A powerful new tool for unconformity identification in a range of geological environments is presented together with very strong evidence of its utility. Commonly in an exploration setting correct sequence interpretation has taken years and multiple detailed studies, now with the new tool it can be done quite easily in near real time. Recognition of unconformities in boreholes, particularly where correlation with outcrop is not available, traditionally relies on paleontological methods, normally palynology or micropalaeontology and correlations between wells where sections of the observed sequence are missing. Observations in recently drilled wells in Dubai have provided evidence for another useful tool. While drilling Well A, bulk rock phosphate concentrations were obtained in near real time while drilling using X-ray fluorescence (XRF). These were then plotted against well depth. Phosphate values were taken as indicators of long duration and high intensity of organic production or conversely a low rate of sedimentation. Unconformities were marked by significant and obvious phosphate peaks while drilling in a marine sequence. Higher than average concentration of phosphates in marine environments during periods of non-deposition or very slow deposition have been known for some time but their use as markers for unconformities while drilling has not been widespread due to the practical difficulties with sample analysis. With advances in XRF technology routine wellsite XRF analysis services are now available. Plots of phosphate concentrations in Well B which was drilled through a sub-aerially deposited sequence also showed phosphate peaks, some of which correlated with known and recognisable unconformity surfaces. Further evaluation, particularly comparison with palynology data, showed that the phosphate peaks which did not correlate with known unconformities indicated previously unrecognised unconformities. Phosphate peaks on unconformity surfaces in sub-aerially deposited sequences have not, as far as the authors can determine, been previously recognised. Well C is an older well which penetrated a similar sub-aerially deposited sequence to Well B with no XRD analyses available. Correct interpretation of the Well C sequence was not possible until the key points were derived from the more complete Well B data. Evidence is presented showing that phosphate peaks are practical and useful indicators of unconformities in near real time, especially when interpreted with other geological information. An example is also given of an unconformity which displays no phosphate peak together with an explanation as to why there is no peak. In an exploration setting analysis of phosphate trends can significantly enhance and simplify sequence and palaeoenvironmental interpretation and understanding of regional tectonics thus providing greater insight when planning follow up wells leading to a higher success rate. As such it is a new and novel exploration to
{"title":"A New Tool for Identifying Unconformities During Exploration Drilling","authors":"J. Ryan, R. Roberts","doi":"10.2118/194973-MS","DOIUrl":"https://doi.org/10.2118/194973-MS","url":null,"abstract":"\u0000 A powerful new tool for unconformity identification in a range of geological environments is presented together with very strong evidence of its utility.\u0000 Commonly in an exploration setting correct sequence interpretation has taken years and multiple detailed studies, now with the new tool it can be done quite easily in near real time.\u0000 Recognition of unconformities in boreholes, particularly where correlation with outcrop is not available, traditionally relies on paleontological methods, normally palynology or micropalaeontology and correlations between wells where sections of the observed sequence are missing. Observations in recently drilled wells in Dubai have provided evidence for another useful tool.\u0000 While drilling Well A, bulk rock phosphate concentrations were obtained in near real time while drilling using X-ray fluorescence (XRF). These were then plotted against well depth. Phosphate values were taken as indicators of long duration and high intensity of organic production or conversely a low rate of sedimentation. Unconformities were marked by significant and obvious phosphate peaks while drilling in a marine sequence. Higher than average concentration of phosphates in marine environments during periods of non-deposition or very slow deposition have been known for some time but their use as markers for unconformities while drilling has not been widespread due to the practical difficulties with sample analysis. With advances in XRF technology routine wellsite XRF analysis services are now available.\u0000 Plots of phosphate concentrations in Well B which was drilled through a sub-aerially deposited sequence also showed phosphate peaks, some of which correlated with known and recognisable unconformity surfaces. Further evaluation, particularly comparison with palynology data, showed that the phosphate peaks which did not correlate with known unconformities indicated previously unrecognised unconformities. Phosphate peaks on unconformity surfaces in sub-aerially deposited sequences have not, as far as the authors can determine, been previously recognised.\u0000 Well C is an older well which penetrated a similar sub-aerially deposited sequence to Well B with no XRD analyses available. Correct interpretation of the Well C sequence was not possible until the key points were derived from the more complete Well B data.\u0000 Evidence is presented showing that phosphate peaks are practical and useful indicators of unconformities in near real time, especially when interpreted with other geological information. An example is also given of an unconformity which displays no phosphate peak together with an explanation as to why there is no peak.\u0000 In an exploration setting analysis of phosphate trends can significantly enhance and simplify sequence and palaeoenvironmental interpretation and understanding of regional tectonics thus providing greater insight when planning follow up wells leading to a higher success rate. As such it is a new and novel exploration to","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89758611","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
