首页 > 最新文献

Day 3 Thu, October 25, 2018最新文献

英文 中文
Alleviating the Solids Issue in Surat Basin CSG Wells 缓解Surat盆地CSG井固相问题
Pub Date : 2018-10-19 DOI: 10.2118/191923-MS
D. Kalinin, D. Choo, Ashley Watling, Hai Liu, L. K. Teng, Gog Soo Hui
A system for reducing solids production in Surat basin coal seam gas (CSG) wells was developed in the laboratory and tested in the laboratory and field trials. Several thousand CSG wells were completed in Surat basin in eastern Australia using what was considered an economic method at a time - an open hole with a predrilled liner. Although the majority of the wells are meeting production expectations, a many wells are producing a substantial amount of solids originating from an interburden rock representing approximately 90% of completed interval length and comprising mudstones, sandstones, and siltstones rich in illite/smectite and other water-sensitive clays. Relatively fresh water, with total dissolved solids (TDS) of approximately 4000 to 7000 mg/l, produced from multiple thin coal seams during dewatering and production phases is causing the interburden rock to swell or disintegrate. Prolific wells with high water rates or high gas velocity are capable of carrying solids to the surface where the solids are deposited in separators, flowlines, and water-treatment settling ponds. Higher solids concentration on lower-rate wells are causing issues with positive cavity pumps (PCP), the artificial lift method of choice in CSG wells. Pump intake plugging with solids, excessive torque and rotation seizure, and wear of tubing/rod strings are frequent causes of workovers and shorter-than-expected pump run-life. Some wells are able to flow freely; however, an extra monitoring program is required to ensure wellheads are not suffering from solids-induced erosion. Recompletion of the wells is not considered practical at this stage because pre-perforated joints form an integral part of the 5 ½-in. or 7-in. casing string, which is cemented above the Walloons subgroup coal seams. An external casing packer (ECP) is often used. Some coal seams were underreamed, thus further complicating recompletion. Plugging existing wells and drilling a pair of wells using same surface location and infrastructure have been considered. A chemical wellbore stabilization solution been developed to alleviate/stop solids production from the interburden rock. The treatment comprises two fluids separated by a spacer that contains clay stabilizer that is typically 3 to 7% KCl, the same as drilling mud base. Proprietary surfactant reduces the possibility of coal damage. Regained permeability testing performed using crushed and sieved coal pack plugs indicated a low level of damage. The wellbore stabilization system could be energized/foamed to reduce hydrostatic pressure and increase compressibility, hence increasing the chance of contacting rock surface in an enlarged wellbore.
在实验室开发了一套降低Surat盆地煤层气(CSG)井固相产量的系统,并在实验室和现场试验中进行了测试。在澳大利亚东部的Surat盆地,数千口CSG井使用了当时被认为是经济的方法——裸眼预钻尾管。虽然大多数井达到了预期产量,但许多井产生了大量固体物质,这些固体物质来自于占完井段长度约90%的夹层岩,包括泥岩、砂岩、富含伊利石/蒙脱石和其他水敏粘土的粉砂岩。多个薄煤层在脱水和生产阶段产生的相对新鲜的水,总溶解固体(TDS)约为4000至7000 mg/l,导致夹层岩石膨胀或崩解。高产水率或高气速的高产井能够将固体带到地面,并将固体沉积在分离器、管线和水处理沉淀池中。低排量井中较高的固体浓度会导致正腔泵(PCP)出现问题,而正腔泵是CSG井中首选的人工举升方法。泵进气口固体堵塞、扭矩过大、旋转卡死、油管/抽油杆磨损是修井和泵运行寿命短的常见原因。有些井可以自由流动;然而,需要额外的监测程序来确保井口不会受到固体侵蚀。由于预射孔接头是5 - 1 / 2 -in井眼的一个组成部分,因此在此阶段对井进行再完井并不可行。或7。套管柱,在Walloons亚组煤层上方固井。通常使用外套管封隔器(ECP)。一些煤层扩眼不足,进一步增加了再完井的难度。在相同的地面位置和基础设施上,堵漏现有井和钻一对井已经被考虑过。开发了一种化学井筒稳定溶液,以减轻/阻止层间岩石产生固体。该处理包括两种流体,由含有粘土稳定剂的隔离剂分开,通常含有3%至7%的KCl,与钻井泥浆基础相同。专有的表面活性剂降低了破坏煤的可能性。使用破碎和筛过的煤塞进行的渗透性测试表明,损伤程度很低。井筒稳定系统可以通过注入/发泡来降低静水压力,提高可压缩性,从而在扩大的井筒中增加与岩石表面接触的机会。
{"title":"Alleviating the Solids Issue in Surat Basin CSG Wells","authors":"D. Kalinin, D. Choo, Ashley Watling, Hai Liu, L. K. Teng, Gog Soo Hui","doi":"10.2118/191923-MS","DOIUrl":"https://doi.org/10.2118/191923-MS","url":null,"abstract":"\u0000 A system for reducing solids production in Surat basin coal seam gas (CSG) wells was developed in the laboratory and tested in the laboratory and field trials.\u0000 Several thousand CSG wells were completed in Surat basin in eastern Australia using what was considered an economic method at a time - an open hole with a predrilled liner.\u0000 Although the majority of the wells are meeting production expectations, a many wells are producing a substantial amount of solids originating from an interburden rock representing approximately 90% of completed interval length and comprising mudstones, sandstones, and siltstones rich in illite/smectite and other water-sensitive clays. Relatively fresh water, with total dissolved solids (TDS) of approximately 4000 to 7000 mg/l, produced from multiple thin coal seams during dewatering and production phases is causing the interburden rock to swell or disintegrate. Prolific wells with high water rates or high gas velocity are capable of carrying solids to the surface where the solids are deposited in separators, flowlines, and water-treatment settling ponds. Higher solids concentration on lower-rate wells are causing issues with positive cavity pumps (PCP), the artificial lift method of choice in CSG wells. Pump intake plugging with solids, excessive torque and rotation seizure, and wear of tubing/rod strings are frequent causes of workovers and shorter-than-expected pump run-life. Some wells are able to flow freely; however, an extra monitoring program is required to ensure wellheads are not suffering from solids-induced erosion.\u0000 Recompletion of the wells is not considered practical at this stage because pre-perforated joints form an integral part of the 5 ½-in. or 7-in. casing string, which is cemented above the Walloons subgroup coal seams. An external casing packer (ECP) is often used. Some coal seams were underreamed, thus further complicating recompletion. Plugging existing wells and drilling a pair of wells using same surface location and infrastructure have been considered.\u0000 A chemical wellbore stabilization solution been developed to alleviate/stop solids production from the interburden rock. The treatment comprises two fluids separated by a spacer that contains clay stabilizer that is typically 3 to 7% KCl, the same as drilling mud base. Proprietary surfactant reduces the possibility of coal damage. Regained permeability testing performed using crushed and sieved coal pack plugs indicated a low level of damage. The wellbore stabilization system could be energized/foamed to reduce hydrostatic pressure and increase compressibility, hence increasing the chance of contacting rock surface in an enlarged wellbore.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"132 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88799808","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}
引用次数: 0
Truly Rigless: A World First Through 3-1/2" Tubing Cable Deployed Electrical Submersible Pump on a Live Well 真正的无钻机:世界上首次在油井上部署3-1/2”油管电缆的电动潜水泵
Pub Date : 2018-10-19 DOI: 10.2118/192100-MS
