The wood quality is a factor of extreme importance when the pulping process is targeting high yield, low cost, and high pulp quality. Thus, wood knowledge is crucial for process optimization. In some northeastern Brazilian eucalyptus plantations, a physiological disturbance caused by water stress has been observed. Up to now, there have been no studies concerning the effects of such disturbances on the wood quality or on the pulping and bleaching process performance. The present work is aimed at understanding the impact of the stress on the production of bleached pulp. The wood quality of two clones (one tolerant to the disturbance and another sensitive), cultivated in sites where the disturbance is present and absent, was evaluated. Kraft pulps of kappa number 20 were produced and bleached by the sequence DHT(EP)D1 to a brightness of 90% ISO, which allowed for assessment of the wood pulpability and bleachability. It was concluded that the disturbance affects the wood quality, and overall it showed a negative impact on the production of bleached eucalyptus kraft pulp, with significant potential economical setbacks.
{"title":"Understanding the pulping and bleaching performances of eucalyptus woods affected by physiological disturbance","authors":"Juliana M. Jardim, C. M. Jardim, J. Colodette","doi":"10.32964/TJ17.11.633","DOIUrl":"https://doi.org/10.32964/TJ17.11.633","url":null,"abstract":"The wood quality is a factor of extreme importance when the pulping process is targeting high yield, low cost, and high pulp quality. Thus, wood knowledge is crucial for process optimization. In some northeastern Brazilian eucalyptus plantations, a physiological disturbance caused by water stress has been observed. Up to now, there have been no studies concerning the effects of such disturbances on the wood quality or on the pulping and bleaching process performance. The present work is aimed at understanding the impact of the stress on the production of bleached pulp. The wood quality of two clones (one tolerant to the disturbance and another sensitive), cultivated in sites where the disturbance is present and absent, was evaluated. Kraft pulps of kappa number 20 were produced and bleached by the sequence DHT(EP)D1 to a brightness of 90% ISO, which allowed for assessment of the wood pulpability and bleachability. It was concluded that the disturbance affects the wood quality, and overall it showed a negative impact on the production of bleached eucalyptus kraft pulp, with significant potential economical setbacks.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"74 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87387474","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 use of 50% concentration and 10% concentration hydrogen peroxide were evaluated for chemical and mechanical pulp bleach plants at storage and at point of use. Several dangerous occurrences have been documented when the supply of 50% peroxide going into the pulping process was not stopped during a process failure. Startup conditions and leaking block valves during maintenance outages have also contributed to explosions. Although hazardous events have occurred, 50% peroxide can be stored safely with proper precautions and engineering controls. For point of use in a chemical bleach plant, it is recommended to dilute the peroxide to 10% prior to application, because risk does not outweigh the benefit. For point of use in a mechanical bleach plant, it is recommended to use 50% peroxide going into a bleach liquor mixing system that includes the other chemicals used to maintain the brightening reaction rate. When 50% peroxide is used, it is critical that proper engineering controls are used to mitigate any risks.
{"title":"Understanding the risks and rewards of using 50% vs. 10% strength peroxide in pulp bleach plants","authors":"A. Rudie, P. Hart","doi":"10.32964/TJ17.11.601","DOIUrl":"https://doi.org/10.32964/TJ17.11.601","url":null,"abstract":"The use of 50% concentration and 10% concentration hydrogen peroxide were evaluated for chemical and mechanical pulp bleach plants at storage and at point of use. Several dangerous occurrences have been documented when the supply of 50% peroxide going into the pulping process was not stopped during a process failure. Startup conditions and leaking block valves during maintenance outages have also contributed to explosions. Although hazardous events have occurred, 50% peroxide can be stored safely with proper precautions and engineering controls. For point of use in a chemical bleach plant, it is recommended to dilute the peroxide to 10% prior to application, because risk does not outweigh the benefit. For point of use in a mechanical bleach plant, it is recommended to use 50% peroxide going into a bleach liquor mixing system that includes the other chemicals used to maintain the brightening reaction rate. When 50% peroxide is used, it is critical that proper engineering controls are used to mitigate any risks.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87336651","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 traditional kappa number method was developed in 1960 as a way to more quickly determine the level of lignin remaining in a completed or in-progress pulp. A significantly faster approach than the Klason lignin procedure, the kappa number method is based on the reaction of a strong oxidizing agent (KMnO4) with lignin and small amounts of other organic functional groups present in the pulp, such as hexenuronic acid. While the usefulness of the kappa number for providing information about bleaching requirements and pulp properties has arguably transformed the pulp and paper industry, it has been mostly developed for kraft, sulfite, and soda wood pulps. Nonwood species have a different chemical makeup than hardwood or softwood sources. These chemical differ-ences can influence kappa and Klason measurements on the pulp and lead to wide ranges of error. Both original data from Sustainable Fiber Technologies’ sulfur and chlorine-free pulping process and kappa and Klason data from various nonwood pulp literature sources will be presented to challenge the assumption that the kappa number accurately represents lignin content in nonwood pulps.
