Scale deposition has been known to occur in porous media when the existing fluid becomes supersaturated based on changes in the ambient pressures and temperatures. Studies have been performed on the generation of mathematical models for evaluating scales in radial flow. Scaling is a well-known problem in producing wells, and prediction models from thermodynamic and kinetic aspects have been provided, and methods have been addressed in the industry to solve this problem. In this study, calcite deposition in the reservoir during CO2 injection processes is evaluated deterministically. Limited studies have been performed on calcite scaling in porous media with a reservoir simulation tool. CO2 EOR and sequestration has been widely analyzed. However, the mineralization factor has only been looked at from a CO2 storage point of view. Some light on the possible effects of calcite precipitation has on oil production. Calcite scaling tends to reduce the cross-sectional flow area for fluids in the pores, thus resulting in a permeability reduction which hampers levels of oil production. In order to quantify scale deposition in porous media, four different simulation cases were studied: 1. CO2 storage in an aquifer model, 2.CO2 EOR in a Light-Oil reservoir model, 3.CO2 storage in an aquifer-like lab-scale core model along with sensitivities. For the field-scale aquifer case, the effect of temperature, salinity, and heterogeneity on calcite deposition in the aquifer. CO2-EOR along with miscible and immiscible CO2 flooding were studied, to visualize the presence of calcite precipitation and its impact on oil recovery.
{"title":"Towards a Deterministic Approach to Calcite Scaling in the Porous Media During CO2 Sequestration and Immiscible CO2 Flooding","authors":"Sajjaat Muhemmed, T. H. Kumar, A. H. Nasr-El-Din","doi":"10.4043/29836-ms","DOIUrl":"https://doi.org/10.4043/29836-ms","url":null,"abstract":"\u0000 Scale deposition has been known to occur in porous media when the existing fluid becomes supersaturated based on changes in the ambient pressures and temperatures. Studies have been performed on the generation of mathematical models for evaluating scales in radial flow. Scaling is a well-known problem in producing wells, and prediction models from thermodynamic and kinetic aspects have been provided, and methods have been addressed in the industry to solve this problem. In this study, calcite deposition in the reservoir during CO2 injection processes is evaluated deterministically. Limited studies have been performed on calcite scaling in porous media with a reservoir simulation tool. CO2 EOR and sequestration has been widely analyzed. However, the mineralization factor has only been looked at from a CO2 storage point of view. Some light on the possible effects of calcite precipitation has on oil production. Calcite scaling tends to reduce the cross-sectional flow area for fluids in the pores, thus resulting in a permeability reduction which hampers levels of oil production. In order to quantify scale deposition in porous media, four different simulation cases were studied: 1. CO2 storage in an aquifer model, 2.CO2 EOR in a Light-Oil reservoir model, 3.CO2 storage in an aquifer-like lab-scale core model along with sensitivities. For the field-scale aquifer case, the effect of temperature, salinity, and heterogeneity on calcite deposition in the aquifer. CO2-EOR along with miscible and immiscible CO2 flooding were studied, to visualize the presence of calcite precipitation and its impact on oil recovery.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"20 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74912474","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}
I. Cruz, A. Ramiro, D. Karunakaran, F. Nicoletti, G. Hepner, Luiz Lemos, M. Chiodo, J. Gouveia
The novel ‘Gimbal Joint Riser’ (GJR) device is an invention that allows for a free-hanging riser catenary configuration by providing the functionality of adding a ‘hinge’ or articulation in midway of the riser column. Such mid-length articulation allows that dynamic bending and compression at touchdown zone (TDZ) be reduced enough to get within acceptable design limits, what is not achievable with a traditional steel catenary riser (SCR) connected to a spread-moored FPSO in ultra-deep-water scenarios like Santos Basin in Brazil. The aim of the invention is to offer an economic competitive option to current state-of-the-art solution of applying Steel Lazy Wave Risers (SLWR), by eliminating the need of relatively expensive buoyancy modules. The objective of this paper is to present this new concept and simulations results.
