A. Nunez, Ibrahim Al-Farei, Ahmed Benchekor, Nasser Khalfan Al Husaini, E. Sayapov, A. Al-Shanfari, Khalfan Bahri, J. C. Chávez, A. Hinai
Hydraulically fracturing operations is becoming much more complex as the gas formations are being depleted with the time. In addition to this, some gas reserves need to be recovered by fracturing horizontal wells with multiple stages which is the case of an extensive gas field in the Sultanate of Oman that has been producing since 1991 mainly by hydraulic fracturing. The scope of this paper is to discuss the different methodologies in the operations associated to hydraulic fracturing in horizontal gas wells with formations depleted in PDO, the main objective is to show operations and well delivery improvement by the optimization of tools conveyance, perforating techniques, clean out and milling strategy. The paper will show the enhancement of the operations and the outstanding results in these challenging well conditions. The paper will start by describing the different methods used to execute operations for fracturing horizontal wells which are mainly related to plug and perf technique, clean out and milling plugs in between stages. Further, it will discuss the strategy, planning and job execution of one of the wells with 14 stages in the horizontal section, the perforating technique and strategy used to help reduce screen out's, it will also discuss the acquisition of spectral Noise log data post fracturing with the assistance of Nitrogen as well as the milling of the isolation plugs at the end of the job. The optimization of the conventional operations is a novel approach to enhance hydraulic fracturing in depleted horizontal gas wells in PDO, this is in alignment with the continuous improvement ideas and the lean thinking across the oil and gas industry. It is easy to replicate in other horizontal wells to be hydraulically fractured which will reduce cost, HSE exposure and will help increase the recovery of hydrocarbon reserves.
{"title":"Hydraulic Fracturing Operations Enhancement in Depleted Horizontal Gas Wells, a Novel Approach with Outstanding Results","authors":"A. Nunez, Ibrahim Al-Farei, Ahmed Benchekor, Nasser Khalfan Al Husaini, E. Sayapov, A. Al-Shanfari, Khalfan Bahri, J. C. Chávez, A. Hinai","doi":"10.2118/197159-ms","DOIUrl":"https://doi.org/10.2118/197159-ms","url":null,"abstract":"\u0000 Hydraulically fracturing operations is becoming much more complex as the gas formations are being depleted with the time. In addition to this, some gas reserves need to be recovered by fracturing horizontal wells with multiple stages which is the case of an extensive gas field in the Sultanate of Oman that has been producing since 1991 mainly by hydraulic fracturing.\u0000 The scope of this paper is to discuss the different methodologies in the operations associated to hydraulic fracturing in horizontal gas wells with formations depleted in PDO, the main objective is to show operations and well delivery improvement by the optimization of tools conveyance, perforating techniques, clean out and milling strategy. The paper will show the enhancement of the operations and the outstanding results in these challenging well conditions. The paper will start by describing the different methods used to execute operations for fracturing horizontal wells which are mainly related to plug and perf technique, clean out and milling plugs in between stages. Further, it will discuss the strategy, planning and job execution of one of the wells with 14 stages in the horizontal section, the perforating technique and strategy used to help reduce screen out's, it will also discuss the acquisition of spectral Noise log data post fracturing with the assistance of Nitrogen as well as the milling of the isolation plugs at the end of the job.\u0000 The optimization of the conventional operations is a novel approach to enhance hydraulic fracturing in depleted horizontal gas wells in PDO, this is in alignment with the continuous improvement ideas and the lean thinking across the oil and gas industry. It is easy to replicate in other horizontal wells to be hydraulically fractured which will reduce cost, HSE exposure and will help increase the recovery of hydrocarbon reserves.","PeriodicalId":11328,"journal":{"name":"Day 4 Thu, November 14, 2019","volume":"123 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79473260","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 most common practice to deploy a lower completion with inflow control devices (ICDs) requires a washpipe assembly to facilitate deployment. Due to the nature of traditional ICDs, with open flow ports, the washpipe assembly provides a conduit to circulate fluids during the installation. However, makeup and break out of washpipe takes time, carries risk, and provides no long-term benefit to the completion or long term value to the operator. The industry has used temporary mechanical isolation in more recent years, but these devices lack redundancy in the event of malfunction. The objective of the hydro-mechanical ICD is to remove the requirement for washpipe, thereby reducing operational risk and rig time while eliminating HSE concerns related to drill pipe handling when deploying the lower completion. The key differentiator being additional redundancy, should manipulation be required. An additional feature of the tool is position verification, the ICDs benefit from a passive attenae. The attenae reader can be deployed in the future to independently verify sleeve position should well optimization be required over the well lifecycle as water cut increases. The paper reviews various techniques that have been adopted to date and concludes with presenting a hydro-mechanical solution that was successfully installed and the value derived.
