Day 1 Mon, November 02, 2020最新文献

{"title":"Topside Distributed Acoustic Sensing of Subsea Wells","authors":"A. Ellmauthaler, B. Seabrook, J. Maida, G. Wilson, J. Bush, J. Dupree, Mauricio Uribe","doi":"10.2118/200717-ms","DOIUrl":"https://doi.org/10.2118/200717-ms","url":null,"abstract":"\u0000 Topside interrogation for distributed acoustic sensing (DAS) of subsea wells for vertical seismic profiling (VSP), well integrity, and sand control requires optical engineering solutions to compensate for the insertion losses and back reflections accumulated through umbilicals, multiple wet- and dry-mate optical connectors, splices, optical feedthrough systems, and downhole sensing fiber and wet mates. Moreover, the acoustic bandwidth is inherently limited by the total length of the sensing fiber. To obviate these problems, we describe a subsea fiber topology with two ultralow loss transmission fibers from the topside to a remote optical circulator deployed in the optical flying lead at the subsea tree. This limits the sensing fiber portion of the total fiber length to the fiber located below the remote circulator, and eliminates all back reflections from the multiple subsea connectors above the remote circulator. The receiver arm in the DAS interrogator only senses pure backscatter light from below the circulator. The pulse repetition rate is only constrained by the fiber length below the remote circulator, thus enabling dry-tree equivalent acoustic bandwidths of 10+ kHz regardless of the tie-back distance. This yields significant signal-to-noise ratio (SNR) improvement via stacking and selective amplification, while further enabling sensing of high-frequency acoustic events occurring inside or in the vicinity of the wellbore. A fiber with enhanced back-reflectance is deployed in both the upper and lower completions inside a triple-tube cable design that provides a hydrogen-permeation barrier to delay onset of hydrogen-induced attenuation. Results from various laboratory and field trials are shown to validate system performance.","PeriodicalId":118168,"journal":{"name":"Day 1 Mon, November 02, 2020","volume":"64 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-11-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127040104","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":"Experimental Investigation of Ultrasound-Assisted Weak-Acid Hydrolysis of Crystalline Starch Nanoparticles for Chemical Enhanced Oil Recovery","authors":"R. Junin, A. Agi","doi":"10.4043/30071-ms","DOIUrl":"https://doi.org/10.4043/30071-ms","url":null,"abstract":"\u0000 Ascorbic acid was used to synthesize crystalline starch nanoparticles (CSNP) for the first time. The CSNP was isolated and the influence of the process variables on the physical properties, recovery yield and crystallinity were studied. Rheology of crystalline starch nanofluid (CSNF) was compared with cassava starch (CS) solution and xanthan. Interfacial tension (IFT) of CSNF was studied at various concentration and temperatures. Influence of concentration, temperature, salinity and their interaction with ultrasound were investigated. Sessile drop contact angle method was used to determine the wettability proficiency of CSNF on an initially oil-wet sandstone core. To justify the finding highlighted above, CSNF and CS solution were applied for EOR purposes at reservoir condition. The approaches were efficient in generating sphere-shaped and elongated nanoparticles (50 nm mean diameter) and higher yield of 39%. Increase in concentration, surface area and temperature of CS and CSNF increased viscosity in comparison to decline in viscosity as the temperature increases for xanthan. Increased concentration, salinity and temperature rise of CSNF decreased IFT and altered the wettability of the sandstone core. CSNF increased the oil recovery by 23% and was effective at high temperature high pressure reservoir conditions. The energy consumption and cost estimation has demonstrated that the methods and polymeric nanofluid are cost-effective than traditional methods and products.","PeriodicalId":118168,"journal":{"name":"Day 1 Mon, November 02, 2020","volume":"234 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115591306","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":"First Successful Utilisation of High Density Micronised Ilmenite in South East Asia","authors":"M. S. Razak, Farah Shakina Ezani","doi":"10.4043/30341-ms","DOIUrl":"https://doi.org/10.4043/30341-ms","url":null,"abstract":"\u0000 The objective of this paper is to share the Operator's first experience in utilizing ilmenite in an offshore HPHT well as part of a low cost well initiative and the value obtained by utilization of such a weighting agent in particular towards lowering ECD. After extensive testing micronized ilmenite was used as the weighting agent for the synthetic based drilling fluid (SBM) for the B1 well. This well was classified as high complexity with a narrow margin window and with predicted maximum bottom hole pressure of 12,013 psi at 3,990 m TVDDF.