Sunisa Watcharasing, Chularat Wattanakit, Saros Salakhum, Anittha Prasertsab, P. Kiattikomol
This project aims to convert production sand waste from oil & gas exploration & production process to be high value silica-based product, Zeolites, and explore opportunities to lower amount of sand waste disposal to landfill. This is one key item in Circular Model for Oil & Gas Exploration & Production. Zeolites is a microporous crystalline aluminosilicate material, which possess a superior characteristic in terms of high surface area. Therefore, it is widely utilized in many industries such as adsorbent, ion exchange, and catalysts in oil refining and petrochemical industry. In this work, various types of zeolites were synthesized from PTTEP production sand waste, to prove concept of turning sand waste to high value-added product, called zeolite. In normal operation, sand waste was sent to dispose as landfill about 50 Ton/annual. To synthesize zeolite from sand waste, there are three main steps, which are 1) Sand Pretreatment, 2) Silica Extraction, and 3) Zeolite Synthesis. Firstly, sand waste from petroleum production were pretreated by water and acid washing. Then, nanosilica was extracted out from pretreated sand by boiling the pretreated sand in NaOH solution at temperature 150 C for 4 hrs, then precipitate them to get the nanosilica substances. It was further used as a reactant source for zeolite synthesis. In the last step, the extracted silica was reacted with Structure Directing Agent (SDA); zeolite template, under optimal condition of hydrothermal treatment process to obtain zeolites product. Zeolites synthesis from production sand waste was firstly initiated and successfully achieved in lab phase, to prove of concept for extracting silica source as a substance for zeolite synthesis. Various types of zeolites (Silicalite-1, ZSM-5, Faujasite (FAU), Mordenite, and Zeolite A) can be synthesized from PTTEP sand waste with synthesis yield 80%, 68%, 85%, 40%, and 81%, respectively. This indicates that silica source from production sand waste can be utilized as a reactant source for zeolites synthesis. The next phase of prototype unit is under design phase, to allow unit can be operated more versatile, and automatically run. From this novel technology, it is expected to reduce an amount of production sand waste disposal out from separator to landfill about 50 Ton/year. The synthesized zeolites from prototype phase will be further applied in many potential applications such as an adsorbent in wastewater treatment process, as catalyst, and moisture adsorbent in oil & gas dehydration unit. New findings and requirements discovered during the prototype test will be used to iteratively optimize and improve the design of the sand to zeolites process for future industrial-scale implementation.
{"title":"Synthesis of Zeolites from Production Sand Waste: The Circular Model for Oil and Gas Exploration and Production","authors":"Sunisa Watcharasing, Chularat Wattanakit, Saros Salakhum, Anittha Prasertsab, P. Kiattikomol","doi":"10.4043/31420-ms","DOIUrl":"https://doi.org/10.4043/31420-ms","url":null,"abstract":"\u0000 This project aims to convert production sand waste from oil & gas exploration & production process to be high value silica-based product, Zeolites, and explore opportunities to lower amount of sand waste disposal to landfill. This is one key item in Circular Model for Oil & Gas Exploration & Production. Zeolites is a microporous crystalline aluminosilicate material, which possess a superior characteristic in terms of high surface area. Therefore, it is widely utilized in many industries such as adsorbent, ion exchange, and catalysts in oil refining and petrochemical industry.\u0000 In this work, various types of zeolites were synthesized from PTTEP production sand waste, to prove concept of turning sand waste to high value-added product, called zeolite. In normal operation, sand waste was sent to dispose as landfill about 50 Ton/annual. To synthesize zeolite from sand waste, there are three main steps, which are 1) Sand Pretreatment, 2) Silica Extraction, and 3) Zeolite Synthesis. Firstly, sand waste from petroleum production were pretreated by water and acid washing. Then, nanosilica was extracted out from pretreated sand by boiling the pretreated sand in NaOH solution at temperature 150 C for 4 hrs, then precipitate them to get the nanosilica substances. It was further used as a reactant source for zeolite synthesis. In the last step, the extracted silica was reacted with Structure Directing Agent (SDA); zeolite template, under optimal condition of hydrothermal treatment process to obtain zeolites product.\u0000 Zeolites synthesis from production sand waste was firstly initiated and successfully achieved in lab phase, to prove of concept for extracting silica source as a substance for zeolite synthesis. Various types of zeolites (Silicalite-1, ZSM-5, Faujasite (FAU), Mordenite, and Zeolite A) can be synthesized from PTTEP sand waste with synthesis yield 80%, 68%, 85%, 40%, and 81%, respectively. This indicates that silica source from production sand waste can be utilized as a reactant source for zeolites synthesis. The next phase of prototype unit is under design phase, to allow unit can be operated more versatile, and automatically run. From this novel technology, it is expected to reduce an amount of production sand waste disposal out from separator to landfill about 50 Ton/year. The synthesized zeolites from prototype phase will be further applied in many potential applications such as an adsorbent in wastewater treatment process, as catalyst, and moisture adsorbent in oil & gas dehydration unit. New findings and requirements discovered during the prototype test will be used to iteratively optimize and improve the design of the sand to zeolites process for future industrial-scale implementation.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"97 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85315841","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}
V. Y. Hon, N. Halim, S. R. Panuganti, Ivy Ching Hsia Chai, I. M. Saaid
