Wan Muhammad Luqman Sazali, Sahriza Salwani Md Shah, M. S. Misnan, M. Z. Kashim, Ahmad Faris Othman, B. Kantaatmadja
When developing a high CO2 field, oil and gas companies must consider the best and most economical carbon capture and storage (CCS) plan. After considering the distance of the storage site and storage capacity, PETRONAS has identified 2 carbonate fields, known as X Field and N Field in East Malaysia as the potential CO2 storage site. Interestingly, both fields are different, as X field is a high CO2 green field, while N field is a depleted gas field. The research team’s initial hypothesis is that N Field would have more severe geochemical reaction between CO2, brine and carbonates compared to X Field, since X field is already saturated with CO2. In order to test the hypothesis, samples from these two fields were selected to undergo static batch reaction analysis, and changes in porosity were determined using Digital Core Analysis (DCA). Both X and N fields are carbonate gas fields, with aquifer zone located below gas zones. The aquifer zones are the preferable CO2 injection zone because the deeper the zone, the longer it will take for the plume migration to happen. For static batch reaction analysis, samples each field were selected from the aquifer zone. After Routine Core Analysis (RCA) and Quality Control (QC), the samples were scanned under the high resolution microCT scan, before they were saturated into the respective synthetic brine. After saturation is completed, both brine and samples were placed inside a batch reactor, where the reactor’s pressure and temperature are set according to the field’s pressure and temperature. Once stabilized, the supercritical CO2 is injected into the brine, and was left for 45 days with constant observation. After aging with supercritical CO2, the samples were then scanned under microCT scan once again, using the same resolution, before being analysed via image processing software. Using registration algorithm software, both pre and post CO2 aging images were overlapped and subtracted digitally. The difference images were analyzed to determine the change in porosity. Samples from X Field has around 1% p.u. increase in porosity, while samples from N field shows increment of 2% p.u. porosity. While N field (depleted field) has higher reaction compared to X field (high CO2) field as per hypothesis, the difference is very minimal, which is much less than expected. The usage of DCA in the analysis enabled the team to determine minute changes that were happening during CO2 batch reaction. Without DCA, the 1% changes usually regarded as equipment’s error margin. The next step would be modelling, where the lab results will be upscaling into field scale, for modelled longer period of time. Hence, although the porosity changes between X and N field are very small under laboratory condition, it can have greater impact in field scale.
{"title":"Comparison of Porosity Change Due to Geochemical Reaction between Samples from High CO2 Field and Depleted Field","authors":"Wan Muhammad Luqman Sazali, Sahriza Salwani Md Shah, M. S. Misnan, M. Z. Kashim, Ahmad Faris Othman, B. Kantaatmadja","doi":"10.2118/205818-ms","DOIUrl":"https://doi.org/10.2118/205818-ms","url":null,"abstract":"\u0000 When developing a high CO2 field, oil and gas companies must consider the best and most economical carbon capture and storage (CCS) plan. After considering the distance of the storage site and storage capacity, PETRONAS has identified 2 carbonate fields, known as X Field and N Field in East Malaysia as the potential CO2 storage site. Interestingly, both fields are different, as X field is a high CO2 green field, while N field is a depleted gas field. The research team’s initial hypothesis is that N Field would have more severe geochemical reaction between CO2, brine and carbonates compared to X Field, since X field is already saturated with CO2. In order to test the hypothesis, samples from these two fields were selected to undergo static batch reaction analysis, and changes in porosity were determined using Digital Core Analysis (DCA). Both X and N fields are carbonate gas fields, with aquifer zone located below gas zones. The aquifer zones are the preferable CO2 injection zone because the deeper the zone, the longer it will take for the plume migration to happen. For static batch reaction analysis, samples each field were selected from the aquifer zone. After Routine Core Analysis (RCA) and Quality Control (QC), the samples were scanned under the high resolution microCT scan, before they were saturated into the respective synthetic brine. After saturation is completed, both brine and samples were placed inside a batch reactor, where the reactor’s pressure and temperature are set according to the field’s pressure and temperature. Once stabilized, the supercritical CO2 is injected into the brine, and was left for 45 days with constant observation. After aging with supercritical CO2, the samples were then scanned under microCT scan once again, using the same resolution, before being analysed via image processing software. Using registration algorithm software, both pre and post CO2 aging images were overlapped and subtracted digitally. The difference images were analyzed to determine the change in porosity. Samples from X Field has around 1% p.u. increase in porosity, while samples from N field shows increment of 2% p.u. porosity. While N field (depleted field) has higher reaction compared to X field (high CO2) field as per hypothesis, the difference is very minimal, which is much less than expected. The usage of DCA in the analysis enabled the team to determine minute changes that were happening during CO2 batch reaction. Without DCA, the 1% changes usually regarded as equipment’s error margin. The next step would be modelling, where the lab results will be upscaling into field scale, for modelled longer period of time. Hence, although the porosity changes between X and N field are very small under laboratory condition, it can have greater impact in field scale.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"25 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87675200","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}
