Day 3 Fri, March 03, 2023最新文献

{"title":"Sand Data Acquisition in Gas Terminal: Challenges and Opportunities","authors":"T. M. Y. Tuan Mahmud, T. Z. T Aziz, Maung Maung Myo Thant, M. F. C Daud, Juhaida M. Johar","doi":"10.2523/iptc-22956-ea","DOIUrl":"https://doi.org/10.2523/iptc-22956-ea","url":null,"abstract":"\u0000 To maximize the hydrocarbon production from wells with sand, the new operating philosophy adopted for sand control. It focusses on limiting production based on the acceptable erosion risk instead of sand production rate. To achieve this, combination of sand production data and laboratory analysis on particle size of the produced sand is crucial. This paper aims to present the challenges and solutions applied for gas terminal sand data acquisition and lab analysis to obtain representative sand data.\u0000 A discussion on typical sand acquisition technologies is discussed. The experience from sub-optimal performance within the company are analyzed, the improvement opportunities are identified. Due to the volatile nature of condensate as compared to crude oil, alternative to conventional sampling method need to be applied for gas terminals. Dual particle filtration setup was developed to capture the wider particle range down to 1 micron. The data acquisition was conducted using a closed loop sand sampling system where the outlet of the sampling equipment is connected back to the processing system. To cover the dynamic of sand production, the data acquisition conducted at both normal and pigging operation for 6 hours continuous duration. The collected samples were analyzed using Automated Minerology imaging technology for particle sand distribution and minerology determination\u0000 The facility was not designed to receive sand including sand sampling facilities, hence imposed several challenges to acquire the sand data. From the experience during the sampling activity, there are few good observations and lessons learnt from utilizing the innovative approach as follows.\u0000 The online continuous sampling allows longer sampling duration without causing interruption to operation. The dual particle filtration ensures as much as possible solid particles that pass through the system will be filtered for analysis. The close loop sampling setup minimizes the exposure of harmful hydrocarbon to the personnel with might contain hazardous contaminant. Sampling that is conducted at different operation mode i.e., normal and pigging will provide wider range of sand PSD and volume.\u0000 Due to fines sand, only a small volume of sample was captured at the filter and insufficient for the analysis using conventional LPSA/Dry Sieve method. The recent technology approach via Automated Minerology imaging technology eliminates the issue of limited sample volume.\u0000 The experience from the sand data acquisition activity enhances understanding and provides opportunities to explore other sampling technologies/techniques and analysis methods. It is important for the team to assess in totality.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129223548","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":"Generation of Sodium Hypochlorite from Produced Water","authors":"M. M. M. Shah, M. F. M. Timyati, Tengku Muhamad Alif Luqman Tengku Mizam, Dzulkarnain B Azaman","doi":"10.2523/iptc-23090-ea","DOIUrl":"https://doi.org/10.2523/iptc-23090-ea","url":null,"abstract":"\u0000 The major process in crude oil terminal was the separation of light hydrocarbon and water from crude using heat. The daily crude output capacity of a crude oil terminal is in between 90 and 100 kbd. The produced water from the separation unit will flow into the produced water tank before being delivered to the skimmer pits for further treatment. Following treatment, the effluent will be released into the ocean in accordance with the standards set by the Department of the Environment (DOE). Approximately 1,085,681 kl of water with a high concentration of chlorine were discharged by the crude oil terminal per year.\u0000 With a high chlorine concentration in place, the large amount of produced water can be used to generate chloralkaline feed. Even if it is now crucial from an environmental standpoint because generated water is regarded as the most significant waste stream, there still needs to be a plan in place for the crude oil terminal to reuse or recycle the wastewater. A baseline analysis was carried out with the present wastewater volume to confirm that water reuse and recycling may provide value, protect the environment, and help the main company to realize its sustainability agenda. Increasing the amount of produced water and wastewater in operations, lowering reliance on outside water supplies, and ensuring the commercial viability of resources are other goals of this study.