The more downhole information measured by LWD tools, the more measurement data they produces. The conventional LWD tools can hardly transfer all the large amount of data of LWD tools to the surface, which greatly limits its advantages in while-drilling production. If retrieved after drilling, certain LWD tools would lose their advantages entirely in while-drilling production. This paper proposes a novel method that employs the basic concept of a "flash drive" downloading and exchanging data among computers. A system is developed to achieve data transmission in a time-division manner using releasable microchip storage. The system includes a plurality of microchip storages, a plurality of sealed chambers each for containing a microchip storage, a release power device, and a circuit. The release signal is sent by time setting or pressure signal triggering. In drilling, the data measured by the LWD tools can be downloaded into the microchip storage. A release signal could be sent on time, or the release signal can be triggered and sent by the pump pressure pulse, when the LWD data is needed. Upon receiving the release signal, the circuit sends a release command to control the power device to release the microchip storage from the drill collar into the drilling fluid in the annular. The microchip storage can be carried to the surface by drilling fluid and can be recovered. The data in the microchip storage can then be retrieved. In this system, there are four contacts on the microchip storage to connect with the circuit, through which power supply and data connection are established. The data access to the LWD data complies with the RS485 data protocol. The system adopts a push technology. The data capacity of single microchip storage is 1 Mbit, and the size of which is 12mm (D)×12.5mm (H). One drill collar system can carry up to 24 microchip storages. Thus it makes a single collar system have a large data storage capacity. It can improve the efficiency of data transmission.
{"title":"Study and Implement of the Large Amount Data Divided Time Transmission System Utilizing Microchip-Storage-Ball Release While Drilling","authors":"Sanguo Li, Ruixiang Gao, Jibo Li, Zuyang Zhu, Zhifa Wang, Eduardo Davio Gramajo Silva","doi":"10.2523/iptc-22368-ms","DOIUrl":"https://doi.org/10.2523/iptc-22368-ms","url":null,"abstract":"\u0000 The more downhole information measured by LWD tools, the more measurement data they produces. The conventional LWD tools can hardly transfer all the large amount of data of LWD tools to the surface, which greatly limits its advantages in while-drilling production. If retrieved after drilling, certain LWD tools would lose their advantages entirely in while-drilling production. This paper proposes a novel method that employs the basic concept of a \"flash drive\" downloading and exchanging data among computers. A system is developed to achieve data transmission in a time-division manner using releasable microchip storage. The system includes a plurality of microchip storages, a plurality of sealed chambers each for containing a microchip storage, a release power device, and a circuit. The release signal is sent by time setting or pressure signal triggering. In drilling, the data measured by the LWD tools can be downloaded into the microchip storage. A release signal could be sent on time, or the release signal can be triggered and sent by the pump pressure pulse, when the LWD data is needed. Upon receiving the release signal, the circuit sends a release command to control the power device to release the microchip storage from the drill collar into the drilling fluid in the annular. The microchip storage can be carried to the surface by drilling fluid and can be recovered. The data in the microchip storage can then be retrieved. In this system, there are four contacts on the microchip storage to connect with the circuit, through which power supply and data connection are established. The data access to the LWD data complies with the RS485 data protocol. The system adopts a push technology. The data capacity of single microchip storage is 1 Mbit, and the size of which is 12mm (D)×12.5mm (H). One drill collar system can carry up to 24 microchip storages. Thus it makes a single collar system have a large data storage capacity. It can improve the efficiency of data transmission.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74039483","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}
To appraise remaining behind casing opportunities in brown field after years of production, and depletion of main perforation intervals. Offshore environment is challenging and ensuring the presence of hydrocarbon requires significant investment, which is not always viable due to the economical additional reservoirs margin. A novel multidisciplinary workflow is developed to add assurance in apprising the remaining opportunities within the Idle wells prior to progress towards plug and abandonment. Limited data availability and economics allowed the development of a workflow to reduce uncertainty and ensure the presence of hydrocarbon when no cased hole saturation logging is justifiable. The workflow starts by relooking into the open hole logs to identify additional or marginal reservoirs. A complication index is assigned to each which refers to the easiness of the planned additional perf and the success ratio based on open hole data. A complete study to nearby wells production and the water oil contact movement is carried out based on the assigned complexity index. Opportunities were then ranked against the economics of additional perforation, cement bond logs were used to identify behind casing channeling especially when a gas or water contact is interpreted. The workflow which integrates the reservoir static and dynamic sand aligns petrophysics, dynamic model, history match and contact movement is developed to mitigate any behind casing opportunity consequent to no cased hole logging possibility, and to minimize the risk of not encountering hydrocarbon due to the long production. Any misleading allocation, potential risk (sand, wax, gravel pack, other completion accessories), predict future production based on location of new perf, plan for simulation or production enhancement job, remedial job, identify potential fault (unseen) at limited pressure data block, The workflow is proven to be successful to derisk the presence of hydrocarbon and to identify the most promising hydrocarbon bearing formations, with positive results as perforations are carried out where hydrocarbon are flew. This novel, comprehensive and integrated workflow generated a reliable tool to identify remaining potential trapped behind casing and possible risks of fluid type, current contact, impurities and well completion. The workflow is developed to generalizes the methodology to assess remained hydrocarbon within idle or high water cut wells, with risk reduced because each discipline contributed to the assessment with the potential risk associated with their discipline. Proper plan is together, capturing all possible risks and ensuring capturing the remained hydrocarbon.