Some conventional drilling fluid additives utilized to adjust drilling fluid properties can lead to many issues related to personnel safety and the environment. Thus, there is a need for alternative materials that have less impact on personnel safety and the environment. Many researchers have begun to investigate new alternatives, one example is food wastes. Due to their eco-friendly properties and their vast availability, food wastes are a good candidate that can be exploited as drilling fluid additives. In this work, five different concentrations of eggshells powder (ESP) were added to a reference fluid and the mud weight was measured using mud balance to understand the effects of ESP on mud weight. The results were compared with five concentrations of two commonly used drilling fluid additives - calcium carbonate (CaCO3) and barite. The findings showed that the drilling fluid blends with ESP have significantly outperformed the drilling fluid blends with barite and CaCO3 and for all concentrations in terms of mud weight improvement. The second best blends in terms of mud weight enhancement were the blends with barite and followed by the blends CaCO3. In conclusion, food waste material - ESP outperforming two of the most common drilling fluid additives shows a potential for ESP and other food wastes to be utilized as drilling mud additives in the petroleum industry. This will reduce the harmful chemicals disposed to the environment, reduce exposure risks of drilling crews to harmful chemicals, minimize drilling fluid cost, and revolutionize the industry while contributing to the economy overall.
{"title":"Green Fluid Technology: How Food Wastes Can Revolutionize the Oil and Gas Industry","authors":"A. T. Al-Hameedi, H. Alkinani, S. Dunn-Norman","doi":"10.2118/205681-ms","DOIUrl":"https://doi.org/10.2118/205681-ms","url":null,"abstract":"\u0000 Some conventional drilling fluid additives utilized to adjust drilling fluid properties can lead to many issues related to personnel safety and the environment. Thus, there is a need for alternative materials that have less impact on personnel safety and the environment. Many researchers have begun to investigate new alternatives, one example is food wastes. Due to their eco-friendly properties and their vast availability, food wastes are a good candidate that can be exploited as drilling fluid additives. In this work, five different concentrations of eggshells powder (ESP) were added to a reference fluid and the mud weight was measured using mud balance to understand the effects of ESP on mud weight. The results were compared with five concentrations of two commonly used drilling fluid additives - calcium carbonate (CaCO3) and barite. The findings showed that the drilling fluid blends with ESP have significantly outperformed the drilling fluid blends with barite and CaCO3 and for all concentrations in terms of mud weight improvement. The second best blends in terms of mud weight enhancement were the blends with barite and followed by the blends CaCO3. In conclusion, food waste material - ESP outperforming two of the most common drilling fluid additives shows a potential for ESP and other food wastes to be utilized as drilling mud additives in the petroleum industry. This will reduce the harmful chemicals disposed to the environment, reduce exposure risks of drilling crews to harmful chemicals, minimize drilling fluid cost, and revolutionize the industry while contributing to the economy overall.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"96 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87698235","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}
Naser Al-Barazi, Faisal Al-naqa, M. Chouhan, A. Al-Mekhlef, Ashraf Mohammad Saleh, Ahmed N. F. Bahgat, M. Mustafa, Rashad Saleh, S. Abdelbaset, M. Al-Qnaai
This article presents a unique case study where operating company, Kuwait Oil Company (KOC), decided to make an attempt to perform open hole side-track through a very narrow side-track window along with other exiting conditions such as severe downhole losses and drill through very challenging formation. To deliver such project in first attempt requires very detailed planning, close coordination with various service partners such as directional drilling and cementing. Placing a good side-track cement plug in such formation was a challenge, and 2nd challenge to get kicked off from this narrow window in first attempt which was the key. In case of failure, whip stock option has to be planned as a contingency, which possess new challenging of opening a depleted zone leading to commingling low/high pressure formation which could cause a complicated problem such as borehole stability, leads to stuck pipe problem. Failure to side-track from open hole could end of planning to drill extra hole which required extra casing string to run which will put this project well over AFE and heavily impact on well objective. This open hole Side-track was planned because while drilling original hole (12 ¼" hole section) close to planned well TD, experienced complete losses. In attempt to cure the losses, LCM was pumped with no success. Performed thixotropic cement plug job for losses control. While performing thixotropic cement plug job, the cement flash set before finishing the displacement, leading to stuck string. After backing off string and fishing attempts, unable to recover the fish completely. Fish left in hole leading to only 68 ft of open hole window available to side-track where performing a cement job was impossible due to severe losses. Only way to secure the well is to try for open hole side-track. With existing sever loss