Cong Lu, Li Zhili, Zheng Yunchuan, C. Yin, Yuan Canming, Yulong Zhou, Zhang Tao, Jianchun Guo
The pulse fracturing is widely used in unconventional reservoirs. It alternately pulse pumping the proppant slurry and clean fluid to form discontinuous placement proppant pillars in the artificial fractures and the pulse fracture conductivity is several orders of magnitude higher than conventional hydraulic fracture conductivity. However, the understanding of the deformation law of proppant pillar under the action of closure pressure and proppant normal stress is unclear, resulting in difficult to calculate the fracture conductivity and prefer proppant. Firstly, replacement construction and experimental displacement by Renault Similarity Criteria, three typical proppant pillars placement structures are extracted through the large-scale visualized flat plate device. The Young's modulus of the proppant pillars are calculated in modified API conductivity cell. Secondly, proppant pillars are dispersed into particles by the Smooth Particle Method (SPH). Using the parameters obtain from the above experiments, fracture-proppant pillar contact models are established to simulate the deformation process of proppant pillar and get normal stress of proppant particles. Thirdly, extracting the shape of stabilized proppant pillars, establish the fracture-proppant pillar flow model, calculate the fracture conductivity in different closure pressure. The simulation results show that as the closure pressure increases from 14MPa to 41MPa, the fracture width present an accelerated downward trend, The fracture width under the support of the initial radius of 9 mm proppant pillars are the largest, decreasing from 2.52mm to 1.72mm, the larger the radius of the proppant pillar, the greater the fracture width, the normal stress of three types of proppant pillar particles are both changed from 73MPa to 110MPa. The elliptical cylinder proppant pillar has the largest fracture conductivity. Its fracture conductivity is reduced from 12500D•cm to 3630D•cm. The larger the construction displacement and the pulse time of proppant slurry, the greater the fracture conductivity. The model in this article can calculate the normal stress of proppant particle and fracture conductivity in different closure pressure, which can significantly guide the choice of construction parameters and the type of proppant.
{"title":"A Novel Method for Characterizing the Dynamic Behavior of Proppant Pillars With Fracture Closure in Pulse Fracturing","authors":"Cong Lu, Li Zhili, Zheng Yunchuan, C. Yin, Yuan Canming, Yulong Zhou, Zhang Tao, Jianchun Guo","doi":"10.2118/195030-MS","DOIUrl":"https://doi.org/10.2118/195030-MS","url":null,"abstract":"\u0000 The pulse fracturing is widely used in unconventional reservoirs. It alternately pulse pumping the proppant slurry and clean fluid to form discontinuous placement proppant pillars in the artificial fractures and the pulse fracture conductivity is several orders of magnitude higher than conventional hydraulic fracture conductivity. However, the understanding of the deformation law of proppant pillar under the action of closure pressure and proppant normal stress is unclear, resulting in difficult to calculate the fracture conductivity and prefer proppant.\u0000 Firstly, replacement construction and experimental displacement by Renault Similarity Criteria, three typical proppant pillars placement structures are extracted through the large-scale visualized flat plate device. The Young's modulus of the proppant pillars are calculated in modified API conductivity cell. Secondly, proppant pillars are dispersed into particles by the Smooth Particle Method (SPH). Using the parameters obtain from the above experiments, fracture-proppant pillar contact models are established to simulate the deformation process of proppant pillar and get normal stress of proppant particles. Thirdly, extracting the shape of stabilized proppant pillars, establish the fracture-proppant pillar flow model, calculate the fracture conductivity in different closure pressure.\u0000 The simulation results show that as the closure pressure increases from 14MPa to 41MPa, the fracture width present an accelerated downward trend, The fracture width under the support of the initial radius of 9 mm proppant pillars are the largest, decreasing from 2.52mm to 1.72mm, the larger the radius of the proppant pillar, the greater the fracture width, the normal stress of three types of proppant pillar particles are both changed from 73MPa to 110MPa. The elliptical cylinder proppant pillar has the largest fracture conductivity. Its fracture conductivity is reduced from 12500D•cm to 3630D•cm. The larger the construction displacement and the pulse time of proppant slurry, the greater the fracture conductivity.\u0000 The model in this article can calculate the normal stress of proppant particle and fracture conductivity in different closure pressure, which can significantly guide the choice of construction parameters and the type of proppant.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"94 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88122379","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}