{"title":"Gimbal Joint Riser: Enabling Free-Hanging and Buoyancy-Free Rigid Risers","authors":"I. Cruz, A. Ramiro, D. Karunakaran, F. Nicoletti, G. Hepner, Luiz Lemos, M. Chiodo, J. Gouveia","doi":"10.4043/29698-ms","DOIUrl":"https://doi.org/10.4043/29698-ms","url":null,"abstract":"\u0000 The novel ‘Gimbal Joint Riser’ (GJR) device is an invention that allows for a free-hanging riser catenary configuration by providing the functionality of adding a ‘hinge’ or articulation in midway of the riser column. Such mid-length articulation allows that dynamic bending and compression at touchdown zone (TDZ) be reduced enough to get within acceptable design limits, what is not achievable with a traditional steel catenary riser (SCR) connected to a spread-moored FPSO in ultra-deep-water scenarios like Santos Basin in Brazil. The aim of the invention is to offer an economic competitive option to current state-of-the-art solution of applying Steel Lazy Wave Risers (SLWR), by eliminating the need of relatively expensive buoyancy modules. The objective of this paper is to present this new concept and simulations results.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"291 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73408712","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}
Baronia field is located in Sarawak Operations, Miri and started production in the year 1973. It consists of two process complexes BN–A and BN–B. Each of these complexes has its own satellite vent platform which are BNV-A and BNV-B. In line with PETRONAS statement of purpose ‘A Progressive Energy and Solutions Partner Enriching Lives for a Sustainable Future’, the operators had initiated to adapt sustainability as a key element in PETRONAS operations. Aligned with BDO EOR PSC venting/flaring reduction roadmap, in 2010, SKO Reliability and Integrity Team were driving two vent to flare conversion project (BNV-A and BNV-B) to be incorporated. The BNV-A vent to flare conversion project was completed at a cost of USD 9.6 million. The high cost has raised concerns to the BNV-B vent to flare conversion project as it was considered a major investment with no expected economic revenue returns. A new project, BARDEGG-2/BN EOR, came up to develop a new Central Processing Platform (BNCPP-B) bridge linked to existing facilities (BNG-B), for processing of new Non Associated Gas (NAG) fields & EOR. BNCPP-B is designed with its own flaring system for the new facilities. The green field project team prefer not to touch any existing brown field scope to avoid complications. In view of this matter, SKO Operations Readiness & Strategic Assurance team (ORSA) has been able to come up with a brilliant idea of achieving zero continuous venting and cost optimization. The proposed innovative design is exclusively from SKO ORSA team and was supported by SKO Management. In this paper we will demonstrate the innovative approached by operators in order to achieve zero continuous flaring/venting in Baronia offshore field. The results and observations post the realization of design will also be discussed. The impact has been huge in terms of enhanced production continuity and plant reliability, maximized environmental sustainability by reduction of greenhouse gas emissions, and major cost savings.