situation for initiating open hole side-track was a serious challenge due to lack of side force and flow restriction to initiate the side-track. Extensive pre-job planning, peer review and risk assessment was done in coordination with various service partners to deliver such challenging side-track. A hazard analysis decision tree was established to pinpoint the risks and appropriate mitigation measures along with contingency plan put in place. A detailed side-track guidelines was shared and review with the field crew. The wellbore was successfully side-tracked through a challenging reactive shale formation in a first attempt using a customized kick-off BHA, which not only helped to avoid loss zone in side-tracked hole but also provide additional cost savings to the company. The good hole condition at the side-track point was important to enable smooth passing of the following directional BHA to achieve directional goals.
{"title":"Delivered Successfully an Open Hole Side-Track from Very Challenging Formation Through Very Narrow MD Window: A Case Study from Kuwait","authors":"Naser Al-Barazi, Faisal Al-naqa, M. Chouhan, A. Al-Mekhlef, Ashraf Mohammad Saleh, Ahmed N. F. Bahgat, M. Mustafa, Rashad Saleh, S. Abdelbaset, M. Al-Qnaai","doi":"10.2118/205545-ms","DOIUrl":"https://doi.org/10.2118/205545-ms","url":null,"abstract":"\u0000 This article presents a unique case study where operating company, Kuwait Oil Company (KOC), decided to make an attempt to perform open hole side-track through a very narrow side-track window along with other exiting conditions such as severe downhole losses and drill through very challenging formation. To deliver such project in first attempt requires very detailed planning, close coordination with various service partners such as directional drilling and cementing.\u0000 Placing a good side-track cement plug in such formation was a challenge, and 2nd challenge to get kicked off from this narrow window in first attempt which was the key. In case of failure, whip stock option has to be planned as a contingency, which possess new challenging of opening a depleted zone leading to commingling low/high pressure formation which could cause a complicated problem such as borehole stability, leads to stuck pipe problem. Failure to side-track from open hole could end of planning to drill extra hole which required extra casing string to run which will put this project well over AFE and heavily impact on well objective.\u0000 This open hole Side-track was planned because while drilling original hole (12 ¼\" hole section) close to planned well TD, experienced complete losses. In attempt to cure the losses, LCM was pumped with no success. Performed thixotropic cement plug job for losses control. While performing thixotropic cement plug job, the cement flash set before finishing the displacement, leading to stuck string. After backing off string and fishing attempts, unable to recover the fish completely. Fish left in hole leading to only 68 ft of open hole window available to side-track where performing a cement job was impossible due to severe losses. Only way to secure the well is to try for open hole side-track. With existing sever loss situation for initiating open hole side-track was a serious challenge due to lack of side force and flow restriction to initiate the side-track.\u0000 Extensive pre-job planning, peer review and risk assessment was done in coordination with various service partners to deliver such challenging side-track. A hazard analysis decision tree was established to pinpoint the risks and appropriate mitigation measures along with contingency plan put in place. A detailed side-track guidelines was shared and review with the field crew.\u0000 The wellbore was successfully side-tracked through a challenging reactive shale formation in a first attempt using a customized kick-off BHA, which not only helped to avoid loss zone in side-tracked hole but also provide additional cost savings to the company. The good hole condition at the side-track point was important to enable smooth passing of the following directional BHA to achieve directional goals.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"25 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80779672","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. Nazri, W. K. Anuar, Lucas Ignatius Avianto Nasution, Hayati Turiman, S. Shafie, Mohamad Mustaqim Mokhlis
Field S located in offshore Malaysia had been producing for more than 30 years with nearly 90% of current active strings dependent on gas lift assistance. Subsurface challenges encountered in this matured field such as management of increasing water-cut, sand production, and depleting reservoir pressure are one of key factors that drive the asset team to continuously monitor the performance of gaslifted wells to ensure better control of production thereby meeting target deliverability of the field. Hence, Gas Lift Optimization (GLOP) campaign was embarked in Field S to accelerate short term production with integration of Gas Lift Management Modules in Integrated Operations (IO). A workflow was created to navigate asset team in this campaign from performing gaslift health check, diagnostic and troubleshooting to data and model validation until execution prior to identification of GLOP candidates with facilitation from digital workflows. Digital Fields and Integrated Operations (IO) developed in Field S provided an efficient collaborative working environment to monitor field performance real time and optimize production continuously. Digital Fields comprises of multiple engineering workflows developed and operationalized to act as enablers for the asset team to quickly identify the low-hanging fruit opportunities. This paper will focus on entire cycle process of digital workflows with engineer's intervention in data hygiene and model validation, the challenges to implement GLOP, and results from the campaign in Field S.
