Mohammad Alfayiz, Monaf S. Alaithan, Abdulaziz Al-Harbi, F. Khan
Tight carbonate gas reservoirs require stimulation in order to establish commercial viability. In order for the development plan to be considered effective and successful, two main parameters have to be studied and evaluated, time, and cost. The conventional method to stimulate tight carbonate reservoirs is bull heading acid fracturing treatment, which is costly and time consuming for multi stages wells, not excluding the high treatment pressure requirement and risk associated with it. Conventional plug and perf technique includes e-line operations to perforate with guns, acid fracturing treatment by bullheading, and e-line operations to set plugs for every single stage. A novel acid-soluble abrasive material, was implanted and tested as an economical and time effective alternative solution. The technique involves perforating through cemented liners utilizing the abrasive material flowed by low volume acid surgesqueeze. By using this technique time and cost associated with the conventional plug and perf technique, can be reduced and achieve even better result with less cost and time. The wells that were stimulated with this technique, were tested and proven superior in terms of production rate over the conventional plug and perf technique in the short term. More evaluation to be done on the wells over the long term and evaluate if they are going to sustain the production over time. This paper provides a brief summary about the technique. Also, will discuss in details, the cost and time effectiveness, the short term result, and compare it with the conventional plug and perf technique.
{"title":"Cost and Time Effective Stimulation Technique in Horizontal Cemented Liner Application in Carbonate Reservoir With HPCT Hydrajetting Tools","authors":"Mohammad Alfayiz, Monaf S. Alaithan, Abdulaziz Al-Harbi, F. Khan","doi":"10.2118/195119-MS","DOIUrl":"https://doi.org/10.2118/195119-MS","url":null,"abstract":"\u0000 Tight carbonate gas reservoirs require stimulation in order to establish commercial viability. In order for the development plan to be considered effective and successful, two main parameters have to be studied and evaluated, time, and cost. The conventional method to stimulate tight carbonate reservoirs is bull heading acid fracturing treatment, which is costly and time consuming for multi stages wells, not excluding the high treatment pressure requirement and risk associated with it. Conventional plug and perf technique includes e-line operations to perforate with guns, acid fracturing treatment by bullheading, and e-line operations to set plugs for every single stage.\u0000 A novel acid-soluble abrasive material, was implanted and tested as an economical and time effective alternative solution. The technique involves perforating through cemented liners utilizing the abrasive material flowed by low volume acid surgesqueeze. By using this technique time and cost associated with the conventional plug and perf technique, can be reduced and achieve even better result with less cost and time.\u0000 The wells that were stimulated with this technique, were tested and proven superior in terms of production rate over the conventional plug and perf technique in the short term. More evaluation to be done on the wells over the long term and evaluate if they are going to sustain the production over time.\u0000 This paper provides a brief summary about the technique. Also, will discuss in details, the cost and time effectiveness, the short term result, and compare it with the conventional plug and perf technique.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73055849","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}
In recent years, the Drilling and Workover (D&WO) operations are growing significantly. The growth of active operations required and produced more data from D&WO operations. With very large number of rig activities daily transmitting more than 60,000 real-time data points every second, it became necessary to understand and utilize this Big Data in order to predict drilling troubles and discover hidden knowledge. The adaption of the industrial Revolution (IR) 4.0 contributed to the use of advanced and novel approaches such as Artificial intelligence (AI) and Machine learning (ML) models. However, those models require continues improvement as drilling data change. When using the industrial standard and adapted Wellsite Information Transfer Specification Markup Language (WITSML) based Big Data environment, the task to monitor the performance of a model at a large scale becomes challenging due to common reasons such as a large number of wells, different models being deployed and different data stored in different systems. In this paper, a new approach is introduced using WITSML based Big Data environment. The methods employed utilize an advanced engine to monitor and evaluate active AI/ML models at a large scale. The engine utilizes anomaly detection methods to monitor abnormal behaviors of the models such as sudden high rate of alerts per day/well or a sudden drop in true event detection. The paper will also demonstrate how such technology can help in early detection of model's decay signs or sudden changes in real-time data quality. The solution improved and automated the process of monitoring and maintaining of AI/ML models in the Drilling domain. It also made the decay detection of models possible and showed how models improve when iterative enhancements are deployed.