Amirul Adha Bin Amsidom, Elsayed Ouda Ghonim, Euan Alexander, K. Kuswanto, Bakhtiyor Abdullaev, H. Hassan, M. F. Ishak, Benny Rajah, Puvethra Nair Gunasegaran, Kamal Ayad, B. Madon, M. A. Hamzah, Kautsar Zamanuri
About 80% of brownfields in Malaysia use Gas Lift as the artificial lift method. Though it is widely used, the operators are facing numerous challenges which include shortages in gas lift source and compressor reliability issues. Consequently fields’ productivity is impacted and results in higher operating expenditure. A case of change from Gas Lift to ESP was studied however due to high rig costs many of these the projects are uneconomic. Given this is the case PETRONAS had been researching the use of high speed slim, power- cable deployed ESPs for installation inside 2- 7/8" and 3-1/2" tubing (TTESP-CD). The challenge was to develop a deployment method using intervention techniques to comply with process safety requirements and installation over a live well without any workover rig. The associated technologies to enable deployment and operation of the ESP were identified, modified, developed and qualified as required in order to meet API 6A, API 14A and ISO 14310. In order to meet the project objectives and derisk technical uncertainties, an onshore test run and offshore pilot were planned. These ensured the design requirements of the key deployment technologies met relevant API and ISO standards; 1) wellhead adapter for cable exit and load handling 2) the anti-rotation anchor packer and 3) the insert safety valve, 4) wireline unit, 5) pressure control equipment. Each of the technologies developed or modified are key components of the deployment technique. Through the onshore testing, the deployment procedure and running equipment were improvised to fit the offshore pilot installation. The deployment of the TTESP-CD system offshore was a success; the ESP was installed within 3-1/2" 9.2ppf tubing to a depth of 1752ft over a live well using the modified deployment package. The actual ESP deployment took around 5days including rig up/down of the deployment package. Running the ESP to depth only took around 8hrs including setting the insert safety valve. Major time consuming events were assembling the ESP, cable space- out, cable termination/splice, landing hanger and cleaning out the electrical connections. Looking forward; this is a technology PETRONAS see great value in for Malaysian and international assets. Currently there are plans for four more installations in 2018 and a minimum of five installations in 2019. The PETRONAS led team have overcome challenges the industry has faced for many years with regards to this type of ESP deployment by investing in R&D and committing resources. By developing this technology PETRONAS and its technology providers have officially opened up market for low cost ESP deployment which is a significant step change to conventional practice. This will be of great benefit to the upstream oil and gas industry, particularly for offshore assets with little infrastructure.
马来西亚约80%的棕地采用Gas Lift作为人工举升方法。虽然它被广泛应用,但运营商面临着许多挑战,包括气举气源短缺和压缩机可靠性问题。因此,油田的生产力受到影响,并导致更高的运营支出。我们研究了从气举到电潜泵的转变案例,但由于钻机成本高,这些项目中的许多都不经济。在这种情况下,马来西亚国家石油公司一直在研究使用高速超薄的电力电缆部署esp,安装在2- 7/8”和3-1/2”油管内(TTESP-CD)。挑战在于开发一种使用修井技术的部署方法,以符合过程安全要求,并在没有任何修井机的情况下安装。为了满足API 6A、API 14A和ISO 14310的要求,ESP部署和操作的相关技术得到了识别、修改、开发和认证。为了实现项目目标并规避技术不确定性,计划进行陆上试井和海上试井。这些确保了关键部署技术的设计要求符合相关API和ISO标准;1)用于电缆出口和负载处理的井口适配器2)防旋转锚封隔器和3)插入式安全阀,4)电缆装置,5)压力控制设备。开发或修改的每一项技术都是部署技术的关键组件。通过陆上测试,改进了部署程序和下入设备,以适应海上试验装置。TTESP-CD系统在海上的部署取得了成功;使用改进的部署包,ESP安装在3-1/2”9.2ppf油管内,深度为1752ft。ESP的实际部署花费了大约5天的时间,包括安装和拆卸部署包。将ESP下入深度只花了大约8小时,包括设置插入式安全阀。主要耗时的工作包括组装ESP、抽出电缆、电缆终端/接头、着陆悬挂架和清理电气连接。期待;马来西亚国家石油公司看到了这项技术对马来西亚和国际资产的巨大价值。目前计划在2018年再安装4个,2019年至少安装5个。PETRONAS领导的团队通过投资研发和投入资源,克服了行业多年来在此类ESP部署方面面临的挑战。通过开发这项技术,马来西亚国家石油公司及其技术提供商正式打开了低成本ESP部署市场,这是对传统做法的重大改变。这将为上游油气行业带来巨大的利益,特别是对于基础设施较少的海上资产。
{"title":"Truly Rigless: A World First Through 3-1/2\" Tubing Cable Deployed Electrical Submersible Pump on a Live Well","authors":"Amirul Adha Bin Amsidom, Elsayed Ouda Ghonim, Euan Alexander, K. Kuswanto, Bakhtiyor Abdullaev, H. Hassan, M. F. Ishak, Benny Rajah, Puvethra Nair Gunasegaran, Kamal Ayad, B. Madon, M. A. Hamzah, Kautsar Zamanuri","doi":"10.2118/192100-MS","DOIUrl":"https://doi.org/10.2118/192100-MS","url":null,"abstract":"\u0000 About 80% of brownfields in Malaysia use Gas Lift as the artificial lift method. Though it is widely used, the operators are facing numerous challenges which include shortages in gas lift source and compressor reliability issues. Consequently fields’ productivity is impacted and results in higher operating expenditure. A case of change from Gas Lift to ESP was studied however due to high rig costs many of these the projects are uneconomic. Given this is the case PETRONAS had been researching the use of high speed slim, power- cable deployed ESPs for installation inside 2- 7/8\" and 3-1/2\" tubing (TTESP-CD). The challenge was to develop a deployment method using intervention techniques to comply with process safety requirements and installation over a live well without any workover rig. The associated technologies to enable deployment and operation of the ESP were identified, modified, developed and qualified as required in order to meet API 6A, API 14A and ISO 14310.\u0000 In order to meet the project objectives and derisk technical uncertainties, an onshore test run and offshore pilot were planned. These ensured the design requirements of the key deployment technologies met relevant API and ISO standards; 1) wellhead adapter for cable exit and load handling 2) the anti-rotation anchor packer and 3) the insert safety valve, 4) wireline unit, 5) pressure control equipment. Each of the technologies developed or modified are key components of the deployment technique. Through the onshore testing, the deployment procedure and running equipment were improvised to fit the offshore pilot installation.\u0000 The deployment of the TTESP-CD system offshore was a success; the ESP was installed within 3-1/2\" 9.2ppf tubing to a depth of 1752ft over a live well using the modified deployment package. The actual ESP deployment took around 5days including rig up/down of the deployment package. Running the ESP to depth only took around 8hrs including setting the insert safety valve. Major time consuming events were assembling the ESP, cable space- out, cable termination/splice, landing hanger and cleaning out the electrical connections. Looking forward; this is a technology PETRONAS see great value in for Malaysian and international assets. Currently there are plans for four more installations in 2018 and a minimum of five installations in 2019.\u0000 The PETRONAS led team have overcome challenges the industry has faced for many years with regards to this type of ESP deployment by investing in R&D and committing resources. By developing this technology PETRONAS and its technology providers have officially opened up market for low cost ESP deployment which is a significant step change to conventional practice. This will be of great benefit to the upstream oil and gas industry, particularly for offshore assets with little infrastructure.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"28 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87598539","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}