Accurate near-surface velocity models are required to correct for shallow velocity heterogeneities that can otherwise lead to the misinterpretation of seismic data, particularly in the case of low-relief structures. Here we show how a novel uphole acquisition system utilizing distributed acoustic sensing (DAS) technology can be used in a number of different ways to generate near-surface models. The novel smart DAS uphole system connects multiple shallow wells with one continuous optical fiber. The horizontal and vertical segments of the fiber allow several techniques for near-surface model building to be tested using the same system. Uphole surveys use the vertical fiber segments to make accurate, localized velocity measurements, while the directivity of the DAS fiber enables horizontal sections to be used for refraction tomography and surface-wave inversion. The smart DAS uphole acquisition system, which enables the collection of data for deep reflection imaging and near-surface characterization simultaneously, has been successfully tested for the first time. Data acquired from ten smart DAS upholes produced excellent early arrival waveform quality for picking and subsequent velocity model building. This direct velocity measurement of the near-surface can reduce uncertainty in the seismic interpretation. In addition, replacing the shallow part of the depth velocity model with the DAS uphole model resulted in significant improvements in the final depth image from topography. The directivity of DAS enables the recording of refracted events on horizontal fiber sections which have been picked as input to refraction tomography. This produces an alternative near-surface model that captures a larger volume of the subsurface. Ultimately, while the uphole velocity model is only suitable for removing long-wavelength components of near-surface variation, the refraction velocity model may allow for the correction of small-to-medium wavelength statics.
{"title":"Smart DAS Uphole Acquisition System for Near-Surface Model Building: Results from the First Successful Field Tests","authors":"Robert B. Smith, A. Bakulin, I. Silvestrov","doi":"10.2118/195154-MS","DOIUrl":"https://doi.org/10.2118/195154-MS","url":null,"abstract":"\u0000 Accurate near-surface velocity models are required to correct for shallow velocity heterogeneities that can otherwise lead to the misinterpretation of seismic data, particularly in the case of low-relief structures. Here we show how a novel uphole acquisition system utilizing distributed acoustic sensing (DAS) technology can be used in a number of different ways to generate near-surface models.\u0000 The novel smart DAS uphole system connects multiple shallow wells with one continuous optical fiber. The horizontal and vertical segments of the fiber allow several techniques for near-surface model building to be tested using the same system. Uphole surveys use the vertical fiber segments to make accurate, localized velocity measurements, while the directivity of the DAS fiber enables horizontal sections to be used for refraction tomography and surface-wave inversion.\u0000 The smart DAS uphole acquisition system, which enables the collection of data for deep reflection imaging and near-surface characterization simultaneously, has been successfully tested for the first time. Data acquired from ten smart DAS upholes produced excellent early arrival waveform quality for picking and subsequent velocity model building. This direct velocity measurement of the near-surface can reduce uncertainty in the seismic interpretation. In addition, replacing the shallow part of the depth velocity model with the DAS uphole model resulted in significant improvements in the final depth image from topography.\u0000 The directivity of DAS enables the recording of refracted events on horizontal fiber sections which have been picked as input to refraction tomography. This produces an alternative near-surface model that captures a larger volume of the subsurface. Ultimately, while the uphole velocity model is only suitable for removing long-wavelength components of near-surface variation, the refraction velocity model may allow for the correction of small-to-medium wavelength statics.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"293 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85215209","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}
Murtada A. Elhaj, O. Abdullatif, A. Abdulraheem, Amjed Hassan, A. Sultan
The science of Acoustics deals with the propagation of mechanical waves in the three phases of materials, solids, liquids, and gases. In exploration and reservoir engineering, acoustic wave velocities play an essential role in reservoir description. The primary challenge in the initial evaluation and characterization of reservoirs is related to the understanding of its geology, petrophysics, and geomechanics. Therefore, an accurate estimation of acoustic wave velocities and rock porosity is essential for better reservoir description and performance as well as a better forecast of seismic properties. In this reseach, the primary objective is to analyze the texture, mineralogy, porosity and permeability data of outcrop carbonate rock samples to study the impact of confining pressure on wave velocities. Furthermore, an empirical correlation is proposed for relating porosity with acoustic properties. Ninety outcrops samples are collected from Dam Formation in Al-Lidam area in Eastern Province, Saudi Arabia to develop a correlation. The carbonate samples varies from mudstone to grainstone facies. The samples are collected, prepared, and tested for this experimental study based on API standards. Compressional and shear wave velocities of carbonate rocks