{"title":"Novel Integrated Behind Casing Opportunity Maturation Workflow","authors":"Nur Farhana Mohd Razali, A. Ashqar","doi":"10.2523/iptc-22473-ea","DOIUrl":"https://doi.org/10.2523/iptc-22473-ea","url":null,"abstract":"\u0000 To appraise remaining behind casing opportunities in brown field after years of production, and depletion of main perforation intervals. Offshore environment is challenging and ensuring the presence of hydrocarbon requires significant investment, which is not always viable due to the economical additional reservoirs margin. A novel multidisciplinary workflow is developed to add assurance in apprising the remaining opportunities within the Idle wells prior to progress towards plug and abandonment.\u0000 Limited data availability and economics allowed the development of a workflow to reduce uncertainty and ensure the presence of hydrocarbon when no cased hole saturation logging is justifiable. The workflow starts by relooking into the open hole logs to identify additional or marginal reservoirs. A complication index is assigned to each which refers to the easiness of the planned additional perf and the success ratio based on open hole data. A complete study to nearby wells production and the water oil contact movement is carried out based on the assigned complexity index. Opportunities were then ranked against the economics of additional perforation, cement bond logs were used to identify behind casing channeling especially when a gas or water contact is interpreted.\u0000 The workflow which integrates the reservoir static and dynamic sand aligns petrophysics, dynamic model, history match and contact movement is developed to mitigate any behind casing opportunity consequent to no cased hole logging possibility, and to minimize the risk of not encountering hydrocarbon due to the long production. Any misleading allocation, potential risk (sand, wax, gravel pack, other completion accessories), predict future production based on location of new perf, plan for simulation or production enhancement job, remedial job, identify potential fault (unseen) at limited pressure data block, The workflow is proven to be successful to derisk the presence of hydrocarbon and to identify the most promising hydrocarbon bearing formations, with positive results as perforations are carried out where hydrocarbon are flew.\u0000 This novel, comprehensive and integrated workflow generated a reliable tool to identify remaining potential trapped behind casing and possible risks of fluid type, current contact, impurities and well completion. The workflow is developed to generalizes the methodology to assess remained hydrocarbon within idle or high water cut wells, with risk reduced because each discipline contributed to the assessment with the potential risk associated with their discipline. Proper plan is together, capturing all possible risks and ensuring capturing the remained hydrocarbon.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"189 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74142687","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}
Zhanhua Zhang, H. Cai, Lizhen Ge, Xiaoyu Yang, Xue Liu
In order to solve the problems of thin interbedded deposition, strong heterogeneity and large interlayer interference in early development of offshore K oilfield, this paper proposes a research idea of three-dimensional adjustment of injection production well pattern based on multi-layer flow field control in early development. Through the combination of reservoir numerical simulation method, reservoir engineering and field test, the expression formula of sweep efficiency of water drive area in different stages of injection production unit is established in plane, the injection production well pattern optimization technology based on plane heterogeneity is formed; The quantitative expression formula of multi factor inter layer interference coefficient is put forward vertically. Combining with Lorentz curve, the evaluation template and technical limit of early subdivision layer system of thin interbedded reservoir are established, and the early subdivision layer system technology based on the dynamic interference representation between layers is formed. By analyzing the seepage characteristics of thin interbedded multi-layer sandstone reservoir and combining with the field practice, the plane well layout model of offshore medium deep thin interbedded reservoir is established, Based on the quantitative characterization of interlayer interference, the technical limits of early subdivision of thin interbedded reservoirs are as follows: the permeability gradient is controlled within 3, the longitudinal span is controlled within 200m, the number of sand control sections is controlled within 4, and the water cut is less than 40%. The horizontal and vertical combination can effectively reduce the interlayer interference and start the poor reservoir area, forming a three-dimensional well pattern deployment technology suitable for the early development of offshore K oilfield. It can effectively improve the plane injection production relationship, increase the sweep range of water flooding as a whole, and improve the development level of oilfield. It can effectively reduce the more serious interlayer interference in the middle and later stage of water injection development of formation, improve the water absorption capacity of thin interbeds, and form balanced displacement and efficient development. The recovery was increased by 4.7%. The field test results show that the technology is effective. This paper is the first time to form a three-dimensional well pattern deployment technology suitable for the early development of offshore K oilfield, which provides effective development experience for the efficient development of offshore medium and deep thin interbedded reservoirs.