引用次数: 3
Zonal Isolation of a Fractured and Gravel Packed Water Producing Zone using an Organically Crosslinked Polymer Sealant: Case Study 使用有机交联聚合物密封胶对裂缝和砾石充填产水层进行层间隔离:案例研究
Pub Date : 2018-10-19 DOI: 10.2118/191972-MS
Ankesh Nagar, G. Dangwal, N. Pandey, Akanksha Jain, A. Parasher, Mayur Deshpande, Vaibhav Gupta, K. Pande
Increasing water cut in oil-producing zones is a common issue faced by operators, particularly for mature fields. Currently, where most of the decisions are governed by economics, incurring additional expenses with activities such as handling produced water becomes extremely undesirable. Depending upon the nature of the zone, one effective solution to this issue is chemical isolation. This paper undertakes this issue, discussing a case study of a successful zonal isolation operation using an organically crosslinked polymer sealant in a fractured zone with a gravel pack and screen completion for a reservoir with a subhydrostatic nature. This zone was an initial oil producer in FM-01 sand of the Mangala onshore oil field and had been stimulated in 2011 with a fracture-pack completion. The zone was completed with screens and a gravel pack with 16/30-mesh sand and 5.5-in. screens across the producing interval. During a period of time, the zone (FM-01) began to produce a significant amount of water, resulting in excessive water cut. To mitigate the issue, it was decided to completely isolate the zone using an organically crosslinked polymer system as a porosity fill sealant. When prepared in the appropriate concentration, subject to reservoir temperature, this low-viscosity formulation (40 to 80 cp) turns into a permanent rigid gel with time. The particular challenges of this operation were the presence of high permeability streaks because of stimulation by hydraulic fracturing, extra pore space because the perforated interval lay within the gravel-packed screens, and the subhydrostatic nature of the reservoir. Extensive laboratory testing was performed to optimize the formulation at the desired temperature, measuring the time necessary for the viscosity to begin increasing and the minimum total time necessary to form a rigid gel. The case study discussed in this paper features the successful application of the treatment using the spot-and-squeeze method with coiled tubing (CT) for the isolation of the zone. After allowing the setting time, pressure tests were performed, indicating positive isolation of the zone. After the pressure test, a jet pump was installed, and a drawdown was created to flow the zone. It was observed that production post operation was almost 95% less than production before operation at the same pressure drawdown, indicating approximately 100% zone isolation.
产油区含水率增加是作业者普遍面临的问题,尤其是成熟油田。目前,大多数决策都是由经济因素决定的,因此处理采出水等活动产生的额外费用变得非常不可取。根据该区域的性质,一个有效的解决方案是化学隔离。本文就这一问题进行了探讨,讨论了一个成功的层间隔离作业的案例研究,该作业采用有机交联聚合物密封胶在裂缝带进行砾石充填,并对具有亚静流体性质的储层进行筛管完井。该区域是Mangala陆上油田FM-01砂区的初始产油区,并于2011年进行了压裂充填完井。该区域通过筛管和砾石充填完成,砾石充填含有16/30目的5.5-in砂。在整个生产区间进行筛检。在一段时间内,区域(FM-01)开始大量产水,导致含水率过高。为了缓解这一问题,开发商决定使用有机交联聚合物体系作为孔隙填充密封剂来完全隔离储层。当以适当的浓度制备时,受储层温度的影响,这种低粘度配方(40至80 cp)随着时间的推移会变成永久的刚性凝胶。该作业面临的特殊挑战是,由于水力压裂增产,存在高渗透率条纹,由于射孔段位于砾石充填筛管内,因此存在额外的孔隙空间,以及储层的亚静流体性质。为了在理想的温度下优化配方,进行了大量的实验室测试,测量了粘度开始增加所需的时间和形成刚性凝胶所需的最短总时间。本文所讨论的案例研究的特点是,利用连续油管(CT)的定点挤压方法成功应用于该区域的隔离。在允许坐封时间后,进行压力测试,表明该区域正隔离。在压力测试后,安装了喷射泵,并产生了一个压降以使该区域流动。在相同的压降下,作业后的产量比作业前的产量减少了近95%,这表明大约100%的层隔离。
{"title":"Zonal Isolation of a Fractured and Gravel Packed Water Producing Zone using an Organically Crosslinked Polymer Sealant: Case Study","authors":"Ankesh Nagar, G. Dangwal, N. Pandey, Akanksha Jain, A. Parasher, Mayur Deshpande, Vaibhav Gupta, K. Pande","doi":"10.2118/191972-MS","DOIUrl":"https://doi.org/10.2118/191972-MS","url":null,"abstract":"\u0000 Increasing water cut in oil-producing zones is a common issue faced by operators, particularly for mature fields. Currently, where most of the decisions are governed by economics, incurring additional expenses with activities such as handling produced water becomes extremely undesirable. Depending upon the nature of the zone, one effective solution to this issue is chemical isolation. This paper undertakes this issue, discussing a case study of a successful zonal isolation operation using an organically crosslinked polymer sealant in a fractured zone with a gravel pack and screen completion for a reservoir with a subhydrostatic nature.\u0000 This zone was an initial oil producer in FM-01 sand of the Mangala onshore oil field and had been stimulated in 2011 with a fracture-pack completion. The zone was completed with screens and a gravel pack with 16/30-mesh sand and 5.5-in. screens across the producing interval. During a period of time, the zone (FM-01) began to produce a significant amount of water, resulting in excessive water cut. To mitigate the issue, it was decided to completely isolate the zone using an organically crosslinked polymer system as a porosity fill sealant. When prepared in the appropriate concentration, subject to reservoir temperature, this low-viscosity formulation (40 to 80 cp) turns into a permanent rigid gel with time. The particular challenges of this operation were the presence of high permeability streaks because of stimulation by hydraulic fracturing, extra pore space because the perforated interval lay within the gravel-packed screens, and the subhydrostatic nature of the reservoir. Extensive laboratory testing was performed to optimize the formulation at the desired temperature, measuring the time necessary for the viscosity to begin increasing and the minimum total time necessary to form a rigid gel.\u0000 The case study discussed in this paper features the successful application of the treatment using the spot-and-squeeze method with coiled tubing (CT) for the isolation of the zone. After allowing the setting time, pressure tests were performed, indicating positive isolation of the zone. After the pressure test, a jet pump was installed, and a drawdown was created to flow the zone. It was observed that production post operation was almost 95% less than production before operation at the same pressure drawdown, indicating approximately 100% zone isolation.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"77 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88114484","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}
引用次数: 0
Hydraulic Fracturing Treatment of Low-Permeability Coal Seam Gas Reservoirs with Finely Layered Coals 煤细层状低渗透煤层气藏水力压裂治理
Pub Date : 2018-10-19 DOI: 10.2118/192017-MS
Xi Zhang, Bisheng Wu, L. Connell, Yanhui Han, R. Jeffrey
