Day 1 Mon, October 17, 2022最新文献

{"title":"Towards Low-Cost Zero Liquid Discharge in Offshore Production Operations","authors":"M. Z. Mohd Sahak, S.R. Mohd Shafian, Shazleen Saadon, Maung Maung Myo Thant","doi":"10.2118/210758-ms","DOIUrl":"https://doi.org/10.2118/210758-ms","url":null,"abstract":"\u0000 Produced water from oil and gas operations across the globe is steadily rising towards a 3:1 ratio of oil production, if not managed properly leads to pollution and severe environmental impact. Treatment and disposal costs remain the primary concern with the ongoing global push towards the transition to cleaner energy and Zero Liquid Discharge (ZLD). Typical PWRI specifications required are Oil-In-Water (OIW) less than 5-10ppm, total suspended solids less than 10ppm, particle size typically less than 2μm for other contaminants and chemicals. These physical and chemical properties depend on the geographic location of the field and reservoir formations, resulting in high treatment costs and complex operations. A new PWRI technology which focuses on reducing the oil droplets' size was studied. In series of laboratory experiments conducted, it was found that an optimum combination of surfactant concentration and mixing intensity was able to effectively reduce OIW size, preventing the formation of larger particles due to the reduced surface size and contact area of the oil droplets and subsequently lower injectivity risk. As a result, produced water with OIW content as high as 300 ppm can be reinjected, leading to a smaller system footprint. It is expected that this technology could accelerate the implementation of PWRI offshore. As produced water stream usually increases towards the latter years of oil and gas fields, this low-cost PWRI technology provides an enormous opportunity at matured offshore assets without substantial investment in new facilities thus favoring project economics. With the ongoing global push towards the transition to cleaner energy and zero liquid discharge, this process is contributing to the sustainable operation of upstream facilities by reducing discharge to the sea, reducing the exposure of hydrocarbon and contaminants from the reservoir to the environment, and supporting SDG12: Responsible Consumption and Production.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116978301","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}

{"title":"Activated Carbon Type Selection to Reduce DEA and MDEA Foaming Tendency and Foam Stability","authors":"Nurlan Kazankapov, P. Vergara, Nurlan Zhaksylykov","doi":"10.2118/210743-ms","DOIUrl":"https://doi.org/10.2118/210743-ms","url":null,"abstract":"\u0000 Amine filtration that usually includes particulate and carbon filter is one of the critical processes of a sour gas sweetening unit that ensures low foaming tendency of amine. Activated carbon adsorption bed is crucial to remove hydrocarbon and surfactants e.g. lube oil, corrosion inhibitor. However, based on empirical analysis and field data, type of activated carbons selection must be carefully performed for the specific amine solution and selected antifoam agent, rather than by-default selection of commonly used carbon types e.g. bituminous carbon. Moreover, removal of surfactants, such as antifoam from amine does not necessarily reduce foaming tendency for all amine types. The aim of the paper is to identify the effectiveness of various activated carbon types on circulated DEA and MDEA solutions, as well as impact of removal antifoam agent on the foaming tendency and foam stability.\u0000 Bituminous and coconut shell activated carbon samples were used for the laboratory tests. The activated carbon type selection for DEA and MDEA was based on amine foaming tendency and foam stability e.g. total suspended solids, foam height and collapse time, and solution opacity.\u0000 Numerous laboratory tests confirmed higher effectiveness of bituminous activated carbon for DEA and coconut carbon for MDEA. Also, it was noted that removal of polyglycol antifoam agent from MDEA e.g. by bituminous carbon does not result in lower foaming tendency and foam stability. Therefore, careful examination of activated carbon type for specific amine solution is required to ensure required amine solution quality.\u0000 It is widely known that removal of antifoam positively affects amine foaming tendency. However, the current study indicated that the rule does not apply for all amine solution types and the selection might need special evaluation to avoid process upsets.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122606158","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}