are measured under dry and fully brine-saturated conditions for 5 to 25 MPa effective confining pressures at room temperature. Moreover, porosity and permeability are measured using three different techniques, viz., AP-608 Automated Porosimeter-Permeameter, Helium Porosimeter, and thin section technique. Finally, the results are compared with those from other studies related to the same area. A state-of-the-art review is presented on seismic properties, relationship with porosity and acoustics in addition to the current trend and the future challenges in the area. The laboratory investigations for this study reveals that Al-Lidam area has different types of facies. The results also show that both compressional and shear wave velocities increase as the confining pressure on the dry samples increase. However, the compressional wave velocities increased and the shear wave velocities decreased with confining pressure under fully saturated conditions. A new correlation is presented for carbonate rocks to predict porosity from acoustic wave velocities. This study will help in improving the exploration efforts as well as give a better explanation for reservoir characterization, facies recognition, geophysical interpretation, and engineering calculations. This attempt will open a new research area for engineers and scientists to study the effect of variation in different properties on wave velocities.
{"title":"Acoustic Properties of Carbonate: An Experimental and Modelling Study","authors":"Murtada A. Elhaj, O. Abdullatif, A. Abdulraheem, Amjed Hassan, A. Sultan","doi":"10.2118/194753-MS","DOIUrl":"https://doi.org/10.2118/194753-MS","url":null,"abstract":"\u0000 The science of Acoustics deals with the propagation of mechanical waves in the three phases of materials, solids, liquids, and gases. In exploration and reservoir engineering, acoustic wave velocities play an essential role in reservoir description. The primary challenge in the initial evaluation and characterization of reservoirs is related to the understanding of its geology, petrophysics, and geomechanics. Therefore, an accurate estimation of acoustic wave velocities and rock porosity is essential for better reservoir description and performance as well as a better forecast of seismic properties. In this reseach, the primary objective is to analyze the texture, mineralogy, porosity and permeability data of outcrop carbonate rock samples to study the impact of confining pressure on wave velocities. Furthermore, an empirical correlation is proposed for relating porosity with acoustic properties.\u0000 Ninety outcrops samples are collected from Dam Formation in Al-Lidam area in Eastern Province, Saudi Arabia to develop a correlation. The carbonate samples varies from mudstone to grainstone facies. The samples are collected, prepared, and tested for this experimental study based on API standards. Compressional and shear wave velocities of carbonate rocks are measured under dry and fully brine-saturated conditions for 5 to 25 MPa effective confining pressures at room temperature. Moreover, porosity and permeability are measured using three different techniques, viz., AP-608 Automated Porosimeter-Permeameter, Helium Porosimeter, and thin section technique. Finally, the results are compared with those from other studies related to the same area.\u0000 A state-of-the-art review is presented on seismic properties, relationship with porosity and acoustics in addition to the current trend and the future challenges in the area. The laboratory investigations for this study reveals that Al-Lidam area has different types of facies. The results also show that both compressional and shear wave velocities increase as the confining pressure on the dry samples increase. However, the compressional wave velocities increased and the shear wave velocities decreased with confining pressure under fully saturated conditions. A new correlation is presented for carbonate rocks to predict porosity from acoustic wave velocities.\u0000 This study will help in improving the exploration efforts as well as give a better explanation for reservoir characterization, facies recognition, geophysical interpretation, and engineering calculations. This attempt will open a new research area for engineers and scientists to study the effect of variation in different properties on wave velocities.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73362670","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}
During drilling or production operations, poisonous, highly flammable hazardous gases can be released into the environment. A next-generation gas emission monitoring system monitors gas leaks and can help the oil and gas industry improve workplace safety. The initial design, architecture, and development of a real-time monitoring and surveillance system consisting of drones capable of performing autonomous aerial inspections is discussed. This system monitors and reports the spatiotemporal evolution of hazardous gas clouds, such as H2S, CH4, and CO2, in the oil and gas facilities in real time and provides necessary actions for a safe operation. The proposed monitoring system is compared to the traditional monitoring approach where sensors are placed near the ground. This work is a significant improvement from the authors’ previous work leveraging state-of-the-art machine learning technologies to create smart drones capable of making intelligent decisions involving gas leak monitoring.