{"title":"Does the kappa number method accurately reflect lignin content in nonwood pulps?","authors":"S. Burkhardt","doi":"10.32964/TJ17.11.611","DOIUrl":"https://doi.org/10.32964/TJ17.11.611","url":null,"abstract":"The traditional kappa number method was developed in 1960 as a way to more quickly determine the level of lignin remaining in a completed or in-progress pulp. A significantly faster approach than the Klason lignin procedure, the kappa number method is based on the reaction of a strong oxidizing agent (KMnO4) with lignin and small amounts of other organic functional groups present in the pulp, such as hexenuronic acid. While the usefulness of the kappa number for providing information about bleaching requirements and pulp properties has arguably transformed the pulp and paper industry, it has been mostly developed for kraft, sulfite, and soda wood pulps. Nonwood species have a different chemical makeup than hardwood or softwood sources. These chemical differ-ences can influence kappa and Klason measurements on the pulp and lead to wide ranges of error. Both original data from Sustainable Fiber Technologies’ sulfur and chlorine-free pulping process and kappa and Klason data from various nonwood pulp literature sources will be presented to challenge the assumption that the kappa number accurately represents lignin content in nonwood pulps.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"10 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85199569","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}
Steady-state models were constructed to predict the response of a southern U.S. softwood brown¬stock to three- and five-stage elemental chlorine-free (ECF) bleach sequences. The models provided insight into how typical (EO) washing efficiencies from a vacuum drum unit affected pulp brightening and total chlorine dioxide con¬sumption. When (EO) carryover was between 15% and 30%, the chlorine dioxide needed to reach target brightness increased by 8% to 15% for the D0(EO)D1(EP)D2 sequence (89% ISO) and by 15% to 23% for the D0(EO)D1 sequence (86% ISO) versus perfect washing. Use of (EO) filtrate as D0 shower water, such as in split-flow countercurrent wash¬ing, caused the bleach uptake to increase by 1.5 to 3.0 kg chlorine dioxide (ClO2)/ton pulp when compared to using cleaner D0 shower water sources. The ClO2 consumed by 15% to 30% (EO) washer carryover is comparable to that consumed by typical carryover levels from brownstock washing (~10 kg Na2SO4/ton pulp). High (EO) carryover made ECF bleaching to higher brightness targets more difficult.