{"title":"Well Portfolio Optimisation: Accelerating Generation of Well Intervention Candidates with Automated Analytics and Machine Learning - A Case Study from Attaka Field, Indonesia","authors":"Edwin Siahaan, Irwan Mamat, Senna Sun Laksana, Agung Setyowibowo, Aulia Ahmad Naufal, Octy Edrianana Wulandari, Sabrina Metra, Ardi Karta Nainggolan, Okky Idelian Arinandy, Livia Ellen, Maharani Devira Pramita, Agnes Tjiong, Yus Wilian, P. Songchitruksa","doi":"10.2118/210614-ms","DOIUrl":"https://doi.org/10.2118/210614-ms","url":null,"abstract":"\u0000 Advancements in technology, complemented with the abundance of static and historical data brought AI and digital automation adapted very well into the oil and gas industry. Specially to solve the challenges by the engineers in selecting well intervention candidates. In Attaka Field, a multi-layered offshore field in Indonesia, workover and well service (WOWS) have been one of the strategies to reduce production decline. With traditional workflows that absorb data from multiple unconsolidated sources and data format and resource limitation, reviewing 400+ wells that penetrates more than 200 reservoirs may take 2-3 months process with a reduced scope of review. As an addition, not all data and values are justified for the prioritization process. An intelligent automated solution termed as WEPON was developed to improve decision speed and quality in Attaka Field WOWS candidate screening.\u0000 WEPON was built on top of a data science platform to ease the development, production and maintenance of the analytics engine and its data pipeline. More than 15 data sources, ranging from reservoir properties, allocated production data, up to well schematics were consumed and aggregated in this solution's flow. The main components for WEPON includes: 1. Technical analysis with analytics and ML plus multi-criteria decision-making process to identify high potential completions, both produced and virgin ones 2. Adopting from the field's old workflow, feasibility checks to surface and subsurface constraints for the proposed completions 3. Diagnosing the wells and determine the right workover/ intervention opportunities 4. Calculating each well's subsurface and surface risks, and historical success rate to be integrated with the well's NPV to produce its expected value (EV) 5. Running on-demand economic analysis accessible from the solution's UI, the engine is tied into the operator's economic analysis tool that contains the currently used calculation and scheme 6. A presentation of the results on a web-based application.\u0000 As the main process is triggered to be run on a weekly basis, the automation of WEPON helps to increase Attaka Field review size to the whole fields, as well as reducing 89.7% of time from 3 days to review a well to hours of run to review the whole field, enabling engineers to spend more time on high-cognitive components of the existing workflows. Moreover, it has shifted the approach to a more data-driven one leading up to smarter decisions. The implementation of this WEPON is the pilot in the Indonesian National Oil Company, PERTAMINA. This is also the first time the solution developed on a data science platform, allowing the tool to be evergreen and extensible process. This implementation is also the first one to integrate an economic analysis tool through its API.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127437418","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}

{"title":"Optimising the Jansz-Io Trunkline Next Project Using Integrated Production Modelling","authors":"M. Barzi, Ewen Siu Ming Sze","doi":"10.2118/210655-ms","DOIUrl":"https://doi.org/10.2118/210655-ms","url":null,"abstract":"\u0000 The Chevron-operated Gorgon asset is the largest single resource project in Australia, with a portfolio of offshore gas fields to supply gas via two trunklines (Gorgon and Jansz-Io) to a three-train, 15.6 MTPA LNG plant and a 300 TJ/D domestic gas plant on Barrow Island. Gorgon will be a legacy project, with decades of production anticipated from the development of backfill fields gas resources. To realise the value of the asset, it is critical to select the right projects and execute them at the right time. Greater Gorgon Integrated Production Modelling (IPM) has been developed by Chevron Australia's gas supply team on behalf of the Gorgon Joint Venture (Australian Subsidiaries of Chevron, ExxonMobil, Shell, Osaka Gas, Tokyo Gas and JERA) to specifically enable optimisation of both the subsurface and surface value chain. It integrates reservoirs, wells, and subsea production networks to enable rigorous assessment of various portfolio-level development and planning scenarios.\u0000 The focus of this paper is on the Jansz-Io trunkline, which is initially supplied by the massive depletion drive Jansz-Io field, and the key decision of how to maintain production post development of the Gorgon Stage 2 (GS2) project. To inform this key decision, extensive evaluation was conducted using coupled INTERSECT (IX) IPM model to assess Jansz-Io Compression (J-IC) concepts (floating platform vs subsea compression). The IX-IPM model includes either detailed IX dynamic simulation or simplified material balance (MBAL) reservoirs, and a detailed production system that captures the full pressure hydraulics and their complex interactions. Using this IX-IPM model, a systematic staircase approach was applied, starting with a minimum facility concept, before sequentially adding more functionalities (power, capacity, phasing and backfill fields tie-in) and quantifying their incremental benefits. This enabled comprehensive understanding of the compression model's pressure hydraulic performance and various value trade-offs at each step. A fit-for-purpose, fixed power compression model was implemented to commence the staircase assessment. Once subsea compression was selected, and as the assessment matured, vendor compressor performance curves were adopted for more rigorous modelling.\u0000 Overall, the Greater Gorgon coupled IX-IPM model has proved to be invaluable in the assessment of the J-IC concept select and supported the Final Investment Decision (FID) on J-IC in 2021. The coupled IX-IPM model is continually refined with greater engineering resolution and additional production history to support the wider Gorgon asset decisions.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"68 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133310632","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}