A full suite of integrated online emulsion management system (IOEMS) transforming the handling of decades old crude oil emulsion production issue at field from reactively onsite to proactively online. This technology is made possible with insights on emulsion formation from physics-based molecular models, access of huge database on crude oil properties, emulsion toughness and demulsifier chemistries, coupling with statistical and supervised machine learning application. Intriguingly, this innovation journey began with designing an enhanced oil recovery (EOR) technology in mind. Study on generating stable emulsion for oil recovery was the aim of our pioneering research initially. We successfully developed physics-based models to assess emulsion stability at molecular level. We then applied these models retrospectively for produced emulsion management, with advancement in data science and computational power. The technology concept is to design and plan demulsification strategy based on predicted emulsion stability. The robustness of IOEMS lies in the combination of the goods of accurate interpolated data based on machine learning, with that of extrapolated data from physics-based model. Firstly, mathematical models of relationships between crude properties and emulsion stability index (ESI) were established using statistical method. This led to a good 90% match with laboratory ESI data. Secondly, a demulsifier selection functionality was developed based on machine learning, covering dozens type of demulsifier. We used operating conditions, fluid and demulsifier properties as training data input, with the corresponding lab bottle tests outcomes as training data output to build a classification model via supervised learning algorithms. Its predictive accuracy is at 87%. By bringing the produced emulsion assessment from on-site to online, offshore emulsion sampling and the associated lab bottle tests are minimized. Health safety and environment (HSE) risks are reduced accordingly with the decrease of human intervention in field sampling. The emulsion stability predictive functionality enables operation to prepare early in anticipation of sudden spike of emulsion production and thus, avoiding unplanned well shut in. Furthermore, this function is especially useful when emulsion samples or historical data are not available during field development stage. Meanwhile, the recommended demulsifers from IOEMS are at 17% lower cost than the incumbent demulsifiers used at fields in Malayia, in addition to 90% manhour reduction from conventional trial and error demulsifier screening in lab. Ultimately, the IOEMS has successfully enabled step-change in oilfield emulsion management via an efficient and reliable scientific based digital platform.
{"title":"Integrated Online Emulsion Management System","authors":"V. Y. Hon, N. Halim, S. R. Panuganti, Ivy Ching Hsia Chai, I. M. Saaid","doi":"10.4043/31441-ms","DOIUrl":"https://doi.org/10.4043/31441-ms","url":null,"abstract":"\u0000 A full suite of integrated online emulsion management system (IOEMS) transforming the handling of decades old crude oil emulsion production issue at field from reactively onsite to proactively online. This technology is made possible with insights on emulsion formation from physics-based molecular models, access of huge database on crude oil properties, emulsion toughness and demulsifier chemistries, coupling with statistical and supervised machine learning application.\u0000 Intriguingly, this innovation journey began with designing an enhanced oil recovery (EOR) technology in mind. Study on generating stable emulsion for oil recovery was the aim of our pioneering research initially. We successfully developed physics-based models to assess emulsion stability at molecular level. We then applied these models retrospectively for produced emulsion management, with advancement in data science and computational power. The technology concept is to design and plan demulsification strategy based on predicted emulsion stability. The robustness of IOEMS lies in the combination of the goods of accurate interpolated data based on machine learning, with that of extrapolated data from physics-based model. Firstly, mathematical models of relationships between crude properties and emulsion stability index (ESI) were established using statistical method. This led to a good 90% match with laboratory ESI data. Secondly, a demulsifier selection functionality was developed based on machine learning, covering dozens type of demulsifier. We used operating conditions, fluid and demulsifier properties as training data input, with the corresponding lab bottle tests outcomes as training data output to build a classification model via supervised learning algorithms. Its predictive accuracy is at 87%.\u0000 By bringing the produced emulsion assessment from on-site to online, offshore emulsion sampling and the associated lab bottle tests are minimized. Health safety and environment (HSE) risks are reduced accordingly with the decrease of human intervention in field sampling. The emulsion stability predictive functionality enables operation to prepare early in anticipation of sudden spike of emulsion production and thus, avoiding unplanned well shut in. Furthermore, this function is especially useful when emulsion samples or historical data are not available during field development stage. Meanwhile, the recommended demulsifers from IOEMS are at 17% lower cost than the incumbent demulsifiers used at fields in Malayia, in addition to 90% manhour reduction from conventional trial and error demulsifier screening in lab.\u0000 Ultimately, the IOEMS has successfully enabled step-change in oilfield emulsion management via an efficient and reliable scientific based digital platform.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"71 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84144331","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}
W. H. F. W Shafie, R. Khan, M. Mahmood, Mazri Mohd Ali, H. Zubir, Girish Kamal
The key objective of this paper is to present the methodology of the Upstream Inspection, Maintenance and Assurance Guideline (U-IMAGe) and its implementation across a fleet of ageing assets. The U-IMAGe has been developed within PETRONAS’, Upstream Operational Excellence (OE), Center of Excellence (CoE). The U-IMAGe provides a flexible, efficient, cost effective new way of inspecting and maintaining current assets and equipment, without compromising the inherent safety and health of the asset. The U-IMAGe is applicable to Upstream assets, facilities and equipment including disciplines such as wells, pipelines, structural (offshore, fixed and floating and onshore), electrical, instrumentation, telecommunications, process, storage tanks, mechanical static, rotating equipment, subsea, single point moorings and piping systems.