{"title":"Real-Time Drilling Models Monitoring Using Artificial Intelligence","authors":"B. Alotaibi, Beshir M. Aman, M. Nefai","doi":"10.2118/194807-MS","DOIUrl":"https://doi.org/10.2118/194807-MS","url":null,"abstract":"\u0000 In recent years, the Drilling and Workover (D&WO) operations are growing significantly. The growth of active operations required and produced more data from D&WO operations. With very large number of rig activities daily transmitting more than 60,000 real-time data points every second, it became necessary to understand and utilize this Big Data in order to predict drilling troubles and discover hidden knowledge. The adaption of the industrial Revolution (IR) 4.0 contributed to the use of advanced and novel approaches such as Artificial intelligence (AI) and Machine learning (ML) models. However, those models require continues improvement as drilling data change. When using the industrial standard and adapted Wellsite Information Transfer Specification Markup Language (WITSML) based Big Data environment, the task to monitor the performance of a model at a large scale becomes challenging due to common reasons such as a large number of wells, different models being deployed and different data stored in different systems.\u0000 In this paper, a new approach is introduced using WITSML based Big Data environment. The methods employed utilize an advanced engine to monitor and evaluate active AI/ML models at a large scale. The engine utilizes anomaly detection methods to monitor abnormal behaviors of the models such as sudden high rate of alerts per day/well or a sudden drop in true event detection. The paper will also demonstrate how such technology can help in early detection of model's decay signs or sudden changes in real-time data quality.\u0000 The solution improved and automated the process of monitoring and maintaining of AI/ML models in the Drilling domain. It also made the decay detection of models possible and showed how models improve when iterative enhancements are deployed.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"6 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77370958","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 success of drilling operations strongly depends on proper mud weight design. In fact, unsuccessfully optimizing the mud weight could lead to wellbore collapse. Within the oil industry, Mogi and Mohr-Coulomb models are the most-practiced failure criterion used in predicting critical mud weight. This paper was aimed at inspecting these models regarding mud weight prediction. A new comparison concept was also developed. Furthermore, the different stochastic perspectives were carried out in the study. Based on field data, the required mud weight was found using the Mogi and Mohr-Coulomb failure criteria. The results suggested that the predicted pressure from the Mogi model is considerably close to the real mud weight. The study is also developed using the new pragmatic comparison criteria called the breakout width. The predicted mud weight from both models was separately utilized to obtain the width of shear failure (breakout) by applying the simple analytical model. The results revealed the breakout dimension was a bit over-predicted with respect to the Mohr criteria. Moreover, the optimum mud weight was a function of input parameters, which include stresses and rock properties. The knowledge of such parameters depends effectively on the quality of the parameters. The deterministic approach was presented to display the influence of each parameter by developing tornado diagrams. The analysis was defined that the maximum horizontal stress is the most influential parameter for collapse pressure prediction for both models. In addition, overburden stress has a considerable effect on the Mogi model and was ignored in the Mohr criteria. Other parameters were also captured in the analysis. In this paper, the probabilistic analysis approach using Monte Carlo simulation was also implemented into wellbore stability models to cover all the significant parameters with their uncertainties rather than certain values for improving predictions. Based on the analysis, the mud weight optimization will have a direct impact on future drilling practices and operation costs.
{"title":"Effective Geomechanic Approach for Wellbore Stability Analysis","authors":"K. Alsiyabi, Mohammed Al-Aamri, N. Siddiqui","doi":"10.2118/194922-MS","DOIUrl":"https://doi.org/10.2118/194922-MS","url":null,"abstract":"\u0000 The success of drilling operations strongly depends on proper mud weight design. In fact, unsuccessfully optimizing the mud weight could lead to wellbore collapse. Within the oil industry, Mogi and Mohr-Coulomb models are the most-practiced failure criterion used in predicting critical mud weight.\u0000 This paper was aimed at inspecting these models regarding mud weight prediction. A new comparison concept was also developed. Furthermore, the different stochastic perspectives were carried out in the study. Based on field data, the required mud weight was found using the Mogi and Mohr-Coulomb failure criteria. The results suggested that the predicted pressure from the Mogi model is considerably close to the real mud weight. The study is also developed using the new pragmatic comparison criteria called the breakout width.