{"title":"Research and Practice on Eor of Three Dimensional Well Pattern in the Thin Interbedded Oil Reservoir in the Middle and Deep Layers of the Sea","authors":"Zhanhua Zhang, H. Cai, Lizhen Ge, Xiaoyu Yang, Xue Liu","doi":"10.2523/iptc-22635-ms","DOIUrl":"https://doi.org/10.2523/iptc-22635-ms","url":null,"abstract":"\u0000 In order to solve the problems of thin interbedded deposition, strong heterogeneity and large interlayer interference in early development of offshore K oilfield, this paper proposes a research idea of three-dimensional adjustment of injection production well pattern based on multi-layer flow field control in early development.\u0000 Through the combination of reservoir numerical simulation method, reservoir engineering and field test, the expression formula of sweep efficiency of water drive area in different stages of injection production unit is established in plane, the injection production well pattern optimization technology based on plane heterogeneity is formed; The quantitative expression formula of multi factor inter layer interference coefficient is put forward vertically. Combining with Lorentz curve, the evaluation template and technical limit of early subdivision layer system of thin interbedded reservoir are established, and the early subdivision layer system technology based on the dynamic interference representation between layers is formed.\u0000 By analyzing the seepage characteristics of thin interbedded multi-layer sandstone reservoir and combining with the field practice, the plane well layout model of offshore medium deep thin interbedded reservoir is established, Based on the quantitative characterization of interlayer interference, the technical limits of early subdivision of thin interbedded reservoirs are as follows: the permeability gradient is controlled within 3, the longitudinal span is controlled within 200m, the number of sand control sections is controlled within 4, and the water cut is less than 40%. The horizontal and vertical combination can effectively reduce the interlayer interference and start the poor reservoir area, forming a three-dimensional well pattern deployment technology suitable for the early development of offshore K oilfield. It can effectively improve the plane injection production relationship, increase the sweep range of water flooding as a whole, and improve the development level of oilfield. It can effectively reduce the more serious interlayer interference in the middle and later stage of water injection development of formation, improve the water absorption capacity of thin interbeds, and form balanced displacement and efficient development. The recovery was increased by 4.7%. The field test results show that the technology is effective.\u0000 This paper is the first time to form a three-dimensional well pattern deployment technology suitable for the early development of offshore K oilfield, which provides effective development experience for the efficient development of offshore medium and deep thin interbedded reservoirs.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"79 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79760503","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}
Andrés Núñez, Mauricio Corona, B. Goodkey, G. Hernandez, E. Brahmanto, Carlos Finol, Raed Ghali, M. Pandey, Sultan Alfaraedhi, Abdulrahman Abdulmajeed Gari, F. Marin
This paper describes the successful implementation of a methodology developed in a Deep Gas field in the Middle East with the intent of increasing the performance in a common intermediate hole section known for its arduous environment and common challenges including anomalous geological features, tight hole events, swelling shales, hole instability, and total losses while drilling scenarios. The initiatives and methodologies presented, are supported by the implementation of new tools and technologies including a drilling automation system, a novel drilling fluid and an experimental downhole mechanics measurement system. Collectively, the strategies implemented have led to a substantial increase in well construction efficiency and well delivery with a variety of applicable lessons for project teams facing similar challenges. Initially the field was mapped to identify localized risks and adopt a region-based engineering approach to overcome the various challenges. A comprehensive risk assessment of the existing practices was completed with the objective to categorize possible areas of improvement and the specific needs to capture and record essential downhole data. Once the gaps and opportunities were identified, special tools were selected and deployed in both Memory and Real Time mode targeting the capture of drilling mechanics data and its variations across different formations and its incluence across the different components of the drill string. Initially data was captured only using the Measurement While Drilling tools (MWD) in the string, in searching for more specific data a new tool helped to measure the drilling mechanics downhole at different positions on the BHA. The collected data helped to understand the different behaviours in each component and the final output came as an optimized BHA that is today giving the best performance and has eliminated all the tool failures. In parallel, a pioneering thixotropic drilling fluid system was implemented aiming to improve the stability across different formations. As part of second stage of the implementations, an opportunity was identified to increase the overall rate of penetration across the section while monitoring the equivalent circulating density. The initiatives were bolstered by the inclusion of automation systems which allowed to standarize the drilling process and more efficient. Thereby enabling gradual increase in operational limits in four sequential wells thus minimizing the time required for routine operations such as drill pipe connections, while beating all the previously established ROP records in this cemetery intermediate section. The third stage was a replication model consisting of the identification of the gaps and main differences in performance across different rigs for each specific activity in this section, the definition of critical zones where the performance gets naturally affected due to various roadblocks and the identification of actions to tackle and brin