建立了稳态模型来预测美国南部软木棕色砧木对三级和五级无氯(ECF)漂白剂序列的反应。这些模型深入了解了真空转鼓装置的典型(EO)洗涤效率如何影响纸浆增白和二氧化氯总消耗。当(EO)残留在15%至30%之间时，与完美洗涤相比，D0(EO)D1(EP)D2序列(89% ISO)达到目标亮度所需的二氧化氯增加了8%至15%，D0(EO)D1序列(86% ISO)增加了15%至23%。使用(EO)滤液作为D0淋浴水，例如在分流逆流洗涤中，与使用更清洁的D0淋浴水源相比，每吨纸浆的漂白剂吸收量增加了1.5至3.0公斤二氧化氯(ClO2)。15%至30% (EO)洗涤残留所消耗的二氧化氯与褐煤洗涤的典型残留水平(~10 kg Na2SO4/吨纸浆)所消耗的二氧化氯相当。高(EO)残留使得ECF漂白到高亮度目标更加困难。
{"title":"Using multistage models to evaluate how pulp washing after the first extraction stage impacts elemental chlorine-free bleach demand","authors":"B. Brogdon, L. Lucia","doi":"10.32964/TJ17.11.621","DOIUrl":"https://doi.org/10.32964/TJ17.11.621","url":null,"abstract":"Steady-state models were constructed to predict the response of a southern U.S. softwood brown¬stock to three- and five-stage elemental chlorine-free (ECF) bleach sequences. The models provided insight into how typical (EO) washing efficiencies from a vacuum drum unit affected pulp brightening and total chlorine dioxide con¬sumption. When (EO) carryover was between 15% and 30%, the chlorine dioxide needed to reach target brightness increased by 8% to 15% for the D0(EO)D1(EP)D2 sequence (89% ISO) and by 15% to 23% for the D0(EO)D1 sequence (86% ISO) versus perfect washing. Use of (EO) filtrate as D0 shower water, such as in split-flow countercurrent wash¬ing, caused the bleach uptake to increase by 1.5 to 3.0 kg chlorine dioxide (ClO2)/ton pulp when compared to using cleaner D0 shower water sources. The ClO2 consumed by 15% to 30% (EO) washer carryover is comparable to that consumed by typical carryover levels from brownstock washing (~10 kg Na2SO4/ton pulp). High (EO) carryover made ECF bleaching to higher brightness targets more difficult.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"75 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86038967","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
S. Ramachandran, S. Lehrer, Soma Chakraborty, Jagrut Jani
Hydrogen sulfide (H2S) scavengers are used to reduce the total well operation cost of working with H2S by reducing the need for gas sweeting equipment, manpower costs for H2S monitoring, fines due to out of specification production and liability due to H2S release. Commonly used H2S scavengers such as triazine and glyoxal have limitations in different applications. When overspent, triazines can form difficult to remove solid deposits. The prescence of triazines in crude oil can lead to the formation of amine hydrochloride salts that cause corrosion in refinery operations. Glyoxal based H2S scavengers are acidic and can cause corrosion especially in stagnant pipelines containing oil and water. In this paper laboratory and field results are provided on new H2S scavengers that are both non-amine and neutral pH. The applications that are examined are batch tower applications and inline injection.
{"title":"Novel Scavenger Technology for Effective Removal of H2S from Produced Gas in Oilfield Applications","authors":"S. Ramachandran, S. Lehrer, Soma Chakraborty, Jagrut Jani","doi":"10.2118/192885-MS","DOIUrl":"https://doi.org/10.2118/192885-MS","url":null,"abstract":"\u0000 Hydrogen sulfide (H2S) scavengers are used to reduce the total well operation cost of working with H2S by reducing the need for gas sweeting equipment, manpower costs for H2S monitoring, fines due to out of specification production and liability due to H2S release. Commonly used H2S scavengers such as triazine and glyoxal have limitations in different applications. When overspent, triazines can form difficult to remove solid deposits. The prescence of triazines in crude oil can lead to the formation of amine hydrochloride salts that cause corrosion in refinery operations. Glyoxal based H2S scavengers are acidic and can cause corrosion especially in stagnant pipelines containing oil and water. In this paper laboratory and field results are provided on new H2S scavengers that are both non-amine and neutral pH. The applications that are examined are batch tower applications and inline injection.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"20 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73099185","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}
Elkin Arroyo Negrete, Steve Webb, J. Rodriguez, A. Mavromatidis, Ahmed Yahya Al Blooshi, M. Basioni
Optimal field development plans are often required to maximize reservoir recovery while keeping costs low. This paper discuss the details of how to select the optimal horizontal well trajectory that maximizes reservoir recovery for an interbedded thinly layered carbonate reservoir. The case study here was applied to one of the largest wet gas / gas condensate fields in the UAE. The development plan targets four different reservoirs using horizontal wells. Each reservoir has different rock qualities, and the top reservoir is not in communication with the three reservoirs below. Each reservoir contains 3-4 sub-layers with varying reservoir properties. Some of the sub-layers may not be in communication with the others, and the vertical communication could be poor. In order to maximize recovery, the development plan calls for placing the horizontal wells crossing from one sub-layer to another sub-layer. The problem is in deciding how long the horizontal well should stay in each sub-layer. Since there are four reservoirs and an average of three sub-layers per reservoir, there are twelve possible lateral placement options that control the well trajectory and length. The methodology presented in this paper utilizes Monte Carlo sampling to calculate the well trajectory that maximizes recovery. The methodology resembles the ideas of the Metropolis Algorithm used in the Marko Chain Monte Carlo. The starting point uses an arbitrary well trajectory. This well trajectory is run in the simulator, and the cumulative production is saved as a reference. Subsequently, the same distribution is sampled and the simulator is run again. If the resulting recovery is greater than the initial recovery or the recovery from any prior iteration step, then the newly found well trajectory is used as the new mean of the distribution, and the steps are repeated until simulated field recovery does not substantially increase.