In this paper, a fracture mechanics model that deals with fracture growth in layered low-permeability rocks is presented and applied to hydraulic fracturing stimulation of coal seam gas reservoirs. The model uses the conventional pseudo-3D treatment by which the vertically planar fracture is divided into cells along the horizontal direction. For each cell, the fracture deformation is represented by a 2D plane-strain fracture. To ensure numerical stability, the model uses an optimization method based on the fluid volume increase of each cell and the solutions for each cell can be obtained in parallel when using a computer with multiple CPU cores. The method was verified based on the comparisons with existing solutions and the computational speed can be significantly increased by using parallel computing. Numerical examples are presented to illustrate cases that result in fracture geometrical complexities caused by material properties contrasts between the thin softer coal seams and the adjacent stiffer rocks. The local horizontal stresses in each layer are calculated based on the layer-independent uniform horizontal strain assumption. The overburden stress is given. The fracture length and opening in the coal can be larger than other layers if the coal is subject to a smaller stress. This will promote growth of the fracture plane to include coal seams that do not receive injected fluid at the wellbore. The well developed fracture opening in the coal can be impeded by an increase in the confining stress of the coal. The fracturing produces wide propped channels below the coal seam in the low stress rock that exists there. These conductive channels allow flow of gas and water to the wellbore. The stress uncertainty is considered and interestingly the injection pressure trends are insensitive to the variation of local stresses. There is a process that favors growth in the softer coal seams for all cases, which yields a slight and progressive increase in the injection pressure.
本文建立了层状低渗透岩石裂缝发育的裂缝力学模型,并将其应用于煤层气储层水力压裂改造。该模型采用传统的伪三维处理方法,将垂直平面裂缝沿水平方向划分为多个单元。对于每个单元,断裂变形由二维平面应变断裂表示。为了保证数值的稳定性,该模型采用了基于每个单元流体体积增量的优化方法,并且在使用多CPU内核的计算机时,可以并行获得每个单元的解。通过与已有解的比较,验证了该方法的有效性,通过并行计算可以显著提高计算速度。数值算例说明了由于较软的薄煤层与相邻较硬的岩石之间的材料性质差异而导致裂隙几何复杂性的情况。基于与层无关的均匀水平应变假设,计算了各层的局部水平应力。给出了覆盖层应力。当煤受到较小的应力时,煤中的裂缝长度和开口可以比其他层大。这将促进裂缝平面的增长,包括在井筒中没有接受注入流体的煤层。煤的围应力增大会阻碍煤中发育良好的裂隙。在煤层下方存在的低应力岩层中,压裂产生了宽的支撑通道。这些导电通道允许气体和水流入井筒。考虑了应力不确定性,有趣的是,注入压力趋势对局部应力的变化不敏感。在所有情况下,都有一个有利于软煤层生长的过程,这导致注入压力轻微而渐进地增加。
{"title":"Hydraulic Fracturing Treatment of Low-Permeability Coal Seam Gas Reservoirs with Finely Layered Coals","authors":"Xi Zhang, Bisheng Wu, L. Connell, Yanhui Han, R. Jeffrey","doi":"10.2118/192017-MS","DOIUrl":"https://doi.org/10.2118/192017-MS","url":null,"abstract":"\u0000 In this paper, a fracture mechanics model that deals with fracture growth in layered low-permeability rocks is presented and applied to hydraulic fracturing stimulation of coal seam gas reservoirs. The model uses the conventional pseudo-3D treatment by which the vertically planar fracture is divided into cells along the horizontal direction. For each cell, the fracture deformation is represented by a 2D plane-strain fracture. To ensure numerical stability, the model uses an optimization method based on the fluid volume increase of each cell and the solutions for each cell can be obtained in parallel when using a computer with multiple CPU cores. The method was verified based on the comparisons with existing solutions and the computational speed can be significantly increased by using parallel computing. Numerical examples are presented to illustrate cases that result in fracture geometrical complexities caused by material properties contrasts between the thin softer coal seams and the adjacent stiffer rocks. The local horizontal stresses in each layer are calculated based on the layer-independent uniform horizontal strain assumption. The overburden stress is given. The fracture length and opening in the coal can be larger than other layers if the coal is subject to a smaller stress. This will promote growth of the fracture plane to include coal seams that do not receive injected fluid at the wellbore. The well developed fracture opening in the coal can be impeded by an increase in the confining stress of the coal. The fracturing produces wide propped channels below the coal seam in the low stress rock that exists there. These conductive channels allow flow of gas and water to the wellbore. The stress uncertainty is considered and interestingly the injection pressure trends are insensitive to the variation of local stresses. There is a process that favors growth in the softer coal seams for all cases, which yields a slight and progressive increase in the injection pressure.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"2 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88133754","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}
引用次数: 0
Behavior Analysis of a Wire Rope Replacing Sucker Rods with Finite Element Simulation 用有限元模拟分析钢丝绳替代抽油杆的性能
Pub Date : 2018-10-19 DOI: 10.2118/191894-MS
Fazeli Tehrani Fatemeh, Langbauer Clemens, H. Herbert
In this paper, a state-of-the-art wire rope is chosen for investigation regarding its applicability as a sucker rod string. Finite element simulation with Abaqus has been used for a detailed analysis of the rope's performance and possible failures along with its length. The sucker rod string is a key component of sucker rod pumps, transferring the reciprocating movement of the surface polished rod to the downhole pump plunger. It is, however, exposed to severe cyclic loads, causing several complications from damaged rods and broken couplings to time-consuming workover procedures. Hence, continuous strings like wire ropes can be a convenient replacement for the conventional design. The mechanical properties of the introduced wire rope demonstrate high tensile strength and great resistance against creep and fatigue while its uniform design eliminates the chances of connection failure. The proposed wire rope was designed to work in tandem with a sucker rod anti-buckling pump (SRABS) to facilitate its motion. The performance of this system was then simulated using a combination of MATLAB and Python codes, visualized in the interface of Abaqus. These simulations confirm that this wire rope can indeed replace the rod string in a sucker rod pumping unit. Detailed stress, load, and movement profiles were also compiled to allow for a comprehensive analysis. The results pointed out that pumping with a wire rope can be just as productive, or surpass the productivity of a system using conventional sucker rods. They indicate that the efficiency of this design highly depends on the geometry and depth of the well, type, and size of the pump, the compressibility of the produced fluid and string material elasticity. The optimization of the wire rope's performance could be achieved by using compatible Pumpjacks and proper downhole equipment, such as string protectors, all operating together under an optimum pumping speed. This paper presents a noteworthy comparison between the performance of a conventional rod string and a wire rope at two reference wells. Laboratory and field tests are being planned to investigate the full capacity of the rope.