{"title":"Reduction of CAPEX & Optimization of OPEX with Innovative Ideas by Integration with Brown Field and Green Field Development to Achieve Zero Venting","authors":"R. Sunnapu, Ahmad Anas B Awang","doi":"10.4043/29806-ms","DOIUrl":"https://doi.org/10.4043/29806-ms","url":null,"abstract":"\u0000 Baronia field is located in Sarawak Operations, Miri and started production in the year 1973. It consists of two process complexes BN–A and BN–B. Each of these complexes has its own satellite vent platform which are BNV-A and BNV-B.\u0000 In line with PETRONAS statement of purpose ‘A Progressive Energy and Solutions Partner Enriching Lives for a Sustainable Future’, the operators had initiated to adapt sustainability as a key element in PETRONAS operations. Aligned with BDO EOR PSC venting/flaring reduction roadmap, in 2010, SKO Reliability and Integrity Team were driving two vent to flare conversion project (BNV-A and BNV-B) to be incorporated. The BNV-A vent to flare conversion project was completed at a cost of USD 9.6 million. The high cost has raised concerns to the BNV-B vent to flare conversion project as it was considered a major investment with no expected economic revenue returns.\u0000 A new project, BARDEGG-2/BN EOR, came up to develop a new Central Processing Platform (BNCPP-B) bridge linked to existing facilities (BNG-B), for processing of new Non Associated Gas (NAG) fields & EOR. BNCPP-B is designed with its own flaring system for the new facilities. The green field project team prefer not to touch any existing brown field scope to avoid complications.\u0000 In view of this matter, SKO Operations Readiness & Strategic Assurance team (ORSA) has been able to come up with a brilliant idea of achieving zero continuous venting and cost optimization. The proposed innovative design is exclusively from SKO ORSA team and was supported by SKO Management.\u0000 In this paper we will demonstrate the innovative approached by operators in order to achieve zero continuous flaring/venting in Baronia offshore field. The results and observations post the realization of design will also be discussed. The impact has been huge in terms of enhanced production continuity and plant reliability, maximized environmental sustainability by reduction of greenhouse gas emissions, and major cost savings.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"115 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79528563","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}
During the last years, a lot of work have been done focusing on development of low shear valves solutions to be applied on petroleum primary process plants. The main goal of the low shear valve is to generate water-in-oil (WiO) and oil-in-water (OiW) emulsions that can be easier treated by the separation process, when compared with emulsion generated by conventional valves. This paper presents experimental results of a comparison between a commercial low shear valve and a conventional valve. Both valves were installedin parallel on a test loop and the fluids used for all test matrix points were potable water mixed with Petrobras Marlim Crude Oil. The test matrix includes variation of differential pressure on valves, flowrates and concentration of water/oil. Samples were collected downstream of both valves and led to settle into several residence times. The degree of contamination of both phases were analyzed for all residence times. The benefit of the application of low shear valve was quantified for all test conditions and the results were very promissory. The pressure drops across valves were selected considering typical values observed at Petrobras choke valves and control level valves. For almost all test matrix's points the emulsion generated by the low shear valve showed at least a slight benefit, allowing have better water quality after settling. The low shear valve solution showed to be a promissory technology but the magnitude of the benefit is very influenced by valve process operation conditions.
{"title":"Test Results of a Comparison between a Conventional and Low Shear Valve and Its Effect on Water/Oil Separation","authors":"A. Monteiro, Fabricio Soares da Silva","doi":"10.4043/29949-ms","DOIUrl":"https://doi.org/10.4043/29949-ms","url":null,"abstract":"\u0000 During the last years, a lot of work have been done focusing on development of low shear valves solutions to be applied on petroleum primary process plants. The main goal of the low shear valve is to generate water-in-oil (WiO) and oil-in-water (OiW) emulsions that can be easier treated by the separation process, when compared with emulsion generated by conventional valves.\u0000 This paper presents experimental results of a comparison between a commercial low shear valve and a conventional valve. Both valves were installedin parallel on a test loop and the fluids used for all test matrix points were potable water mixed with Petrobras Marlim Crude Oil. The test matrix includes variation of differential pressure on valves, flowrates and concentration of water/oil. Samples were collected downstream of both valves and led to settle into several residence times. The degree of contamination of both phases were analyzed for all residence times.\u0000 The benefit of the application of low shear valve was quantified for all test conditions and the results were very promissory. The pressure drops across valves were selected considering typical values observed at Petrobras choke valves and control level valves. For almost all test matrix's points the emulsion generated by the low shear valve showed at least a slight benefit, allowing have better water quality after settling. The low shear valve solution showed to be a promissory technology but the magnitude of the benefit is very influenced by valve process operation conditions.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88982583","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}