{"title":"Next Generation Gas Emission Monitoring System","authors":"Ilyas Uyanik, A. Wesley","doi":"10.2118/195015-MS","DOIUrl":"https://doi.org/10.2118/195015-MS","url":null,"abstract":"\u0000 During drilling or production operations, poisonous, highly flammable hazardous gases can be released into the environment. A next-generation gas emission monitoring system monitors gas leaks and can help the oil and gas industry improve workplace safety. The initial design, architecture, and development of a real-time monitoring and surveillance system consisting of drones capable of performing autonomous aerial inspections is discussed. This system monitors and reports the spatiotemporal evolution of hazardous gas clouds, such as H2S, CH4, and CO2, in the oil and gas facilities in real time and provides necessary actions for a safe operation. The proposed monitoring system is compared to the traditional monitoring approach where sensors are placed near the ground. This work is a significant improvement from the authors’ previous work leveraging state-of-the-art machine learning technologies to create smart drones capable of making intelligent decisions involving gas leak monitoring.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77740775","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}
Techniques for 3D seismic interpretation by geoscientists are continuously undergoing improvements, and future exploration is anticipated to continue to benefit from high-confidence first pass interpretations utilizing all of the available seismic and well data. Workflows have been developed on a ‘super-merge’ 3D volume to produce attribute-enhanced chronostratigraphic stratal surfaces, allowing interpretation of regional-scale seismic facies and associated seismic geomorphology and tectonostratigraphy. In this example, a semi-supervised machine-based learning workflow has provided rapid turnaround interpretation of the structural framework and chronostratigraphy throughout the entire 3D seismic volume, maximizing the value of the seismic information. This workflow consists of a three-step auto-tracking workflow to build a Relative Geological Time (RGT) geo-model directly from the seismic volume. This enables more time to spend on geological validation and interpretation of the stratal surface seismic geomorphology. Study results have provided the foundation for rapid turnaround well and seismic integrated play fairway maps; a powerful tool for stimulating exploration in mature areas or wildcat acreage assessment. This study focused on Middle and Upper Jurassic carbonates deposited on a broad low angle platform on the Arabian Plate. Interpreting in map view on RGT constrained stratal surfaces with attributes such as, relative acoustic impedance and spectral decomposition, is invaluable for visualization since the stratal surface follows the morphology of the imaged geologic features. The ability to select any stratal surface within the volume and flatten, either on a seismic display or the Relative Geological Time geo-model, is particularly useful to establish the timing of major tectonic episodes and accommodation space fluctuations.
{"title":"Reframing Exploration Workflows for Small to Super-Merge 3D Seismic Interpretation","authors":"David J. A. Taylor, Sadaqat S. Ali","doi":"10.2118/194947-MS","DOIUrl":"https://doi.org/10.2118/194947-MS","url":null,"abstract":"\u0000 Techniques for 3D seismic interpretation by geoscientists are continuously undergoing improvements, and future exploration is anticipated to continue to benefit from high-confidence first pass interpretations utilizing all of the available seismic and well data. Workflows have been developed on a ‘super-merge’ 3D volume to produce attribute-enhanced chronostratigraphic stratal surfaces, allowing interpretation of regional-scale seismic facies and associated seismic geomorphology and tectonostratigraphy.\u0000 In this example, a semi-supervised machine-based learning workflow has provided rapid turnaround interpretation of the structural framework and chronostratigraphy throughout the entire 3D seismic volume, maximizing the value of the seismic information. This workflow consists of a three-step auto-tracking workflow to build a Relative Geological Time (RGT) geo-model directly from the seismic volume. This enables more time to spend on geological validation and interpretation of the stratal surface seismic geomorphology. Study results have provided the foundation for rapid turnaround well and seismic integrated play fairway maps; a powerful tool for stimulating exploration in mature areas or wildcat acreage assessment.\u0000 This study focused on Middle and Upper Jurassic carbonates deposited on a broad low angle platform on the Arabian Plate. Interpreting in map view on RGT constrained stratal surfaces with attributes such as, relative acoustic impedance and spectral decomposition, is invaluable for visualization since the stratal surface follows the morphology of the imaged geologic features. The ability to select any stratal surface within the volume and flatten, either on a seismic display or the Relative Geological Time geo-model, is particularly useful to establish the timing of major tectonic episodes and accommodation space fluctuations.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"8 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74211791","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}