{"title":"A Success Story in Managing and Optimising Gas Lift Wells in Matured Oil Field: Automated Workflows in Digital Fields as Enablers to Accelerate Opportunities Creation and Production Optimisation","authors":"A. Nazri, W. K. Anuar, Lucas Ignatius Avianto Nasution, Hayati Turiman, S. Shafie, Mohamad Mustaqim Mokhlis","doi":"10.2118/205576-ms","DOIUrl":"https://doi.org/10.2118/205576-ms","url":null,"abstract":"\u0000 Field S located in offshore Malaysia had been producing for more than 30 years with nearly 90% of current active strings dependent on gas lift assistance. Subsurface challenges encountered in this matured field such as management of increasing water-cut, sand production, and depleting reservoir pressure are one of key factors that drive the asset team to continuously monitor the performance of gaslifted wells to ensure better control of production thereby meeting target deliverability of the field.\u0000 Hence, Gas Lift Optimization (GLOP) campaign was embarked in Field S to accelerate short term production with integration of Gas Lift Management Modules in Integrated Operations (IO). A workflow was created to navigate asset team in this campaign from performing gaslift health check, diagnostic and troubleshooting to data and model validation until execution prior to identification of GLOP candidates with facilitation from digital workflows.\u0000 Digital Fields and Integrated Operations (IO) developed in Field S provided an efficient collaborative working environment to monitor field performance real time and optimize production continuously. Digital Fields comprises of multiple engineering workflows developed and operationalized to act as enablers for the asset team to quickly identify the low-hanging fruit opportunities.\u0000 This paper will focus on entire cycle process of digital workflows with engineer's intervention in data hygiene and model validation, the challenges to implement GLOP, and results from the campaign in Field S.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"26 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79296639","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}
Yan Ding, Meng Cui, Haiyang Wang, Zhao Fei, Xiaoming Shi, Kai Huang
While drilling into fracture zones, lost circulation frequently occurs, resulting in a waste of productive operation severe cases, the well's destruction. However, due to complex development mechanisms and high heterogeneity, identifying and predicting fractures is extremely difficult. This study proposes a new drilling loss prevention idea to evaluate fractured lost circulation risk using seismic and wellbore data by a novel neural network. The approach works in two steps. First, the fracture anisotropy of a lost circulation sample curve is computed and interpreted using well logs. Second, using seismic attributes as constraints, a novel neural network is used to develop a prediction model. The field application in the Sichuan basin verifies the method's efficacy and confirms the method's ability for predicting lost circulation probability both along the well trajectory and in regions away from the drilled wells.