Renan Tapias, M. Mansour-Tehrani, Nina K. Langhelle
This paper presents detailed learnings into the dissection of a flexible riser section, which had been operating for seven (7) years and subjected to high rates of fatigue damage, after operational field changes. Detailed global and local fatigue analyses were performed to assess the response of the riser system taking into account significant changes between the design and the operational history. These environmental and operational changes were shown to have a negative impact on the fatigue performance of the risers, in particular the top section located inside the bend stiffner. Fatigue analyses are performed using field measured data such as vessel headings, internal pressures and environmental conditions, aiming to replicate the riser response history and calculate fatigue usage to date. Actual field data are shown to be more onerous than design data and therefore a detrimental fatigue response is expected. Results from detailed fatigue analysis shows that flexible risers fatigue usage were above the maximum allowable of 0.1, as outlined in API [1,2]. The most critical location was the pressure armour wires of the top section, located inside the bend stiffener. A mitigation plan was proposed, including an immediate reduction of internal pressure to reduce the risk of riser failure, and the removal of the fatigued riser top section. After removal of the fatigue critical section, the riser was re-terminated and its fatigue performance reinstated. The pipe section removed from operation was carefully dissected. Following the dissection, each riser layer was investigated to determine possible signs of degradation. Additionally, fatigue testing of both pressure and tensile armour wires were performed to determine potential fatigue degradation and confirm analyses findings. Dissection and fatigue tests have demonstrated that the pipe condition was better than expected, highlighting conservatisms in design and analyses methodologies. In-service inspection of flexible riser internal layers is highly complex, with no detailed insight of all the respective layers. Dissection of a flexible riser, in service for seven (7) years and exposed to high rates of fatigue damage, provides valuable information about the state of the different layers comprising the cross section. This is particularly useful since analytical work have shown the riser to have exceeded the fatigue limit of 0.1 as defined per API. The good state of the flexible riser, on the contrary to the prediction, highlights a good level of conservatism in flexible riser design and methodology.
{"title":"Flexible Riser Repair and Dissection Following Exceedance of API Fatigue Limit","authors":"Renan Tapias, M. Mansour-Tehrani, Nina K. Langhelle","doi":"10.4043/29824-ms","DOIUrl":"https://doi.org/10.4043/29824-ms","url":null,"abstract":"\u0000 This paper presents detailed learnings into the dissection of a flexible riser section, which had been operating for seven (7) years and subjected to high rates of fatigue damage, after operational field changes.\u0000 Detailed global and local fatigue analyses were performed to assess the response of the riser system taking into account significant changes between the design and the operational history. These environmental and operational changes were shown to have a negative impact on the fatigue performance of the risers, in particular the top section located inside the bend stiffner.\u0000 Fatigue analyses are performed using field measured data such as vessel headings, internal pressures and environmental conditions, aiming to replicate the riser response history and calculate fatigue usage to date. Actual field data are shown to be more onerous than design data and therefore a detrimental fatigue response is expected. Results from detailed fatigue analysis shows that flexible risers fatigue usage were above the maximum allowable of 0.1, as outlined in API [1,2]. The most critical location was the pressure armour wires of the top section, located inside the bend stiffener. A mitigation plan was proposed, including an immediate reduction of internal pressure to reduce the risk of riser failure, and the removal of the fatigued riser top section. After removal of the fatigue critical section, the riser was re-terminated and its fatigue performance reinstated.\u0000 The pipe section removed from operation was carefully dissected. Following the dissection, each riser layer was investigated to determine possible signs of degradation. Additionally, fatigue testing of both pressure and tensile armour wires were performed to determine potential fatigue degradation and confirm analyses findings. Dissection and fatigue tests have demonstrated that the pipe condition was better than expected, highlighting conservatisms in design and analyses methodologies.\u0000 In-service inspection of flexible riser internal layers is highly complex, with no detailed insight of all the respective layers. Dissection of a flexible riser, in service for seven (7) years and exposed to high rates of fatigue damage, provides valuable information about the state of the different layers comprising the cross section. This is particularly useful since analytical work have shown the riser to have exceeded the fatigue limit of 0.1 as defined per API. The good state of the flexible riser, on the contrary to the prediction, highlights a good level of conservatism in flexible riser design and methodology.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"92 13","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91522785","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. L. D’Almeida, Bruno de Paula Apolinário, Luiz F. C. Ribeiro