{"title":"Deployment of Lower Completions with Interventionless Inflow Control Device to Increase Operational Efficiency, Save Rig Time and Reduce Deployment Risk","authors":"Iain Adan, R. Boggs","doi":"10.2118/197489-ms","DOIUrl":"https://doi.org/10.2118/197489-ms","url":null,"abstract":"\u0000 The most common practice to deploy a lower completion with inflow control devices (ICDs) requires a washpipe assembly to facilitate deployment. Due to the nature of traditional ICDs, with open flow ports, the washpipe assembly provides a conduit to circulate fluids during the installation. However, makeup and break out of washpipe takes time, carries risk, and provides no long-term benefit to the completion or long term value to the operator.\u0000 The industry has used temporary mechanical isolation in more recent years, but these devices lack redundancy in the event of malfunction.\u0000 The objective of the hydro-mechanical ICD is to remove the requirement for washpipe, thereby reducing operational risk and rig time while eliminating HSE concerns related to drill pipe handling when deploying the lower completion. The key differentiator being additional redundancy, should manipulation be required.\u0000 An additional feature of the tool is position verification, the ICDs benefit from a passive attenae. The attenae reader can be deployed in the future to independently verify sleeve position should well optimization be required over the well lifecycle as water cut increases.\u0000 The paper reviews various techniques that have been adopted to date and concludes with presenting a hydro-mechanical solution that was successfully installed and the value derived.","PeriodicalId":11328,"journal":{"name":"Day 4 Thu, November 14, 2019","volume":"41 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75713157","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 deepwater drilling, it is inevitable to disconnect the riser from the Low Marine Riser Package (LMRP) with the blowout preventer (BOP) under some extreme operating conditions. Since the riser is in tensile state under normal working conditions, elastic potential energy is stored in the riser. So, the riser will move upward like a spring under the combined action of the elastic potential energy and the frictional resistance generated by the discharge of drilling mud in riser, which is called recoil response. Recoil analysis of drilling riser is of great significance to the safety of deepwater drilling, from which the recoil response, main controlling factors and corresponding solutions can be defined. In this paper, the mechanical model and governing equations are established based on the mass-spring-damping system with two degrees of freedom. In this model, the frictional resistance on the riser inner wall when the drilling fluid is discharged, and the elastic potential energy stored in the riser are taken into account. In addition, the direct acting tensioner (DAT), which is simplified as sinusoidal motion and spring model, is selected as the top boundary condition of the disconnected riser. The tension force and spring stiffness is calculated based on the configuration and working principle of the DAT. Finally, the time-history displacement of the LMRP after disconnected from the BOP is obtained. On this basis, the parameter sensitivity analysis is presented. Analysis results show that with the increase of water depth and the amplitude of the DAT, the possibility of collision between them rises. For a determined riser system, there is an optimal heave motion frequency for the DAT to implement riser emergency disconnection. Corresponding measures should be taken to prevent the spring stiffness of the DAT from decreasing. Besides, the riser size has a comprehensive effect on the riser recoil response. This paper can provide reference for the research of riser emergency disconnection.