{"title":"How to Turn Over a Cemetery Well Section, into Efficient, Outperforming and Record Hole Size, in a Deep Gas Wells in the Middle East","authors":"Andrés Núñez, Mauricio Corona, B. Goodkey, G. Hernandez, E. Brahmanto, Carlos Finol, Raed Ghali, M. Pandey, Sultan Alfaraedhi, Abdulrahman Abdulmajeed Gari, F. Marin","doi":"10.2523/iptc-22173-ms","DOIUrl":"https://doi.org/10.2523/iptc-22173-ms","url":null,"abstract":"\u0000 This paper describes the successful implementation of a methodology developed in a Deep Gas field in the Middle East with the intent of increasing the performance in a common intermediate hole section known for its arduous environment and common challenges including anomalous geological features, tight hole events, swelling shales, hole instability, and total losses while drilling scenarios. The initiatives and methodologies presented, are supported by the implementation of new tools and technologies including a drilling automation system, a novel drilling fluid and an experimental downhole mechanics measurement system. Collectively, the strategies implemented have led to a substantial increase in well construction efficiency and well delivery with a variety of applicable lessons for project teams facing similar challenges.\u0000 Initially the field was mapped to identify localized risks and adopt a region-based engineering approach to overcome the various challenges. A comprehensive risk assessment of the existing practices was completed with the objective to categorize possible areas of improvement and the specific needs to capture and record essential downhole data. Once the gaps and opportunities were identified, special tools were selected and deployed in both Memory and Real Time mode targeting the capture of drilling mechanics data and its variations across different formations and its incluence across the different components of the drill string. Initially data was captured only using the Measurement While Drilling tools (MWD) in the string, in searching for more specific data a new tool helped to measure the drilling mechanics downhole at different positions on the BHA. The collected data helped to understand the different behaviours in each component and the final output came as an optimized BHA that is today giving the best performance and has eliminated all the tool failures. In parallel, a pioneering thixotropic drilling fluid system was implemented aiming to improve the stability across different formations.\u0000 As part of second stage of the implementations, an opportunity was identified to increase the overall rate of penetration across the section while monitoring the equivalent circulating density. The initiatives were bolstered by the inclusion of automation systems which allowed to standarize the drilling process and more efficient. Thereby enabling gradual increase in operational limits in four sequential wells thus minimizing the time required for routine operations such as drill pipe connections, while beating all the previously established ROP records in this cemetery intermediate section.\u0000 The third stage was a replication model consisting of the identification of the gaps and main differences in performance across different rigs for each specific activity in this section, the definition of critical zones where the performance gets naturally affected due to various roadblocks and the identification of actions to tackle and brin","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"8 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79500663","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 Plug and Perf technique is the most common application used in completions or horizontal wells that require multistage hydraulic fracturing. Once the horizontal well is drilled, cased, cemented and isolated - two runs of coiled tubing will be required. The first coil tubing run will be to clean up residual cement and the second run to convey the first set of perforating guns to the end of the well or toe. Once the perforating guns are initiated and perforated holes through the casing and cement into the formation, fluids can now be pumped into the formation. This injected fluid is required to push the WireLine bottom hole assembly (BHA), containing a frac plug to the target depth. The use of pressure-activated toe valves or Toe Injection Valve (TIV) in a completion string is yet another innovative approach to completing a horizontal well. This technology eliminates the need for perforating guns prior to a multi-stage hydraulic fracturing (frac) operation. Subsequently, the operator can greatly reduce costs when the need for coiled tubing (CT), wireline (WL), or workover rig (WOR) is no longer needed on location to convey perforating guns. However, if the completion is not equipped with Toe Injection Valve TIV or when injection rate through it is not adequate for wireline pump-down operations, or the toe valve (TIV) fails to open, in this cases the operator must rely on the conventional methods of perforating in order to achieve injection into the well and begin the frac operation. The conventional method will negate any cost savings that the TIV was designed to provide. In this paper will review cost effective solution using a motor BHA and abrasive perforator in tandem to clean-out, perforate make another clean out, test the infectivity and Pump acid if needed all in one run using by-pass abrasive tool.