This paper is dedicated to enhancing Organizational Health and Adaptability by finding a suitable leadership model for service companies in the oil & gas industry in the Arabian Gulf. This becomes a more challenging task if you are dealing with multicultural teams. The author relied on literature review to define the variables that can be correlated with or impact the choice of leadership styles. Variables such as the culture of the team, the characteristics of the leader, Industrial or occupational constraints. All these variables were considered & studied. A field research was also conducted to stand on the views of both the field personnel & management and test their perceptions regarding the subject matter. A quantitative approach relied on a questionnaire that was used as the base for testing field team's perception. And a qualitative approach relied on one to one interviews with members in management in leading positions to stand on the applicability of leadership models and the constraints involved. Three main leadership models were tested. Transactional, where leadership style is more authoritarian and relies on close supervision, strict organizational procedures, and is performance oriented through rewards & punishment. Transformational, where leadership style is based on a certain vision, and is more into inspiring a committed team to be creative, identify the aspects that require change, and execute plans as a team to march towards that particular vision. Laissez-Faire, where leadership style is more into delegating the leaders’ authority to the team who are given complete freedom to take decisions in order to achieve objectives, while the leader tries to provide the required resources and tools for his team. The results of the research recommend the Transactional model of leadership as the most appropriate style or model of leadership as both the qualitative and quantitative approaches recommend it. This research paper is believed to add value to the body of knowledge as it focuses on a specific sector of a specific industry in a specific region and guides its leaders towards being more effective in their roles in order to achieve better results.
{"title":"Best Leadership Style to Lead Multi- Cultural Teams of Service Companies in the Oil & Gas Industry in the Arabian Gulf","authors":"A. Nassef, Hussain Al-Basha","doi":"10.2118/194749-MS","DOIUrl":"https://doi.org/10.2118/194749-MS","url":null,"abstract":"\u0000 This paper is dedicated to enhancing Organizational Health and Adaptability by finding a suitable leadership model for service companies in the oil & gas industry in the Arabian Gulf. This becomes a more challenging task if you are dealing with multicultural teams.\u0000 The author relied on literature review to define the variables that can be correlated with or impact the choice of leadership styles. Variables such as the culture of the team, the characteristics of the leader, Industrial or occupational constraints. All these variables were considered & studied. A field research was also conducted to stand on the views of both the field personnel & management and test their perceptions regarding the subject matter.\u0000 A quantitative approach relied on a questionnaire that was used as the base for testing field team's perception. And a qualitative approach relied on one to one interviews with members in management in leading positions to stand on the applicability of leadership models and the constraints involved. Three main leadership models were tested. Transactional, where leadership style is more authoritarian and relies on close supervision, strict organizational procedures, and is performance oriented through rewards & punishment. Transformational, where leadership style is based on a certain vision, and is more into inspiring a committed team to be creative, identify the aspects that require change, and execute plans as a team to march towards that particular vision. Laissez-Faire, where leadership style is more into delegating the leaders’ authority to the team who are given complete freedom to take decisions in order to achieve objectives, while the leader tries to provide the required resources and tools for his team. The results of the research recommend the Transactional model of leadership as the most appropriate style or model of leadership as both the qualitative and quantitative approaches recommend it.\u0000 This research paper is believed to add value to the body of knowledge as it focuses on a specific sector of a specific industry in a specific region and guides its leaders towards being more effective in their roles in order to achieve better results.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"45 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74857494","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The oil and gas industry will continue to play an essential role in meeting the growing world energy demand for decades to come. A fact sometimes overlooked is that the industry is also a major consumer of energy and a contributor to Greenhouse Gas (GHG) emissions. In recent years, there has been increasing interest in the use of renewable energy in the oil industry. Various technologies are used to produce renewable energy, from solar radiation to harnessing the power of the wind and sea. The application of different types of renewable energy in oil and gas fields is reviewed. The advantages and limitations of each technology are discussed. This paper presents the state of the art on current and potential applications of the different technologies of renewable energy in the oil and gas industry. The paper demonstrates that using renewables offer many advantages including saving hydrocarbon resources, minimizing the oil industry's GHG emission and enhancing its public image.