{"title":"Methodology for Recoil Analysis of Emergency Disconnection Drilling Riser in a Deepwater Environment","authors":"Yanbin Wang, D. Gao, Jinduo Wang","doi":"10.2118/197863-ms","DOIUrl":"https://doi.org/10.2118/197863-ms","url":null,"abstract":"\u0000 In deepwater drilling, it is inevitable to disconnect the riser from the Low Marine Riser Package (LMRP) with the blowout preventer (BOP) under some extreme operating conditions. Since the riser is in tensile state under normal working conditions, elastic potential energy is stored in the riser. So, the riser will move upward like a spring under the combined action of the elastic potential energy and the frictional resistance generated by the discharge of drilling mud in riser, which is called recoil response. Recoil analysis of drilling riser is of great significance to the safety of deepwater drilling, from which the recoil response, main controlling factors and corresponding solutions can be defined.\u0000 In this paper, the mechanical model and governing equations are established based on the mass-spring-damping system with two degrees of freedom. In this model, the frictional resistance on the riser inner wall when the drilling fluid is discharged, and the elastic potential energy stored in the riser are taken into account. In addition, the direct acting tensioner (DAT), which is simplified as sinusoidal motion and spring model, is selected as the top boundary condition of the disconnected riser. The tension force and spring stiffness is calculated based on the configuration and working principle of the DAT. Finally, the time-history displacement of the LMRP after disconnected from the BOP is obtained. On this basis, the parameter sensitivity analysis is presented.\u0000 Analysis results show that with the increase of water depth and the amplitude of the DAT, the possibility of collision between them rises. For a determined riser system, there is an optimal heave motion frequency for the DAT to implement riser emergency disconnection. Corresponding measures should be taken to prevent the spring stiffness of the DAT from decreasing. Besides, the riser size has a comprehensive effect on the riser recoil response. This paper can provide reference for the research of riser emergency disconnection.","PeriodicalId":11328,"journal":{"name":"Day 4 Thu, November 14, 2019","volume":"28 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88821413","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 the oil and gas sector, energy is wasted far too often. By recovering those losses and increasing efficiency, the operators of production facilities and transmission systems can make dramatic improvements and yield new commercial opportunities. For instance, energy recovery may potentially allow profits to be realized from fields that might otherwise be marginal prospects or represent an additional revenue stream for gas pipeline transmission and distribution network operators. Now, a breakthrough technology that supports energy recovery from heat rejected from a broad range of industrial processes is available to the oil and gas industry. There is a lot of wasted energy available. Globally, it is estimated that rejected heat corresponds to about 65% of the net energy input across the industrial infrastructure, with numbers varying from 60% to 70% depending on the region, including the Middle East. Considerable waste heat is ejected from equipment like the gas turbines that are commonly used in mechanical drive applications found in the compression processes of gas production platforms and transmission pipelines. While most gas turbine heat recovery systems use a bottoming steam cycle to improve thermal efficiency, so-called combined cycle turbines, the new development presented in this paper is significantly different.
{"title":"Transforming Waste Heat to Electric Power in Oil and Gas Compression Systems using Supercritical Carbon Dioxide","authors":"T. Soulas","doi":"10.2118/197965-ms","DOIUrl":"https://doi.org/10.2118/197965-ms","url":null,"abstract":"\u0000 In the oil and gas sector, energy is wasted far too often. By recovering those losses and increasing efficiency, the operators of production facilities and transmission systems can make dramatic improvements and yield new commercial opportunities. For instance, energy recovery may potentially allow profits to be realized from fields that might otherwise be marginal prospects or represent an additional revenue stream for gas pipeline transmission and distribution network operators.\u0000 Now, a breakthrough technology that supports energy recovery from heat rejected from a broad range of industrial processes is available to the oil and gas industry. There is a lot of wasted energy available. Globally, it is estimated that rejected heat corresponds to about 65% of the net energy input across the industrial infrastructure, with numbers varying from 60% to 70% depending on the region, including the Middle East.\u0000 Considerable waste heat is ejected from equipment like the gas turbines that are commonly used in mechanical drive applications found in the compression processes of gas production platforms and transmission pipelines. While most gas turbine heat recovery systems use a bottoming steam cycle to improve thermal efficiency, so-called combined cycle turbines, the new development presented in this paper is significantly different.","PeriodicalId":11328,"journal":{"name":"Day 4 Thu, November 14, 2019","volume":"170 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85426264","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 Eocene C-Sup VLG3676 reservoir is one of the most important oil reservoirs of Western Venezuela. It has a high lateral sedimentological heterogeneity, some sand production issues due to low sandstone cohesion and high stress gradients, and asphaltene precipitation problems. All these features have created production problems since the beginning of the reservoir production, with a drastic impact on the reservoir potential. This has lead to the construction of a compositional/geomechanical model in order to design a palliative strategy. The proposed modeling methodology includes nine phases: 1) Development of the 3D mechanical earth model (MEM) to simulate reservoir compaction; 2) Quality control of the static model, including the relative permeability values; 3) Development of a fluid model that predicts the onset of asphaltene precipitation; 4) Development of a rock-fluid interaction model; 5) Initialization and calibration of the compositional model; 6) Coupling of the compositional and geomechanics models; 7) History matching; 8) Analytical estimation of the onset of sand production; 9) Implementation of an opportunity index analysis for asphaltene precipitation and sand production. Based on this compositional/geomechanical model it has been possible to map the risk of asphaltene precipitation and sand production in the reservoir, therefore showing that such problems are critical in the Eocene Misoa C-2-Sup and C-3-Sup stratigraphic units, due to the energy depletion caused by the production. This model allowed optimizing the locations of 35 wells to be drilled. The applied methodology enabled engineers to efficiently estimate the bottomhole flowing pressures and the critical drawdown pressures in the reservoir, identify the most prospective areas of the deposit, and design the trajectories of the new wells. It allowed designing the future Asset Development Plan (ADP) to maximize the hydrocarbon recovery and optimize the resources and investments necessary to increase the reservoir productivity. This paper will go through all the nine phases of the workflow, will highlight their most specific features, and will conclude on the value on such an approach.