{"title":"Pre-Intervention for Multistage Frac Operation: Abrasive Perforation Challenges and Lessons Learnt","authors":"Othmane Mezabia, Ahmed Amir Belkacemi","doi":"10.2523/iptc-22403-ea","DOIUrl":"https://doi.org/10.2523/iptc-22403-ea","url":null,"abstract":"\u0000 The Plug and Perf technique is the most common application used in completions or horizontal wells that require multistage hydraulic fracturing.\u0000 Once the horizontal well is drilled, cased, cemented and isolated - two runs of coiled tubing will be required. The first coil tubing run will be to clean up residual cement and the second run to convey the first set of perforating guns to the end of the well or toe. Once the perforating guns are initiated and perforated holes through the casing and cement into the formation, fluids can now be pumped into the formation. This injected fluid is required to push the WireLine bottom hole assembly (BHA), containing a frac plug to the target depth.\u0000 The use of pressure-activated toe valves or Toe Injection Valve (TIV) in a completion string is yet another innovative approach to completing a horizontal well. This technology eliminates the need for perforating guns prior to a multi-stage hydraulic fracturing (frac) operation. Subsequently, the operator can greatly reduce costs when the need for coiled tubing (CT), wireline (WL), or workover rig (WOR) is no longer needed on location to convey perforating guns.\u0000 However, if the completion is not equipped with Toe Injection Valve TIV or when injection rate through it is not adequate for wireline pump-down operations, or the toe valve (TIV) fails to open, in this cases the operator must rely on the conventional methods of perforating in order to achieve injection into the well and begin the frac operation.\u0000 The conventional method will negate any cost savings that the TIV was designed to provide.\u0000 In this paper will review cost effective solution using a motor BHA and abrasive perforator in tandem to clean-out, perforate make another clean out, test the infectivity and Pump acid if needed all in one run using by-pass abrasive tool.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"42 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84359155","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}
Since the inception of the modern concept of safety instrumented systems there has always been the need to bypass for many reasons, such as during start up, during process transitions, for maintenance, testing, repair, or replacement of faulty instruments. Bypasses are also referred to as inhibits, suppressions, forcing, impairments, or bridging, but regardless of the name, the process of enacting a bypass is risky. Why? When Safety Instrumented Functions (SIF) are bypassed there is an increased risk to operating facilities associated with the loss of the specific safety function. The extent of the increased risk is dependent on the consequence of the hazard involved (e.g. rupture, explosion, toxic exposure) and the other protective layers that have been designed into the facility. Bypasses intentionally designed into an Emergency Shutdown System (ESD) must be strictly controlled to minimize the risk to people, production, the environment, and profits. But the act of bypassing isn’t new. Traditional bypassing methods vary, for example: Hardwired-initiated bypass: Dedicated switches are connected to the inputs of the safety system to deactivate sensors and actuators, and then handled as part of the application program.Sensors and actuators are electrically isolated (disconnected) from the PLC (e.g. using clamps) and checked manually by special measures.Software-initiated bypass: Maintenance overrides initiated by serial communication to the safety system via an operator interface such as BPCS, DCS, SIS engineering tools or an independent HMI.