{"title":"U-IMAGe: An Optimised, Efficient and Cost Effective Approach to the Inspection and Maintenance of Upstream Facilities","authors":"W. H. F. W Shafie, R. Khan, M. Mahmood, Mazri Mohd Ali, H. Zubir, Girish Kamal","doi":"10.4043/31530-ms","DOIUrl":"https://doi.org/10.4043/31530-ms","url":null,"abstract":"\u0000 \u0000 \u0000 The key objective of this paper is to present the methodology of the Upstream Inspection, Maintenance and Assurance Guideline (U-IMAGe) and its implementation across a fleet of ageing assets. The U-IMAGe has been developed within PETRONAS’, Upstream Operational Excellence (OE), Center of Excellence (CoE). The U-IMAGe provides a flexible, efficient, cost effective new way of inspecting and maintaining current assets and equipment, without compromising the inherent safety and health of the asset. The U-IMAGe is applicable to Upstream assets, facilities and equipment including disciplines such as wells, pipelines, structural (offshore, fixed and floating and onshore), electrical, instrumentation, telecommunications, process, storage tanks, mechanical static, rotating equipment, subsea, single point moorings and piping systems.\u0000","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"28 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83587889","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}
C. Colreavy, N. Boylan, K. Andersen, N. N. Huang, C. Girsang
Offshore structures are subjected to cyclic loading from a range of sources and an appreciation for how the underlying soil responds to that loading is essential for design. The behaviour of soil under cyclic loading differs to that from monotonic loading and advanced laboratory testing is required to assess this behaviour. This paper describes the behaviour of a deepwater soft clay under cyclic loading. The site is located offshore Sabah, Malaysia in water depths up to 1,200 m. As part of the geotechnical investigation for the site, a suite of cyclic simple shear tests was carried out on samples retrieved from boreholes on the site. Results from this suite of tests were used to establish a set of cyclic contour diagrams for the site. These contour diagrams will be used in the design of foundations for offshore structures at the site. This is the first comprehensive study of the cyclic behaviour of deepwater Malaysian clay. As such, they provide a useful starting point for the development of contour diagrams in similar soils.
{"title":"Cyclic Behaviour of a Malaysian Deepwater Clay","authors":"C. Colreavy, N. Boylan, K. Andersen, N. N. Huang, C. Girsang","doi":"10.4043/31518-ms","DOIUrl":"https://doi.org/10.4043/31518-ms","url":null,"abstract":"\u0000 Offshore structures are subjected to cyclic loading from a range of sources and an appreciation for how the underlying soil responds to that loading is essential for design. The behaviour of soil under cyclic loading differs to that from monotonic loading and advanced laboratory testing is required to assess this behaviour. This paper describes the behaviour of a deepwater soft clay under cyclic loading. The site is located offshore Sabah, Malaysia in water depths up to 1,200 m. As part of the geotechnical investigation for the site, a suite of cyclic simple shear tests was carried out on samples retrieved from boreholes on the site. Results from this suite of tests were used to establish a set of cyclic contour diagrams for the site. These contour diagrams will be used in the design of foundations for offshore structures at the site. This is the first comprehensive study of the cyclic behaviour of deepwater Malaysian clay. As such, they provide a useful starting point for the development of contour diagrams in similar soils.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"49 3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87956825","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}
E. Samuel, Mohd Faizal Yusoff, P. Bee, A. Hakam, Kasim B. Selamat, James Stevenson, N. Nopsiri
Designing and delivering a successful completion in a Subsea High Rate Gas Deepwater environment is known to be one of the most challenging aspects of a Field Development. For the specific case of high rate gas wells with reservoirs requiring sand control, it makes the completion reliability and longevity an uncompromising prerequisite, as it is well known that formation solids moving at high velocity through the wellbore can drastically affect the functionality and integrity of downhole equipment as well as the subsurface and production facilities. In addition, to the previously mentioned aspects, the complexities and costs associated with Well reentries and Workovers in a Subsea Deepwater environment can quickly erode the overall financial viability of a development program. This paper covers the sand control design and execution techniques applied to four (4) High Rate Gas Wells in the PTTEP's Block H Development in the Malaysian Deepwater region of Sabah, between 2020 and 2021.