{"title":"Coupled Compositional/Geomechanics Reservoir Simulation of Eocene C-Sup VLG3676, Block VII Ceuta Field, Venezuela: A Case Study","authors":"E. Carrero, C. Lobo, A. Bois","doi":"10.2118/197401-ms","DOIUrl":"https://doi.org/10.2118/197401-ms","url":null,"abstract":"\u0000 The Eocene C-Sup VLG3676 reservoir is one of the most important oil reservoirs of Western Venezuela. It has a high lateral sedimentological heterogeneity, some sand production issues due to low sandstone cohesion and high stress gradients, and asphaltene precipitation problems. All these features have created production problems since the beginning of the reservoir production, with a drastic impact on the reservoir potential. This has lead to the construction of a compositional/geomechanical model in order to design a palliative strategy.\u0000 The proposed modeling methodology includes nine phases: 1) Development of the 3D mechanical earth model (MEM) to simulate reservoir compaction; 2) Quality control of the static model, including the relative permeability values; 3) Development of a fluid model that predicts the onset of asphaltene precipitation; 4) Development of a rock-fluid interaction model; 5) Initialization and calibration of the compositional model; 6) Coupling of the compositional and geomechanics models; 7) History matching; 8) Analytical estimation of the onset of sand production; 9) Implementation of an opportunity index analysis for asphaltene precipitation and sand production.\u0000 Based on this compositional/geomechanical model it has been possible to map the risk of asphaltene precipitation and sand production in the reservoir, therefore showing that such problems are critical in the Eocene Misoa C-2-Sup and C-3-Sup stratigraphic units, due to the energy depletion caused by the production. This model allowed optimizing the locations of 35 wells to be drilled. The applied methodology enabled engineers to efficiently estimate the bottomhole flowing pressures and the critical drawdown pressures in the reservoir, identify the most prospective areas of the deposit, and design the trajectories of the new wells. It allowed designing the future Asset Development Plan (ADP) to maximize the hydrocarbon recovery and optimize the resources and investments necessary to increase the reservoir productivity. This paper will go through all the nine phases of the workflow, will highlight their most specific features, and will conclude on the value on such an approach.","PeriodicalId":11328,"journal":{"name":"Day 4 Thu, November 14, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84282521","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}
H. Ahmad, M. Kamal, Mobeen Murtaza, Sarmad Khan, M. Al‐harthi
Hydration of shale formations during drilling operations have adverse effects on wellbore stability. The shale hydration resulted from the interactions between drilling fluid and swelling clay contents in the shale formations. This paper addresses the improvement of wettability and hydration properties of shale to enhance the wellbore stability during the drilling operations. The novel ionic liquid-based drilling fluids were used to alter the wettability and hydration properties of shale. The novel ionic liquid based drilling fluid was developed by blending various ionic liquids and drilling fluid additives such as filtration control agent and rheological modifier. The rheology and filtration related properties of the base drilling fluid and its modified version with ionic liquids were determined. Shale inhibition characteristics of modified drilling fluids were evaluated by using real field shale sample and analyzing it with linear shale swelling test and hot rolling dispersion test. Two different ionic liquids (IL-1, IL-2) were deployed in the formulation of drilling fluids with a concentration of 0.05%. The conventionally used shale inhibitor KCl was also used in the formulation of drilling fluid with the concentration of up to 2%. The results of modified drilling fluids were then compared with the base drilling fluids prepared by mixing bentonite and cationic polymer (polydadmac). The rheological experiments showed that the addition of KCl and ionic liquids in the base drilling fluid resulted in a decrease in rheological properties. The filtration experiments also showed that filtrate volume has increased with the addition of KCl and ionic liquids in the drilling fluids. The hot rolling shale recovery experiment was performed at 65°C and superior shale recovery was observed with the synergistic effect of B/IL-2/K drilling fluid. Linear swelling of shale was assessed over a time period of 10 hours and minimum linear swelling of shale was observed with B/IL-2/K drilling fluid which indicated that the ionic liquid in the drilling fluid chemically interacts with the shale surface and makes it hydrophobic in nature which limits the interactions of water with shale. This use of novel ionic liquid-based drilling fluid enhances the borehole stability by modifying the shale surface and resulted in improved wellbore stability. The novel drilling fluid also has superior rheological, filtration properties and salt tolerance.