{"title":"Application of Renewable Energy in the Oil and Gas Industry","authors":"H. Saadawi","doi":"10.2118/194972-MS","DOIUrl":"https://doi.org/10.2118/194972-MS","url":null,"abstract":"\u0000 The oil and gas industry will continue to play an essential role in meeting the growing world energy demand for decades to come. A fact sometimes overlooked is that the industry is also a major consumer of energy and a contributor to Greenhouse Gas (GHG) emissions.\u0000 In recent years, there has been increasing interest in the use of renewable energy in the oil industry. Various technologies are used to produce renewable energy, from solar radiation to harnessing the power of the wind and sea.\u0000 The application of different types of renewable energy in oil and gas fields is reviewed. The advantages and limitations of each technology are discussed. This paper presents the state of the art on current and potential applications of the different technologies of renewable energy in the oil and gas industry.\u0000 The paper demonstrates that using renewables offer many advantages including saving hydrocarbon resources, minimizing the oil industry's GHG emission and enhancing its public image.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"20 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73479381","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
M. Shamlooh, Sayed Abdelrady, Mohamed Buasali, K. Farouque
Gas wells of the Bahrain Field in the Kingdom of Bahrain suffer from corrosion and scale issues due to the presence of water, Carbondioxide (CO2), and a high Hydrogen Sulphide (H2S) content in the formation. The current method applied to overcome these issues involves bullheading a corrosion inhibitor batch treatment. However, high costs and low effectiveness are driving a shift from batch treatments to continuous downhole treatment techniques. This paper describes the process of converting to continuous downhole treatments. The process of continuously injecting a corrosion inhibitor downhole is much more efficient and cost effective than bullheading the well with a corrosion inhibitor. This application reduces the potential of scale buildup and avoids well deliverability reduction problems. Additionally, the injection system may be used to continuously inject multi-blend chemicals downhole and can thereby treat other problems downstream and reduce the need for surface inhibition. Designing the system with the appropriate chemicals and tubing material is the key to success. The selection of materials and chemicals should take into account the CO2, H2S, temperature, and pH concentration in the candidate well. The chemical injection string can be installed into a live well using a capillary unit, without the need to shut-in or choke-back production. This can be carried out as a rigless installation similar to a coiled-tubing operation, but on a much smaller scale. The capillary unit is small and compact, and is mounted onto a truck or a trailer. The unit can be mobilized and de-mobilized for operation rapidly and easily, saving time and cost. Routine maintenance to the injection system is crucial for a long-term successful application. The qualification of the chemicals should be stringent and must allow for friction loss through such small inner diameters (IDs), however it must also withstand the pressures, temperatures, fluids, and extreme downhole conditions that it will face. Using the continuous downhole injection system will positively impact well integrity, improve completion lifetime, assure production continuity, reduce downtime and treatment operating costs, and avoid coiled-tubing descaling operational costs. Installing a downhole treatment system can also be used for other purposes if needed, such as H2S management, deliquification, scale inhibition, controlling paraffin/asphaltene, and treating downhole pumps.
{"title":"Well Integrity Protection Using Corrosion Inhibitor Treatment System for Sour Gas Producers in Bahrain Field","authors":"M. Shamlooh, Sayed Abdelrady, Mohamed Buasali, K. Farouque","doi":"10.2118/194893-MS","DOIUrl":"https://doi.org/10.2118/194893-MS","url":null,"abstract":"\u0000 \u0000 \u0000 Gas wells of the Bahrain Field in the Kingdom of Bahrain suffer from corrosion and scale issues due to the presence of water, Carbondioxide (CO2), and a high Hydrogen Sulphide (H2S) content in the formation. The current method applied to overcome these issues involves bullheading a corrosion inhibitor batch treatment. However, high costs and low effectiveness are driving a shift from batch treatments to continuous downhole treatment techniques. This paper describes the process of converting to continuous downhole treatments.\u0000 \u0000 \u0000 \u0000 The process of continuously injecting a corrosion inhibitor downhole is much more efficient and cost effective than bullheading the well with a corrosion inhibitor. This application reduces the potential of scale buildup and avoids well deliverability reduction problems. Additionally, the injection system may be used to continuously inject multi-blend chemicals downhole and can thereby treat other problems downstream and reduce the need for surface inhibition.\u0000 Designing the system with the appropriate chemicals and tubing material is the key to success. The selection of materials and chemicals should take into account the CO2, H2S, temperature, and pH concentration in the candidate well.\u0000 \u0000 \u0000 \u0000 The chemical injection string can be installed into a live well using a capillary unit, without the need to shut-in or choke-back production. This can be carried out as a rigless installation similar to a coiled-tubing operation, but on a much smaller scale. The capillary unit is small and compact, and is mounted onto a truck or a trailer. The unit can be mobilized and de-mobilized for operation rapidly and easily, saving time and cost.\u0000 Routine maintenance to the injection system is crucial for a long-term successful application. The qualification of the chemicals should be stringent and must allow for friction loss through such small inner diameters (IDs), however it must also withstand the pressures, temperatures, fluids, and extreme downhole conditions that it will face.\u0000 Using the continuous downhole injection system will positively impact well integrity, improve completion lifetime, assure production continuity, reduce downtime and treatment operating costs, and avoid coiled-tubing descaling operational costs.\u0000 \u0000 \u0000 \u0000 Installing a downhole treatment system can also be used for other purposes if needed, such as H2S management, deliquification, scale inhibition, controlling paraffin/asphaltene, and treating downhole pumps.\u0000","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"25 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86796560","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