{"title":"Applying Downhole Sand Control for High Rate Gas Completions in Deepwater Malaysia","authors":"E. Samuel, Mohd Faizal Yusoff, P. Bee, A. Hakam, Kasim B. Selamat, James Stevenson, N. Nopsiri","doi":"10.4043/31413-ms","DOIUrl":"https://doi.org/10.4043/31413-ms","url":null,"abstract":"\u0000 Designing and delivering a successful completion in a Subsea High Rate Gas Deepwater environment is known to be one of the most challenging aspects of a Field Development.\u0000 For the specific case of high rate gas wells with reservoirs requiring sand control, it makes the completion reliability and longevity an uncompromising prerequisite, as it is well known that formation solids moving at high velocity through the wellbore can drastically affect the functionality and integrity of downhole equipment as well as the subsurface and production facilities. In addition, to the previously mentioned aspects, the complexities and costs associated with Well reentries and Workovers in a Subsea Deepwater environment can quickly erode the overall financial viability of a development program.\u0000 This paper covers the sand control design and execution techniques applied to four (4) High Rate Gas Wells in the PTTEP's Block H Development in the Malaysian Deepwater region of Sabah, between 2020 and 2021.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"362 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76498840","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}
Legacy Unocal have drilled hundreds of exploration wells between 1970's to 1990's in Gulf of Thailand with semi-submersible drilling rigs and drillships. Those exploration wells were plugged and abandoned as per the requirements back in the 1970's which the subsea wellheads were not cut and removed. According to asset retirement obligation, all structures above seabed need to be removed before returning concession area. These subsea wellheads are planned for cut and recovery, however, there are many uncertainties in regard to well conditions which includes trapped gas in casing annulus and casing corrosion. The correct and safest approaches to cut and recovery are to perform wellbore logging runs, gas evaluations, and casing wall thickness investigation. The challenges faced in executing the logging runs in open water environment are to conduct safe, efficient, and reliable operations on Dynamic Positioning (DP) vessel which includes a work-class Remotely Operated Vehicle (ROV). The key factor is to attain as much information and quality logging data to engineer a successful cut and recovery campaign for these complex subsea abandonments. To perform this operation in open water, it can lead to inaccurate logging data due to uncompensated conditions. An innovative solution was collaboratively invented and developed with Business Partners to deploy Logging Tower Subsea Deployment system (LTSDS) to mimic static logging condition. The tower is self-standing design with a capability to rig up on different type of wellhead. The trial was performed but had complications of deployment due to weather impact. The new method, non-compensated real time logging on Electric Line, was introduced to improve time spent per wells. The comparison of logging results from both methods shown similar and reliable log interpretations. The remaining wells were logged with non-compensated real time method, which reduce operational time by 45% as well as lower associated operational risks. Other challenges encountered included logging depths 100 ft below mudline. Since some wells have shallower holdup depths or the tool could not pass due to encountering obstruction at shallow depths, gauge cutter was deployed with slickline unit to remove obstruction, followed by downhole high pressure jetting tool which was effectively helping to achieved logging intervals. Interpretation of logging data were completed on more than 100 wells and results were used to engineer a detailed cut and recovery campaign and utilize new technology that the team had sourced to execute the operation. With innovative designed set up of riser-less operation on light construction vessel, it is proven to meet objective of reliable logging data and cost efficiency and demonstrated flexibility for operation improvement.