{"title":"Alteration of Wettability and Hydration Properties of Shale using Ionic Liquids in Water-Based Drilling Fluids","authors":"H. Ahmad, M. Kamal, Mobeen Murtaza, Sarmad Khan, M. Al‐harthi","doi":"10.2118/197940-ms","DOIUrl":"https://doi.org/10.2118/197940-ms","url":null,"abstract":"\u0000 Hydration of shale formations during drilling operations have adverse effects on wellbore stability. The shale hydration resulted from the interactions between drilling fluid and swelling clay contents in the shale formations. This paper addresses the improvement of wettability and hydration properties of shale to enhance the wellbore stability during the drilling operations. The novel ionic liquid-based drilling fluids were used to alter the wettability and hydration properties of shale. The novel ionic liquid based drilling fluid was developed by blending various ionic liquids and drilling fluid additives such as filtration control agent and rheological modifier. The rheology and filtration related properties of the base drilling fluid and its modified version with ionic liquids were determined. Shale inhibition characteristics of modified drilling fluids were evaluated by using real field shale sample and analyzing it with linear shale swelling test and hot rolling dispersion test. Two different ionic liquids (IL-1, IL-2) were deployed in the formulation of drilling fluids with a concentration of 0.05%. The conventionally used shale inhibitor KCl was also used in the formulation of drilling fluid with the concentration of up to 2%. The results of modified drilling fluids were then compared with the base drilling fluids prepared by mixing bentonite and cationic polymer (polydadmac). The rheological experiments showed that the addition of KCl and ionic liquids in the base drilling fluid resulted in a decrease in rheological properties. The filtration experiments also showed that filtrate volume has increased with the addition of KCl and ionic liquids in the drilling fluids. The hot rolling shale recovery experiment was performed at 65°C and superior shale recovery was observed with the synergistic effect of B/IL-2/K drilling fluid. Linear swelling of shale was assessed over a time period of 10 hours and minimum linear swelling of shale was observed with B/IL-2/K drilling fluid which indicated that the ionic liquid in the drilling fluid chemically interacts with the shale surface and makes it hydrophobic in nature which limits the interactions of water with shale. This use of novel ionic liquid-based drilling fluid enhances the borehole stability by modifying the shale surface and resulted in improved wellbore stability. The novel drilling fluid also has superior rheological, filtration properties and salt tolerance.","PeriodicalId":11328,"journal":{"name":"Day 4 Thu, November 14, 2019","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89385055","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, in unconventional reservoirs, main fracture parameters including fracture permeability and fracture volume can be early evaluated using flowback data analysis. For analysis purposes, diagnostic plots, straight-line methods, and simulation model history-matching techniques are utilized. Usually, immediate gas and water production occur during flowback in shale gas wells. In this paper, solution of water diffusivity equation for different flow regimes during the early time of well life was used to analyze water performance. These flow regimes were determined based on the diagnostic plot of water rate vs. time. The analysis from Water RTA was used to calculate initial water in place (OWIP) and fracture parameters. The difference between the OWIP and the injected fracturing fluid was correlated against the formation water saturation. The main conclusions from this analysis are; 1) High quality shale if the OWIP equal to the total injected water volume, and water-production data usually do not show the transient period and in some cases, boundary dominated flow (BDF) is present. 2) Low quality shale if the OWIP is greater than the total injected fracture fluid volume, and transient flow regimes are expected. High quality shale is good candidate for soaking process. The well performance increases after soaking process in the case of low formation water comparing to the high-water saturation wells. Honoring the flowback data can help to estimate the fracture geometry and indicate the quality of the shale formation.