\u0000 The predicted mud weight from both models was separately utilized to obtain the width of shear failure (breakout) by applying the simple analytical model. The results revealed the breakout dimension was a bit over-predicted with respect to the Mohr criteria. Moreover, the optimum mud weight was a function of input parameters, which include stresses and rock properties.\u0000 The knowledge of such parameters depends effectively on the quality of the parameters. The deterministic approach was presented to display the influence of each parameter by developing tornado diagrams. The analysis was defined that the maximum horizontal stress is the most influential parameter for collapse pressure prediction for both models. In addition, overburden stress has a considerable effect on the Mogi model and was ignored in the Mohr criteria. Other parameters were also captured in the analysis. In this paper, the probabilistic analysis approach using Monte Carlo simulation was also implemented into wellbore stability models to cover all the significant parameters with their uncertainties rather than certain values for improving predictions. Based on the analysis, the mud weight optimization will have a direct impact on future drilling practices and operation costs.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"42 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81113849","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}
Innovation in the analysis of oil well surface measurements has led to the discovery of an instantaneous and straightforward emulsion detection calculation. When applied in the Bahrain Field, this led to the treatment of emulsion in over 100 wells, resulting in a cumulative production gain of over 500,000 barrels to date at negligible cost. Artificial Intelligence (AI) was then employed to identify and understand factors related to emulsion and optimisation treatment programs. Once the wells were treated and the method was confirmed to prove emulsion existence, a focused approach was carried out to understand it further. Wells were categorised based on their production response to standard demulsifier bullheading. In addition to a variety of well parameters, this data was used to build a machine learning model that helped identify patterns with regards to problematic zones, properties of wells with emulsion, and the best treatment method for each well. The results of the study were rather substantial and resulted in numerous new insights. Firstly, a model was built to predict the sustainability and economics of expected bullheading job treatments. This is currently being used to rank the priority of wells for either bullheading treatment or continuous chemical injection. Once the wells were classified into basic sub groups and sorted by zones, geographic analysis was carried out to identify wells with emulsion being formed as a result of waterflooding. This led to further insight into the nature of emulsion blocks, where in some cases, although it was found that these blocks exist downhole, traces of emulsion will flow to the surface and can have a unique signature. This paper discusses in further detail insights into emulsion and the different types of AI algorithms used to answer questions raised as a result of the discovery. The necessity of using machine learning cannot be overstated enough and the observations made in the paper could not have been found if it were purely by observed by the naked eye. The topic of emulsion is highly understudied, and the concept of using the emulsion detection calculation was not published before. In addition to highlighting this discovery, this paper can influence other operators to test their findings and have a real world application of machine learning in their fields.
{"title":"Detecting Emulsion Using Surface Temperature, Pressure, and the Application of Artificial Intelligence","authors":"R. Esbai, Ahmed Alrumaidh, S. Sharaf","doi":"10.2118/195089-MS","DOIUrl":"https://doi.org/10.2118/195089-MS","url":null,"abstract":"\u0000 Innovation in the analysis of oil well surface measurements has led to the discovery of an instantaneous and straightforward emulsion detection calculation. When applied in the Bahrain Field, this led to the treatment of emulsion in over 100 wells, resulting in a cumulative production gain of over 500,000 barrels to date at negligible cost. Artificial Intelligence (AI) was then employed to identify and understand factors related to emulsion and optimisation treatment programs. Once the wells were treated and the method was confirmed to prove emulsion existence, a focused approach was carried out to understand it further. Wells were categorised based on their production response to standard demulsifier bullheading.\u0000 In addition to a variety of well parameters, this data was used to build a machine learning model that helped identify patterns with regards to problematic zones, properties of wells with emulsion, and the best treatment method for each well. The results of the study were rather substantial and resulted in numerous new insights. Firstly, a model was built to predict the sustainability and economics of expected bullheading job treatments. This is currently being used to rank the priority of wells for either bullheading treatment or continuous chemical injection. Once the wells were classified into basic sub groups and sorted by zones, geographic analysis was carried out to identify wells with emulsion being formed as a result of waterflooding. This led to further insight into the nature of emulsion blocks, where in some cases, although it was found that these blocks exist downhole, traces of emulsion will flow to the surface and can have a unique signature.