{"title":"Finding the Optimal Horizontal Well Trajectory using Monte Carlo Techniques: Implementation Details and Case Study in Abu Dhabi, UAE","authors":"Elkin Arroyo Negrete, Steve Webb, J. Rodriguez, A. Mavromatidis, Ahmed Yahya Al Blooshi, M. Basioni","doi":"10.2118/192630-MS","DOIUrl":"https://doi.org/10.2118/192630-MS","url":null,"abstract":"\u0000 Optimal field development plans are often required to maximize reservoir recovery while keeping costs low. This paper discuss the details of how to select the optimal horizontal well trajectory that maximizes reservoir recovery for an interbedded thinly layered carbonate reservoir. The case study here was applied to one of the largest wet gas / gas condensate fields in the UAE. The development plan targets four different reservoirs using horizontal wells. Each reservoir has different rock qualities, and the top reservoir is not in communication with the three reservoirs below.\u0000 Each reservoir contains 3-4 sub-layers with varying reservoir properties. Some of the sub-layers may not be in communication with the others, and the vertical communication could be poor. In order to maximize recovery, the development plan calls for placing the horizontal wells crossing from one sub-layer to another sub-layer. The problem is in deciding how long the horizontal well should stay in each sub-layer. Since there are four reservoirs and an average of three sub-layers per reservoir, there are twelve possible lateral placement options that control the well trajectory and length. The methodology presented in this paper utilizes Monte Carlo sampling to calculate the well trajectory that maximizes recovery. The methodology resembles the ideas of the Metropolis Algorithm used in the Marko Chain Monte Carlo. The starting point uses an arbitrary well trajectory. This well trajectory is run in the simulator, and the cumulative production is saved as a reference. Subsequently, the same distribution is sampled and the simulator is run again. If the resulting recovery is greater than the initial recovery or the recovery from any prior iteration step, then the newly found well trajectory is used as the new mean of the distribution, and the steps are repeated until simulated field recovery does not substantially increase.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"28 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74344791","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}
Ultra Deepwater wells are commonly characterized by a narrow margin between pore and fracture gradients. Eni pioneer of the Continuous circulation technique has pushed the control of annulus dynamic pressure to the limit. The experience presented in this paper cover the drilling of an HPHT Deepwater well, through an ultra narrow PPFG window by means of technology application and strict procedural control. In the case study presented the reservoir section of an HPHT well was planned to be reached with an adequate kick tolerance and choke margin by applying the ENI near balance drilling technique (e-nbd™) in order to ensure strict control on the primary barrier and achieving the aimed operational and safety performance. The plan required the use of e-cd™ (eni circulating devices) system installed for the first time on a drilling ship with the 6 5/8″ DPs.