本文选择一种最先进的钢丝绳作为抽油杆管柱进行适用性研究。利用Abaqus进行有限元模拟,详细分析了绳索的性能和可能发生的故障以及其长度。抽油杆管柱是有杆泵的关键部件,将地面抛光抽油杆的往复运动传递给井下泵柱塞。然而,它暴露在剧烈的循环载荷下,会导致钻杆损坏、接箍断裂以及耗时的修井作业等并发症。因此,像钢丝绳这样的连续绳可以方便地替代传统设计。引入的钢丝绳具有高抗拉强度、抗蠕变和抗疲劳性能,同时其均匀的设计消除了连接失败的可能性。该钢丝绳被设计成与抽油杆抗屈曲泵(SRABS)串联工作,以促进其运动。然后结合MATLAB和Python代码对该系统的性能进行了仿真,并在Abaqus的界面中进行了可视化。这些模拟结果证实,这种钢丝绳确实可以替代有杆抽油机中的抽油杆管柱。详细的应力、载荷和运动剖面也被编译,以便进行全面的分析。结果表明,使用钢丝绳进行泵送的产能与使用传统抽油杆的系统一样高,甚至超过了该系统的产能。他们指出,这种设计的效率在很大程度上取决于井的几何形状和深度、泵的类型和尺寸、产出流体的可压缩性和管柱材料的弹性。通过使用兼容的Pumpjacks和合适的井下设备(如管柱保护器),在最佳泵速下一起工作,可以实现钢丝绳性能的优化。本文对两口参考井的常规抽油杆柱和钢丝绳的性能进行了值得注意的比较。正在计划进行实验室和现场试验,以调查该绳索的全部承载能力。
{"title":"Behavior Analysis of a Wire Rope Replacing Sucker Rods with Finite Element Simulation","authors":"Fazeli Tehrani Fatemeh, Langbauer Clemens, H. Herbert","doi":"10.2118/191894-MS","DOIUrl":"https://doi.org/10.2118/191894-MS","url":null,"abstract":"\u0000 In this paper, a state-of-the-art wire rope is chosen for investigation regarding its applicability as a sucker rod string. Finite element simulation with Abaqus has been used for a detailed analysis of the rope's performance and possible failures along with its length.\u0000 The sucker rod string is a key component of sucker rod pumps, transferring the reciprocating movement of the surface polished rod to the downhole pump plunger. It is, however, exposed to severe cyclic loads, causing several complications from damaged rods and broken couplings to time-consuming workover procedures. Hence, continuous strings like wire ropes can be a convenient replacement for the conventional design. The mechanical properties of the introduced wire rope demonstrate high tensile strength and great resistance against creep and fatigue while its uniform design eliminates the chances of connection failure.\u0000 The proposed wire rope was designed to work in tandem with a sucker rod anti-buckling pump (SRABS) to facilitate its motion. The performance of this system was then simulated using a combination of MATLAB and Python codes, visualized in the interface of Abaqus. These simulations confirm that this wire rope can indeed replace the rod string in a sucker rod pumping unit. Detailed stress, load, and movement profiles were also compiled to allow for a comprehensive analysis. The results pointed out that pumping with a wire rope can be just as productive, or surpass the productivity of a system using conventional sucker rods. They indicate that the efficiency of this design highly depends on the geometry and depth of the well, type, and size of the pump, the compressibility of the produced fluid and string material elasticity. The optimization of the wire rope's performance could be achieved by using compatible Pumpjacks and proper downhole equipment, such as string protectors, all operating together under an optimum pumping speed.\u0000 This paper presents a noteworthy comparison between the performance of a conventional rod string and a wire rope at two reference wells. Laboratory and field tests are being planned to investigate the full capacity of the rope.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"123 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77571465","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}
引用次数: 1
Review of Water Saturation Calculation Methods in Shale Gas Reservoir 页岩气储层含水饱和度计算方法综述
Pub Date : 2018-10-19 DOI: 10.2118/192115-MS
Hongyan Yu, Xiaolong Wei, Zhenliang Wang, R. Rezaee, Yihuai Zhang, M. Lebedev, S. Iglauer
The gas content in shale reservoir is of great importance in reservoir evaluation. Shale reservoir has various gas including free gas, adsorpted gas and soluted gas. Free gas take an important part for the total gas content. Hence, we investigated three equations for water saturation calculating and compared and improved them based on theoretical analysis in order to find a siutable one for the shale reservoir characterization. The results indicate that the Archie formula has several limitations applied to complex pore structure, which leads to high water saturation. Since the Archie formula was proposed by experimental data in pure sandstone without enough consideration about the clay of shale reservoir. The Waxman-Smits is suitable to shale gas reservoirs through theoretical analysis, but there are several uncertain parameters. The conductivity of formation water is necessary parameter in calculation of formation water saturation, but calculating the conductivity of formation water is difficult in shale gas reservoir because of its intricate characterization of pore structure and conductivity. Waxman-Smits model take account for the clay conductivity, but there are several uncertain parameters which are hard to obtained, resuting high error. For instance, the equivalent conductivity of exchange cations (B) and the capacitance of exchange anions (Qv) can not be defined accurately relied on experimental calculation, which causes indefinite influence on results. Thus, we concluded that selecting the improved Indonesia equation is a better method to calculate water saturation. This study provided a comprehensive analysis and an accurate way for water satruartion evaluation in shale reservoir.