\u0000 This paper discusses in further detail insights into emulsion and the different types of AI algorithms used to answer questions raised as a result of the discovery. The necessity of using machine learning cannot be overstated enough and the observations made in the paper could not have been found if it were purely by observed by the naked eye.\u0000 The topic of emulsion is highly understudied, and the concept of using the emulsion detection calculation was not published before. In addition to highlighting this discovery, this paper can influence other operators to test their findings and have a real world application of machine learning in their fields.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78527944","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}
A. Sadykov, S. Baki, Karim Mechkak, A. Momin, J. Rueda, S. Kazakoff, Abdullah Kalbani, Mohammed Kurdi, N. Mulhim
Saudi Aramco has made substantial progress in developing its unconventional gas resources with Plug and Perf (PnP) completions and multistage slickwater fracturing, with optimal production performance. Wells in Jafurah basin are generally completed with 5,000 feet horizontal lateral and up to 33 stages with 4 to 5 clusters per stage. Increasing the number of clusters per stage in such completions could lead to cost and efficiency optimization, but also increases the risk of having non-stimulated clusters, considering geomechanical heterogeneity, and without providing sufficient pumping rate. Thus introducing diversion techniques becomes a necessity in this unconventional play to optimize cluster efficiency, improve operational efficiency, and thus reduce cost. Near wellbore chemical particulates and intra-well perforation mechanical diversion techniques from degradable materials found their wide application in different unconventional assets. A mega-diversion experiment with both techniques took place in one of the wells, where a damaged section of the lateral did not allow regular PnP operations at the toe. Laboratory tests before operation ensured degradation of the material is within operational thresholds for positive isolation. The lateral section below the casing deformation (1,200 ft in the toe section) was planned with 30 clusters in one single stage, with the intrawell diversion technique. Another eight stages in 1,200 feet were attempted with a standard five cluster stages as a baseline. The remaining 2,400 feet of the lateral were stimulated with eight stages, 10 clusters per stage, and sequential application of both intrawell mechanical and near wellbore diversion technologies. Other wells in the area, which had damage in the casing, were also completed with mechanical diverters. The 1,200 ft lateral section was successfully stimulated without additional well intervention operations with a selected diversion technique. Proppant placement challenges were encountered in the regular five cluster stages with significant improvement in the subsequent 10 cluster stages introducing diversion. Positive diversion indication was confirmed by surface pressure observations and mainly proppant placement success. Multiple instances of non-typical pressure behavior were observed during placement of the mega-diversion stages. This pressure behavior is the subject of technical analysis and results will feed into the future design strategy. The intrawell mechanical diversion technique showed positive diversion indications in different wells in Saudi Arabia, with good repeatability of slickwater propped fracturing treatment success. This technique could be utilized whenever wellbore accessibility challenges are encountered, or during refracturing application cases. Both diversion technques could be used efficiently to stimulate the clusters and optimize well intervention operations, by minimizing the number of stages per well without compromising s
沙特阿美公司在非常规天然气资源开发方面取得了重大进展，采用了Plug and Perf (PnP)完井和多级滑溜水压裂技术，并取得了最佳的生产性能。Jafurah盆地的井通常有5000英尺的水平段，最多可达33级，每级4到5个簇。在此类完井中，增加每级压裂簇的数量可以实现成本和效率的优化，但考虑到地质力学的非均匀性，并且没有提供足够的泵速，也会增加未增产压裂簇的风险。因此，为了优化簇效率，提高作业效率，从而降低成本，在非常规油气藏中引入导流技术是必要的。近井化学颗粒和井内可降解材料射孔机械导流技术在不同的非常规资产中得到了广泛的应用。在其中一口井中进行了两种技术的大型转向试验，该井的分支段受损，无法在趾部进行常规的PnP操作。操作前的实验室测试确保材料的降解在正隔离的操作阈值范围内。在套管变形段以下的水平段(趾段1200英尺处)，计划采用井内导流技术，一次压裂30个簇。在1200英尺的井段中，以标准的5级井段为基准，尝试了另外8级井段。其余2400英尺的分支段采用8级压裂，每级压裂10个压裂簇，并依次采用井内机械和近井导流技术。该地区其他套管受损的井也使用了机械转喷器。采用选定的导流技术，在没有额外干预井作业的情况下，成功增产了1200英尺的水平段。在常规的5个压裂段中，支撑剂的放置遇到了挑战，在随后的10个压裂段中，引入了导流技术，支撑剂的放置得到了显著改善。通过地面压力观测和支撑剂投放成功，证实了正向导流迹象。在巨型导流段的布置过程中，观察到多个非典型压力行为。这种压力行为是技术分析的主题，其结果将提供给未来的设计策略。在沙特阿拉伯的不同井中，井内机械导流技术显示出积极的导流迹象，具有良好的滑溜水支撑压裂成功重复性。每当遇到井筒可达性问题或重复压裂应用时，都可以使用该技术。这两种导流技术都可以有效地用于增产簇和优化油井干预作业，在不影响增产油藏体积的情况下，减少每口井的压裂段数。