S. M. Kholy, O. Sameh, N. Mounir, M. Shams, I. Mohamed, A. Abou-Sayed, O. Abou-Sayed
Oilfields produce huge amount of waste on daily basis such as drilling mud, tank bottoms, completion fluids, well treatment chemicals, dirty water and produced saltwater. These waste types represent a real challenge to the surrounding environment especially when the oilfield is located within a sensitive environment as in the Western Desert where there are natural reserves and fresh water aquifers. Waste slurry injection has proven to be an economic, environmentally friendly technique to achieve zero waste discharge on the surface over the past years. This technique involves creating a hydraulic fracture in a deep, subsurface, non-hydrocarbon bearing formation which acts as a storage domain to the injected slurrified waste. The objective of this study is to evaluate the feasibility of waste slurry injection in an oil prospect located in the Western Desert. The evaluation includes assessing the subsurface geology, recognizing the possible candidate injection formation(s), and designing the optimum injection parameters. Both geological and petrophysical data have been used to create the geomechanical earth model for an oil prospect located at Farafra oasis in the Western Desert. This model defines the mechanical properties, pore pressure, and in-situ stresses of the different subsurface formations. Afterwards, a fully 3D fracture simulator has been used to simulate the fracture growth within the candidate injection zone at different injection scenarios. Additionally, the fracture simulator has assessed the containment of the created fracture within the candidate injection formation(s) due to the presence of stress barriers above and below the formation. Finally, the formation disposal capacity has been calculated for each of the injection scenarios using a stress increment model. The geomechanical earth model shows that there is a good candidate injection zone which is upper/lower bounded by stress barriers. More importantly, it is located deeper than the local fresh water aquifer and thus no contamination is expected to the fresh ground water. In addition, the possible candidate is not a hydrocarbon bearing formation. A 3D fracture simulator has been used to determine the optimum injection parameters such as: the injection flow rate, the volumetric solids concentration, the slurry rheology and the injection batch duration. These optimum parameters are defined to minimize the stress increment rate over the well life, which ensure the highest disposal capacity and to contain the fracture within the candidate injection formation. Guidelines to conduct waste slurry injection technique in a new oil prospect that is located within a sensitive environment as in the Western desert are presented in this study. Also, the study highlights that this technique is economic for disposal of the different oilfield waste types in an environmentally friendly fashion.
{"title":"Evaluating the Feasibility of Waste Slurry Injection in an Oil Prospect in the Western Desert, Egypt","authors":"S. M. Kholy, O. Sameh, N. Mounir, M. Shams, I. Mohamed, A. Abou-Sayed, O. Abou-Sayed","doi":"10.2118/194837-MS","DOIUrl":"https://doi.org/10.2118/194837-MS","url":null,"abstract":"\u0000 Oilfields produce huge amount of waste on daily basis such as drilling mud, tank bottoms, completion fluids, well treatment chemicals, dirty water and produced saltwater. These waste types represent a real challenge to the surrounding environment especially when the oilfield is located within a sensitive environment as in the Western Desert where there are natural reserves and fresh water aquifers. Waste slurry injection has proven to be an economic, environmentally friendly technique to achieve zero waste discharge on the surface over the past years. This technique involves creating a hydraulic fracture in a deep, subsurface, non-hydrocarbon bearing formation which acts as a storage domain to the injected slurrified waste. The objective of this study is to evaluate the feasibility of waste slurry injection in an oil prospect located in the Western Desert. The evaluation includes assessing the subsurface geology, recognizing the possible candidate injection formation(s), and designing the optimum injection parameters.\u0000 Both geological and petrophysical data have been used to create the geomechanical earth model for an oil prospect located at Farafra oasis in the Western Desert. This model defines the mechanical properties, pore pressure, and in-situ stresses of the different subsurface formations. Afterwards, a fully 3D fracture simulator has been used to simulate the fracture growth within the candidate injection zone at different injection scenarios. Additionally, the fracture simulator has assessed the containment of the created fracture within the candidate injection formation(s) due to the presence of stress barriers above and below the formation. Finally, the formation disposal capacity has been calculated for each of the injection scenarios using a stress increment model.