{"title":"Predicting Seismic-Based Anisotropy for Prevent Pre-Drill Risk Using a Novel Type Neural Network","authors":"Yan Ding, Meng Cui, Haiyang Wang, Zhao Fei, Xiaoming Shi, Kai Huang","doi":"10.2118/205710-ms","DOIUrl":"https://doi.org/10.2118/205710-ms","url":null,"abstract":"\u0000 While drilling into fracture zones, lost circulation frequently occurs, resulting in a waste of productive operation severe cases, the well's destruction. However, due to complex development mechanisms and high heterogeneity, identifying and predicting fractures is extremely difficult. This study proposes a new drilling loss prevention idea to evaluate fractured lost circulation risk using seismic and wellbore data by a novel neural network. The approach works in two steps. First, the fracture anisotropy of a lost circulation sample curve is computed and interpreted using well logs. Second, using seismic attributes as constraints, a novel neural network is used to develop a prediction model. The field application in the Sichuan basin verifies the method's efficacy and confirms the method's ability for predicting lost circulation probability both along the well trajectory and in regions away from the drilled wells.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"8 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87433976","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}
T. Luu, Bomidi John Abhishek Raj, A. Magana-Mora, Alawi G. Alalsayednassir, G. Zhan
Drilling operations rely on learned expertise in monitoring the drilling performance data and the rock data to assess the dull condition of the drill bit. While human learning can subjectively pick up the indicators based on rig surface data streams, this information is highly convoluted with changes in rock and drilling data. Recent approaches for bit wear estimation also include model-based and traditional supervised machine learning methods, which are usually costly and time-consuming. In this study, we developed a bi-directional long short-term memory-based variational autoencoder (biLSTM-VAE) to project raw drilling data into a latent space in which the real-time bit-wear can be estimated. The proposed deep neural network was trained in an unsupervised manner, and the bit-wear estimation is demonstrated as an end-to-end process.
{"title":"Bi-Directional Long Short-Term Memory Variational Autoencoder for Real-Time Bit-Wear Estimation","authors":"T. Luu, Bomidi John Abhishek Raj, A. Magana-Mora, Alawi G. Alalsayednassir, G. Zhan","doi":"10.2118/205627-ms","DOIUrl":"https://doi.org/10.2118/205627-ms","url":null,"abstract":"\u0000 Drilling operations rely on learned expertise in monitoring the drilling performance data and the rock data to assess the dull condition of the drill bit. While human learning can subjectively pick up the indicators based on rig surface data streams, this information is highly convoluted with changes in rock and drilling data. Recent approaches for bit wear estimation also include model-based and traditional supervised machine learning methods, which are usually costly and time-consuming. In this study, we developed a bi-directional long short-term memory-based variational autoencoder (biLSTM-VAE) to project raw drilling data into a latent space in which the real-time bit-wear can be estimated. The proposed deep neural network was trained in an unsupervised manner, and the bit-wear estimation is demonstrated as an end-to-end process.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"42 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88929047","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}
Digital oilfield applications have been implemented in numerous operating companies to streamline processes and automate workflows to optimize oil and gas production in real-time. These applications are mostly deployed using traditional on-premises systems; where maintenance, accessibility and scalability serves as a major bottleneck for an efficient outcome. In addition to this challenge, the sector still faces limitations in data integration from disparate data sources, liberation of consolidated data for consumption and cross domain workflow orchestration of that data. The dimensional change brought by digital transformation strategies has paved a path for the Cloud- based solutions, which have recently gained momentum in the oil and gas industry pertaining to their wider accessibility, simpler customization, greater system stability and scalability to support larger amount of data in a performant way. To address the challenges mentioned earlier, we have embarked on a journey with Production Data Foundation which brings together production and equipment data from across an organization. In this paper, we will highlight how Production Data Foundation, hosted on the cloud, provides the underlying infrastructure, services, interfaces required to support and unify production data ingestion, workflow orchestration, and through the alignment of the common domain and digital concepts, improve collaboration between people in distinct roles, such as production engineers, reservoir engineers, drilling engineers, deployment engineers, software developers, data scientists, architects, and subject matter experts (SME) working with production operations products and solutions.