{"title":"Diversion Techniques Applications in Unconventional Resources Fields","authors":"A. Sadykov, S. Baki, Karim Mechkak, A. Momin, J. Rueda, S. Kazakoff, Abdullah Kalbani, Mohammed Kurdi, N. Mulhim","doi":"10.2118/194791-MS","DOIUrl":"https://doi.org/10.2118/194791-MS","url":null,"abstract":"\u0000 Saudi Aramco has made substantial progress in developing its unconventional gas resources with Plug and Perf (PnP) completions and multistage slickwater fracturing, with optimal production performance. Wells in Jafurah basin are generally completed with 5,000 feet horizontal lateral and up to 33 stages with 4 to 5 clusters per stage. Increasing the number of clusters per stage in such completions could lead to cost and efficiency optimization, but also increases the risk of having non-stimulated clusters, considering geomechanical heterogeneity, and without providing sufficient pumping rate. Thus introducing diversion techniques becomes a necessity in this unconventional play to optimize cluster efficiency, improve operational efficiency, and thus reduce cost.\u0000 Near wellbore chemical particulates and intra-well perforation mechanical diversion techniques from degradable materials found their wide application in different unconventional assets. A mega-diversion experiment with both techniques took place in one of the wells, where a damaged section of the lateral did not allow regular PnP operations at the toe. Laboratory tests before operation ensured degradation of the material is within operational thresholds for positive isolation. The lateral section below the casing deformation (1,200 ft in the toe section) was planned with 30 clusters in one single stage, with the intrawell diversion technique. Another eight stages in 1,200 feet were attempted with a standard five cluster stages as a baseline. The remaining 2,400 feet of the lateral were stimulated with eight stages, 10 clusters per stage, and sequential application of both intrawell mechanical and near wellbore diversion technologies. Other wells in the area, which had damage in the casing, were also completed with mechanical diverters.\u0000 The 1,200 ft lateral section was successfully stimulated without additional well intervention operations with a selected diversion technique. Proppant placement challenges were encountered in the regular five cluster stages with significant improvement in the subsequent 10 cluster stages introducing diversion. Positive diversion indication was confirmed by surface pressure observations and mainly proppant placement success. Multiple instances of non-typical pressure behavior were observed during placement of the mega-diversion stages. This pressure behavior is the subject of technical analysis and results will feed into the future design strategy.\u0000 The intrawell mechanical diversion technique showed positive diversion indications in different wells in Saudi Arabia, with good repeatability of slickwater propped fracturing treatment success. This technique could be utilized whenever wellbore accessibility challenges are encountered, or during refracturing application cases. Both diversion technques could be used efficiently to stimulate the clusters and optimize well intervention operations, by minimizing the number of stages per well without compromising s","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79601410","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}
Gas condensate reservoirs are a major player in the oil and gas industry. Proper understanding of reservoir fluid composition and their spatial distribution helps define our resource base and forecast field production profile. In a gas accumulation with substantial vertical span, a composition gradient is expected, where heavier molecules gravitate towards the bottom end and lighter components' concentration increases towards the top of the column. However, in the literature some investigators have reported both condensate content and heavy hydrocarbon components decrease with increasing depth and temperature. Their observations appear to be contradicting the expected gravity driven compositional gradient as per thermodynamic equilibrium. In this paper, we have done an integrated areal and vertical composition trend analysis of some gas condensate reservoirs across a big area i.e. a three-dimensional trend analysis. Field wide areal and vertical reservoir anhydrite content has been mapped. The areal composition gradient that defies expected gravity driven composition gradient, while honoring vertical thermodynamic equilibrium has been reconciled. Post depositional fluid/rock thermochemical reaction and low areal diffusivity has resulted in this areal variation. In-situ H2S generation has been enhanced where reservoir deepens and temperature increases, thus overcoming the activation energy hump. H2S concentration increase has happened at the expense of the hydrocarbon concentration as per the thermochemical reaction stoichiometry. It was found that the vertical compositional gradient is consistent with thermodynamic equilibrium calculations. Some observed trend anomalies have been explained using rock composition and geological information. Thus, a three dimensional compositional gradient was deciphered for reservoirs with such behavior. The aim of this study has been to provide a better quality forecast for reserves, rate, recovery and composition mix for gas condensate fields.