\u0000 The geomechanical earth model shows that there is a good candidate injection zone which is upper/lower bounded by stress barriers. More importantly, it is located deeper than the local fresh water aquifer and thus no contamination is expected to the fresh ground water. In addition, the possible candidate is not a hydrocarbon bearing formation.\u0000 A 3D fracture simulator has been used to determine the optimum injection parameters such as: the injection flow rate, the volumetric solids concentration, the slurry rheology and the injection batch duration. These optimum parameters are defined to minimize the stress increment rate over the well life, which ensure the highest disposal capacity and to contain the fracture within the candidate injection formation.\u0000 Guidelines to conduct waste slurry injection technique in a new oil prospect that is located within a sensitive environment as in the Western desert are presented in this study. Also, the study highlights that this technique is economic for disposal of the different oilfield waste types in an environmentally friendly fashion.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"201202 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77694914","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Recent technological progress within the petroleum industry has enabled much deeper discoveries than conventionally accepted depths. One example of such exploration success is drilling and stimulating an appraisal well in a Devonian age carbonate reservoir in northwestern Kazakhstan. This paper describes a successful case study of hydraulic fracturing stimulation as a solution to enhance hydrocarbon recovery. A specific workflow developed for stimulation of high pressure and temperature low permeability reservoir is suggested. This workflow includes an adapted study of petrophysical properties, fracture geometry modeling, and completion design selection. Fracture stimulations and pre- and post-completion results are also analyzed and compared. One of the main tasks of the technical staff was designing a production enhancement method which would maintain positive return on investment (ROI) for the project. A reservoir study was conducted during the planning stage of this pilot project. The design workflow included geomechanical analysis to estimate reservoir rock properties. Fracture stimulation modeling was performed to forecast treating pressures and adjust treatment stage sizes to help achieve optimum fracture geometries. Perforation intervals were selected and recommended to provide the best placement of fracturing fluid and proppant into the zone of interest. Previously, the operator had attempted an acid wash, which was unsuccessful because of coiled tubing (CT) capability limitations, making it impossible to inject acid in desired rates into the rock due to low permeabilities and high stresses. Then, based on the final designed stimulation treatment plan, the operator conducted a massive proppant and acid fracturing stimulation operation, where high pressure pumping was performed at the treating pressures above formation breakdown limits. Created hydraulic fractures provided conductive pathways for reservoir fluid inflow. This method has shown an improved recovery of reservoir fluid. This hydraulic fracturing technique provided economically effective field exploration in the previously undeveloped part of the licensed block. Field execution has shown challenges with respect to performing operations in deviated wells. Observations conducted in three stages during the pilot project are described and conclusions presented. This paper also describes operational difficulties with equipment combined with materials logistics.
{"title":"Hydraulic Fracturing in a Devonian Age Carbonate Reservoir: A Case Study","authors":"Almas Istayev, T. Jatykov, Talgat Kosset","doi":"10.2118/194942-MS","DOIUrl":"https://doi.org/10.2118/194942-MS","url":null,"abstract":"\u0000 Recent technological progress within the petroleum industry has enabled much deeper discoveries than conventionally accepted depths. One example of such exploration success is drilling and stimulating an appraisal well in a Devonian age carbonate reservoir in northwestern Kazakhstan.\u0000 This paper describes a successful case study of hydraulic fracturing stimulation as a solution to enhance hydrocarbon recovery. A specific workflow developed for stimulation of high pressure and temperature low permeability reservoir is suggested. This workflow includes an adapted study of petrophysical properties, fracture geometry modeling, and completion design selection. Fracture stimulations and pre- and post-completion results are also analyzed and compared.\u0000 One of the main tasks of the technical staff was designing a production enhancement method which would maintain positive return on investment (ROI) for the project. A reservoir study was conducted during the planning stage of this pilot project. The design workflow included geomechanical analysis to estimate reservoir rock properties. Fracture stimulation modeling was performed to forecast treating pressures and adjust treatment stage sizes to help achieve optimum fracture geometries. Perforation intervals were selected and recommended to provide the best placement of fracturing fluid and proppant into the zone of interest.\u0000 Previously, the operator had attempted an acid wash, which was unsuccessful because of coiled tubing (CT) capability limitations, making it impossible to inject acid in desired rates into the rock due to low permeabilities and high stresses. Then, based on the final designed stimulation treatment plan, the operator conducted a massive proppant and acid fracturing stimulation operation, where high pressure pumping was performed at the treating pressures above formation breakdown limits. Created hydraulic fractures provided conductive pathways for reservoir fluid inflow. This method has shown an improved recovery of reservoir fluid. This hydraulic fracturing technique provided economically effective field exploration in the previously undeveloped part of the licensed block.