{"title":"Deepwater HPHT Drilling through Ultra Narrow PPFG Window: A Case Study by ENI Where the Combination of Continuous Circulation Technology Together with MPD Drilling has been Successfully Applied to Extreme Drilling Environment Condition in HPHT Ultra Deepwater Well","authors":"E. Squintani, A. Uslenghi, S. Ferrari, L. Affede","doi":"10.2118/192749-MS","DOIUrl":"https://doi.org/10.2118/192749-MS","url":null,"abstract":"\u0000 Ultra Deepwater wells are commonly characterized by a narrow margin between pore and fracture gradients. Eni pioneer of the Continuous circulation technique has pushed the control of annulus dynamic pressure to the limit. The experience presented in this paper cover the drilling of an HPHT Deepwater well, through an ultra narrow PPFG window by means of technology application and strict procedural control.\u0000 In the case study presented the reservoir section of an HPHT well was planned to be reached with an adequate kick tolerance and choke margin by applying the ENI near balance drilling technique (e-nbd™) in order to ensure strict control on the primary barrier and achieving the aimed operational and safety performance. The plan required the use of e-cd™ (eni circulating devices) system installed for the first time on a drilling ship with the 6 5/8″ DPs.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"47 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78409546","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}
Kamlesh Kumar, MohamedOsman. Azzazi., A. Hamdi, Zaidi Awang, C. Nicholls, Y. Lawati, H. Huseini, S. Abri, H. Sharji
The Upper Shuaiba reservoirs in Lekhwair consist of carbonate formations extending over a very large area (40 km × 40 km). Earlier development projects identified thicker, well-appraised formations, resulting in successful waterfloods. In contrast, challenges have been encountered in some of the waterflood pilots attempting to unlock future development areas. An integrated evaluation of these poor performing areas led to the development of a rock type catalogue that mapped out different rock types and their properties. Initial developments were mostly in high permeability rock types (Rudist Rich and Grainstone) whilst the underperforming pilots are associated with microporous rock characterized by low permeability (~1 mD) and thin formations (2-5m). These microporous rocks are associated with a large hydrocarbon volume in place. Resolving this development challenge is critical in maintaining the company's long-term production targets. Waterflood is the preferred development concept as it is in line with the existing facilities and infrastructure. The existing pilots demonstrate that low water injectivity/throughput is the key challenge to waterflood feasibility. Conventional acid stimulation does not work in these formations. Four different initiatives, in addition to injection water quality monitoring and improvements, are being tried to ensure successful maturation of microporous resources: Abrasive Jetting: used to create small tunnels up to 3m into the reservoir.Controlled Directional Acid Jetting: using acid to create multiple small laterals (up to 12 m in length) into the reservoir.Designer Acid: acid tailored to improve conventional acid stimulation.Fracture Aligned Sweep Technology (FAST) as implemented in Halfdan field; which creates longitudinal fractures along the length of the well. The outcome of this study includes identification and mapping of the different rocktypes across the entire Upper Shuaiba; waterflood performance assessment of microporous rocks and new technology trials to accelerate the development of microporous resources. Whilst abrasive jetting has achieved limited success in improving injectivity, result from designer acid stimulation was disappointing. The other two trials are still under evaluation. In case all the initiatives fail to establish the feasibility of waterflood, alternate developments mechanisms are proposed as Phase 2 in the strategy. This paper highlights how integration between different disciplines can help in maturation of a large resource volume, whilst accelerating its development by standardization of designs.
Lekhwair上帅坝储层由碳酸盐地层组成，面积非常大(40 km × 40 km)。早期的开发项目发现了较厚、评价良好的地层，并成功进行了注水开发。相比之下，在一些尝试开发未来开发区域的注水试验中遇到了挑战。对这些表现不佳的地区进行综合评估，形成了一份岩石类型目录，列出了不同的岩石类型及其性质。最初的开发主要是在高渗透岩石类型(Rudist Rich和Grainstone)中，而表现不佳的先导则与低渗透(~1 mD)和薄层(2-5m)的微孔岩石有关。这些微孔岩石与大量的碳氢化合物有关。解决这一开发挑战对于维持公司的长期生产目标至关重要。注水开发是首选的开发理念，因为它符合现有的设施和基础设施。现有的试验表明，低注入/吞吐能力是水驱可行性的关键挑战。常规的酸增产在这些地层中不起作用。为了确保微孔资源的成功成熟，除了对注水水质进行监测和改进外，还尝试了四种不同的措施:磨料喷射:用于在储层中创建长达3米的小隧道。可控定向酸喷射:使用酸在储层中形成多个小分支(长度不超过12米)。设计酸:为改善常规酸增产而定制的酸。裂缝对齐扫描技术(FAST)在Halfdan油田的应用这会沿着井的长度产生纵向裂缝。研究成果包括:对整个上帅坝地区的不同岩石类型进行了识别和制图;微孔岩石注水性能评价及新技术试验加快微孔资源开发虽然磨料喷射在提高注入能力方面取得了有限的成功，但设计酸刺激的结果令人失望。另外两项试验仍在评估中。如果所有的措施都不能确定水驱的可行性，则在策略的第二阶段提出替代开发机制。本文强调了不同学科之间的整合如何有助于大型资源量的成熟，同时通过标准化设计加速其发展。