{"title":"Riser-Less Surveillance for Aging Subsea Wellhead with Light Construction Vessel","authors":"Pobtorn Sripramote, Worawit Yingvorapant","doi":"10.4043/31485-ms","DOIUrl":"https://doi.org/10.4043/31485-ms","url":null,"abstract":"\u0000 Legacy Unocal have drilled hundreds of exploration wells between 1970's to 1990's in Gulf of Thailand with semi-submersible drilling rigs and drillships. Those exploration wells were plugged and abandoned as per the requirements back in the 1970's which the subsea wellheads were not cut and removed. According to asset retirement obligation, all structures above seabed need to be removed before returning concession area. These subsea wellheads are planned for cut and recovery, however, there are many uncertainties in regard to well conditions which includes trapped gas in casing annulus and casing corrosion. The correct and safest approaches to cut and recovery are to perform wellbore logging runs, gas evaluations, and casing wall thickness investigation.\u0000 The challenges faced in executing the logging runs in open water environment are to conduct safe, efficient, and reliable operations on Dynamic Positioning (DP) vessel which includes a work-class Remotely Operated Vehicle (ROV). The key factor is to attain as much information and quality logging data to engineer a successful cut and recovery campaign for these complex subsea abandonments.\u0000 To perform this operation in open water, it can lead to inaccurate logging data due to uncompensated conditions. An innovative solution was collaboratively invented and developed with Business Partners to deploy Logging Tower Subsea Deployment system (LTSDS) to mimic static logging condition. The tower is self-standing design with a capability to rig up on different type of wellhead. The trial was performed but had complications of deployment due to weather impact. The new method, non-compensated real time logging on Electric Line, was introduced to improve time spent per wells. The comparison of logging results from both methods shown similar and reliable log interpretations. The remaining wells were logged with non-compensated real time method, which reduce operational time by 45% as well as lower associated operational risks.\u0000 Other challenges encountered included logging depths 100 ft below mudline. Since some wells have shallower holdup depths or the tool could not pass due to encountering obstruction at shallow depths, gauge cutter was deployed with slickline unit to remove obstruction, followed by downhole high pressure jetting tool which was effectively helping to achieved logging intervals.\u0000 Interpretation of logging data were completed on more than 100 wells and results were used to engineer a detailed cut and recovery campaign and utilize new technology that the team had sourced to execute the operation.\u0000 With innovative designed set up of riser-less operation on light construction vessel, it is proven to meet objective of reliable logging data and cost efficiency and demonstrated flexibility for operation improvement.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"76 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76616777","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}
R. Hidayat, P. S. Kurniawati, Aries Taufiq Kurniawan, Irwan Setyaji, Gerardus Putra Pancawisna, R. Marindha, K. Umar, G. D. Dahnil, Risal Rahman, M. N. Jamal, Yufa Safitri, Raden-Muhamad Prayuda Azhar, William Lodiman, Hibroni Syarif
Well N-1 in Mahakam Sisi Nubi field, East Kalimantan, had a problem with water and condensate production up to 11,000 BLPD which instantly rendered the production facility overwhelmed despite the high 34 MMSCD gas rate. To solve this, reservoir production profiling using production logging tool was first carried out. Selection of existing zone isolation method was then compared, yet none satisfies the challenges in this well due to restriction and cost issues. A relatively new technology, High Expansion (HEX) Straddle Packer, was introduced as another alternative. A series of engineering design and followed by operation design was then carried out to solve the well problem safely. A dummy tool run with 2.875" OD and 30ft of length passed through the restriction safely. Caliper logging observes reduction in tubing ID from 3.9" to 3.0". Temperature of the borehole reached 115 deg C at 3417 mBRT of this well. The two water producing zones were next to each other with a total top reservoir to bottom reservoir length of 11 m. With these values, a custom 2.7" straddle packer was built and tested to required temperature and passed. Production simulation with 0.7" ID, indicated the well could still flow over its critical flow regime. After installation, the well flows with 11 MMSCFD of gas with ~1800 BLPD liquid produced, a 83% reduction over previous liquid flowrate. Despite the well flows only 30% from initial gas rate, this well can now flow at an acceptable liquid rate. The successful installation of the first HEX Straddle expands the portfolio of mechanical water shut off methods in Mahakam and in Indonesia as this was the first HEX Straddle installed in Indonesia. Further study and replications are needed, yet this method can be a viable alternative if other has failed for wells with similar problems.