\u0000 Field execution has shown challenges with respect to performing operations in deviated wells. Observations conducted in three stages during the pilot project are described and conclusions presented. This paper also describes operational difficulties with equipment combined with materials logistics.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"67 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74114892","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The gas deviation factor (Z-factor) is an effective thermodynamic property required to address the deviation of the real gas behavior from that of an ideal gas. Empirical models and correlations to compute Z-factor based on the equation of states (EOS) are often implicit, because they needed huge number of iterations and thus computationally very expensive. Many explicit empirical correlations are also reported in the literature to improve the simplicity; yet, no individual explicit correlation has been formulated for the complete full range of pseudoreduced temperatures and pseudo-reduced pressures, which demonstrates a significant research gap. The inaccuracy in determining gas deviation factor will lead to huge error in computing subsequent natural gas properties such as gas formation volume factor (Bg), gas compressibility (cg), and original gas in place (OGIP). Previously reported empirical correlations provide better estimation of gas deviation factor at lower pressures but at higher reservoir pressures their accuracies becomes questionable. In this study, a simple and improved Z-factor empirical model is presented in a linear fashion using a robust artificial intelligence (AI) tool, the Artificial Neural Network (ANN). The new model is trained on more than 3000 data points from laboratory experiments obtained from several published sources. The proposed model is only a function of pseudo reduced temperature and pseudo reduced pressure of the gases which makes it simpler than the existing implicit and complicated correlations. The accuracy and generalization capabilities of the proposed ANN based model is also tested against previously published correlations at low and high gas reservoir pressures on an unseen published dataset. The comparative results on a published dataset show that the new model outperformed other methods of predicting Z-factor by giving less average absolute percentage error (AAPE), less root mean square error (RMSE) and high coefficient of determination (R2). The error obtained was less than 3% compared to the measured data.
{"title":"An Intelligent Data-Driven Framework to Develop New Correlation to Predict Gas Deviation Factor for High-Temperature and High-Pressure Gas Reservoirs Using Artificial Neural Network","authors":"Zeeshan Tariq, M. Mahmoud, A. Asad","doi":"10.2118/194715-MS","DOIUrl":"https://doi.org/10.2118/194715-MS","url":null,"abstract":"\u0000 The gas deviation factor (Z-factor) is an effective thermodynamic property required to address the deviation of the real gas behavior from that of an ideal gas. Empirical models and correlations to compute Z-factor based on the equation of states (EOS) are often implicit, because they needed huge number of iterations and thus computationally very expensive. Many explicit empirical correlations are also reported in the literature to improve the simplicity; yet, no individual explicit correlation has been formulated for the complete full range of pseudoreduced temperatures and pseudo-reduced pressures, which demonstrates a significant research gap. The inaccuracy in determining gas deviation factor will lead to huge error in computing subsequent natural gas properties such as gas formation volume factor (Bg), gas compressibility (cg), and original gas in place (OGIP). Previously reported empirical correlations provide better estimation of gas deviation factor at lower pressures but at higher reservoir pressures their accuracies becomes questionable.\u0000 In this study, a simple and improved Z-factor empirical model is presented in a linear fashion using a robust artificial intelligence (AI) tool, the Artificial Neural Network (ANN). The new model is trained on more than 3000 data points from laboratory experiments obtained from several published sources. The proposed model is only a function of pseudo reduced temperature and pseudo reduced pressure of the gases which makes it simpler than the existing implicit and complicated correlations. The accuracy and generalization capabilities of the proposed ANN based model is also tested against previously published correlations at low and high gas reservoir pressures on an unseen published dataset.\u0000 The comparative results on a published dataset show that the new model outperformed other methods of predicting Z-factor by giving less average absolute percentage error (AAPE), less root mean square error (RMSE) and high coefficient of determination (R2). The error obtained was less than 3% compared to the measured data.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79292142","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Adel Al Shayaa, K. Tamimi, Sara Bakhti, A. Arnaout, G. Thonhauser
The digital era is upon us in the oil and gas industry, enforcing the importance of integrating this novel concept of digital transformation is mandatory to improve the overall efficiency of the drilling process. The advances in Artificial Intelligence for the industry, and the methodology of how these solutions can be implemented will be addressed in this paper. The digital transformation of drilling will provide an unprecedented stream of high-quality information that has never been accomplished in the industry, through the utilization of automated real-time drilling downhole tools, data analytics and predictive analysis. Therefore, a real-time measurement and processing technology based on automated rig activities detection was established to improve the performance of the rig crew and drilling operations of an international operating company. A monitoring process was implemented for all drilling operations and benchmarked against operational Key Performance Indicators (KPIs).