页岩储层含气量在储层评价中具有重要意义。页岩储层含游离气、吸附气和溶解气等多种气体。游离气在总含气量中占有重要地位。为此,研究了3种含水饱和度计算公式,并在理论分析的基础上对其进行了比较和改进,以期找到适合页岩储层表征的含水饱和度计算公式。结果表明,对于复杂孔隙结构,Archie公式存在一定的局限性,导致含水饱和度较高。由于阿尔奇公式是根据纯砂岩的实验数据提出的,没有充分考虑页岩储层的粘土。理论分析表明,Waxman-Smits方法适用于页岩气储层,但存在一些不确定参数。地层水的导电性是计算地层含水饱和度的必要参数,但页岩气储层孔隙结构和导电性表征复杂,给地层水的导电性计算带来困难。Waxman-Smits模型考虑了粘土的电导率,但存在一些难以获得的不确定参数,误差较大。例如,交换阳离子的等效电导率(B)和交换阴离子的电容(Qv)不能依靠实验计算准确地定义,这对结果造成了不确定的影响。因此,我们认为选择改进的印度尼西亚方程是一种更好的计算含水饱和度的方法。该研究为页岩储层含水饱和度评价提供了全面的分析和准确的方法。
{"title":"Review of Water Saturation Calculation Methods in Shale Gas Reservoir","authors":"Hongyan Yu, Xiaolong Wei, Zhenliang Wang, R. Rezaee, Yihuai Zhang, M. Lebedev, S. Iglauer","doi":"10.2118/192115-MS","DOIUrl":"https://doi.org/10.2118/192115-MS","url":null,"abstract":"\u0000 The gas content in shale reservoir is of great importance in reservoir evaluation. Shale reservoir has various gas including free gas, adsorpted gas and soluted gas. Free gas take an important part for the total gas content. Hence, we investigated three equations for water saturation calculating and compared and improved them based on theoretical analysis in order to find a siutable one for the shale reservoir characterization. The results indicate that the Archie formula has several limitations applied to complex pore structure, which leads to high water saturation. Since the Archie formula was proposed by experimental data in pure sandstone without enough consideration about the clay of shale reservoir. The Waxman-Smits is suitable to shale gas reservoirs through theoretical analysis, but there are several uncertain parameters. The conductivity of formation water is necessary parameter in calculation of formation water saturation, but calculating the conductivity of formation water is difficult in shale gas reservoir because of its intricate characterization of pore structure and conductivity. Waxman-Smits model take account for the clay conductivity, but there are several uncertain parameters which are hard to obtained, resuting high error. For instance, the equivalent conductivity of exchange cations (B) and the capacitance of exchange anions (Qv) can not be defined accurately relied on experimental calculation, which causes indefinite influence on results. Thus, we concluded that selecting the improved Indonesia equation is a better method to calculate water saturation. This study provided a comprehensive analysis and an accurate way for water satruartion evaluation in shale reservoir.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77655808","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}
引用次数: 4
Increasing Coal Seam Gas Field Productivity with Horizontal Well Technology: A Case Study 利用水平井技术提高煤层气田产能的实例研究
Pub Date : 2018-10-19 DOI: 10.2118/192114-MS
Xuejun Lin, G. Sutherland, D. Cumming, B. Thomas, A. Sani
A Coal Seam Gas Field, operated by Origin Energy as upstream operator of the APLNG project in Queensland, Australia has been on commercial production since 2005. From inception to 2012 the development concept used vertical cavitated wells or vertical fracture stimulated wells. Four pilot surface to in-seam well pairs were successfully drilled and commissioned in 2012 and 2013. Based on the performance of these pilots, further development of the coal seam gas field converted from stimulated vertical wells to horizontal wells from 2015 onwards. Surface-in-seam (SIS), high-angle-sump-horizontals (HASH), and multi-laterals wells drilled with coil tubing technologies were implemented in the field. The paper describes horizontal wells drilling, completion and geo-steering technology. The optimal operational strategies of horizontal wells are also described and the production performance of horizontal wells are compared to the vertical well performance. The key factors contributing to the success of horizontal drilling in the field are presented.
Origin Energy作为澳大利亚昆士兰APLNG项目的上游运营商,自2005年以来一直在进行商业生产。从一开始到2012年,开发理念是使用垂直空化井或垂直压裂井。2012年和2013年,4口从地面到缝内的试验井成功钻井并投产。基于这些试点的表现,从2015年起,煤层气田的进一步开发从增产直井转向水平井。在现场使用了螺旋管技术钻井的面槽井(SIS)、大角度井槽水平井(HASH)和多分支井。介绍了水平井钻井、完井和地质导向技术。阐述了水平井的最佳作业策略,并将水平井的生产动态与直井的生产动态进行了比较。介绍了影响该油田水平井钻井成功的关键因素。
{"title":"Increasing Coal Seam Gas Field Productivity with Horizontal Well Technology: A Case Study","authors":"Xuejun Lin, G. Sutherland, D. Cumming, B. Thomas, A. Sani","doi":"10.2118/192114-MS","DOIUrl":"https://doi.org/10.2118/192114-MS","url":null,"abstract":"\u0000 A Coal Seam Gas Field, operated by Origin Energy as upstream operator of the APLNG project in Queensland, Australia has been on commercial production since 2005. From inception to 2012 the development concept used vertical cavitated wells or vertical fracture stimulated wells. Four pilot surface to in-seam well pairs were successfully drilled and commissioned in 2012 and 2013. Based on the performance of these pilots, further development of the coal seam gas field converted from stimulated vertical wells to horizontal wells from 2015 onwards. Surface-in-seam (SIS), high-angle-sump-horizontals (HASH), and multi-laterals wells drilled with coil tubing technologies were implemented in the field. The paper describes horizontal wells drilling, completion and geo-steering technology. The optimal operational strategies of horizontal wells are also described and the production performance of horizontal wells are compared to the vertical well performance. The key factors contributing to the success of horizontal drilling in the field are presented.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75572440","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}
引用次数: 0
Sand Conglomeration Trial as an Alternative to Sand Control: Case Study from Mahakam Delta, Indonesia 砂团试验作为防砂的替代方案:以印度尼西亚马哈坎三角洲为例
Pub Date : 2018-10-19 DOI: 10.2118/191987-MS
B. Styward, R. Wijaya, D. Manalu, F. Wahyudhi, T. Setiawan, Albert Malvin Richal Dading, M. Rizal, T. Widarena, Geraldie Lukman, I. Primasari, Putu Astari Merati, Rizka Hezmela, M. Fuad, C. Nwafor, Liu Hai, Pratyush Singh
Pertamina Hulu Energi operates numerous wells that produce gas from unconsolidated, tight sands in the Mahakam Delta. The company maintains a zero-sand production policy as its surface facilities are not designed to handle sand. If sand is produced, the wells are choked back, thus impairing the overall field production. To fix sand and fines in place, the primary sand control method used has been multizone single-trip gravel packing, sometimes in conjunction with sand consolidation or ceramic screen for noneconomic zones. However, the current state of the Tunu shallow portfolio renders sand consolidation infeasible, as more than 50% of the remaining reservoirs are either low-stakes (i.e. not economical) or are located in low-permeability zones. Against this backdrop, sand conglomeration is being considered as an alternative solution to produce the remaining reservoirs. A trial has been conducted to assess the feasibility of using sand conglomeration technology as an alternative to sand consolidation in the Mahakam Delta, the results of which will be reviewed in this paper.