\u0000 Extensive laboratory testing was conducted to determine the optimum formulation for a 16 ppg SBM. Part of the methodology in the testing was conducting rheology comparisons between various weighting agents, manganese tetraoxide, barite and micronized ilmenite. The subsequent results were then run through hydraulics simulations to determine the best formulation for optimized hydraulics. Additional testing was conducted to determine the overall stability of the system including conducting static sag tests with a similar duration to the planned wireline logging operation.\u0000 The primary drivers for using this fluid were to reduce ECD in a narrow margin environment and facilitate the taking of good wireline logs by providing optimum hole conditions without any sag. The micronized ilmenite system successfully achieved a similar rheology to manganese tetraoxide with low PV's of less than 50 cP at 17 ppg and a sag index of less than 0.52. These properties were at an OWR of 80:20. This led to both the successful drilling of the well and completing the required wireline logging with no fluids related NPT or issues related to sag. During logging, the mud was static for 5 days without problems. The mud weight of 17 ppg was the highest density, at that time, at which the micronized ilmenite system had been used.","PeriodicalId":118168,"journal":{"name":"Day 1 Mon, November 02, 2020","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117152553","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":"Laser Drilling in Extremely Hard Formation","authors":"S. Batarseh, A. M. Al-Harith, Wisam J. Assiri, D. S. R. Alerigi","doi":"10.4043/30416-ms","DOIUrl":"https://doi.org/10.4043/30416-ms","url":null,"abstract":"\u0000 The objective of this work is to demonstrate the success and the ability of high power lasers beam to drill in extremely hard formations. The result showed that the rate of penetration in these formations is much faster than conventional drilling methods. Formations with high compressive strength can prevent or slow drilling and rock penetration. A High power laser program was established to overcome the limitations of conventional drilling methods and provide an innovative non-damaging technology as alternatives to current practices. The technology is not only able to drill in extremely hard formations but also enhances rock properties without compromising wellbore integrity.\u0000 For the past two decades, researchers attempted to deploy high power laser technology for several downhole applications, with no success because the power needed to penetrate the rock was insufficient. Laser technology has evolved and advanced recently, creating compact efficient, higher power, and economically feasible systems.\u0000 An experimental setup was designed to evaluate the performance of a high power laser in different rock types and with different compressive strengths, ranging from 12,000 to 43,000 psi. These samples were exposed to a high power laser for several applications. The results demonstrated that a high power laser could penetrate extreme rock formation in seconds, for example, at the lab scale, it took 3 seconds to drill 3 inches of basalt (43,000 psi compressive strength). The flow properties were also enhanced regardless of the compressive strength and hardness of the rock.\u0000 Laser technology attracted the oil and gas industry due to its unique features, such as the precision in controlling and orienting the energy in any direction. Laser drilling is independent of the reservoir stress orientation and magnitude. The laser generation unit is mounted on the surface and the laser beam delivered downhole via fiber optics cable. The system has a minimal footprint, is an environmentally friendly technology, and can drill and case simultaneously.\u0000 High power lasers have the potential to be the next intelligent drilling and completion generation that will change current practice. State-of-the-art high power laser technology provides an innovative and safe non-explosive based technology. Precision, speed, small footprint, and reliability are some of the properties of the technology that make it attractive for downhole applications.","PeriodicalId":118168,"journal":{"name":"Day 1 Mon, November 02, 2020","volume":"35 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123343412","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":"Agglomeration of Fines and Sand in the Separator","authors":"N.'