{"title":"A Step Change in the Digital Oilfield Arena: Cloud Computing and Workflow Integration for Production Operations Solutions","authors":"Aditya Kotiyal, G. Nagaraj, Lester Tugung Michael","doi":"10.2118/205761-ms","DOIUrl":"https://doi.org/10.2118/205761-ms","url":null,"abstract":"\u0000 Digital oilfield applications have been implemented in numerous operating companies to streamline processes and automate workflows to optimize oil and gas production in real-time. These applications are mostly deployed using traditional on-premises systems; where maintenance, accessibility and scalability serves as a major bottleneck for an efficient outcome. In addition to this challenge, the sector still faces limitations in data integration from disparate data sources, liberation of consolidated data for consumption and cross domain workflow orchestration of that data.\u0000 The dimensional change brought by digital transformation strategies has paved a path for the Cloud- based solutions, which have recently gained momentum in the oil and gas industry pertaining to their wider accessibility, simpler customization, greater system stability and scalability to support larger amount of data in a performant way.\u0000 To address the challenges mentioned earlier, we have embarked on a journey with Production Data Foundation which brings together production and equipment data from across an organization.\u0000 In this paper, we will highlight how Production Data Foundation, hosted on the cloud, provides the underlying infrastructure, services, interfaces required to support and unify production data ingestion, workflow orchestration, and through the alignment of the common domain and digital concepts, improve collaboration between people in distinct roles, such as production engineers, reservoir engineers, drilling engineers, deployment engineers, software developers, data scientists, architects, and subject matter experts (SME) working with production operations products and solutions.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81657115","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. Bachtiar, O. Octaviani, Iqbal Fauzi, Sayak Roy, Lena Brunet-Errard, M. Mascle
Indonesian oil and gas reserves have been depleting since 2000 with no major addition of new oil reserves. Therefore, it is imperative to increase national oil production by optimizing the mature fields through the implementation of successful EOR technology. Out of this approach, a comprehensive study has been carried out on the targeted field by exploring the potential of surfactant-polymer (SP) flooding. This article describes the formulation design, optimization, and lessons learned leading up to a successful and robust chemical EOR formulation designing for a low permeability and high clay (>20% clay) containing Indonesian oil field. The detailed workflow consists of analysis of fluid and rock characterization, tailor-made SP formulation designing, optimization and coreflood validation as presented in previous papers (Bazin, 2010). A series of surfactant formulation were designed and screened synthetically through a validated High Throughput Screening (HTS) methodology using a robotic platform combined with microfluidic tools for ultra-low interfacial tension (IFT), solubility, compatibility with brine and polymer. Rock mineralogy has played an important role due to heterogeneity and very high (>20%) clay content. Surfactants retention through adsorption on reservoir rocks was the main constraint to achieve high performance and economical chemical EOR for the targeted field. Specific strategies by optimizing the surfactant formulation and by injecting adsorption inhibitor thus needed to be deployed to mitigate high surfactant retention. The detailed laboratory screening experiments conclude that the designed robust SP formulation is able to induce ultra-low IFT, excellent solubility and compatibility at the injection water salinity. The dynamic coreflood experiment using reservoir rock shows high incremental oil recovery (>60% ROIP) in short SP slug injection. As expected from the nature of rock, adsorption was the main challenge encountered during the course of this study, which resulted in a very promising oil recovery in economically realistic conditions.
{"title":"Designing a Robust Surfactant Based SP Formulation in High Clay Containing Low Permeability Indonesian Field","authors":"A. Bachtiar, O. Octaviani, Iqbal Fauzi, Sayak Roy, Lena Brunet-Errard, M. Mascle","doi":"10.2118/205566-ms","DOIUrl":"https://doi.org/10.2118/205566-ms","url":null,"abstract":"\u0000 Indonesian oil and gas reserves have been depleting since 2000 with no major addition of new oil reserves. Therefore, it is imperative to increase national oil production by optimizing the mature fields through the implementation of successful EOR technology. Out of this approach, a comprehensive study has been carried out on the targeted field by exploring the potential of surfactant-polymer (SP) flooding. This article describes the formulation design, optimization, and lessons learned leading up to a successful and robust chemical EOR formulation designing for a low permeability and high clay (>20% clay) containing Indonesian oil field.\u0000 The detailed workflow consists of analysis of fluid and rock characterization, tailor-made SP formulation designing, optimization and coreflood validation as presented in previous papers (Bazin, 2010). A series of surfactant formulation were designed and screened synthetically through a validated High Throughput Screening (HTS) methodology using a robotic platform combined with microfluidic tools for ultra-low interfacial tension (IFT), solubility, compatibility with brine and polymer. Rock mineralogy has played an important role due to heterogeneity and very high (>20%) clay content. Surfactants retention through adsorption on reservoir rocks was the main constraint to achieve high performance and economical chemical EOR for the targeted field. Specific strategies by optimizing the surfactant formulation and by injecting adsorption inhibitor thus needed to be deployed to mitigate high surfactant retention.