{"title":"Method of Characteristics Based Model for a Coaxial Borehole Heat Exchanger","authors":"Rohit Duggal, R. Rayudu, J. Hinkley, J. Burnell, M. Mcguinness","doi":"10.2118/210689-ms","DOIUrl":"https://doi.org/10.2118/210689-ms","url":null,"abstract":"\u0000 Mature petroleum fields provide readily accessible wells for geothermal energy extraction in many parts of the world. Likewise, the major hydrocarbon-producing region of New Zealand, the Taranaki region, has many mature wells with high temperatures (∼150 °C) measured at the bottom. Borehole heat exchangers could be a cost-effective way of producing geothermal energy from these wells. Therefore, the purpose of this study is to present a mathematical model capable of evaluating the potential of geothermal energy production from unused wells.\u0000 We first set up our mathematical model using the Method of Characteristics for the wellbore heat exchangers. A co-axial borehole heat exchanger is selected for our study due to its simple design and popularity in use. The model is then validated against the analytical results available in the literature.\u0000 For the first time, a study utilizing borehole heat exchangers to produce geothermal energy is being conducted in New Zealand. This study will help boost interest in reusing unused wells for residential and industrial direct use applications. Based on our model, the capability of alternate fluids such as supercritical CO2 to further enhance the performance of heat exchange will be analyzed in the future.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"55 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123140741","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}

{"title":"Compressor Dry Gas Seal Failure Mitigation for Reliable Gas Injection System at Banyu Urip Field","authors":"N. S. Huang, Y. H. Putra","doi":"10.2118/210697-ms","DOIUrl":"https://doi.org/10.2118/210697-ms","url":null,"abstract":"\u0000 The gas injection system at Banyu Urip oil production facility in Indonesia consists of two compressor trains. Each train comprises one LP and one HP centrifugal compressor with a gas dehydration system in between. In 2020, one dehydration system experienced fouling and subsequently increased the gas moisture content. The condition initiated corrosion product formation flowing to both the LP and HP compressors of the particular train and subsequently damaged the compressor Dry Gas Seal (DGS) system.\u0000 The paper will be focusing on the investigation of two dry gas seal failure cases due to contaminated process gas by corrosion product. The corrosion product blocked the seal gas strainer of HP compressor and caused reverse flow across the labyrinths seal, exposing the dry gas seal to dirty gas. Additionally, as the process gas coming into the LP compressor has not been dehydrated, field inspections revealed the second failure case that the process gas condensation caused accumulation of the fine debris at the orifice plate of the seal gas leakage line.\u0000 Various improvements and dry gas seal system modifications were carried out to cope with the dry gas seal failures, such as the installation of duplex seal gas strainer to allow strainer replacement without shutting down the compressor. Furthermore, the Electrical Heat Tracing (EHT) installation at the seal orifice plate also successfully prevented the process gas condensation. Upon implementation of the strategies, the Banyu Urip facility successfully managed to improve the reliability of the gas injection system despite fouling gas dehydration unit.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124220824","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}