{"title":"Drilling Process Digitalization Using Advanced Machine Learning Techniques – Case Study","authors":"Adel Al Shayaa, K. Tamimi, Sara Bakhti, A. Arnaout, G. Thonhauser","doi":"10.2118/194962-MS","DOIUrl":"https://doi.org/10.2118/194962-MS","url":null,"abstract":"\u0000 The digital era is upon us in the oil and gas industry, enforcing the importance of integrating this novel concept of digital transformation is mandatory to improve the overall efficiency of the drilling process. The advances in Artificial Intelligence for the industry, and the methodology of how these solutions can be implemented will be addressed in this paper.\u0000 The digital transformation of drilling will provide an unprecedented stream of high-quality information that has never been accomplished in the industry, through the utilization of automated real-time drilling downhole tools, data analytics and predictive analysis.\u0000 Therefore, a real-time measurement and processing technology based on automated rig activities detection was established to improve the performance of the rig crew and drilling operations of an international operating company. A monitoring process was implemented for all drilling operations and benchmarked against operational Key Performance Indicators (KPIs).","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"109 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76185305","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Monitoring of multi-stage hydraulic fractures in unconventional reservoirs has shown that some fractures are more effective and productive than others. Stress shadowing, in addition to reservoir lateral heterogeneity, are two potential factors behind this phenomenon. The focus of this study is to find the optimum hydraulic fracture spacing that aims to reduce the stress shadowing effect and ensure placement of hydraulic fractures in the best quality reservoir rock along the horizontal lateral. A base hydraulic fracture model was created for a well in the Eagle Ford reservoir. Fiber optic distributed acoustic sensing (DAS) data were analyzed to find the individual perforation cluster contribution to production based on the total proppant placed in each cluster. The modeled well cluster contribution and production data were then matched with actual data. Reservoir and geomechanical properties for certain stages of the horizontal wellbore were altered from the base model to address the effect of rock quality lateral variations. Four scenarios of 57 ft, 76 ft, 100 ft, and 142 ft spacing between perforation clusters were investigated to address the effect of stress shadowing. The sensitized reservoir and geomechanical properties include matrix permeability, Poisson's ratio, and Biot's coefficient. Increasing the matrix permeability from a base value of 0.2 ?D to 2 ?D caused the flowing fracture lengths to increase by 69%, 68%, and 48% in the heel, middle, and toe clusters, respectively. Stages with higher Poisson's ratio of 0.33, compared to a base value of 0.28, created larger flowing fracture lengths by 32% and 41% in the heel and middle clusters. Altering Biot's coefficient resulted in the same effect on flowing fracture lengths as altering Poisson's ratio. Overall, the rate of increase in flowing fracture lengths as a response to changing these properties was found to be more pronounced in the heel and middle clusters but less evident in the toe clusters. As for the cluster spacing scenarios, simulations showed that tighter spacing scenarios yielded a larger fracture network volume due to the higher number of clusters. However, these created fractures were less conductive than the ones created with wider spacing scenarios due to the stress shadowing effects. Production runs showed that scenarios with more accessed reservoir volume via more perforation clusters yielded a larger cumulative production over a 30-year simulation period.