{"title":"Strategy Towards Unlocking and Accelerated Development of Low Permeability, Microporous Reservoirs","authors":"Kamlesh Kumar, MohamedOsman. Azzazi., A. Hamdi, Zaidi Awang, C. Nicholls, Y. Lawati, H. Huseini, S. Abri, H. Sharji","doi":"10.2118/193339-MS","DOIUrl":"https://doi.org/10.2118/193339-MS","url":null,"abstract":"\u0000 The Upper Shuaiba reservoirs in Lekhwair consist of carbonate formations extending over a very large area (40 km × 40 km). Earlier development projects identified thicker, well-appraised formations, resulting in successful waterfloods. In contrast, challenges have been encountered in some of the waterflood pilots attempting to unlock future development areas. An integrated evaluation of these poor performing areas led to the development of a rock type catalogue that mapped out different rock types and their properties. Initial developments were mostly in high permeability rock types (Rudist Rich and Grainstone) whilst the underperforming pilots are associated with microporous rock characterized by low permeability (~1 mD) and thin formations (2-5m). These microporous rocks are associated with a large hydrocarbon volume in place. Resolving this development challenge is critical in maintaining the company's long-term production targets.\u0000 Waterflood is the preferred development concept as it is in line with the existing facilities and infrastructure. The existing pilots demonstrate that low water injectivity/throughput is the key challenge to waterflood feasibility. Conventional acid stimulation does not work in these formations. Four different initiatives, in addition to injection water quality monitoring and improvements, are being tried to ensure successful maturation of microporous resources: Abrasive Jetting: used to create small tunnels up to 3m into the reservoir.Controlled Directional Acid Jetting: using acid to create multiple small laterals (up to 12 m in length) into the reservoir.Designer Acid: acid tailored to improve conventional acid stimulation.Fracture Aligned Sweep Technology (FAST) as implemented in Halfdan field; which creates longitudinal fractures along the length of the well.\u0000 The outcome of this study includes identification and mapping of the different rocktypes across the entire Upper Shuaiba; waterflood performance assessment of microporous rocks and new technology trials to accelerate the development of microporous resources. Whilst abrasive jetting has achieved limited success in improving injectivity, result from designer acid stimulation was disappointing. The other two trials are still under evaluation. In case all the initiatives fail to establish the feasibility of waterflood, alternate developments mechanisms are proposed as Phase 2 in the strategy.\u0000 This paper highlights how integration between different disciplines can help in maturation of a large resource volume, whilst accelerating its development by standardization of designs.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"103 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84261334","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. Khalil, R. Martinez, M. Sudarev, Zainah Salem Al Agbari, A. Al-Ameri, M. Baslaib, Mohamed Ali Al-Attar, M. Albadi, Mohammed Ibrahim Al Janahi, Mohamed Salem Al-Hosani, Fouad Shamekh Al Badi
Onshore Drilling practices implemented in the past in congested environment had established the need to shut the surrounding gas wells within 2 km radius for time period of 3 weeks prior and during drilling of relevant reservoirs of the new well. This very conservative contingency process led to a significant reduction of gas production affecting meeting the targets. This study aims to determine the optimum drainage radius of gas wells to minimize the production deferment along with other operational risks without sacrificing safety. Drilling activities in a giant field has embedded many challenges. One of the major challenges is the one related with managing wellbore stability while drilling various reservoirs with different pressures, whereby the pore and fracture pressures are used as an important factor to design the mud weight to guarantee an optimum wellbore stability; however near-by wells either producers or injectors under flowing conditions would influence the severity of unexpected drilling issues such as mud losses and/or gas kick while drilling new wells, since the collateral effect of the pressure drawdown would affect the vicinity of the new well being drilled affecting the reservoir pressure established on the well design. A detailed study was carried out assessing the impact of the drainage radius of the surrounding gas wells while drilling a new well; considering the whole range of rates and permeability found in the depletion or recycle reservoirs including also the shut in time period of the surrounding wells as an important additional variable. The drainage radius of gas producers and injectors (vertical and horizontal) were estimated using single gas phase pseudo steady state radial flow equations and bottom hole pressure surveys test data plus operational issues previously encountered. Meanwhile, the dimensionless radius, pressure and time were used to estimate the stabilization time required shut in period to reduce the collateral effect on the new well. Accordingly, a new criterion was developed to minimize the gas and condensate production impact taking into consideration the real effect that would be created by drilling a well within the 2 Km radius, assessing pressure variation on the wellbore radius considering permeability variation (100 – 30 – 1 md) along with Flow Variation (gas rate: 40 – 15 – 5 MMscf/d). Several sensitivities and analysis were made ending with very interesting conclusions along with a new shut in well selection criteria, including flow diagram with action parties, roles and responsibilities, and deliverables. The aim of the new process is to set a communication protocol between action parties and optimizing the number of surrounding wells to be shut-in. The New Offset Wells Shut-in Criteria developed for Drilling New Wells was implemented successfully without sacrificing safety, but also saving 46.5 Bscf of gas production, 2.6 MMstb of condensate and 4.5 Bscf of gas injection per year (i.e.