{"title":"A Bypass by Any Name is Risky. Time for a Rethink?","authors":"S. Elliott","doi":"10.2523/iptc-22358-ms","DOIUrl":"https://doi.org/10.2523/iptc-22358-ms","url":null,"abstract":"\u0000 Since the inception of the modern concept of safety instrumented systems there has always been the need to bypass for many reasons, such as during start up, during process transitions, for maintenance, testing, repair, or replacement of faulty instruments.\u0000 Bypasses are also referred to as inhibits, suppressions, forcing, impairments, or bridging, but regardless of the name, the process of enacting a bypass is risky. Why?\u0000 When Safety Instrumented Functions (SIF) are bypassed there is an increased risk to operating facilities associated with the loss of the specific safety function. The extent of the increased risk is dependent on the consequence of the hazard involved (e.g. rupture, explosion, toxic exposure) and the other protective layers that have been designed into the facility. Bypasses intentionally designed into an Emergency Shutdown System (ESD) must be strictly controlled to minimize the risk to people, production, the environment, and profits.\u0000 But the act of bypassing isn’t new. Traditional bypassing methods vary, for example: Hardwired-initiated bypass: Dedicated switches are connected to the inputs of the safety system to deactivate sensors and actuators, and then handled as part of the application program.Sensors and actuators are electrically isolated (disconnected) from the PLC (e.g. using clamps) and checked manually by special measures.Software-initiated bypass: Maintenance overrides initiated by serial communication to the safety system via an operator interface such as BPCS, DCS, SIS engineering tools or an independent HMI.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85211239","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. Kwak, Jun Gao, Y. An, Muhammad Kasule, P. Doyle, A. Kleinhammes, Yue Wu
Reservoir wettability is a parameter of crucial importance for oil recovery1. However, its definition and its measurement are quite complex. For a flat surface, wettability is directly related to the contact angle of a water droplet on a surface controlled by the hydrophilicity of the surface. For an arbitrary surface, the contact angle, however, does not only depend on the hydrophilicity of the surface but also depends on the surface roughness at various length scales. Therefore, wetting is a macroscopic property that is only directly related to the hydrophilicity of the surface if the surface is flat and smooth. The hydrophilicity of the surface is a microscopic property that determined the surface interactions with water and hydrocarbons and plays a crucial role in oil production and recovery. The unknown surface roughness of internal surfaces of rock porous media makes wettability definition and measurement of such internal surfaces extremely challenging. Identifying a wettability index of porous media surfaces with broad applicability is a primary objective in oil and gas industry. Here we demonstrate an NMR-detected isotherm technique for measuring surface wettability of porous media. This technique is not only related directly to the traditional measure of wettability using macroscopic contact angles, it is also directly related to the microscopic surface property of hydrophilicity. It is shown that NMR-detected isotherms of both water and isopropanol (IPA) are needed to obtain the wettability index. Through systematic studies of quartz glass beads and quartz slides that are hydrophilic- or hydrophobic-modified, we established a quantitative relationship between the NMR isotherm-based wettability index and the traditional measure of wettability using contact angle. Therefore, the proposed wettability index derived from NMR isotherms provides a clear link to both macroscopic and microscopic properties of internal surfaces of porous media and can be a reliable measure of interactions between water and hydrocarbon with internal surfaces of rock porous media, as evidenced by preliminary studies of rock samples.