Pertamina Hulu Energi公司在Mahakam三角洲运营着许多从松散致密砂岩中开采天然气的井。该公司坚持零出砂政策,因为其地面设施不是为处理砂而设计的。如果出砂,井就会堵塞,从而影响整个油田的产量。为了将砂石和细砂固定到位,主要的防砂方法是多层单趟砾石充填,有时在非经济层使用固砂或陶瓷筛管。然而,目前Tunu浅层组合的现状使得砂体固结不可行,因为超过50%的剩余储层要么是低风险(即不经济),要么位于低渗透层。在这种背景下,砂团被认为是开采剩余储层的另一种解决方案。已经进行了一项试验,以评估在马哈坎三角洲使用砂团技术作为砂固结的替代方案的可行性,本文将对其结果进行审查。
{"title":"Sand Conglomeration Trial as an Alternative to Sand Control: Case Study from Mahakam Delta, Indonesia","authors":"B. Styward, R. Wijaya, D. Manalu, F. Wahyudhi, T. Setiawan, Albert Malvin Richal Dading, M. Rizal, T. Widarena, Geraldie Lukman, I. Primasari, Putu Astari Merati, Rizka Hezmela, M. Fuad, C. Nwafor, Liu Hai, Pratyush Singh","doi":"10.2118/191987-MS","DOIUrl":"https://doi.org/10.2118/191987-MS","url":null,"abstract":"\u0000 Pertamina Hulu Energi operates numerous wells that produce gas from unconsolidated, tight sands in the Mahakam Delta. The company maintains a zero-sand production policy as its surface facilities are not designed to handle sand. If sand is produced, the wells are choked back, thus impairing the overall field production. To fix sand and fines in place, the primary sand control method used has been multizone single-trip gravel packing, sometimes in conjunction with sand consolidation or ceramic screen for noneconomic zones. However, the current state of the Tunu shallow portfolio renders sand consolidation infeasible, as more than 50% of the remaining reservoirs are either low-stakes (i.e. not economical) or are located in low-permeability zones. Against this backdrop, sand conglomeration is being considered as an alternative solution to produce the remaining reservoirs. A trial has been conducted to assess the feasibility of using sand conglomeration technology as an alternative to sand consolidation in the Mahakam Delta, the results of which will be reviewed in this paper.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"3 3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78849663","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}
引用次数: 1
Foam Cementing in Australian Coal Seam Gas Operations 泡沫固井技术在澳大利亚煤层气作业中的应用
Pub Date : 2018-10-19 DOI: 10.2118/191892-MS
T. Saunders, A. Shaban, Mohammad Zaman
The Australian coal seam gas (CSG)/coal bed methane (CBM) fields present multiple challenges (i.e., losses, naturally fractured formations, and highly depleted zones) typically addressed using various well design and cementing techniques (i.e., additional casing strings, stage cementers/tools, lost-circulation materials, lightweight designs, and additional cement volume) to manage the potential risk of losses. Foamed cement is a viable option to address these challenges; however, despite the documented benefits, its application within Australia has been minimal at best. The lack of application can be primarily attributed to misconceptions concerning cost, potential risk, excessive equipment footprint, and a limited proven track record, which increases the potential risk of execution. A recent 10-well campaign conducted within the Bowen Basin, Queensland, Australia, demonstrated that foamed cement can be used as an alternative to traditional lightweight and/or elastomeric cement slurries. Further, the benefits of foamed cement make it an economically and technically advantageous solution compared to conventional cementing techniques used to overcome CSG challenges. This case study details the campaign challenges, cement design, and detailed results of the 10 wells with the intention of providing other engineers a road map to better understand foamed cementing with a specific Australian context and how it could be applied to their projects.
澳大利亚煤层气(CSG)/煤层气(CBM)油田面临多重挑战(即漏失、天然裂缝地层和高度枯竭区),通常采用各种井设计和固井技术(即额外的套管柱、一级固井剂/工具、漏失材料、轻量化设计和额外的水泥体积)来管理潜在的漏失风险。泡沫水泥是解决这些挑战的可行选择;然而,尽管有记录在案的好处,它在澳大利亚的应用最多是最少的。缺乏应用的主要原因可能是对成本、潜在风险、过多的设备占用空间和有限的已证明的跟踪记录的误解,这增加了执行的潜在风险。最近在澳大利亚昆士兰州Bowen盆地进行的10口井试验表明,泡沫水泥可以替代传统的轻质和/或弹性水泥浆。此外,与传统固井技术相比,泡沫水泥的优点使其成为一种经济和技术上的优势解决方案,用于克服CSG挑战。本案例研究详细介绍了作业挑战、水泥设计以及10口井的详细结果,旨在为其他工程师提供路线图,以便更好地了解泡沫固井在澳大利亚的具体情况,以及如何将其应用到他们的项目中。
{"title":"Foam Cementing in Australian Coal Seam Gas Operations","authors":"T. Saunders, A. Shaban, Mohammad Zaman","doi":"10.2118/191892-MS","DOIUrl":"https://doi.org/10.2118/191892-MS","url":null,"abstract":"\u0000 The Australian coal seam gas (CSG)/coal bed methane (CBM) fields present multiple challenges (i.e., losses, naturally fractured formations, and highly depleted zones) typically addressed using various well design and cementing techniques (i.e., additional casing strings, stage cementers/tools, lost-circulation materials, lightweight designs, and additional cement volume) to manage the potential risk of losses.\u0000 Foamed cement is a viable option to address these challenges; however, despite the documented benefits, its application within Australia has been minimal at best. The lack of application can be primarily attributed to misconceptions concerning cost, potential risk, excessive equipment footprint, and a limited proven track record, which increases the potential risk of execution.\u0000 A recent 10-well campaign conducted within the Bowen Basin, Queensland, Australia, demonstrated that foamed cement can be used as an alternative to traditional lightweight and/or elastomeric cement slurries. Further, the benefits of foamed cement make it an economically and technically advantageous solution compared to conventional cementing techniques used to overcome CSG challenges.\u0000 This case study details the campaign challenges, cement design, and detailed results of the 10 wells with the intention of providing other engineers a road map to better understand foamed cementing with a specific Australian context and how it could be applied to their projects.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"99 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77210947","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}
引用次数: 0
A Novel Downhole Gas Separator in ESP Systems 一种新型ESP井下气体分离器
Pub Date : 2018-10-19 DOI: 10.2118/192028-MS
Qinghua Wang, Liu Yonghui, Junzheng Yang, M. Cui, Dan Qi
For Electrical Submersible Pump (ESP) systems in high-GLR wells, presence of gas inside ESP results in the degradation of hydraulic head. As a remedial tool to improve the ability of handling gas-liquid mixtures, Downhole Gas Separator (DGS) is of crucial importance. However, conventional DGS has limited capability in separating free gas and a maximum separating efficiency of 45%. It can't meet the field applications to a wider range of flow conditions and different pump models. Therefore, the paper proposed a solution to improve gas handling ability of DGS to expand its application. Combining centrifugal separation method and gravity separation method, three-annular design was proposed to address the problem of two-stage separator with fairly long length. In the new design, a device is used to accelerate the fluid for higher velocity flowing into the annular between the spiral outer pipe and the central pipe. Then, the helical blades in the annular separate the gas-liquid mixture, leading gas attaching on the out wall of the central pipe and subsequently discharge into casing through the vent holes. The liquid attached on the inner wall of the spiral outer pipe flows reversal because of gravity. Afterwards, liquid is forced into the central pipe through the drainage holes and then flow into the ESP. In order to improve separating efficiency, the structure of helical blades, including distance and number of thread for centrifugal separator was then optimized by numerical simulation. In addition, an experimental study was conducted in different GLR and deviation. The experimental results show separating efficiency ranges between 88% and 96% while the conventional is under 60%. Furthermore, the separation efficiency decreases with the increasing of deviation, and maximum deviation of the new separator can be applied is 50°[1]. The novel DGS provide an economic solution for ESP application in gassy reservoir with low cost and power; since the new design greatly shorten the length of traditional two-stage separator.