\u0000 In this study, electro-chlorination (ECU), a water filtering process, and a test for free and total chlorine were all used to carry out experiment work utilizing the HACH method. These tests were performed to see out how much chlorine was present in the sodium hypochlorite solution that the ECU generates. The outcome showed that the electro-chlorination process would produce a more alkaline solution the longer it operated. It results from the electrolysis process, which increases the concentration of OH- ions in the solution.\u0000 Laboratory testing is done to confirm that the produced water from the crude oil terminal can be used to electrogenerate hydrogen and sodium hypochlorite. The wastewater was subjected to three (3) tests, the first of which involved water filtration to remove suspended particulates, the second of which involved electro-chlorination using an electro-chlorination unit (ECU), which produced NaOCl as a product and H2 as a by-product. Finally, a dilution experiment is conducted to lower the concentration of the NaOCl solution so that it is within the range prior to the Free and Total Chlorine test. Using a Hach DR900 machine, the solution is then tested to determine the amount of free and total chlorine present in the effluent.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"399 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121803209","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":"Research and Practice of Steam Huff and Puff Depressurization and Increase Injection Volume Technology for the First Offshore Super Heavy Oil Reservoir in China","authors":"Hongyu Wang, Qiuxia Wang, H. Xiaodong, Zhang Hongwen, Hao Liu, Cheng Wang, Hua Zhang, Zhiyuan Wang, Peng Dou","doi":"10.2523/iptc-23057-ms","DOIUrl":"https://doi.org/10.2523/iptc-23057-ms","url":null,"abstract":"\u0000 The surface crude oil viscosity of the first ultra-heavy oil field in Bohai Oilfield is more than 50,00mpa·s, which is unable to be developed under the condition of original formation temperature and requires steam stimulation. In the first period of steam huff and puff well, due to sufficient formation energy, steam injection pressure is high in the process of steam injection. The measures to reduce the steam injection speed are mostly adopted in the field, but it will lead to the problem of large wellbore heat loss and affect the steam stimulation heat injection effect. In this paper, based on the oil characteristics of the first ultra-heavy oil field in Bohai Oilfield, the evaluation of oil soluble surfactant was carried out, and the experimental study of pre-injection of oil soluble surfactant to reduce steam injection pressure was carried out. It has been successfully applied in the development of the first ultra-heavy oil in Bohai oilfield. The results show that the oil soluble surfactant with asphaltene dispersibility has better temperature resistance and viscosity reduction effect, and the viscosity reduction effect is more than 95% before and after aging. Laboratory experiments show that the oil soluble surfactant can reduce the steam displacement resistance of the displacement front and the affected area. When the injection amount of oil soluble surfactant is 0.2PV, the maximum steam injection pressure can be reduced by 22.9% and the steady steam injection pressure by 10.8%. The design treatment radius of oil soluble surfactant is 0.15m, and the field test shows that the steam injection pressure decreases by 1.1MPa during steam injection.\u0000 After adopting the depressurization and increase injection volume technology, the field injection pressure is effectively reduced, the steam injection effect of ultra-heavy oil is guaranteed, and the technical guarantee for the subsequent development, promotion and application of ultra-heavy oil is provided.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"140 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124430884","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":"Application of Fracture Propagation and Production Simulation Technology to Multi-Stage Length Optimisation in Horizontal Wells","authors":"Xiaojun Ding, Wei Zhou, Jinlian Bai, Dongjiao Yuan, Liming Lian, Jinghua Chen, Haizhu Zhao, Xianming Li, Xiao Yang, Yantao Deng, Xingning Huang","doi":"10.2523/iptc-23069-ms","DOIUrl":"https://doi.org/10.2523/iptc-23069-ms","url":null,"abstract":"\u0000 Low-permeability reservoirs are characterized by low oil and gas abundance, poor permeability, natural productivity lower than the lower limit of industrial oil flow, and rapid decline of formation energy. Hydraulic fracturing technology is widely used for the development of low-porosity and low-permeability reservoirs. The hydraulic fractures formed by using the hydraulic fracturing technology are the \"underground highway\" for oil and gas flowing from the deep reservoir to the