东加里曼丹Mahakam Sisi Nubi油田的N-1井出现了水和凝析油产量高达11000桶/天的问题，尽管产气量高达34 MMSCD，但生产设施立即不堪重负。为了解决这一问题，首先利用生产测井工具进行了油藏生产剖面。然后比较了现有层间隔离方法的选择，但由于限制和成本问题，没有一种方法能满足该井的挑战。一种相对较新的技术，高膨胀(HEX)跨式封隔器，作为另一种选择。在此基础上进行了一系列的工程设计和施工设计，安全解决了该井的问题。一个外径为2.875”、长度为30英尺的假工具安全地通过了限制。井径测井观察到油管内径从3.9”减小到3.0”。井眼温度在3417 mBRT时达到115℃。两个产水区相邻，上储层至下储层总长度为11 m。根据这些数据，制作了定制的2.7”跨式封隔器，并对其进行了温度测试并通过了测试。生产模拟显示，该井的内径为0.7”，但仍可超过其临界流量范围。安装后，该井的产气量为11 MMSCFD，产液量为1800 BLPD，比之前的产液量减少了83%。尽管该井的产气量仅为初始产气量的30%，但该井现在可以以可接受的液体产气量生产。首个HEX跨接器的成功安装扩大了Mahakam和印度尼西亚的机械断水方法组合，因为这是在印度尼西亚安装的首个HEX跨接器。需要进一步的研究和重复，但如果其他方法在类似问题的井中失败，这种方法可以作为可行的替代方法。
{"title":"Mechanical Isolation of a Challenging Reservoir: First Installation of High Expansion Straddle Packer in Indonesia","authors":"R. Hidayat, P. S. Kurniawati, Aries Taufiq Kurniawan, Irwan Setyaji, Gerardus Putra Pancawisna, R. Marindha, K. Umar, G. D. Dahnil, Risal Rahman, M. N. Jamal, Yufa Safitri, Raden-Muhamad Prayuda Azhar, William Lodiman, Hibroni Syarif","doi":"10.4043/31475-ms","DOIUrl":"https://doi.org/10.4043/31475-ms","url":null,"abstract":"\u0000 Well N-1 in Mahakam Sisi Nubi field, East Kalimantan, had a problem with water and condensate production up to 11,000 BLPD which instantly rendered the production facility overwhelmed despite the high 34 MMSCD gas rate. To solve this, reservoir production profiling using production logging tool was first carried out. Selection of existing zone isolation method was then compared, yet none satisfies the challenges in this well due to restriction and cost issues. A relatively new technology, High Expansion (HEX) Straddle Packer, was introduced as another alternative. A series of engineering design and followed by operation design was then carried out to solve the well problem safely.\u0000 A dummy tool run with 2.875\" OD and 30ft of length passed through the restriction safely. Caliper logging observes reduction in tubing ID from 3.9\" to 3.0\". Temperature of the borehole reached 115 deg C at 3417 mBRT of this well. The two water producing zones were next to each other with a total top reservoir to bottom reservoir length of 11 m. With these values, a custom 2.7\" straddle packer was built and tested to required temperature and passed. Production simulation with 0.7\" ID, indicated the well could still flow over its critical flow regime. After installation, the well flows with 11 MMSCFD of gas with ~1800 BLPD liquid produced, a 83% reduction over previous liquid flowrate. Despite the well flows only 30% from initial gas rate, this well can now flow at an acceptable liquid rate.\u0000 The successful installation of the first HEX Straddle expands the portfolio of mechanical water shut off methods in Mahakam and in Indonesia as this was the first HEX Straddle installed in Indonesia. Further study and replications are needed, yet this method can be a viable alternative if other has failed for wells with similar problems.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"113 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74536148","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}
Maung Maung Myo Thant, M. F. Che Daud, T. M. Y. Tuan Mahmud, Z. Kayat, Ivan Chee Xian Lung, Tran Nguyet Ngo, Rob McNaught, T. Wood, See Chin Kiat
Sand production in oil and gas fields severely affects multiphase flow pipelines, piping and production facilities result in erosion damages and operational difficulties including valves, bends and other geometric fittings leading to loss of primary containment (LOPC). Presently, there is no technology available which can control sand erosion in real-time and help optimize production. This paper aims to present the first field deployment of a uniquely engineered flow modification device in debottlenecking a high sand producing well and maximizing production while reduction in erosion. The sand erosion challenge can be overcome by using a patented Erosion Control Technology (ECT), to deflect and redistribute sand in the product flow stream. ECT has been successfully developed and validated through three test programs between 2016-2019. Following these, ECT technology maturity has been qualified for field application and selected to be deployed by PETRONAS, in one of the offshore fields located in Sabah, Malaysia, which is currently experiencing high erosion due to high sand production. The ECT pipe spool consists of a 3D printed Inconel 718 alloy insert integrated into carbon steel pipe to protect an elbow from sand erosion within the topsides wellhead piping system upstream of the wellhead choke. A control elbow upstream of the ECT device has also been installed to act as a mean of comparison throughout the pilot. The protected elbow and control elbow will be monitored using manual UT at marked locations to measure localized wall thickness variation over the pilot testing period. The pilot is part way through its test program having been installed and commissioned at the end of 2021. Photos of the arrangement are shared in this paper along with the baseline wall thickness measurement. The pilot trial success criteria are to show that the protected elbow will have minimal wall loss compared to the control elbow showing the effectiveness of ECT. The pilot expects ECT to reduce erosion due to sand and safeguard the facilities as well as maximize well production in preventing shortfall in total field production.