对于高glr井的电潜泵(ESP)系统,ESP内部存在气体会导致液压头退化。井下气体分离器(DGS)作为一种提高气液混合处理能力的补救工具,具有至关重要的作用。然而,常规DGS对游离气的分离能力有限,最大分离效率仅为45%。它不能满足更大范围的流量条件和不同的泵型号的现场应用。因此,本文提出了提高DGS气体处理能力的解决方案,以扩大其应用范围。结合离心分离法和重力分离法,提出了三环形设计方案,解决了两级分离器长度较大的问题。在新设计中,采用了一种加速装置,使流体以更高的速度流入螺旋外管与中心管之间的环空。然后,环空中的螺旋叶片将气液混合物分离,导致气体附着在中心管的外壁上,随后通过排气孔排出到套管中。附着在螺旋外管内壁的液体在重力作用下发生反向流动。然后,液体通过排液孔强制进入中心管,流入电除尘器。为了提高分离效率,通过数值模拟对离心分离器螺旋叶片的结构进行优化,包括螺旋叶片的距离和螺纹数。另外,在不同的GLR和偏差下进行了实验研究。实验结果表明,该方法的分离效率在88% ~ 96%之间,而常规方法的分离效率在60%以下。分离效率随偏差的增大而降低,新分离器可应用的最大偏差为50°[1]。新型DGS具有低成本、低功耗的特点,为气层电潜泵的应用提供了经济可行的解决方案;由于新设计大大缩短了传统两级分离器的长度。
{"title":"A Novel Downhole Gas Separator in ESP Systems","authors":"Qinghua Wang, Liu Yonghui, Junzheng Yang, M. Cui, Dan Qi","doi":"10.2118/192028-MS","DOIUrl":"https://doi.org/10.2118/192028-MS","url":null,"abstract":"\u0000 For Electrical Submersible Pump (ESP) systems in high-GLR wells, presence of gas inside ESP results in the degradation of hydraulic head. As a remedial tool to improve the ability of handling gas-liquid mixtures, Downhole Gas Separator (DGS) is of crucial importance. However, conventional DGS has limited capability in separating free gas and a maximum separating efficiency of 45%. It can't meet the field applications to a wider range of flow conditions and different pump models. Therefore, the paper proposed a solution to improve gas handling ability of DGS to expand its application.\u0000 Combining centrifugal separation method and gravity separation method, three-annular design was proposed to address the problem of two-stage separator with fairly long length. In the new design, a device is used to accelerate the fluid for higher velocity flowing into the annular between the spiral outer pipe and the central pipe. Then, the helical blades in the annular separate the gas-liquid mixture, leading gas attaching on the out wall of the central pipe and subsequently discharge into casing through the vent holes. The liquid attached on the inner wall of the spiral outer pipe flows reversal because of gravity. Afterwards, liquid is forced into the central pipe through the drainage holes and then flow into the ESP. In order to improve separating efficiency, the structure of helical blades, including distance and number of thread for centrifugal separator was then optimized by numerical simulation. In addition, an experimental study was conducted in different GLR and deviation. The experimental results show separating efficiency ranges between 88% and 96% while the conventional is under 60%. Furthermore, the separation efficiency decreases with the increasing of deviation, and maximum deviation of the new separator can be applied is 50°[1].\u0000 The novel DGS provide an economic solution for ESP application in gassy reservoir with low cost and power; since the new design greatly shorten the length of traditional two-stage separator.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88503088","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}
引用次数: 2
期刊
Day 3 Thu, October 25, 2018
全部 Acc. Chem. Res. ACS Applied Bio Materials ACS Appl. Electron. Mater. ACS Appl. Energy Mater. ACS Appl. Mater. Interfaces ACS Appl. Nano Mater. ACS Appl. Polym. Mater. ACS BIOMATER-SCI ENG ACS Catal. ACS Cent. Sci. ACS Chem. Biol. ACS Chemical Health & Safety ACS Chem. Neurosci. ACS Comb. Sci. ACS Earth Space Chem. ACS Energy Lett. ACS Infect. Dis. ACS Macro Lett. ACS Mater. Lett. ACS Med. Chem. Lett. ACS Nano ACS Omega ACS Photonics ACS Sens. ACS Sustainable Chem. Eng. ACS Synth. Biol. Anal. Chem. BIOCHEMISTRY-US Bioconjugate Chem. BIOMACROMOLECULES Chem. Res. Toxicol. Chem. Rev. Chem. Mater. CRYST GROWTH DES ENERG FUEL Environ. Sci. Technol. Environ. Sci. Technol. Lett. Eur. J. Inorg. Chem. IND ENG CHEM RES Inorg. Chem. J. Agric. Food. Chem. J. Chem. Eng. Data J. Chem. Educ. J. Chem. Inf. Model. J. Chem. Theory Comput. J. Med. Chem. J. Nat. Prod. J PROTEOME RES J. Am. Chem. Soc. LANGMUIR MACROMOLECULES Mol. Pharmaceutics Nano Lett. Org. Lett. ORG PROCESS RES DEV ORGANOMETALLICS J. Org. Chem. J. Phys. Chem. J. Phys. Chem. A J. Phys. Chem. B J. Phys. Chem. C J. Phys. Chem. Lett. Analyst Anal. Methods Biomater. Sci. Catal. Sci. Technol. Chem. Commun. Chem. Soc. Rev. CHEM EDUC RES PRACT CRYSTENGCOMM Dalton Trans. Energy Environ. Sci. ENVIRON SCI-NANO ENVIRON SCI-PROC IMP ENVIRON SCI-WAT RES Faraday Discuss. Food Funct. Green Chem. Inorg. Chem. Front. Integr. Biol. J. Anal. At. Spectrom. J. Mater. Chem. A J. Mater. Chem. B J. Mater. Chem. C Lab Chip Mater. Chem. Front. Mater. Horiz. MEDCHEMCOMM Metallomics Mol. Biosyst. Mol. Syst. Des. Eng. Nanoscale Nanoscale Horiz. Nat. Prod. Rep. New J. Chem. Org. Biomol. Chem. Org. Chem. Front. PHOTOCH PHOTOBIO SCI PCCP Polym. Chem.
×
引用
GB/T 7714-2015
复制
MLA
复制
APA
复制
导出至
BibTeX EndNote RefMan NoteFirst NoteExpress
×
0
微信
客服QQ
Book学术公众号 扫码关注我们
反馈
×
意见反馈
请填写您的意见或建议
请填写您的手机或邮箱
×
提示
您的信息不完整,为了账户安全,请先补充。
现在去补充
×
提示
您因"违规操作"
具体请查看互助需知
我知道了
×
提示
现在去查看 取消
×
提示
确定
Book学术官方微信
Book学术文献互助
Book学术文献互助群
群 号:481959085
Book学术
文献互助 智能选刊 最新文献 互助须知 联系我们:info@booksci.cn
Book学术提供免费学术资源搜索服务,方便国内外学者检索中英文文献。致力于提供最便捷和优质的服务体验。
Copyright © 2023 Book学术 All rights reserved.
ghs 京公网安备 11010802042870号 京ICP备2023020795号-1