Local Content Policies are worldwide applied to oil and gas (O&G) exploration and production (E&P) contracts, in order to stimulate the national goods and services industry. This policy implements Local Content (LC) commitments in contracts for O&G exploration blocks. In this way, minimum LC percentages are established and supervised in Brazil by the National Agency of Petroleum, Natural Gas and Biofuels (ANP). Additionally, this minimum percentage is taken as a judgment criterion for the concession regime bidding rounds, as well as pre-established in Production Sharing and Onerous Cession contracts. In the past years, high levels of LC, coupled with oil price drop, have taken oil companies to request adjustment and/or exemption of this contractual commitment. Although provided for in E&P contracts, the mechanism regarding the exemption and adjustment of Local Content clauses had not yet been regulated by ANP until 2017. Then, in 2018 ANP approved Resolution No. 726/2018, defining clear and objective criteria for the request and its conditions. Therefore, this paper intent to present and analyze the history of local content policy in the Brazilian O&G industry, the regulatory framework, also evaluating the quantity of requests for changing CL commitments and ANP responses.
{"title":"Brazilian Local Content Policy: An Overview and Analisys of Adjustment Clauses Applications","authors":"A. L. D’Almeida, Bruno de Paula Apolinário, Luiz F. C. Ribeiro","doi":"10.4043/29696-ms","DOIUrl":"https://doi.org/10.4043/29696-ms","url":null,"abstract":"\u0000 Local Content Policies are worldwide applied to oil and gas (O&G) exploration and production (E&P) contracts, in order to stimulate the national goods and services industry. This policy implements Local Content (LC) commitments in contracts for O&G exploration blocks. In this way, minimum LC percentages are established and supervised in Brazil by the National Agency of Petroleum, Natural Gas and Biofuels (ANP). Additionally, this minimum percentage is taken as a judgment criterion for the concession regime bidding rounds, as well as pre-established in Production Sharing and Onerous Cession contracts. In the past years, high levels of LC, coupled with oil price drop, have taken oil companies to request adjustment and/or exemption of this contractual commitment. Although provided for in E&P contracts, the mechanism regarding the exemption and adjustment of Local Content clauses had not yet been regulated by ANP until 2017. Then, in 2018 ANP approved Resolution No. 726/2018, defining clear and objective criteria for the request and its conditions. Therefore, this paper intent to present and analyze the history of local content policy in the Brazilian O&G industry, the regulatory framework, also evaluating the quantity of requests for changing CL commitments and ANP responses.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"81 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87004295","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}
Offshore drilling is reaching for targets further from shore, at greater depths and in more hazardous geological settings such as in proximity to salt. All these factors heighten the risk of poorly managed mishaps evolving into a major emergency. Onshore monitoring centers observe numerous data feeds from the rig, analyzing the information for indicators of potentially dangerous situations. Such centers provide a broad cross-section of expertise to assist in understanding a problem and suggesting remedies. As MWD / LWD took hold in the 1990s, automatic data transfer protocols were used to interrogate servers on the rig and collect data waiting to be transmitted. This would deliver bursts of data 10 to 15 seconds after being acquired on the rig. To offer proper support in emergency situations, data needed to be lag-free. More data channels were needed to get a full picture. A complete re-think of the process to move data from rig to shore was needed. A new standard was developed and published that addressed the specific needs for 2-way data connections for offshore oil & gas, supporting streaming with 1-second lag times, and using one tenth of the bandwidth. This was achieved by defining a compact binary transfer with practically no overhead in the transmission process. A full-scale test was conducted to compare legacy data transmittal processes with the new standard, running both systems in parallel from the same drilling rig to the same onshore facility. The test confirmed the expected 10 to 15 second lag to retrieve data using the legacy approach. The new protocol delivered constant data flows with a lag time as little as 1 to 1.2 seconds after being acquired on the rig. Staff monitoring the data onshore could discuss observations contemporaneously with the rig crew since both were looking at the same data at the same time. In the event of a developing emergency affecting a deep-water drilling operation, the ability to share critical data readings in true real time among a broad constituency of shore-based actors together with the rig crew dramatically improves the ability to reach a fact-based conclusion among all parties in a timely manner. The standard transfer protocol will continue to evolve to better serve the needs of drillers and operators, and their effective management of emergencies.