wellbore. The combination between the long well section of the horizontal well in the reservoir and the wellbore can greatly improve the utilization of oil and gas resources in the reservoir. Therefore, hydraulic fracturing is the key technology to improve the production of low-permeability reservoirs. This paper establishes a volume fracturing propagation model by using the finite element method and discrete element method, and conducts the fracture propagation simulation of multi cluster fracturing in horizontal wells of low-permeability Nanyishan reservoirs in Qinghai Oilfield. The results show that when the stress difference（Difference between the maximum horizontal principal stress and the minimum horizontal principal stress） is less than 4 MPa, volume cracks tend to be generated. When the stress difference is higher than 5 MPa, plane cracks are mainly generated. The natural fracture density affects the volume fracturing effect only under the condition of low stress difference. When the stress difference is 3 MPa, the number of perforating clusters is increased, the cluster spacing is reduced, the improvement area is not significantly increased, the cracks between clusters are seriously interfered, and local cracks are merged. When the stress difference is 5 MPa, there is relatively weak interference between clusters. The increase of perforation clusters promotes the communication between natural fractures, volume fracture development, and expansion of reconstruction area. The research results of this paper provide strong technical support for optimizing the fracturing scheme, improving the single well productivity of low-permeability reservoirs, and developing low-permeability reservoirs in a cost-effective way.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"57 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133654570","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":"Revealing the Hikurangi Subduction Zone with Joint Sparse OBN and Streamer FWI","authors":"Zongying Gong, Xinyue Gao, Xiaodong Wu, Yi Xie, B. Hung, N. Bangs","doi":"10.2523/iptc-22944-ea","DOIUrl":"https://doi.org/10.2523/iptc-22944-ea","url":null,"abstract":"\u0000 Full-waveform inversion (FWI) utilizing long-offset ocean bottom node (OBN) data has become a key velocity model building tool for resolving complex velocities for deeper targets. Acquiring such OBN datasets with dense shot and receiver sampling remains costly. Sparse OBN data has been studied in recent years to reduce acquisition expense while maintaining desired benefits for FWI. Whereas sparse OBN data can provide velocities comparable to dense OBN data, it alone cannot provide seismic images and gathers fit for interpretation purposes. We demonstrate a cost-effective approach using joint sparse OBN and streamer FWI that effectively updates the deep velocity of a complex subduction zone in the Hikurangi margin near New Zealand's East Coast. The streamer data is then migrated to provide detailed and accurate images fit for interpretation.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116914978","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":"A Breakthrough in Completion Technology—Development of Interventionless Hydrostatic-Set Isolation Packer for High-Pressure, Ultradeep Well","authors":"S. Gupta, J. Singh, A. Rudic, Agnes Tan, D. Chua, K. G. Goh, Abhinandan Tripathi","doi":"10.2523/iptc-23033-ms","DOIUrl":"https://doi.org/10.2523/iptc-23033-ms","url":null,"abstract":"\u0000 An ultradeep well, as commonly drilled in the Gulf of Mexico, can run up to 35,000 ft of total depth. The pressure at such depths is extremely high, at approximately 22,500 psi. These wells require highly specialized rigs with expensive day rates; therefore, a significant part of the cost to drill and complete a well is the rig time. As such, minimizing the rig time results in significant cost savings. Often, these wells have a high deviation angle and \"S\" curve, placing the completion packers at the limits of wireline access. Therefore, completion planning is critical for a successful well completion execution and to reduce the rig time and operational risks. One way to eliminate multiple trips is to set the packer using interventionless methods. Many commercial products are available with designs using hydrostatic setting by means of atmospheric chamber(s), pressure pulse telemetry, and hydro-mechanical-chemical devices. However, these are not designed for the pressure demands of ultradeep wells.