\u0000 The detailed laboratory screening experiments conclude that the designed robust SP formulation is able to induce ultra-low IFT, excellent solubility and compatibility at the injection water salinity. The dynamic coreflood experiment using reservoir rock shows high incremental oil recovery (>60% ROIP) in short SP slug injection.\u0000 As expected from the nature of rock, adsorption was the main challenge encountered during the course of this study, which resulted in a very promising oil recovery in economically realistic conditions.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89423182","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
M. Mirza, H. Saadi, R. Trejo, R. Kayumov, A. Hilal
Karim and Haradh reservoirs within the Karim Small Fields (KSF) cluster in the South of the Sultanate of Oman are characterized by low to medium permeability and significant heterogeneity and contain medium to heavy crude oil. Reservoir depths are in the range of 1500 to 2000 m and productive areas are relatively small (around 2 km2 per field). Over the past 10 years, fields development did not result in sustained oil production despite the close well spacing. Geological and reservoir studies indicated that this is mainly due to the heterogeneity, lack of reservoir continuity and presence of significant wellbore damage in most wells. Accordingly, the KSF operator initiated an appraisal campaign focusing on hydraulic fracturing to stimulate the producing wells and improve the extension of their drainage areas. This campaign resulted in significant improvement in well productivity and the analysis of results indicates good potential for improving the ultimate oil recovery from these reservoirs. Although the results from hydraulic fracturing campaign are encouraging, they also indicate that appropriate selection of well candidates, key parameters in the fracturing procedure, effects of well completion and impact of well age are very important for successful oil gain. As a result, a comprehensive procedure for selecting and ranking candidate wells for hydraulic fracturing in Karim and Haradh formations has been developed. The procedure includes assessing the impacts of key properties such as fracture height, depth of oil-water contact, thickness of oil column, and distance to faults. In addition, the lessons learned from the previous appraisal campaign will contribute to achieving optimum fracture geometry in future campaigns. The candidate selection workflow involves understanding the geology, geomechanics, and petrophysics of the wells in which a fracturing operation was performed previously in different formations in KSF. More than 20 existing wells were screened through the candidate selection process using a clear workflow to incorporate all the relevant aspects of the selection criteria. The outcome of the candidate selection phase led to selection of the best wells for fracturing operations in the Karim and Haradh formations. The improvements on the fracturing design have been followed to obtain the optimum fracturing design for the selected wells.
{"title":"Novel Approach for Selecting Well Candidates and Appropriate Design of Hydraulic Fracturing in Challenging Reservoirs","authors":"M. Mirza, H. Saadi, R. Trejo, R. Kayumov, A. Hilal","doi":"10.2118/205646-ms","DOIUrl":"https://doi.org/10.2118/205646-ms","url":null,"abstract":"\u0000 Karim and Haradh reservoirs within the Karim Small Fields (KSF) cluster in the South of the Sultanate of Oman are characterized by low to medium permeability and significant heterogeneity and contain medium to heavy crude oil. Reservoir depths are in the range of 1500 to 2000 m and productive areas are relatively small (around 2 km2 per field).\u0000 Over the past 10 years, fields development did not result in sustained oil production despite the close well spacing. Geological and reservoir studies indicated that this is mainly due to the heterogeneity, lack of reservoir continuity and presence of significant wellbore damage in most wells. Accordingly, the KSF operator initiated an appraisal campaign focusing on hydraulic fracturing to stimulate the producing wells and improve the extension of their drainage areas. This campaign resulted in significant improvement in well productivity and the analysis of results indicates good potential for improving the ultimate oil recovery from these reservoirs.\u0000 Although the results from hydraulic fracturing campaign are encouraging, they also indicate that appropriate selection of well candidates, key parameters in the fracturing procedure, effects of well completion and impact of well age are very important for successful oil gain. As a result, a comprehensive procedure for selecting and ranking candidate wells for hydraulic fracturing in Karim and Haradh formations has been developed. The procedure includes assessing the impacts of key properties such as fracture height, depth of oil-water contact, thickness of oil column, and distance to faults. In addition, the lessons learned from the previous appraisal campaign will contribute to achieving optimum fracture geometry in future campaigns.\u0000 The candidate selection workflow involves understanding the geology, geomechanics, and petrophysics of the wells in which a fracturing operation was performed previously in different formations in KSF. More than 20 existing wells were screened through the candidate selection process using a clear workflow to incorporate all the relevant aspects of the selection criteria. The outcome of the candidate selection phase led to selection of the best wells for fracturing operations in the Karim and Haradh formations. The improvements on the fracturing design have been followed to obtain the optimum fracturing design for the selected wells.