{"title":"Improving Emergency Response with Better and Faster Remote Monitoring","authors":"P. Neri, R. Philo","doi":"10.4043/29713-ms","DOIUrl":"https://doi.org/10.4043/29713-ms","url":null,"abstract":"\u0000 Offshore drilling is reaching for targets further from shore, at greater depths and in more hazardous geological settings such as in proximity to salt. All these factors heighten the risk of poorly managed mishaps evolving into a major emergency. Onshore monitoring centers observe numerous data feeds from the rig, analyzing the information for indicators of potentially dangerous situations. Such centers provide a broad cross-section of expertise to assist in understanding a problem and suggesting remedies. As MWD / LWD took hold in the 1990s, automatic data transfer protocols were used to interrogate servers on the rig and collect data waiting to be transmitted. This would deliver bursts of data 10 to 15 seconds after being acquired on the rig. To offer proper support in emergency situations, data needed to be lag-free. More data channels were needed to get a full picture. A complete re-think of the process to move data from rig to shore was needed. A new standard was developed and published that addressed the specific needs for 2-way data connections for offshore oil & gas, supporting streaming with 1-second lag times, and using one tenth of the bandwidth. This was achieved by defining a compact binary transfer with practically no overhead in the transmission process. A full-scale test was conducted to compare legacy data transmittal processes with the new standard, running both systems in parallel from the same drilling rig to the same onshore facility. The test confirmed the expected 10 to 15 second lag to retrieve data using the legacy approach. The new protocol delivered constant data flows with a lag time as little as 1 to 1.2 seconds after being acquired on the rig. Staff monitoring the data onshore could discuss observations contemporaneously with the rig crew since both were looking at the same data at the same time. In the event of a developing emergency affecting a deep-water drilling operation, the ability to share critical data readings in true real time among a broad constituency of shore-based actors together with the rig crew dramatically improves the ability to reach a fact-based conclusion among all parties in a timely manner. The standard transfer protocol will continue to evolve to better serve the needs of drillers and operators, and their effective management of emergencies.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85927788","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}
Taisa Calvette, Allan Gurwicz, A. C. Abreu, M. Pacheco
As smart well technology is increasingly being adopted in oilfield development projects, the need to optimize controls emerged in order to justify its higher initial investment by considerably increasing net present value. While there are numerous methodologies to achieve this goal, a common fact in all is the need for a great number of computationally expensive reservoir simulations, hindering extensive optimizations. This paper proposes the use of deep learning algorithms in proxy models, in order to accurately replicate the behavior of the simulator by forecasting production based on previous data. Thus, a smaller number of simulations are required for a training dataset, and the proxy can then be used in lieu of the simulator for optimization purposes. Other benefits in the use of the proposed methodology include the gathering of insights on production, as problems might be occurring if measured production noticeably deviates from the forecast. Two case studies were done, and the results indicate that a Long Short-Term Memory Network-based proxy is able to forecast production with a remarkably low error, validating the methodology and supporting its use.