Hydrocarbon production from high-pressure/high-temperature (HPHT) unconventional and tight gas reservoirs is challenging the industry with its increasing complexities, changing geological and reservoir dynamics with deeper depth and temperature, stimulation techniques and the strategic cost investment. The southern basins of India offers a complete set of such variability, uncertainties and challenges that demand a more synergic approach and effort to produce. Field X is a deep HPHT tight gas field in the Krishna Godavri Basin with a permeability of < 0.1 mD and a porosity of 10-12%. Prior attempts of hydraulic fracturing were carried out in the field with limited success. Small volume jobs were pumped, yielding low-permeability coverage, with just an initial production gain and no sustainability on the gas production increase. Frac fluid recovery was an additional concern because of the tight nature of the reservoir. This paper discusses the integration of log data, lab/fluid testing, production modelling, and fracture diagnostics that were used to design and optimize the massive hydraulic fracturing treatment. The technical methodology implemented during design, execution and evaluation phases for fracturing an HPHT tight gas well is discussed, including how the various risks were mitigated and the technical challenges were overcome. Finally, this paper elaborates the successful execution of the hydraulic fracturing treatment wherein ~332,000 lb of proppant were pumped–the largest in this field in a single stage. Initial production was enhanced by four times after the hydraulic fracturing. With the success of the hydraulic fracturing treatment execution strategy, fracturing operations were planned for the future field development wells to realize the true potential of the reservoir for increased and sustainable production.
{"title":"First Successful Massive Hydraulic Fracturing Treatment Unlocks Reservoir Potential 4 Fold: Case Study from Tight Gas HPHT Field in Southern India","authors":"Vinit Sharma, A. Negi","doi":"10.2118/194901-MS","DOIUrl":"https://doi.org/10.2118/194901-MS","url":null,"abstract":"\u0000 Hydrocarbon production from high-pressure/high-temperature (HPHT) unconventional and tight gas reservoirs is challenging the industry with its increasing complexities, changing geological and reservoir dynamics with deeper depth and temperature, stimulation techniques and the strategic cost investment. The southern basins of India offers a complete set of such variability, uncertainties and challenges that demand a more synergic approach and effort to produce. Field X is a deep HPHT tight gas field in the Krishna Godavri Basin with a permeability of < 0.1 mD and a porosity of 10-12%.\u0000 Prior attempts of hydraulic fracturing were carried out in the field with limited success. Small volume jobs were pumped, yielding low-permeability coverage, with just an initial production gain and no sustainability on the gas production increase. Frac fluid recovery was an additional concern because of the tight nature of the reservoir.\u0000 This paper discusses the integration of log data, lab/fluid testing, production modelling, and fracture diagnostics that were used to design and optimize the massive hydraulic fracturing treatment. The technical methodology implemented during design, execution and evaluation phases for fracturing an HPHT tight gas well is discussed, including how the various risks were mitigated and the technical challenges were overcome. Finally, this paper elaborates the successful execution of the hydraulic fracturing treatment wherein ~332,000 lb of proppant were pumped–the largest in this field in a single stage. Initial production was enhanced by four times after the hydraulic fracturing. With the success of the hydraulic fracturing treatment execution strategy, fracturing operations were planned for the future field development wells to realize the true potential of the reservoir for increased and sustainable production.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89508605","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}
A. A. Al-Hashemi, Gharbi Jabri, S. Khudhuri, I. T. Marjibi, Tope Hamed