{"title":"Connection Between Wettability and NMR-Detected Isotherms","authors":"H. Kwak, Jun Gao, Y. An, Muhammad Kasule, P. Doyle, A. Kleinhammes, Yue Wu","doi":"10.2523/iptc-22408-ea","DOIUrl":"https://doi.org/10.2523/iptc-22408-ea","url":null,"abstract":"\u0000 Reservoir wettability is a parameter of crucial importance for oil recovery1. However, its definition and its measurement are quite complex. For a flat surface, wettability is directly related to the contact angle of a water droplet on a surface controlled by the hydrophilicity of the surface. For an arbitrary surface, the contact angle, however, does not only depend on the hydrophilicity of the surface but also depends on the surface roughness at various length scales. Therefore, wetting is a macroscopic property that is only directly related to the hydrophilicity of the surface if the surface is flat and smooth. The hydrophilicity of the surface is a microscopic property that determined the surface interactions with water and hydrocarbons and plays a crucial role in oil production and recovery. The unknown surface roughness of internal surfaces of rock porous media makes wettability definition and measurement of such internal surfaces extremely challenging. Identifying a wettability index of porous media surfaces with broad applicability is a primary objective in oil and gas industry.\u0000 Here we demonstrate an NMR-detected isotherm technique for measuring surface wettability of porous media. This technique is not only related directly to the traditional measure of wettability using macroscopic contact angles, it is also directly related to the microscopic surface property of hydrophilicity. It is shown that NMR-detected isotherms of both water and isopropanol (IPA) are needed to obtain the wettability index. Through systematic studies of quartz glass beads and quartz slides that are hydrophilic- or hydrophobic-modified, we established a quantitative relationship between the NMR isotherm-based wettability index and the traditional measure of wettability using contact angle. Therefore, the proposed wettability index derived from NMR isotherms provides a clear link to both macroscopic and microscopic properties of internal surfaces of porous media and can be a reliable measure of interactions between water and hydrocarbon with internal surfaces of rock porous media, as evidenced by preliminary studies of rock samples.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78495731","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}
Seismic acquisition system is the most essential equipment in seismic exploration for oil and gas. Quality, efficiency, and accuracy of seismic data acquisition play the most important role in oil and gas exploration. True wireless seismic exploration is of great significance in "cost decreasing and benefit increasing" in oil and gas industrial. Seismometer and its supporting software are core equipment in seismic acquisition. With build-in features of eMBB, uRLLC and mMTC, 5G provides a good opportunity in developing wireless real-time seismic acquisition system. This paper is mainly about R&D progress of SmartPoint Seismic Data Acquisition System (SmartPoint system for short). Based on 5G, SmartPoint system consists of seismographs, software system, 5G networking system and auxiliary system. SmartPoint system takes good use of industry leading technology such as 5G, AI, Big Data and Cloud Computing to solve the difficulties of high economic and labor cost in seismic acquisition. Field test of SmartPoint system has shown some very promising results. From the current test result, we are confident to deduce that with the help of advanced communication and information technology, SmartPoint system will make seismic data acquisition much more efficient, economic, and less costly.
{"title":"SmartPoint Seismic Data Acquisition System","authors":"Zhixia Song, Qingfu Lin","doi":"10.2523/iptc-22676-ms","DOIUrl":"https://doi.org/10.2523/iptc-22676-ms","url":null,"abstract":"\u0000 Seismic acquisition system is the most essential equipment in seismic exploration for oil and gas. Quality, efficiency, and accuracy of seismic data acquisition play the most important role in oil and gas exploration. True wireless seismic exploration is of great significance in \"cost decreasing and benefit increasing\" in oil and gas industrial. Seismometer and its supporting software are core equipment in seismic acquisition.\u0000 With build-in features of eMBB, uRLLC and mMTC, 5G provides a good opportunity in developing wireless real-time seismic acquisition system. This paper is mainly about R&D progress of SmartPoint Seismic Data Acquisition System (SmartPoint system for short). Based on 5G, SmartPoint system consists of seismographs, software system, 5G networking system and auxiliary system.\u0000 SmartPoint system takes good use of industry leading technology such as 5G, AI, Big Data and Cloud Computing to solve the difficulties of high economic and labor cost in seismic acquisition. Field test of SmartPoint system has shown some very promising results. From the current test result, we are confident to deduce that with the help of advanced communication and information technology, SmartPoint system will make seismic data acquisition much more efficient, economic, and less costly.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73175250","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}
Alina Rogulina, A. Zaytsev, L. Ismailova, D. Kovalev, Klemens Katterbauer, A. Marsala
Determining and predicting reservoir formation properties for newly drilled wells represents a significant challenge for oil and gas companies. Extensive well logs are available only while or after drilling, and thus they bear substantial financial, technical, and operational risks. We propose a new machine learning data-based model for determining well properties similarity and further derive and predict well logs before drilling in a specific geological context. Our model starts with selecting crucial well intervals and aggregation of vital features that determine the petrophysical properties related to particular well layers. Then, a machine-learning algorithm uses this info as input to provide a similarity score between wells. Our fast-to-train nonlinear data-based model is a variant of gradient boosting. We show that this approach can work well in complex scenarios with missing data and inconsistent similarity measures. We compare the modern machine learning algorithms for the evaluation of well similarity models based on aggregated features. The algorithms include gradient boosting and baseline logistic regression models. Our assessment for a real well log dataset via group cross-validation demonstrates that the gradient boosting model pretty accurately identifies well similarity. The receiver operating characteristic quality metric (ROC AUC) is 0.824. The developed similarity learning framework provides a data-driven approach towards estimating well logs for planned and newly drilled wells. Therefore, it allows prediction, improves determination, and can drive an optimal selection of log measurements to be executed in a new well in a specific field / geological context.