\u0000 After careful consideration of the available products, a new high-performance, modular, removable, interventionless high-pressure-rated production packer that conforms with API SPEC 11D1 (2009) V0 validation grade was developed. Under a tight development schedule, the new product was developed to meet the needs of ultradeep well completions. The packer comprises slips for anchoring and elastomeric elements to provide a sealing capability for zonal isolation. A packer setting module was developed to be attached to the bottom of the packer and set the packer by enabling a fixed volume of high-pressure control fluid to flow from the packer setting chamber to the atmospheric chamber through an intricate flow conduit. An analytical calculation was performed to estimate the resistance coefficient for each feature of the flow conduit, which helped to calculate the macro-level flow characteristics (flow rate, overall packer setting time, and setting piston speed) and the micro-level flow characteristics (Reynolds number, differential pressure, kinetic head, and head losses at steady-state conditions) as well as to optimize the setting mechanism design. The same characteristics for transient flow were evaluated using computational fluid dynamics (CFD) analysis. An experimental proof-of-concept test was conducted on a small-scale version of the flow conduit and, to understand and validate the analytical flow behavior prediction and further optimize the flow conduit, an in-situ high-speed data-acquisition monitoring system was designed to record transient behavior at a high rate of 20,000 samples per second. The measured characteristics from the experimental test matched well with the analytical calculations and CFD analysis.\u0000 Component-level testing was conducted on the packer element to verify element integrity at 15,000- and 20,000-psi isolation differential pressures. The component-level test was successful, enabling further rigorous testing per API SPEC 1","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"2017 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132989410","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":"Non-Conventional Engineering Approaches to Effectively Shut Off Highly Deviated Gas Producer Wells in One of the World Oldest Gas Producers: Myanmar Experiences","authors":"Pravin Nair Venugopalan, Wan Mohamad Safwan, Yin Min Htun, Hset Winn, Siti Aisyah Abdul Ghani, F. Yahaya, S. A. Sy M Shahril, Khairil Anuar Kamal, Kelvinder Singh, Nigel Yong, Kai San Wong, Sanggeetha Kalidas","doi":"10.2523/iptc-22997-ea","DOIUrl":"https://doi.org/10.2523/iptc-22997-ea","url":null,"abstract":"\u0000 The aim of this project is to reduce the water cut in highly deviated well and subsequently enhance gas production of an offshore gas producer. Well A is located in a mature field in the Andaman Sea and contains 10% CO2 and 400 μg/m3 mercury. Due to the high-water cut, the well was struggling to meet its daily gas nomination, and any further decline in production would reduce the national daily gas supply, thus leading to penalties to the operator if not tackled properly.\u0000 With limited historical data acquisition opportunities at the location, adjacent well performance and well test data were correlated to pinpoint the problematic zones that were contributing to the high-water production being shut off. The well construction posed several challenges for installation, as severe completion ovality and minimum internal diameter (ID) at landing nipple restricted conventional plug application. Elastomers with high expansion capability were made-to-order to fully seal around the casing liner ID for effective downhole barrier isolation. Furthermore, the presence of CO2 content in produced gas may potentially cause elastomer swelling and embrittlement, leading to downhole failure. Guided by the lessons learned from previous operations, a structured engineering approach was undertaken to select a bridge plug with a customized deployment method to ensure the successful zonal shut-off operation for Well A.\u0000 A high expansion mechanical plug (>30% ratio) dressed in customized swellable elastomers was selected instead of conventional inflatable plugs to tackle swelling and embrittlement concerns due to high CO2. The elastomer was required to meet the gas-tight requirement without the need to spot cement above it and should be economically viable. The plug was to be deployed through coiled tubing to enable activation of the plug mechanism via the hydraulic setting tool and cater for contingencies post-plug setting such as nitrogen kickoff. During execution, the water production layers were successfully shut off within the planned duration while meeting safety objectives. Upon flowing the well, the instantaneous gas gain increased by 190% and WGR (Water Gas Ratio) reduced by 70%, allowing production to flow without any unplanned shutdown. Despite the successful operation, it is highly recommended that production logging is performed post-operation to confirm the state of the downhole condition.