{"title":"Ranking Shale Performance from Water Flowback Analysis, Field Case","authors":"A. Ibrahim, Ahmed Assem, M. Ibrahim, C. Pieprzica","doi":"10.2118/197792-ms","DOIUrl":"https://doi.org/10.2118/197792-ms","url":null,"abstract":"\u0000 In recent years, in unconventional reservoirs, main fracture parameters including fracture permeability and fracture volume can be early evaluated using flowback data analysis. For analysis purposes, diagnostic plots, straight-line methods, and simulation model history-matching techniques are utilized. Usually, immediate gas and water production occur during flowback in shale gas wells.\u0000 In this paper, solution of water diffusivity equation for different flow regimes during the early time of well life was used to analyze water performance. These flow regimes were determined based on the diagnostic plot of water rate vs. time. The analysis from Water RTA was used to calculate initial water in place (OWIP) and fracture parameters. The difference between the OWIP and the injected fracturing fluid was correlated against the formation water saturation.\u0000 The main conclusions from this analysis are; 1) High quality shale if the OWIP equal to the total injected water volume, and water-production data usually do not show the transient period and in some cases, boundary dominated flow (BDF) is present. 2) Low quality shale if the OWIP is greater than the total injected fracture fluid volume, and transient flow regimes are expected. High quality shale is good candidate for soaking process. The well performance increases after soaking process in the case of low formation water comparing to the high-water saturation wells.\u0000 Honoring the flowback data can help to estimate the fracture geometry and indicate the quality of the shale formation.","PeriodicalId":11328,"journal":{"name":"Day 4 Thu, November 14, 2019","volume":"75 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86077796","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}
Halokinesis has strongly stimuluses the Abu Dhabi petroleum system. During the Late Precambrian, the basement terranes of the Arabian and adjoining plates were fused along the northeastern margin of the African Gondwanaland plate. This phase was followed by continental rifting and intra-continental extension. The Arabian Infracambrian extensional system established rifted salt basins in the Zagros region, South Oman and in the Arabian Gulf. The Hormuz salt in these areas contains basalt and rhyolite, suggesting tectonic extension at this time. The Zagros thrust fault and Dibba transform fault define the current limits of the Hormuz Complex of the Arabian Gulf. As a passive margin during Paleozoic time, the Arabian plate accumulated a continentally influenced shallow marine sequence characterized by interbedded siltstones, sandstones, shales and carbonates sediments. The Late Ordovician-Early Silurian glaciation interrupted the Paleozoic deposition by lowering sea level in the Late Silurian and Late Carboniferous-Early Permian glaciation. Salt movement was started an extensional phase in Permo-Jurassic with the Neo-Tethys opening and basement faults reactivation. Followed by Cretaceous compression stress due to Afro-Arabian Plate movement. The third phase happened by Late Cretaceous with the closing of the Neo-Tethys. The salt was finally pierced to the surface by Mid Tertiary compression stress forces accompanied with Oman thrusting and Zagros folding. Since Miocene uplift, the salt movement extended until present day onwards. Previously, the pierced salt was considered stacked, but subsidence measurements indicating salt is still moving in some islands reaching about 2cm per year. This paper uses 3D seismic, core data and outcrops investigations to assess the geometry, kinematics, and the halokinetic phases that stimuluses the hydrocarbon exploration targets. The paper revisited the flowage phases of the salt in Abu Dhabi, investigated the accompanying fault geometries and relate this to the structural styles. The diapiric anticlines forming during salt movement phases forming domal structures with radial faults. Contradicting what is known, the Miocene-recent strata are tilted indicating the continuation of the salt movement. The Hormuz salt is characterized by a regionally consistent stratigraphy, formed of evaporites interbedded with clastic and carbonate sediments with dolomite intervals and vein intrusions of volcanic rocks. Interpreted faults were categorized into three families, Type I comprising domal radial faults, Type II representing faults triggered salt movements and Type III describing salt movements triggered faults. The first type is characterizing itself by its location relative to the crystal parts of the domes. The relatively low overburden pressure at the crest of the diapir and the original high dip angles of these fault planes favor salt intrusions near the diapir crest. Depending on the salt movement phases, the gener