{"title":"Optimization of Hydraulic Fracture Spacing Through the Investigation of Stress Shadowing and Reservoir Lateral Heterogeneity","authors":"Ahmed A. Alrashed, J. Miskimins, A. Tura","doi":"10.2118/195071-MS","DOIUrl":"https://doi.org/10.2118/195071-MS","url":null,"abstract":"\u0000 Monitoring of multi-stage hydraulic fractures in unconventional reservoirs has shown that some fractures are more effective and productive than others. Stress shadowing, in addition to reservoir lateral heterogeneity, are two potential factors behind this phenomenon. The focus of this study is to find the optimum hydraulic fracture spacing that aims to reduce the stress shadowing effect and ensure placement of hydraulic fractures in the best quality reservoir rock along the horizontal lateral.\u0000 A base hydraulic fracture model was created for a well in the Eagle Ford reservoir. Fiber optic distributed acoustic sensing (DAS) data were analyzed to find the individual perforation cluster contribution to production based on the total proppant placed in each cluster. The modeled well cluster contribution and production data were then matched with actual data. Reservoir and geomechanical properties for certain stages of the horizontal wellbore were altered from the base model to address the effect of rock quality lateral variations. Four scenarios of 57 ft, 76 ft, 100 ft, and 142 ft spacing between perforation clusters were investigated to address the effect of stress shadowing.\u0000 The sensitized reservoir and geomechanical properties include matrix permeability, Poisson's ratio, and Biot's coefficient. Increasing the matrix permeability from a base value of 0.2 ?D to 2 ?D caused the flowing fracture lengths to increase by 69%, 68%, and 48% in the heel, middle, and toe clusters, respectively. Stages with higher Poisson's ratio of 0.33, compared to a base value of 0.28, created larger flowing fracture lengths by 32% and 41% in the heel and middle clusters. Altering Biot's coefficient resulted in the same effect on flowing fracture lengths as altering Poisson's ratio. Overall, the rate of increase in flowing fracture lengths as a response to changing these properties was found to be more pronounced in the heel and middle clusters but less evident in the toe clusters. As for the cluster spacing scenarios, simulations showed that tighter spacing scenarios yielded a larger fracture network volume due to the higher number of clusters. However, these created fractures were less conductive than the ones created with wider spacing scenarios due to the stress shadowing effects. Production runs showed that scenarios with more accessed reservoir volume via more perforation clusters yielded a larger cumulative production over a 30-year simulation period.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80211227","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Drilling, as a direct and effective method of opening oil and gas layers, has been widely used. A reasonable combination of drilling tools plays a key role in increasing the rate of mechanical drilling, reducing drilling costs, and reducing downhole accidents. Conventional drilling relies on years of experience of on-site workers and reference to the operation of drilling wells, making use of drilling tools and lacking scientific basis. However, the reservoir situation is erratic, the unknown factors are very numerous, unpredictable, and the difficulty of drilling is increased. Drilling into unknown reservoirs, especially high-temperature and high-temperature risk wells, poses a huge threat to the lives of workers on site. Conventional drilling of known reservoirs will also encounter unknown problems such as drilling distance growth, stuck drilling, drilling tools falling, increased inclination, and deviation from the intended target position, which seriously reduces drilling efficiency, increases operating time, risk and drilling difficulty affected by the reasonable use of the drilling tool combination. With the development and application of computational intelligence, through the accumulation of massive geological property data, reservoir structure data, drilling tool parameters, construction data, drilling fluid parameters and other drilling data, intelligent drilling is used to predict unknown drilling information which can reduce the risk of drilling and improve drilling efficiency. In this paper, the work mode of "data running first, operation post" is used to further strengthen the application of drilling tools combination to improve the rate of mechanical drilling and reduce downhole problems.
{"title":"Application in Drilling Tool Combination Aided Design Based on Data Intelligence","authors":"Qi Zhu","doi":"10.2118/195093-MS","DOIUrl":"https://doi.org/10.2118/195093-MS","url":null,"abstract":"\u0000 Drilling, as a direct and effective method of opening oil and gas layers, has been widely used. A reasonable combination of drilling tools plays a key role in increasing the rate of mechanical drilling, reducing drilling costs, and reducing downhole accidents. Conventional drilling relies on years of experience of on-site workers and reference to the operation of drilling wells, making use of drilling tools and lacking scientific basis.\u0000 However, the reservoir situation is erratic, the unknown factors are very numerous, unpredictable, and the difficulty of drilling is increased. Drilling into unknown reservoirs, especially high-temperature and high-temperature risk wells, poses a huge threat to the lives of workers on site. Conventional drilling of known reservoirs will also encounter unknown problems such as drilling distance growth, stuck drilling, drilling tools falling, increased inclination, and deviation from the intended target position, which seriously reduces drilling efficiency, increases operating time, risk and drilling difficulty affected by the reasonable use of the drilling tool combination.\u0000 With the development and application of computational intelligence, through the accumulation of massive geological property data, reservoir structure data, drilling tool parameters, construction data, drilling fluid parameters and other drilling data, intelligent drilling is used to predict unknown drilling information which can reduce the risk of drilling and improve drilling efficiency.\u0000 In this paper, the work mode of \"data running first, operation post\" is used to further strengthen the application of drilling tools combination to improve the rate of mechanical drilling and reduce downhole problems.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"083 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91154077","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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