\u0000 Dealing with a mature well with declining production due to water loading is a problem for any operator. Every solution must lead to cost savings & able to prolong the production life of well. As iterated above, zone shut-off using the high expansion mechanical plug was able to enhance production from Well A, thus meeting the gas nomination supply. This paper will help other operators who are experiencing the same problem and drive replication efforts.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"170 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121037162","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":"The Borehole Properties Analysist Using Advanced Algorithms and Automatic Inversion","authors":"Ida Bagus Gede Hermawan Manuaba, Mohammad Jad Kareem, Mustafa Al Mubarak, G. Santoso","doi":"10.2523/iptc-22731-ea","DOIUrl":"https://doi.org/10.2523/iptc-22731-ea","url":null,"abstract":"\u0000 The study is based on multi well analysist drilled side by side in carbonate reservoir using high-resolution resistivity image. The objective is to define reservoir characterization, facies architecture, heterogeneity, and connectivity between two wells that is ready for reservoir modeling.\u0000 The methods presented in this paper are using an automatic inversion and advanced algorithm to generate matrix conductivity images and curves, histogram, analyses rock texture heterogeneities, quantify fluid filled vugs density from high resolution borehole images, fast extraction of dips (beds, fractures), delineate planar features crossing deviated borehole over long distances, extract fracture traces and statistics.\u0000 More than 3,000 picks of boundaries and fractures were found in a 3,300 ft horizontal length. Those divided into 6 different categories (Bed Boundary, Conductive Fracture, Discontinuous Conductive Fracture, Resistive Fracture, Litho-Bound Fracture, and Vugular fracture). Using high-definition imaging-while-drilling service provides supreme logging-while-drilling (LWD) imaging for reservoir description, from structural modeling, sedimentology analysis, image-based porosity determination and thin-bed analysis.\u0000 The presence of heterogeneity in carbonates poses a challenge for the characterization of such rocks. The identification of textural variations advanced techniques in borehole image analysis have been applied and presented good results that determine secondary porosity and litho-facies, and, moreover, delivered new insight into previously established interpretations of the reservoir. The data comparison and validation to other measurement show a significant relationship to bring the value even beyond. By using an automatic inversion, the geological interpretation can be constantly delivered around the clock with higher consistency with the number of feature variation.\u0000 It has been demonstrated that with the advanced analysis, microelectrical borehole images can provide quantitative measures of important reservoir parameters. Accuracy and consistency have been greatly improved since the introduction of microelectrical borehole image logging and subsequent automatic interpretation workflows.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"45 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117340811","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":"Novel Approach of Autonomous Drilling Using Rotary Steerable System in Middle Eastern Oil and Gas Wells","authors":"Victor Oliveira, M. Elsadig, A. Al-Ghazzawi, A. Osman, Abdullah M. Al Dossary","doi":"10.2523/iptc-22975-ms","DOIUrl":"https://doi.org/10.2523/iptc-22975-ms","url":null,"abstract":"\u0000 The history of wellbore trajectory control can be traced back to the days of drilling with rotary assemblies. During that time, experienced directional drillers (DDs) used their knowledge about the response of bottomhole assemblies (BHA) in a specific area or field by means of drilling parameters and assembly configurations changes. This method required intensive field and human experience and still resulted in considerable deviations from the required trajectories. Technologies evolved with the introduction of motor and rotary steerable systems that have additional predicted directional responses, however, considerable human intervention was still required to control the trajectories. As the rotary steerable system (RSS) tools matured, entire sections of the well trajectories were automated with closed-loop trajectory control that required minimum human intervention. However, the curved sections continued to be drilled in manual modes with DDs interventions.