{"title":"Production Enhancement by Creating a New Shut-in Criteria and Process for Drilling New Wells without Jeopardizing HSE, Case Study- Abu Dhabi","authors":"I. Khalil, R. Martinez, M. Sudarev, Zainah Salem Al Agbari, A. Al-Ameri, M. Baslaib, Mohamed Ali Al-Attar, M. Albadi, Mohammed Ibrahim Al Janahi, Mohamed Salem Al-Hosani, Fouad Shamekh Al Badi","doi":"10.2118/192710-MS","DOIUrl":"https://doi.org/10.2118/192710-MS","url":null,"abstract":"\u0000 Onshore Drilling practices implemented in the past in congested environment had established the need to shut the surrounding gas wells within 2 km radius for time period of 3 weeks prior and during drilling of relevant reservoirs of the new well. This very conservative contingency process led to a significant reduction of gas production affecting meeting the targets. This study aims to determine the optimum drainage radius of gas wells to minimize the production deferment along with other operational risks without sacrificing safety.\u0000 Drilling activities in a giant field has embedded many challenges. One of the major challenges is the one related with managing wellbore stability while drilling various reservoirs with different pressures, whereby the pore and fracture pressures are used as an important factor to design the mud weight to guarantee an optimum wellbore stability; however near-by wells either producers or injectors under flowing conditions would influence the severity of unexpected drilling issues such as mud losses and/or gas kick while drilling new wells, since the collateral effect of the pressure drawdown would affect the vicinity of the new well being drilled affecting the reservoir pressure established on the well design.\u0000 A detailed study was carried out assessing the impact of the drainage radius of the surrounding gas wells while drilling a new well; considering the whole range of rates and permeability found in the depletion or recycle reservoirs including also the shut in time period of the surrounding wells as an important additional variable. The drainage radius of gas producers and injectors (vertical and horizontal) were estimated using single gas phase pseudo steady state radial flow equations and bottom hole pressure surveys test data plus operational issues previously encountered. Meanwhile, the dimensionless radius, pressure and time were used to estimate the stabilization time required shut in period to reduce the collateral effect on the new well.\u0000 Accordingly, a new criterion was developed to minimize the gas and condensate production impact taking into consideration the real effect that would be created by drilling a well within the 2 Km radius, assessing pressure variation on the wellbore radius considering permeability variation (100 – 30 – 1 md) along with Flow Variation (gas rate: 40 – 15 – 5 MMscf/d). Several sensitivities and analysis were made ending with very interesting conclusions along with a new shut in well selection criteria, including flow diagram with action parties, roles and responsibilities, and deliverables. The aim of the new process is to set a communication protocol between action parties and optimizing the number of surrounding wells to be shut-in.\u0000 The New Offset Wells Shut-in Criteria developed for Drilling New Wells was implemented successfully without sacrificing safety, but also saving 46.5 Bscf of gas production, 2.6 MMstb of condensate and 4.5 Bscf of gas injection per year (i.e.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"47 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77063676","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 significant portion of natural gas reserves around the world contain large quantities of sulfur species and carbon dioxide, which are often referred to as sour gas reservoirs. The IEA reports that more than 40% of the world's gas reserves are sour, with the number increasing to 60% for Middle Eastern gas reserves. Sulfur species, such as hydrogen sulfide (H2S), are highly corrosive when mixed with water and toxic to biological organisms. Compounds such as SO2 and SO3, which are derived from direct sour gas combustion, are also highly corrosive when mixed with water at the condensation temperature of sulfuric acid. Therefore, removal of H2S to trace levels from natural gas is typically considered as the first step of the utilization of sour gas for power generation. This paper presents a novel method which enables sour natural gas to be directly burned for power generation without pretreatment. Oxidized sulfur compounds are captured by limestone in the combustion process to eliminate downstream sulfur corrosion. The desulfurized