{"title":"Similarity Learning for Well Logs Prediction Using Machine Learning Algorithms","authors":"Alina Rogulina, A. Zaytsev, L. Ismailova, D. Kovalev, Klemens Katterbauer, A. Marsala","doi":"10.2523/iptc-22067-ms","DOIUrl":"https://doi.org/10.2523/iptc-22067-ms","url":null,"abstract":"\u0000 Determining and predicting reservoir formation properties for newly drilled wells represents a significant challenge for oil and gas companies. Extensive well logs are available only while or after drilling, and thus they bear substantial financial, technical, and operational risks. We propose a new machine learning data-based model for determining well properties similarity and further derive and predict well logs before drilling in a specific geological context.\u0000 Our model starts with selecting crucial well intervals and aggregation of vital features that determine the petrophysical properties related to particular well layers. Then, a machine-learning algorithm uses this info as input to provide a similarity score between wells. Our fast-to-train nonlinear data-based model is a variant of gradient boosting. We show that this approach can work well in complex scenarios with missing data and inconsistent similarity measures.\u0000 We compare the modern machine learning algorithms for the evaluation of well similarity models based on aggregated features. The algorithms include gradient boosting and baseline logistic regression models. Our assessment for a real well log dataset via group cross-validation demonstrates that the gradient boosting model pretty accurately identifies well similarity. The receiver operating characteristic quality metric (ROC AUC) is 0.824.\u0000 The developed similarity learning framework provides a data-driven approach towards estimating well logs for planned and newly drilled wells. Therefore, it allows prediction, improves determination, and can drive an optimal selection of log measurements to be executed in a new well in a specific field / geological context.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78781938","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}
Stephen Adjei, S. Elkatatny, W. N. Aggrey, Y. Abdelraouf
Over the years, various cementitious materials have been investigated as a substitute for conventional cement. One example of these materials is geopolymer, a binder developed when an alkaline solution is used to activate materials containing alumina and silica. The use of this material is well established in the construction industry. In oil-well cementing, its feasibility is currently being investigated. An extensive survey on the various geopolymer studies has been conducted. The goal is to present a manuscript containing a summary of these studies. This will help researchers merge the knowledge acquired going forward. The study showed that the application of geopolymer in acidic and saline conditions, and in well plugging and abandonment operations. Additionally, geopolymer-mud compatibility and the impact of temperature on geopolymer systems have also been studied. In general, geopolymer systems show better performance, overcoming the limitations of the OPC systems. For instance, the geopolymer is more suited for CO2 sequestrations wells as it does not undergo a carbonation reaction which would result in degradation. Furthermore, geopolymers have superior performance in highly saline conditions and besides their compatibility with mud, a geopolymer-mud combination produces cementitious systems with enhanced properties.
{"title":"Extended Abstract: The Feasibility of Using Geopolymer in Oil-Well Cementing: A Review","authors":"Stephen Adjei, S. Elkatatny, W. N. Aggrey, Y. Abdelraouf","doi":"10.2523/iptc-22130-ms","DOIUrl":"https://doi.org/10.2523/iptc-22130-ms","url":null,"abstract":"\u0000 Over the years, various cementitious materials have been investigated as a substitute for conventional cement. One example of these materials is geopolymer, a binder developed when an alkaline solution is used to activate materials containing alumina and silica. The use of this material is well established in the construction industry. In oil-well cementing, its feasibility is currently being investigated.\u0000 An extensive survey on the various geopolymer studies has been conducted. The goal is to present a manuscript containing a summary of these studies. This will help researchers merge the knowledge acquired going forward.\u0000 The study showed that the application of geopolymer in acidic and saline conditions, and in well plugging and abandonment operations. Additionally, geopolymer-mud compatibility and the impact of temperature on geopolymer systems have also been studied. In general, geopolymer systems show better performance, overcoming the limitations of the OPC systems. For instance, the geopolymer is more suited for CO2 sequestrations wells as it does not undergo a carbonation reaction which would result in degradation. Furthermore, geopolymers have superior performance in highly saline conditions and besides their compatibility with mud, a geopolymer-mud combination produces cementitious systems with enhanced properties.","PeriodicalId":11027,"journal":{"name":"Day 3 Wed, February 23, 2022","volume":"84 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76100155","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：