{"title":"Three Dimensional Compositional Variation in Gas Condensate Reservoirs","authors":"A. Kabir, Mahbub S. Ahmed, Dhaher Elew","doi":"10.2118/194898-MS","DOIUrl":"https://doi.org/10.2118/194898-MS","url":null,"abstract":"\u0000 Gas condensate reservoirs are a major player in the oil and gas industry. Proper understanding of reservoir fluid composition and their spatial distribution helps define our resource base and forecast field production profile. In a gas accumulation with substantial vertical span, a composition gradient is expected, where heavier molecules gravitate towards the bottom end and lighter components' concentration increases towards the top of the column. However, in the literature some investigators have reported both condensate content and heavy hydrocarbon components decrease with increasing depth and temperature. Their observations appear to be contradicting the expected gravity driven compositional gradient as per thermodynamic equilibrium.\u0000 In this paper, we have done an integrated areal and vertical composition trend analysis of some gas condensate reservoirs across a big area i.e. a three-dimensional trend analysis. Field wide areal and vertical reservoir anhydrite content has been mapped. The areal composition gradient that defies expected gravity driven composition gradient, while honoring vertical thermodynamic equilibrium has been reconciled. Post depositional fluid/rock thermochemical reaction and low areal diffusivity has resulted in this areal variation. In-situ H2S generation has been enhanced where reservoir deepens and temperature increases, thus overcoming the activation energy hump. H2S concentration increase has happened at the expense of the hydrocarbon concentration as per the thermochemical reaction stoichiometry. It was found that the vertical compositional gradient is consistent with thermodynamic equilibrium calculations. Some observed trend anomalies have been explained using rock composition and geological information.\u0000 Thus, a three dimensional compositional gradient was deciphered for reservoirs with such behavior. The aim of this study has been to provide a better quality forecast for reserves, rate, recovery and composition mix for gas condensate fields.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"191 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83458670","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}
Proppant transport adequately during hydraulic fracturing treatment assumes same perforation contribution through multi-perforation system. Proppant transport performance into the different ordination fracture system using multi-entry perforation technique is still not fully understood. This experimental study was aimed to deeply investigate five factors that affect proppant transport performance: number of perforations, perforation opening size, shear rate, fracture orientation, and proppant size distribution. The impact of these factors on proppant transport performance from different perspective was studied. Fracture slot model was designed and built to observe easily the effects of perforation density and fracture orientation. The results of this experimental work show that limited-entry perforation technique has significant impact on proppant transport within fractures where single top perforation had better proppant placement than multi-perforation system. Fracture area was approximately propped with 66% and 48% using top perforation and multi-perforation system, respectively. Slurry with high shear rate has a negative effect on the proppant equilibrium dune level (EDL) and fracture propped area (FPA). Fracturing treatment using high shear rate causes high pressure drop in the fracture that leads to decreasing EDL by 17% and fracture propped area by 23% comparing to using low shear rate. Using large proppant size (20/40) leads to form high EDL and FPA compared to 100 mesh size. Proppant transport dominated by four mechanisms and the vertexes near wellbore plays main mechanism to carry proppant farther inside the fracture.
{"title":"Investigate Proppant Transport with Varying Perforation Density and its Impact on Proppant Dune Development Inside Hydraulic Fractures","authors":"M. B. Geri, Abdulmohsin Imqam, Mohammed Suhail","doi":"10.2118/195018-MS","DOIUrl":"https://doi.org/10.2118/195018-MS","url":null,"abstract":"\u0000 Proppant transport adequately during hydraulic fracturing treatment assumes same perforation contribution through multi-perforation system. Proppant transport performance into the different ordination fracture system using multi-entry perforation technique is still not fully understood. This experimental study was aimed to deeply investigate five factors that affect proppant transport performance: number of perforations, perforation opening size, shear rate, fracture orientation, and proppant size distribution. The impact of these factors on proppant transport performance from different perspective was studied. Fracture slot model was designed and built to observe easily the effects of perforation density and fracture orientation. The results of this experimental work show that limited-entry perforation technique has significant impact on proppant transport within fractures where single top perforation had better proppant placement than multi-perforation system. Fracture area was approximately propped with 66% and 48% using top perforation and multi-perforation system, respectively. Slurry with high shear rate has a negative effect on the proppant equilibrium dune level (EDL) and fracture propped area (FPA). Fracturing treatment using high shear rate causes high pressure drop in the fracture that leads to decreasing EDL by 17% and fracture propped area by 23% comparing to using low shear rate. Using large proppant size (20/40) leads to form high EDL and FPA compared to 100 mesh size. Proppant transport dominated by four mechanisms and the vertexes near wellbore plays main mechanism to carry proppant farther inside the fracture.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"281 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76796424","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 purpose of the paper is to present the results of using local sand resources in Saudi Arabia for the manufacture of resin coated proppant as a ceramic proppant alternative for deep conventional gas development. Crushed Miocene sandstone, old river sand and dune sand has been tested for a source to manufacture resin coated sand proppant. Compared to Northern White Sand in USA, each sand source has its own set of limitations such as angularity, low aspect ratio, clay, carbonate scale or iron oxide coating, and/or micro-fracture damage. Complete resin bonding to the particle surface required clean quartz surface free of sharp edges and no dust contamination. Conductivity testing of the resin coated sand at reservoir pressure and temperature reveals that over 95 wt% of the mesh sized sand particles should pass the room temperature crush test before coating.