\u0000 A major operator focused on evaluating and validating a novel approach from its major directional drilling service provider using the auto-curve drilling mode to automatically drill the curved sections without human intervention and complete the missing puzzle of the autonomous well construction. The system is based on a minimum curvature method, which updates the target inclination and azimuth in a closed-loop system, similar to the one used in the hold inclination & azimuth method. Expected run rate of penetration (ROP) and planned dogleg severity (DLS) are needed while programming the tool for the RSS calculation update. Once the auto-curve mode is engaged in the RSS tool, updating the target inclination and azimuth will continue along the well to deliver the programmed DLS as per the ROP input.\u0000 A detailed comparison of the measurements has been performed through three directional drilling curve sections in three wells. Combining the data of the three wells, 5,632-ft were drilled in different sections. The results were promising and showed an average of 70% reduction of human intervention. Furthermore, regarding the well positioning, the new auto-curve automation technology delivered the wells within the required profile target tolerances with minimum tortuosity.\u0000 The novel autonomous curve drilling technology helped to minimize human error, enhance the accuracy of well positioning, and improve hole quality for drilling and workover operations. The system proved that this autonomous drilling technology is capable of improved well trajectory delivery with minimum intervention, faster well delivery, and reduction in operation costs.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"212 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116297641","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":"Successful Development of the Deepest Oligocene Syn-Rift Sediment in the Malaysia-Thailand Joint Development Area: Is the Deeper Zone Our Future?","authors":"Avidianto Suryo Setiawan, M. Simatupang, Arif Rachmadi, Sippakorn Apiwathanasorn, Samsul Bari Moh. Said","doi":"10.2523/iptc-23010-ms","DOIUrl":"https://doi.org/10.2523/iptc-23010-ms","url":null,"abstract":"\u0000 Field X, located in the offshore Malaysia-Thailand Joint Development Area (MTJDA), comprises multiple stack gas reservoirs with a combination of trap styles. This paper highlights the challenges and lessons learned in successfully developing the deepest Oligocene syn-rift sediment in the MTJDA, which was initially discovered by the one appraisal well drilled in 2010. A further comprehensive evaluation was performed to justify the deepening of development drilling in 2019 (as appraisal cum to development) and 2021-2022 (as infill wells) with promising results.\u0000 The discovery of hydrocarbon resources in the deepest Oligocene syn-rift sediment at MTJDA was part of an appraisal program by deepening the development well. The two wells discovered and proved the presence of multi-stack gas sands in this deepest section (3800-4000 mTVDSS). The clastic sediment deposits in a fluvio-deltaic system. The reservoir properties of this syn-rift sediment are better than the early post-rift sediment (early Miocene). The production test confirmed the initial gas flow rate of about 15 MMscfd. A comprehensive analysis was performed to evaluate a sizeable volume before more development wells were proposed for this deepest sediment.\u0000 The initial understanding of Late Oligocene syn-rift sediment was very minimal at the beginning of the project. One of the neighbouring well information suggests lacustrine delta environments based on core data. However, a fair-quality seismic amplitude shows a broader channel belt (over 3km width) which usually exists in the braided stream. In view of the two appraisals cum to development wells' successful discovery, more than five wells were proposed to penetrate this zone as a deepening target from the existing discovered zone. The fit for purpose well designed with a monobore concept, was selected. Upon completing the development drilling with denser well spacing, it suggests the discontinuity of blocky sand presence with multiple fluid contact (stratigraphic compartmentalization), which is usually found in narrower channel reservoirs at the deltaic system rather than the braided stream. The good reservoir properties observe from the open hole log, formation tester, and production test. The success story of these wells opens future opportunities to plan more deep well to develop Oligocene sediment, which prove to be a good hydrocarbon producer.\u0000 This paper updates the previous understanding of geology, such as the depositional environment, and the understanding of reservoir productivity of the Oligocene sediment in MTJDA. It also proved sizable reservoir quality with extensive lateral presence and good productivity. Hence, the company foresee a promising future from this deep reservoir to prolong its long-term development plan.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"188 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128187894","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}