2بهزاد تخم چی94.12.25.3@yahoo.com3غلامحسین نوروزی94.12.25.4@yahoo.com4University of TehranUniversity of TehranUniversity of TehranUniversity of TehranReconnaissance and interpretation of undeerground heterogeneity ,particularly litho-facies,always plays an important role in evaluation and management of hydrocarbon resources.Between various methods presented for modeling discrete characteristics of hydrocarbon reservoirs such as litho-facies, one with a more proper conformity with actual condition of reservoir facies is of great advantage .Formed on basis of probability and presenting transition matrix.markov method is widely applied as a powerful tool for modeling the facies .In the present study ,first the method is introduced in details;then in order to optimize it. suggestion is made based on changing the type of the move of chain in simulation procedure. The case study is a12 km long 110 m thick section of Anhydrite and three major members of Asmari Formation from an oilfield ,south-West Iran .This section is modeled through Markov procedure and proposed solution.The models set indicated that on basis of using the data from two wells and five seismic horizons.best result ,with 90% accuracy, is for reciprocating motion.http://journal.ispg.ir/Article/33759Markov chain Litho-facies Transition matrix Hydrocarbon reservoirsperISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleساره صدیق 7.1.95-1@yahoo.com1مهرنوش علی پور شهسواری7.1.95-2@yahoo.com2حسین معماریان7.1.95-3@yahoo.com3بهزاد تخم چی7.1.95-4@yahoo.com4University of TehranUniversity of TehranUniversity of TehranAbstruct Reservoir lithology determination is one of the main studies used for well correlation and analyzing productive zones of the reservoir. The best way foer lithology determination is using core and cutting information . Nevertheless,in most wells these data is not complete and continual, so in these cases usually use well logging for lithology estimation of petrophysical well data with Clustering- Estimation approach . This method has been generalized according to one well from one of the oil fields in South of Iran that contains core data . Then this method is generalized in un cored wells. Clustering is used as a way for grouping well data in homogenous lithology clusters After ward, percentage of mineral is estimated in each of these clusters. The regression coefficients are calculated 92.93% and 74.99% between real and estimated data respectively for calcite and dolomite in one of the wells. The results with high accuracy show the generalization of this method. http://journal.ispg.ir/Article/33760Asmari reservoir Clustering Lithology MLP estimator K-means clustering Gustafson-Kessel clustering IranperISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleزهرا شمشیری 7.1.95-5@yahoo.com1فریدون سحابی7.1.95-6@yahoo.com2غلامحسین نوروزی7.1.95-7@yahoo.com3حسین معماریان7.1.95-3@yahoo.com4University of TehranUniversity of TehranUniversity of TehranUniversity of TehranAbstruct Survey and study of porosity and the form and the size of that in oil and gas reservoirs are important due to its key role in reservoir quality and productivity. In this paper, unlike conventional methods of using cores to recognize the geometry and morphology of porosity, FMS image log and thin section of cutting from drilling are used .after determining the over all dimension of the porosity shown as black patches and spots by FMS log, the shape and the size of the porosity was studied in the form of petrological study,based on thin sections from Mzdouran reservoir formation(lower Jurassic) in one of the gas fields in the East of Kopedagh basin. Tracing and comparing of the results of the two methods show a good correlation for determining the type and geometry of porosity .Data fusion of FMS log data with petrological studies of thin sections of cutting from drilling has advantages the most important of which is the possibility of replacement of core with FMS log and thin sections in order to determining the geometry of porosity. http://journal.ispg.ir/Article/33761Geometry of porosity Porosity morophology FMS log Thin section study Mozdouran Formation kopedagh BasinperISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleMohammad حمزه14.1.95-1@yahoo.com1علی درویش بلورانی 14.1.95@yahoo.com2سید کاظم علوی پناه14.1.95.@yahoo.com3فروغ بیک14.1.95-3@yahoo.com4حسین نصیری14.1.95.-4@yahoo.com5University of TehranUniversity of TehranUniversity of Tehran The hydrocarbon seepages theory puts forward a cause and effect relation ship between the oil and gas reservoir s and the specific surface anomalies which are basically related to hydrocarbon leakages as well as their related alterations. Hence,the spectral reflectance of the hydrocarbons and their linked mineral alterntions produce credible pieces of evidence for oil and gas ex ploration .Hyperion images of EO-1 satellite was used in this study for identifying the oil seepages and their relevant alterations. After collecting the required data,the images under went the needed preprocessing. In order to recognize the oil seepages, these corrected data along with field-sampled spectrometric ones were employed. Then, VISA and SCM combined model was applied to indirectly identify the hydrocarbon seepages . Moreover, two hydrocarbon indexes were developed for direct recognition of the hydrocarbon seeps using Hyperion images. The finding indicate that the two mentioned techniques are efficacious for the purpose of the study at hand http://journal.ispg.ir/Article/33762Oil seepage remote sensing Hyperspectral image EO-1/Hyperion Field spectrometry Data miningperISPGمجله زمین شناسی نفت ایران 2251-87382251-87382016-0635110articleغلامرضا بشیری15.1.95-2@yahoo.com1Abstruct There are two key method of simulating multi-phase flow experiments. One is the actual estimation of multi-phase flow properties from measured data, and the other is the representation of the analytical functions for relative permeability and capillary pressure .It is essential that these functions have sufficient degrees of freedom to model the measured data whilst remaining straightforward and easy to communicate. A new smooth and flexible three-parameter analytical correlation for relative permeability is proposed . Results from e.g. unsteady state relative permeability experiments often exhibit behavior which is difficult to model using e.g. Corey correlation. The new correlation influences different parts of the relative permeability curve and thereby captures variable behavior across the entire saturation range .The validity of new correlation is demonstrated by utilizing unsteady-state experiments performed at ambient conditions on core samples from the Southern Iranian reservoir rocks . results show that there is a logical relation between the basic rock properties and tuning parameters against basic parameters, i.e. permeability and porosity , should be found . Knowing the logical correlation and the basic parameters from routine analysis or logs, the tuning parameters and therefore relative permeability curves will be easily calculated. http://journal.ispg.ir/Article/33763Water/oil relative permeability LET model Modeling Extended LET model Rock classification