{"title":"Development of a Ceramic Proppant Alternative for Deep Conventional Gas Development in Saudi Arabia","authors":"M. Fraim, Saleh H. Al-Awaji","doi":"10.2118/194718-MS","DOIUrl":"https://doi.org/10.2118/194718-MS","url":null,"abstract":"\u0000 The purpose of the paper is to present the results of using local sand resources in Saudi Arabia for the manufacture of resin coated proppant as a ceramic proppant alternative for deep conventional gas development. Crushed Miocene sandstone, old river sand and dune sand has been tested for a source to manufacture resin coated sand proppant. Compared to Northern White Sand in USA, each sand source has its own set of limitations such as angularity, low aspect ratio, clay, carbonate scale or iron oxide coating, and/or micro-fracture damage. Complete resin bonding to the particle surface required clean quartz surface free of sharp edges and no dust contamination. Conductivity testing of the resin coated sand at reservoir pressure and temperature reveals that over 95 wt% of the mesh sized sand particles should pass the room temperature crush test before coating.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75036844","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. Holyoak, M. Sawafi, Abdesslam Belghache, Talal Aulaqi
This paper will describe a methodology which has been developed as an alternative to four-dimensional (4D) Seismic. The main objective is to track heat conformance over time in the thermally developed "A" Field, Sultanate of Oman. The method has several significant advantages over 4D Seismic, including: Negligible cost and manpower requirements;Provision of close to real-time information and no processing time requirements;No Health, Safety or Environmental exposure, or disruption to ongoing operations. The paper will also demonstrate the power of integrating wide-ranging data sources for effective well and reservoir management. The increasingly close well spacing at "A" Field has made Seismic Acquisition progressively more challenging. Conversely, it has created an opportunity to utilize dynamic Tubing-Head Temperatures (THTs) for tracking areal thermal conformance over time. For each month in turn an automated workflow:- Grids the monthly THT averages;Integrates the production and injection data, represented as bubble plot overlays;Adds the top reservoir structure from the subsurface model, highlighting structural dip, and fault locations. Morphing (movie) software then interpolates the monthly images to create a smoothly transitioning "Heat Movie". The Heat Movie demonstrates the general effectiveness of the Development in terms of warming the reservoir over time. This in turn is reducing the oil viscosity and increasing production. However, it also highlights temperature anomalies that can be linked to geological features such as faults and high permeability layers. Identification of these anomalies may underpin decisions to optimise the thermal development. In addition to the Movie, time-lapse images can be created for any chosen period. This is similar to 4D Seismic, but more powerful, since the period can be directly linked to significant field milestones, for example equal time periods before and after upgrading the steam generation process. Proof of Concept was demonstrated in early 2018, and the technique has already been deemed sufficiently mature to utilize it for tracking and managing Thermal Conformance in place of 4D Seismic. This is resulting in annual cost savings of millions of dollars and man-years of staff time. One potential advantage of 4D Seismic is highlighting vertical conformance. Although this is not possible using THTs alone, at "A" Field the plan is to mitigate this by integrating data from ongoing Distributed Temperature Sensing (DTS) and well temperature surveys. Regarding applicability, the workflow can be adapted for other objectives, for example creating a movie of surface uplift and/or subsidence integrated with bubble plots of production and injection data, or water breakthrough for wells with downhole gauges, in water flood developments. In addition to describing the methodology underpinning this innovative approach, this paper will also discuss the vision for further improving
{"title":"Heat Movie - A Low-Cost Alternative to 4D Seismic, A Field, Sultanate of Oman","authors":"S. Holyoak, M. Sawafi, Abdesslam Belghache, Talal Aulaqi","doi":"10.2118/194997-MS","DOIUrl":"https://doi.org/10.2118/194997-MS","url":null,"abstract":"\u0000 \u0000 \u0000 This paper will describe a methodology which has been developed as an alternative to four-dimensional (4D) Seismic. The main objective is to track heat conformance over time in the thermally developed \"A\" Field, Sultanate of Oman. The method has several significant advantages over 4D Seismic, including: Negligible cost and manpower requirements;Provision of close to real-time information and no processing time requirements;No Health, Safety or Environmental exposure, or disruption to ongoing operations.\u0000 The paper will also demonstrate the power of integrating wide-ranging data sources for effective well and reservoir management.