{"title":"First Field Deployment of Erosion Control Technology for High Sand Production Wells in Offshore Malaysia","authors":"Maung Maung Myo Thant, M. F. Che Daud, T. M. Y. Tuan Mahmud, Z. Kayat, Ivan Chee Xian Lung, Tran Nguyet Ngo, Rob McNaught, T. Wood, See Chin Kiat","doi":"10.4043/31554-ms","DOIUrl":"https://doi.org/10.4043/31554-ms","url":null,"abstract":"\u0000 Sand production in oil and gas fields severely affects multiphase flow pipelines, piping and production facilities result in erosion damages and operational difficulties including valves, bends and other geometric fittings leading to loss of primary containment (LOPC). Presently, there is no technology available which can control sand erosion in real-time and help optimize production. This paper aims to present the first field deployment of a uniquely engineered flow modification device in debottlenecking a high sand producing well and maximizing production while reduction in erosion.\u0000 The sand erosion challenge can be overcome by using a patented Erosion Control Technology (ECT), to deflect and redistribute sand in the product flow stream. ECT has been successfully developed and validated through three test programs between 2016-2019. Following these, ECT technology maturity has been qualified for field application and selected to be deployed by PETRONAS, in one of the offshore fields located in Sabah, Malaysia, which is currently experiencing high erosion due to high sand production. The ECT pipe spool consists of a 3D printed Inconel 718 alloy insert integrated into carbon steel pipe to protect an elbow from sand erosion within the topsides wellhead piping system upstream of the wellhead choke. A control elbow upstream of the ECT device has also been installed to act as a mean of comparison throughout the pilot.\u0000 The protected elbow and control elbow will be monitored using manual UT at marked locations to measure localized wall thickness variation over the pilot testing period. The pilot is part way through its test program having been installed and commissioned at the end of 2021. Photos of the arrangement are shared in this paper along with the baseline wall thickness measurement.\u0000 The pilot trial success criteria are to show that the protected elbow will have minimal wall loss compared to the control elbow showing the effectiveness of ECT. The pilot expects ECT to reduce erosion due to sand and safeguard the facilities as well as maximize well production in preventing shortfall in total field production.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"6 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79269887","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}
In this era of low oil price, it is vital for the operators to deliver low cost wells with enhanced production. A continuous technological advancement in the oil and gas industry has played a pivotal role in establishing high returns on investments. Many techniques have been developed so far in this aspiration to improve the quality of the reservoirs, enhanced production mechanisms and efficient drilling operations. Situated in Sulaiman fold belt of Pakistan a large Gas field was discovered by one of the NOCs in 2011. It was a carbonate reservoir, laterally extended on a large portion resulting in a big volumetric reservoir. When discovered it was observed that being naturally fractured and having low reservoir pressure it was plagued with massive loss of circulation and associated drilling challenges. Conventional drilling technique has also resulted in immense reservoir damage. To overcome the challenges of overbalanced drilling the operator started drilling with underbalanced drilling methodology in this formation, which resulted in efficient drilling, saving time and cost. In order to improve the field economics, the operator decided to drill horizontally into this formation to maximize the production potential of each well. As a pilot project a well was designed to drill a horizontal leg of almost 504 m into this carbonate reservoir. It was obvious that this formation could not be drilled with conventional overbalanced mud system so it would be drilled with underbalanced multiphase foam drilling system. The biggest challenge in this gaseous foam drilling medium is to control the trajectory of the well as the measurement while drilling (MWD) system works through mud pulse telemetry that could only be done in an incompressible drilling fluid. To address this major glitch an electromagnetic (EM) MWD system was suggested that can transmit the signals via electromagnetic waves and is independent of the drilling medium being used. Based on the resistivity analysis of the formations laying above this reservoir, modeling was performed to design the most suitable measuring system. As the lateral was long and deep so the requirement of extended range antenna system was also incorporated so that signal transmission remain uninterrupted throughout the drilling operation. Through the application of this unconventional MWD technique the operator was able to drill the longest horizontal well in this block. The well was completed without any NPT in an excellent fashion and tested to evaluate the maximum flow potential of this reservoir. This application has shown the operators how to reach beyond the limits in such troublesome formations.