flue gas then goes through a solids removal process before entering a gas turbine or a turbine expander for power generation. A steam cycle is used for waste heat recuperation from both the turbine exhaust stream and the solids stream to improve the cycle performance. Both air-combustion and oxy-combustion configurations were investigated and modeled using Aspen Plus. The design conditions of each cycle are within the operating envelope of commercially available equipment, including compressors, turbines and heat exchangers, enabling near-term deployment of the presented system. Aspen modeling results show the range of efficiency percentages for different cycles is from the low 40's to the low 50's on a Lower Heating Value (LHV) basis. Without pretreatment, the heating value of sulfur in the sour gas and the heat released from the limestone scrubbing process can be fully utilized for power generation, thus improving the cycle performance. Economic analyses estimate that the baseline air-combustion sour gas system with a conservative estimated Capex ($2142/kW) is 41% cheaper than NGCC in 2011, and is about 28% cheaper than advanced NGCC in 2022 on a simplified Levelized Cost of Electricity (LCOE) basis. The LCOE of the oxy-combustion sour gas system is estimated to be 53% lower than advanced NGCC in 2022 when the revenue from CO2 and Argon sales is taken into account. Therefore, the novel untreated sour gas combustion system presented in this paper enables the petroleum and power industries to use sour gas for power generation more efficiently and cost effectively, even with full carbon capture.
{"title":"A Novel Power Generation System Utilizing Un-treated Sour Gas Fuel","authors":"Lu Xi-jia, P. Miles, F. Brock, M. Mike","doi":"10.2118/192823-MS","DOIUrl":"https://doi.org/10.2118/192823-MS","url":null,"abstract":"\u0000 A significant portion of natural gas reserves around the world contain large quantities of sulfur species and carbon dioxide, which are often referred to as sour gas reservoirs. The IEA reports that more than 40% of the world's gas reserves are sour, with the number increasing to 60% for Middle Eastern gas reserves. Sulfur species, such as hydrogen sulfide (H2S), are highly corrosive when mixed with water and toxic to biological organisms. Compounds such as SO2 and SO3, which are derived from direct sour gas combustion, are also highly corrosive when mixed with water at the condensation temperature of sulfuric acid. Therefore, removal of H2S to trace levels from natural gas is typically considered as the first step of the utilization of sour gas for power generation. This paper presents a novel method which enables sour natural gas to be directly burned for power generation without pretreatment. Oxidized sulfur compounds are captured by limestone in the combustion process to eliminate downstream sulfur corrosion. The desulfurized flue gas then goes through a solids removal process before entering a gas turbine or a turbine expander for power generation. A steam cycle is used for waste heat recuperation from both the turbine exhaust stream and the solids stream to improve the cycle performance. Both air-combustion and oxy-combustion configurations were investigated and modeled using Aspen Plus. The design conditions of each cycle are within the operating envelope of commercially available equipment, including compressors, turbines and heat exchangers, enabling near-term deployment of the presented system. Aspen modeling results show the range of efficiency percentages for different cycles is from the low 40's to the low 50's on a Lower Heating Value (LHV) basis. Without pretreatment, the heating value of sulfur in the sour gas and the heat released from the limestone scrubbing process can be fully utilized for power generation, thus improving the cycle performance. Economic analyses estimate that the baseline air-combustion sour gas system with a conservative estimated Capex ($2142/kW) is 41% cheaper than NGCC in 2011, and is about 28% cheaper than advanced NGCC in 2022 on a simplified Levelized Cost of Electricity (LCOE) basis. The LCOE of the oxy-combustion sour gas system is estimated to be 53% lower than advanced NGCC in 2022 when the revenue from CO2 and Argon sales is taken into account. Therefore, the novel untreated sour gas combustion system presented in this paper enables the petroleum and power industries to use sour gas for power generation more efficiently and cost effectively, even with full carbon capture.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78541058","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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