{"title":"Halokinesis Stimuluses on Petroleum System of Abu Dhabi","authors":"A. Noufal, H. Shebl","doi":"10.2118/197597-ms","DOIUrl":"https://doi.org/10.2118/197597-ms","url":null,"abstract":"\u0000 Halokinesis has strongly stimuluses the Abu Dhabi petroleum system. During the Late Precambrian, the basement terranes of the Arabian and adjoining plates were fused along the northeastern margin of the African Gondwanaland plate. This phase was followed by continental rifting and intra-continental extension. The Arabian Infracambrian extensional system established rifted salt basins in the Zagros region, South Oman and in the Arabian Gulf. The Hormuz salt in these areas contains basalt and rhyolite, suggesting tectonic extension at this time. The Zagros thrust fault and Dibba transform fault define the current limits of the Hormuz Complex of the Arabian Gulf. As a passive margin during Paleozoic time, the Arabian plate accumulated a continentally influenced shallow marine sequence characterized by interbedded siltstones, sandstones, shales and carbonates sediments. The Late Ordovician-Early Silurian glaciation interrupted the Paleozoic deposition by lowering sea level in the Late Silurian and Late Carboniferous-Early Permian glaciation.\u0000 Salt movement was started an extensional phase in Permo-Jurassic with the Neo-Tethys opening and basement faults reactivation. Followed by Cretaceous compression stress due to Afro-Arabian Plate movement. The third phase happened by Late Cretaceous with the closing of the Neo-Tethys. The salt was finally pierced to the surface by Mid Tertiary compression stress forces accompanied with Oman thrusting and Zagros folding. Since Miocene uplift, the salt movement extended until present day onwards. Previously, the pierced salt was considered stacked, but subsidence measurements indicating salt is still moving in some islands reaching about 2cm per year.\u0000 This paper uses 3D seismic, core data and outcrops investigations to assess the geometry, kinematics, and the halokinetic phases that stimuluses the hydrocarbon exploration targets. The paper revisited the flowage phases of the salt in Abu Dhabi, investigated the accompanying fault geometries and relate this to the structural styles. The diapiric anticlines forming during salt movement phases forming domal structures with radial faults. Contradicting what is known, the Miocene-recent strata are tilted indicating the continuation of the salt movement. The Hormuz salt is characterized by a regionally consistent stratigraphy, formed of evaporites interbedded with clastic and carbonate sediments with dolomite intervals and vein intrusions of volcanic rocks.\u0000 Interpreted faults were categorized into three families, Type I comprising domal radial faults, Type II representing faults triggered salt movements and Type III describing salt movements triggered faults. The first type is characterizing itself by its location relative to the crystal parts of the domes. The relatively low overburden pressure at the crest of the diapir and the original high dip angles of these fault planes favor salt intrusions near the diapir crest. Depending on the salt movement phases, the gener","PeriodicalId":11328,"journal":{"name":"Day 4 Thu, November 14, 2019","volume":"32 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76620507","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 prosperous business player must gain a competitive advantage over other companies to survive and dominate the market. In Japan, electricity market has progressively started its liberalization in 2000, and full liberalization in 2016 allowed all consumers to freely choose the power retailer. In response to these dramatic changes in the business environment, we have proactively introduced KAIZEN and digital technology to gain a competitive edge. KAIZEN was introduced in Japanese automobile manufacturing and based on the philosophical belief that "nothing is seen as a status quo and everything can be continuously improved by racking one's brain." Simply saying, it is an initiative to improve efficiency value-adding work, and to eliminate non-value-adding work and waste & loss which we can not recognize. In addition, the advancement of digital technology enabled us to analyze the big data which we have storaged from the past more easily and in more detail. As a result of introducing of KAIZEN and digital technology, the periodic inspection of thermal power plants has been shortened by over 40 %, and maintenance costs have been reduced by over 30 %. This paper illustrates the details of our initiatives implementing KAIZEN and digital technology and our challenges in optimizing the LNG value chain applying the KAIZEN knowledge.