{"title":"Electromagnetic Measurement While Drilling System Enabled the Operator to Reach Beyond the Limits in a Multiphase Foam Drilling Medium","authors":"Qasim Ashraf, A. Khalid, Syed Ahrar Hussain","doi":"10.4043/31644-ms","DOIUrl":"https://doi.org/10.4043/31644-ms","url":null,"abstract":"\u0000 In this era of low oil price, it is vital for the operators to deliver low cost wells with enhanced production. A continuous technological advancement in the oil and gas industry has played a pivotal role in establishing high returns on investments. Many techniques have been developed so far in this aspiration to improve the quality of the reservoirs, enhanced production mechanisms and efficient drilling operations.\u0000 Situated in Sulaiman fold belt of Pakistan a large Gas field was discovered by one of the NOCs in 2011. It was a carbonate reservoir, laterally extended on a large portion resulting in a big volumetric reservoir. When discovered it was observed that being naturally fractured and having low reservoir pressure it was plagued with massive loss of circulation and associated drilling challenges. Conventional drilling technique has also resulted in immense reservoir damage. To overcome the challenges of overbalanced drilling the operator started drilling with underbalanced drilling methodology in this formation, which resulted in efficient drilling, saving time and cost.\u0000 In order to improve the field economics, the operator decided to drill horizontally into this formation to maximize the production potential of each well. As a pilot project a well was designed to drill a horizontal leg of almost 504 m into this carbonate reservoir. It was obvious that this formation could not be drilled with conventional overbalanced mud system so it would be drilled with underbalanced multiphase foam drilling system. The biggest challenge in this gaseous foam drilling medium is to control the trajectory of the well as the measurement while drilling (MWD) system works through mud pulse telemetry that could only be done in an incompressible drilling fluid.\u0000 To address this major glitch an electromagnetic (EM) MWD system was suggested that can transmit the signals via electromagnetic waves and is independent of the drilling medium being used. Based on the resistivity analysis of the formations laying above this reservoir, modeling was performed to design the most suitable measuring system. As the lateral was long and deep so the requirement of extended range antenna system was also incorporated so that signal transmission remain uninterrupted throughout the drilling operation.\u0000 Through the application of this unconventional MWD technique the operator was able to drill the longest horizontal well in this block. The well was completed without any NPT in an excellent fashion and tested to evaluate the maximum flow potential of this reservoir. This application has shown the operators how to reach beyond the limits in such troublesome formations.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"108 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79431424","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}
In a case study of four wells located in offshore Sabah Malaysia, a field application using microemulsion technology to develop a customized in-situ breaker solution enhanced production rate by removing oil-based mud (OBM) and synthetic based mud (SBM) filter cake and remediating near-wellbore damage. All wells were completed as open–hole horizontal wells. Key challenges of the field are the multiple sand layers interbedded with intra-reservoir shale intervals necessitating a complex well trajectory and an operational preference for drilling with SBM drill-in fluid (SBM DIF). Lower than expected production rates were associated a water-impermeable SBM DIF filter cake and solids residue resulting from a conventional breaker system being unable to fully remove emulsion damage and effectively disrupt the filtercake. A series of laboratory tests for return permeability using formation cores from the offset wells and ceramic discs were completed as part of a feasibility study prior to field trials of the new microemulsion breaker system - a customized formulation consisting of a proprietary surfactant blend, organic acid, corrosion inhibitor and brine designed to remove the damage caused by the SBM DIF and restore open-hole flow conditions. The new breaker system has ultra-low interfacial tension which, when pumped into the open-hole section and allowed to soak for a sufficient period of time, diffuses into the rock matrix and forms an in-situ microemulsion completely and uniformly cleaning the near wellbore environment of SBM DIF residue, dispersing solids and leaving all surfaces water-wet. Laboratory results described in this paper show that the customized microemulsion breaker has the capability to remove SBM DIF filter cake, remediate emulsion damage caused by SBM-DIF, and restores the rock matrix back to its original permeability and predrilled state. All four wells in this field application have exceeded their expected production rate. The customized microemulsion breaker is the major contributing factor.
{"title":"Novel Microemulsion Breaker System Remove Drill-in-Fluids Filter Cake and Remediate Near Wellbore Damage to Enhance Productivity of Horizontal Wells of Offshore Sabah, Malaysia","authors":"Nurul Amyra Jaffar, Nan Luan, Edo Arisandi","doi":"10.4043/31684-ms","DOIUrl":"https://doi.org/10.4043/31684-ms","url":null,"abstract":"\u0000 In a case study of four wells located in offshore Sabah Malaysia, a field application using microemulsion technology to develop a customized in-situ breaker solution enhanced production rate by removing oil-based mud (OBM) and synthetic based mud (SBM) filter cake and remediating near-wellbore damage. All wells were completed as open–hole horizontal wells. Key challenges of the field are the multiple sand layers interbedded with intra-reservoir shale intervals necessitating a complex well trajectory and an operational preference for drilling with SBM drill-in fluid (SBM DIF). Lower than expected production rates were associated a water-impermeable SBM DIF filter cake and solids residue resulting from a conventional breaker system being unable to fully remove emulsion damage and effectively disrupt the filtercake.\u0000 A series of laboratory tests for return permeability using formation cores from the offset wells and ceramic discs were completed as part of a feasibility study prior to field trials of the new microemulsion breaker system - a customized formulation consisting of a proprietary surfactant blend, organic acid, corrosion inhibitor and brine designed to remove the damage caused by the SBM DIF and restore open-hole flow conditions. The new breaker system has ultra-low interfacial tension which, when pumped into the open-hole section and allowed to soak for a sufficient period of time, diffuses into the rock matrix and forms an in-situ microemulsion completely and uniformly cleaning the near wellbore environment of SBM DIF residue, dispersing solids and leaving all surfaces water-wet.\u0000 Laboratory results described in this paper show that the customized microemulsion breaker has the capability to remove SBM DIF filter cake, remediate emulsion damage caused by SBM-DIF, and restores the rock matrix back to its original permeability and predrilled state. All four wells in this field application have exceeded their expected production rate. The customized microemulsion breaker is the major contributing factor.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75027032","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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