{"title":"Design, Operation and Maintenance of Subsea High Integrity Pressure Protection System and Subsea Automated Pig Launcher for Shallow Water Gas Condensate Field Development in Malaysia","authors":"Farah Julieana Nasri Huang, Muhammad Fikri Hashim, Siti Aisyah Omar","doi":"10.2118/210768-ms","DOIUrl":"https://doi.org/10.2118/210768-ms","url":null,"abstract":"\u0000 \u0000 \u0000 This paper provides an overview of design, operation, and maintenance of Subsea High Integrity Pressure Protection System (HIPPS) and Subsea Automated Pig Launcher (SAPL) in a shallow water gas condensate field development offshore Sarawak, Malaysia. It will outline the key technical drivers for the subsea field architecture development and technology qualification programme that was undertaken to manage the risk and uncertainties with deployment and operation of new subsea technology.\u0000 \u0000 \u0000 \u0000 The shallow water field hereby denotes as \"Field K\" is located approximately 200 km offshore Sarawak, Malaysia at water depth of around 80 meter. The field consists of two (2) subsea wells and is expected to deliver non-associated gas at rate of 200 MMscf/d to a Central Processing Platform (CPP), located approximately 5 km away from the wells. The field was initially planned to be developed using a wellhead platform but mid-way through the project, it was decided for Field K to be developed using Subsea Production System (SPS) with the following key requirements: -\u0000 Meet production target of 200 MMscf/d Achieve production availability of 96% Diverless philosophy throughout the field life Utilize the procured 24 inch Carbon Steel (CS) pipeline with design pressure of 83 barg Implement safety protection system that complies to Safety Integrity Level (SIL) 4 requirement to safeguard downstream facilities from the wells Closed in Tubing Head Pressure (CITHP) of 240 barg. Operational pigging to be carried out every 3 months and intelligent pigging every five (5) year for the 24 inch CS pipeline Any new technology to be implemented shall reach minimum Technology Readiness Level (TRL) 5 as per API 17N prior to its installation.\u0000 \u0000 \u0000 \u0000 A subsea technology screening and gap assessment was performed using API 17N and Company Internal Standards, and it was decided for the field to be developed using two 7 in. horizontal subsea tree, with two unit of Subsea HIPPS on manifold and retrievable Subsea Automated Pig Launcher at Pipeline End Termination (PLET). The field commenced its operation in December 2012 and was able to meet all the field key requirements identified. It was also the first subsea shallow water field that was designed, build, and operated by the Company. The paper will also highlight the key lessons learned and best practices during design, operation and maintenance that can be shared with other Operators and Industry.\u0000 \u0000 \u0000 \u0000 The paper will outline the design, operational consideration, and necessary technology qualification program for new/modified subsea technology i.e., Subsea HIPPS and Subsea Automated Pig Launcher prior to deployment.\u0000","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121092695","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}

{"title":"Advanced Gas Separation Membrane for Optimised Methane Recovery and Reduction of Green House Gas Emission","authors":"J. Murphy, Steven Vassiloudis, Norris Aden September, Masoud Eghtedari, Dimitrios Koulouris","doi":"10.2118/210626-ms","DOIUrl":"https://doi.org/10.2118/210626-ms","url":null,"abstract":"\u0000 Carbon Dioxide is a greenhouse gas naturally found as a component in natural gas, biogas and landfill gas and is also generated whilst flaring or burning the waste methane/gases. For CO2 capture and CO2-CH4 separation, we have investigated the membrane-based technology which offers high energy efficiency, simple modules and process design, reduced footprint, and enhanced energy content of the product gas whilst reducing pipeline corrosion problems and minimising greenhouse gas (GHG) emission. Gas separation membranes require not only materials with excellent separation performance such as selectivity and permeability but also resistant to high temperatures and pressures.\u0000 In this work, we have examined the performance of advanced polymeric membranes made from the high-performance intrinsic polyimide material for the recovery of methane and subsequent reduction of GHG emission in natural gas and biogas upgrading applications. Pressure-driven gas separation simulations were performed using the intrinsic parameters of hollow-fibre membranes. It was found that employing the advanced polyimide membrane allows a wider range of operating temperatures (up to 80 °C) and pressures (500 kPag to 100,000 kPag) whilst achieving performance and GHG emission reduction goals. Thus, we employed an innovative concept by combining the advanced membrane materials with a novel multi-stage separation process to recover the CH4 up to 95%-99% in the product (retentate) and CO2 concentration of up to 95%-98% in off-gas (permeate).\u0000 Subsequent field-tests for the membranes durability, stability and relative capacity and separation performance compared to cellulose acetate (CA) based membrane systems. These tests have found that the polyimide hollow-fibre membranes are resistant to degradation from hydrogen sulphide (H2S), heavy hydrocarbons (HHCs), and are less susceptible to time effected degradation of permeance and selectivity.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"22 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115257068","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}