\u0000 \u0000 \u0000 \u0000 The increasingly close well spacing at \"A\" Field has made Seismic Acquisition progressively more challenging. Conversely, it has created an opportunity to utilize dynamic Tubing-Head Temperatures (THTs) for tracking areal thermal conformance over time. For each month in turn an automated workflow:- Grids the monthly THT averages;Integrates the production and injection data, represented as bubble plot overlays;Adds the top reservoir structure from the subsurface model, highlighting structural dip, and fault locations.\u0000 Morphing (movie) software then interpolates the monthly images to create a smoothly transitioning \"Heat Movie\".\u0000 \u0000 \u0000 \u0000 The Heat Movie demonstrates the general effectiveness of the Development in terms of warming the reservoir over time. This in turn is reducing the oil viscosity and increasing production. However, it also highlights temperature anomalies that can be linked to geological features such as faults and high permeability layers. Identification of these anomalies may underpin decisions to optimise the thermal development.\u0000 In addition to the Movie, time-lapse images can be created for any chosen period. This is similar to 4D Seismic, but more powerful, since the period can be directly linked to significant field milestones, for example equal time periods before and after upgrading the steam generation process.\u0000 Proof of Concept was demonstrated in early 2018, and the technique has already been deemed sufficiently mature to utilize it for tracking and managing Thermal Conformance in place of 4D Seismic. This is resulting in annual cost savings of millions of dollars and man-years of staff time.\u0000 \u0000 \u0000 \u0000 One potential advantage of 4D Seismic is highlighting vertical conformance. Although this is not possible using THTs alone, at \"A\" Field the plan is to mitigate this by integrating data from ongoing Distributed Temperature Sensing (DTS) and well temperature surveys.\u0000 Regarding applicability, the workflow can be adapted for other objectives, for example creating a movie of surface uplift and/or subsidence integrated with bubble plots of production and injection data, or water breakthrough for wells with downhole gauges, in water flood developments.\u0000 In addition to describing the methodology underpinning this innovative approach, this paper will also discuss the vision for further improving","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"146 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77849184","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. Ali, A. Attia, M. Taha, M. El-Maadawy, A. M. Abo-Raia, Amr Abouria
Environmental and health issues are critical challenges for sustainable development in the 21st century; therefore, this paper investigates a simple and cost-effective process for recovery of organic matter (OM) from phosphoric acid to provide environmentally acceptable P-fertilizer. This study analyzed the structural transformations and adsorption properties of Na-bentonite clay before and after chemical activation by sulfuric and hydrochloric acids. The untreated and treated clay samples have been used for adsorption of organic matter from high strength phosphoric acid. The experimental data exhibited that the clay treated with sulfuric acid caused highest organic matter adsorption capacity. The kinetic models of adsorption were analyzed by the pseudo-first order, pseudo-second order, Elovich kinetic and Morris-Weber models. The results indicated that the pseudo-second-order kinetic model is more appropriate than the others for natural bentonite; but, for chemical activated clays, pseudo-first order is fitting. Obtained adsorption thermodynamic parameters (ΔH°, ΔS°, and ΔG°) expose that the organic matter adsorption is an endothermic, physical, and spontaneous process.
{"title":"Application of Acid Activated Bentonite for Efficient Removal of Organic Pollutants from Industrial Phosphoric Acid: Kinetic and Thermodynamic Study","authors":"M. Ali, A. Attia, M. Taha, M. El-Maadawy, A. M. Abo-Raia, Amr Abouria","doi":"10.2118/194719-MS","DOIUrl":"https://doi.org/10.2118/194719-MS","url":null,"abstract":"\u0000 Environmental and health issues are critical challenges for sustainable development in the 21st century; therefore, this paper investigates a simple and cost-effective process for recovery of organic matter (OM) from phosphoric acid to provide environmentally acceptable P-fertilizer. This study analyzed the structural transformations and adsorption properties of Na-bentonite clay before and after chemical activation by sulfuric and hydrochloric acids. The untreated and treated clay samples have been used for adsorption of organic matter from high strength phosphoric acid. The experimental data exhibited that the clay treated with sulfuric acid caused highest organic matter adsorption capacity. The kinetic models of adsorption were analyzed by the pseudo-first order, pseudo-second order, Elovich kinetic and Morris-Weber models. The results indicated that the pseudo-second-order kinetic model is more appropriate than the others for natural bentonite; but, for chemical activated clays, pseudo-first order is fitting. Obtained adsorption thermodynamic parameters (ΔH°, ΔS°, and ΔG°) expose that the organic matter adsorption is an endothermic, physical, and spontaneous process.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"11 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":"78345270","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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