{"title":"Forecasting Smart Well Production via Deep Learning and Data Driven Optimization","authors":"Taisa Calvette, Allan Gurwicz, A. C. Abreu, M. Pacheco","doi":"10.4043/29861-ms","DOIUrl":"https://doi.org/10.4043/29861-ms","url":null,"abstract":"\u0000 As smart well technology is increasingly being adopted in oilfield development projects, the need to optimize controls emerged in order to justify its higher initial investment by considerably increasing net present value. While there are numerous methodologies to achieve this goal, a common fact in all is the need for a great number of computationally expensive reservoir simulations, hindering extensive optimizations. This paper proposes the use of deep learning algorithms in proxy models, in order to accurately replicate the behavior of the simulator by forecasting production based on previous data. Thus, a smaller number of simulations are required for a training dataset, and the proxy can then be used in lieu of the simulator for optimization purposes. Other benefits in the use of the proposed methodology include the gathering of insights on production, as problems might be occurring if measured production noticeably deviates from the forecast. Two case studies were done, and the results indicate that a Long Short-Term Memory Network-based proxy is able to forecast production with a remarkably low error, validating the methodology and supporting its use.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"22 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82448051","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}
Guilherme Freitas Melo, W. B. Filho, Rodrigo Freitas da Silva Alvarenga, M. Paes, D. C. Ferreira, S. Franco
High strength steels have large applicability in the gas and oil industry and are often used in aggressive environments, requiring the use of cathodic protection, with the consequent generation of atomic hydrogen in the cathode that may lead to hydrogen embrittlement, HE. The aim of this work was to evaluate the fracture toughness and HE susceptibility of two high strength steels, named as 38CrMo4 and 30CrMo6, used as components for oil extraction from the seabed. J-Δa curves for JIC evaluation were carried out following the ASTM E1820 [1] at room temperature in laboratorial air using C(T) specimen. For KTH evaluation the tests were based on NACE TM0177 standard [2], using sharply notched DCB specimens. For this test a 3.5 wt% NaCl aqueous solution with −1.2 V cathodic protection for the in-situ hydrogen charging were used. From the results it was observed that both steels presented predominantly martensitic/bainitic microstructures, with 30CrMo6 steel exhibiting lower mechanical strength and higher total elongation. The great microstructural differences rely mainly on the prior austenite grain size and in the S and Ca contents. 30CrMo6 steel presented a very fine prior austenite grain and mostly spherical CaS inclusions instead of the elongated MnS. These microstructural features lead to much higher KJIC value and it did not exhibit HE in the conditions analyzed here.
{"title":"Structural Integrity of HSLA Steels under Hydrogen Embrittlement Condition","authors":"Guilherme Freitas Melo, W. B. Filho, Rodrigo Freitas da Silva Alvarenga, M. Paes, D. C. Ferreira, S. Franco","doi":"10.4043/29962-ms","DOIUrl":"https://doi.org/10.4043/29962-ms","url":null,"abstract":"\u0000 High strength steels have large applicability in the gas and oil industry and are often used in aggressive environments, requiring the use of cathodic protection, with the consequent generation of atomic hydrogen in the cathode that may lead to hydrogen embrittlement, HE. The aim of this work was to evaluate the fracture toughness and HE susceptibility of two high strength steels, named as 38CrMo4 and 30CrMo6,\u0000 used as components for oil extraction from the seabed. J-Δa curves for JIC evaluation were carried out following the ASTM E1820 [1] at room temperature in laboratorial air using C(T) specimen. For KTH evaluation the tests were based on NACE TM0177 standard [2], using sharply notched DCB specimens. For this test a 3.5 wt% NaCl aqueous solution with −1.2 V cathodic protection for the in-situ hydrogen charging were used. From the results it was observed that both steels presented predominantly martensitic/bainitic microstructures, with 30CrMo6 steel exhibiting lower mechanical strength and higher total elongation. The great microstructural differences rely mainly on the prior austenite grain size and in the S and Ca contents. 30CrMo6 steel presented a very fine prior austenite grain and mostly spherical CaS inclusions instead of the elongated MnS. These microstructural features lead to much higher KJIC value and it did not exhibit HE in the conditions analyzed here.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"111 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82464070","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}