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89610681","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 development effect of low permeability reservoirs of offshore Shahejie Formation in China is poor with fast formation pressure drop, rapid production decline and numerous abnormal wells due to the influence of low permeability, strong heterogeneity, ultra-high reservoir temperature and pressure and high wax and asphaltene content. To overcome these difficulties, this paper takes geological conditions, reservoir potential, stimulation technology and actual wells situation into consideration on the basis of the reservoir performance research, and gives full play to the integration of reservoir and mechanical recovery. A set of production enhancement and efficiency improvement technologies has been formed, including moderate periodic water injection based on pressure fluctuation theory, liquid extraction optimization for low permeability fields, modified compound plugging removal technology, small flowrate and broad width electric pump selection technology, and pump stuck early warning technique to achieve the efficient development of offshore low-permeability oilfields. Moderate periodic water injection not only makes full use of the imbibition effect to achieve the equilibrium displacement, but also avoids the water channeling in fracture area; eight main controlling factors are used to classify and evaluate the liquid extraction potential and select the well group at level-1 for the workover with the effect of daily oil increase of 42 m3; modified compound plugging removal technique completely removes the pollution and plugging of the formation and the wellbore to release the potential of the oil wells to the greatest extent and cumulative oil increase of 6 well times is expected to be 12.44×104 m3; small flowrate and broad width electric pump selection technology applied for more than 30 well times improves the adaptability of the pumps substantially and extends the pump inspection cycle to 857 days; real-time pump stuck warning technique through the dual pattern of analyzing both conventional and high-frequency data guarantees the efficient operation of oil wells. The technologies in this paper have been applied in the target low-permeability field with daily oil production of 429 m3, oil recovery rate of 1.1%, natural decline rate drop year by year and the expected recovery factor of 20.9% under current well pattern. The key technologies in this paper have improved the target reservoir development effect significantly and provided important reference significance for other offshore low-permeability reservoirs development.
{"title":"Best Practices in Development and Production Optimization of Offshore Low Permeability Reservoir","authors":"Lijian Zhang, Panpan Tian, Chuanheng Xing, Ruiting Bai, Yanjun Yin, Quanzhi Li, Jianying Zhu, Qiang Zhang","doi":"10.2118/205613-ms","DOIUrl":"https://doi.org/10.2118/205613-ms","url":null,"abstract":"\u0000 The development effect of low permeability reservoirs of offshore Shahejie Formation in China is poor with fast formation pressure drop, rapid production decline and numerous abnormal wells due to the influence of low permeability, strong heterogeneity, ultra-high reservoir temperature and pressure and high wax and asphaltene content. To overcome these difficulties, this paper takes geological conditions, reservoir potential, stimulation technology and actual wells situation into consideration on the basis of the reservoir performance research, and gives full play to the integration of reservoir and mechanical recovery. A set of production enhancement and efficiency improvement technologies has been formed, including moderate periodic water injection based on pressure fluctuation theory, liquid extraction optimization for low permeability fields, modified compound plugging removal technology, small flowrate and broad width electric pump selection technology, and pump stuck early warning technique to achieve the efficient development of offshore low-permeability oilfields. Moderate periodic water injection not only makes full use of the imbibition effect to achieve the equilibrium displacement, but also avoids the water channeling in fracture area; eight main controlling factors are used to classify and evaluate the liquid extraction potential and select the well group at level-1 for the workover with the effect of daily oil increase of 42 m3; modified compound plugging removal technique completely removes the pollution and plugging of the formation and the wellbore to release the potential of the oil wells to the greatest extent and cumulative oil increase of 6 well times is expected to be 12.44×104 m3; small flowrate and broad width electric pump selection technology applied for more than 30 well times improves the adaptability of the pumps substantially and extends the pump inspection cycle to 857 days; real-time pump stuck warning technique through the dual pattern of analyzing both conventional and high-frequency data guarantees the efficient operation of oil wells. The technologies in this paper have been applied in the target low-permeability field with daily oil production of 429 m3, oil recovery rate of 1.1%, natural decline rate drop year by year and the expected recovery factor of 20.9% under current well pattern. The key technologies in this paper have improved the target reservoir development effect significantly and provided important reference significance for other offshore low-permeability reservoirs development.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"68 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73799196","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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