.A. M Fauzi, T. Ganat, K. Elraies, S. Ridha, S. Zainal, W. Saphanuchart","doi":"10.4043/30102-ms","DOIUrl":"https://doi.org/10.4043/30102-ms","url":null,"abstract":"\u0000 Fines and sand capturing inside the separator is one of the methods to prevent solids carry over. Currently, there are ongoing studies to identify the suitable method to agglomerate the produced solids. Generally, heavier solids would be denser and easily settled at the bottom of the vessel, hence no solids carry over issues. Produced solids can be consisting of natural solids and/or artificial solids. Several types of polymers have been evaluated based on its agglomeration performance, rheology and compatibility as an approach to establish suitable particle size to minimize sand free rate.\u0000 The procedures involved include bottle test experiments coupled with particle size distribution (PSD) analysis via Laser Particle Size Analyzer (LPSA). The materials used in the experiments are glass beads with sizes of 50µm and 100µm, synthetic water (0.1M NaCl), a cationic polymer and an anionic polymer. Both polymers have high molecular weight which is known to provide good agglomeration capacity. For each experiment, a 5g of glass bead was placed together with 90mL of synthetic water in a 100mL measuring cylinder. The system was then tested using three polymer system; i) a single cationic polymer system, ii) a single anionic polymer system and iii) a combination of both cationic and anionic polymer system. Light agitation was applied on each, PSD was evaluated and results compared to those of the untreated samples.\u0000 The improvement of particle size distribution was observed for all three systems. The results will be discussed further in the paper. The novelty of this research is the application of the sand agglomeration mechanism towards surface sand capturing via separator.","PeriodicalId":118168,"journal":{"name":"Day 1 Mon, November 02, 2020","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117061403","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":"Rigid Riser System: Alternative System for Coiled Tubing Rig Up on Spar","authors":"Intiran Raman, J. Blacklock, Kasim B. Selamat, L. Chabot, M. N. Ghazali, R. Ramnarine","doi":"10.2118/184791-MS","DOIUrl":"https://doi.org/10.2118/184791-MS","url":null,"abstract":"\u0000 A rigid riser system has been designed, built, and proven as an effective method to conduct coiled tubing operations on floating platforms. This system is installed above the Christmas tree which is supported by the platform's production riser and riser tensioner system. The rigid riser set up is a passive system that does not require the use of a crane or other mechanisms to support or hold up the coiled tubing injector head during operations. The axial load resulting from the weight of the injector head, coiled tubing, and snubbing/pulling forces on the pipe are carried in compression through the rigid riser to the tree and wellhead. The excess capacity of the top tensioner riser (TTR) supports these loads while allowing for relative motion due to tide, waves, and platform motion.\u0000 The rigid riser system uses a purpose-built, heavy-wall riser and a spider beam insert to resist buckling effects and bending moments. In practice, this system has improved the rig-up time and mitigated HSE issues as compared to the conventional motion-compensated lift frame method.\u0000 In addition, the system has a support frame that increases the rigidity of the injector head and accessories, resisting the excessive bending and torsional loads imparted by back tension and movements of the coiled tubing (CT) reel. An engineering study was performed to determine the dynamic loads and stresses for the various operational and contingency conditions on all the components of the rigid riser system and to confirm sufficient capacity of the TTR system.\u0000 The rigid riser system has proven to be a safe and cost-effective solution for coiled tubing operations from a floating platform compared to current motion-compensated jacking frame systems. Coiled tubing well interventions were executed using the rigid riser system, and the operational results have been convincing. The passive nature of the system provides an HSE advantage by eliminating mechanical or human intervention during operation.\u0000 This paper reviews the design aspects of the rigid riser system, its advantages over the current coil tubing intervention systems, and the operational results after executing the coiled tubing interventions.","PeriodicalId":118168,"journal":{"name":"Day 1 Mon, November 02, 2020","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124377530","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}