Providing an overview of an ensemble of oil reservoir models could help users compare and analyze their characteristics. Approaches that show a single model at a time may hamper analysts’ understanding of the whole model set. In this paper, we propose two visualization approaches that show multiple reservoir models, simultaneously and on a single screen, with the goal of helping users to compare models and improve their understanding of ensemble characteristics. First, we calculate 2D models from the ensemble's 3D models. We then create two visualizations that represent ensembles of these 2D models. The Small Multiples approach lays out heatmaps of 2D models side-by-side on a grid. Pixelization approach shows n 2D models in a single heatmap, where each cell (i, j) contains n subcells that represent values in the coordinate (i, j) of each model. Both approaches display their elements (heatmaps and subcells) clustered by X-means, which may help analysts identify similarities and representative models in the ensemble. We used two types of distance matrices: based on Euclidean distance of models for a given property or, based on Euclidean distance of feature vectors of the 2D models. We tested our approaches within models based on Brazilian benchmark cases corresponding to a turbiditic reservoir (UNISIM-I-D/M/H) and a presalt carbonatic reservoir (UNISIM-II-D). As a result, the Small Multiples approach presented clusters of similar models for some properties of the ensembles we studied, e.g. eight clusters of porosity values in UNISIM-II-D's ensemble. This fact suggests that eight representative models can represent the ensemble, regarding porosity. Also, a Pixelization approach revealed patterns that happen in specific regions of all models of an ensemble, such as an abrupt change of porosity values in the northwest region of UNISIM-I-M's models. Both approaches have the potential to help analysts perceive situations that would be improbable to observe in a graph with only mean values for each cell. Therefore, our proposal can be helpful to users who need to deal with uncertainties and have an overview of ensembles of models for better understanding and decisionmaking, e.g. when they need to choose representative models for a process of decision analysis related to petroleum field development and management.
{"title":"Visualization of Ensembles of Oil Reservoir Models Based on Pixelization, Small Multiples and Reservoir Similarities","authors":"C. G. Silva, A. A. S. Santos, D. Schiozer","doi":"10.4043/29788-ms","DOIUrl":"https://doi.org/10.4043/29788-ms","url":null,"abstract":"\u0000 Providing an overview of an ensemble of oil reservoir models could help users compare and analyze their characteristics. Approaches that show a single model at a time may hamper analysts’ understanding of the whole model set. In this paper, we propose two visualization approaches that show multiple reservoir models, simultaneously and on a single screen, with the goal of helping users to compare models and improve their understanding of ensemble characteristics. First, we calculate 2D models from the ensemble's 3D models. We then create two visualizations that represent ensembles of these 2D models. The Small Multiples approach lays out heatmaps of 2D models side-by-side on a grid. Pixelization approach shows n 2D models in a single heatmap, where each cell (i, j) contains n subcells that represent values in the coordinate (i, j) of each model. Both approaches display their elements (heatmaps and subcells) clustered by X-means, which may help analysts identify similarities and representative models in the ensemble. We used two types of distance matrices: based on Euclidean distance of models for a given property or, based on Euclidean distance of feature vectors of the 2D models. We tested our approaches within models based on Brazilian benchmark cases corresponding to a turbiditic reservoir (UNISIM-I-D/M/H) and a presalt carbonatic reservoir (UNISIM-II-D). As a result, the Small Multiples approach presented clusters of similar models for some properties of the ensembles we studied, e.g. eight clusters of porosity values in UNISIM-II-D's ensemble. This fact suggests that eight representative models can represent the ensemble, regarding porosity. Also, a Pixelization approach revealed patterns that happen in specific regions of all models of an ensemble, such as an abrupt change of porosity values in the northwest region of UNISIM-I-M's models. Both approaches have the potential to help analysts perceive situations that would be improbable to observe in a graph with only mean values for each cell. Therefore, our proposal can be helpful to users who need to deal with uncertainties and have an overview of ensembles of models for better understanding and decisionmaking, e.g. when they need to choose representative models for a process of decision analysis related to petroleum field development and management.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"52 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84927781","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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