{"title":"State-of-the-Art Plant Operation Combining Kaizen & Digital Technology and the Challenge for LNG Value Chain Optimization","authors":"T. Arai, Y. Otawara","doi":"10.2118/197602-ms","DOIUrl":"https://doi.org/10.2118/197602-ms","url":null,"abstract":"\u0000 A prosperous business player must gain a competitive advantage over other companies to survive and dominate the market. In Japan, electricity market has progressively started its liberalization in 2000, and full liberalization in 2016 allowed all consumers to freely choose the power retailer.\u0000 In response to these dramatic changes in the business environment, we have proactively introduced KAIZEN and digital technology to gain a competitive edge. KAIZEN was introduced in Japanese automobile manufacturing and based on the philosophical belief that \"nothing is seen as a status quo and everything can be continuously improved by racking one's brain.\" Simply saying, it is an initiative to improve efficiency value-adding work, and to eliminate non-value-adding work and waste & loss which we can not recognize. In addition, the advancement of digital technology enabled us to analyze the big data which we have storaged from the past more easily and in more detail.\u0000 As a result of introducing of KAIZEN and digital technology, the periodic inspection of thermal power plants has been shortened by over 40 %, and maintenance costs have been reduced by over 30 %.\u0000 This paper illustrates the details of our initiatives implementing KAIZEN and digital technology and our challenges in optimizing the LNG value chain applying the KAIZEN knowledge.","PeriodicalId":11328,"journal":{"name":"Day 4 Thu, November 14, 2019","volume":"17 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89669779","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}
Mohamed Mubarak Al-Ghaferi, Fawzi Omar Al Jaberi, M. Albadi, A. Yugay, Anubhav Agarwal, Yohannes Fisher Pangestu
Downhole Safety Valve is an integral part of Well Integrity Mangement System and acts as a failsafe equipment to prevent uncontrolled release of reservoir fluids. Periodic inspection and maintenance of downhole Safety Valve is essential under normal service conditions. Each Downhole Safety Valve should be tested and lubricated at specified regular intervals as recommended by ADNOCs Standard Operating Procedure and as dictated by field experience. Since it is a Critical Safety Equipment, preventive maintenance of Wireline Retrievable type downhole Safety Valve is being carried out annually which involves valve retrieval, leak/function test and redressing if required. Current practice within ADNOC Onshore is to carry out redressing with third party for all Wireline Retrievable Safety Valve annually or in case they are observed to be passing (not meeting the maximum acceptable gas leak rate of 15 scf/min for gas and 400 cc/min for liquid) or do not pass function test carried out during 6 monthly and yearly Preventive Maintenance Schedule. The cost incurred for third party redressing is substantial and can be optimized by evaluating the possibility of carrying out redressing in-house with available resources and using Original Equipment Manufacturer redress kit in situations where internal leak is not observed in the valve and valve can be redressed without the need to open tension spring and flow tube which requires extensive redressing setup available with third party. The new proposal helped in saving cost and time for redressing by utilizing the available resources and formalising in-house redressing wherever applicable under compliance to ADNOC Onshore competent authority guidelines.
{"title":"Surface Controlled Subsurface Safety Valve Refurbishment, In-house","authors":"Mohamed Mubarak Al-Ghaferi, Fawzi Omar Al Jaberi, M. Albadi, A. Yugay, Anubhav Agarwal, Yohannes Fisher Pangestu","doi":"10.2118/197453-ms","DOIUrl":"https://doi.org/10.2118/197453-ms","url":null,"abstract":"\u0000 Downhole Safety Valve is an integral part of Well Integrity Mangement System and acts as a failsafe equipment to prevent uncontrolled release of reservoir fluids. Periodic inspection and maintenance of downhole Safety Valve is essential under normal service conditions. Each Downhole Safety Valve should be tested and lubricated at specified regular intervals as recommended by ADNOCs Standard Operating Procedure and as dictated by field experience. Since it is a Critical Safety Equipment, preventive maintenance of Wireline Retrievable type downhole Safety Valve is being carried out annually which involves valve retrieval, leak/function test and redressing if required.\u0000 Current practice within ADNOC Onshore is to carry out redressing with third party for all Wireline Retrievable Safety Valve annually or in case they are observed to be passing (not meeting the maximum acceptable gas leak rate of 15 scf/min for gas and 400 cc/min for liquid) or do not pass function test carried out during 6 monthly and yearly Preventive Maintenance Schedule.\u0000 The cost incurred for third party redressing is substantial and can be optimized by evaluating the possibility of carrying out redressing in-house with available resources and using Original Equipment Manufacturer redress kit in situations where internal leak is not observed in the valve and valve can be redressed without the need to open tension spring and flow tube which requires extensive redressing setup available with third party.\u0000 The new proposal helped in saving cost and time for redressing by utilizing the available resources and formalising in-house redressing wherever applicable under compliance to ADNOC Onshore competent authority guidelines.","PeriodicalId":11328,"journal":{"name":"Day 4 Thu, November 14, 2019","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73675303","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}