This paper discusses KSI project which is the first in-house study on QA Cluster, aimed to accelerate delivery. This abstract spotlights the surface & subsurface integrated work results on fast track from DG1 to FID within 1.5 years by utilizing data from analogue fields & replication of surface concept & facility design. For the subsurface, an extensive analogue study was conducted. Then simple 1D analytical model used to generate well by well forecast. A small box model constructed to test different water flood development sensitivity & define the optimum spacing, type of pattern & water injection depth where the outcome compared with 3D simulation model & they match. For the surface, a small Well Test Unit (WTU) is leased to maximize the oil production from KSI field & provide an early view of reservoir waterflood uncertainty. The full field surface facility concept is a replication from H analogue field. This replication leads to accelerate the on stream date by 24 months. KSI is a green field which is one of the Lower Shuaiba pancake reservoir where it transferred from exploration with a high UTC project & very long schedule. It was identified that the key critical success factors are accelerating initial oil production & reducing Capex by using analogue field data, optimized phased-development, replication for facility design, & optimized well design & well spacing. Comparing the KSI field with analogue fields, resulted on chosen a line-derive waterflood as development concept which was validated by running a box model. The good match achieved between 1D analytical model used at DG2 & 3D simulation model used at DG3 indicated that the analytical model is sufficient as promise for Field Development Plan (FDP). However the numerical model will be needed for easily future waterflood management. Changing the well completion design from single horizontal to dual lateral is resulted in reducing the CAPEX (Drillex) by 54%. The replication of surface facility resulted on achieving two years ahead of initial schedule. The in-house study & replication of surface facility led to reduce the total project CAPEX 7%, increase NPV by 77%, reduce the project UTC by 21% & accelerated the schedule by 2 years as below figure 1
{"title":"KSI Field Fast Track to FID","authors":"A. A. Al-Hashemi, Gharbi Jabri, S. Khudhuri, I. T. Marjibi, Tope Hamed","doi":"10.2118/194919-MS","DOIUrl":"https://doi.org/10.2118/194919-MS","url":null,"abstract":"\u0000 This paper discusses KSI project which is the first in-house study on QA Cluster, aimed to accelerate delivery. This abstract spotlights the surface & subsurface integrated work results on fast track from DG1 to FID within 1.5 years by utilizing data from analogue fields & replication of surface concept & facility design.\u0000 For the subsurface, an extensive analogue study was conducted. Then simple 1D analytical model used to generate well by well forecast. A small box model constructed to test different water flood development sensitivity & define the optimum spacing, type of pattern & water injection depth where the outcome compared with 3D simulation model & they match.\u0000 For the surface, a small Well Test Unit (WTU) is leased to maximize the oil production from KSI field & provide an early view of reservoir waterflood uncertainty. The full field surface facility concept is a replication from H analogue field. This replication leads to accelerate the on stream date by 24 months.\u0000 KSI is a green field which is one of the Lower Shuaiba pancake reservoir where it transferred from exploration with a high UTC project & very long schedule.\u0000 It was identified that the key critical success factors are accelerating initial oil production & reducing Capex by using analogue field data, optimized phased-development, replication for facility design, & optimized well design & well spacing.\u0000 Comparing the KSI field with analogue fields, resulted on chosen a line-derive waterflood as development concept which was validated by running a box model.\u0000 The good match achieved between 1D analytical model used at DG2 & 3D simulation model used at DG3 indicated that the analytical model is sufficient as promise for Field\u0000 Development Plan (FDP). However the numerical model will be needed for easily future waterflood management.\u0000 Changing the well completion design from single horizontal to dual lateral is resulted in reducing the CAPEX (Drillex) by 54%. The replication of surface facility resulted on achieving two years ahead of initial schedule.\u0000 The in-house study & replication of surface facility led to reduce the total project CAPEX 7%, increase NPV by 77%, reduce the project UTC by 21% & accelerated the schedule by 2 years as below figure 1","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88387470","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}
Over the last few years, machine learning has become more and more a topic of interest in the seismic industry. In seismic interpretation like fault/salt dome detection (Amin et al. 2015, Guitton et al. 2017) and velocity picking (Smith 2017), there already have been successful implementations for some years now. Recently, machine learning was introduced in seismic processing algorithms like denoising, regularization and tomography (Araya-Polo et al. 2018) as well. In this abstract a deblending algorithm is proposed that utilizes supervised machine learning algorithms. The method combines the two main functionalities of supervised learning, classification and regression to achieve maximum control on the deblending process. First, blended acquisition and conventional deblending methods are discussed, followed by an introduction to machine learning algorithms and how these machine learning methods can contribute to improve existing deblending algorithms. Finally, synthetic data examples are shown to illustrate the machine learning deblending approach.
在过去的几年里，机器学习已经成为地震行业越来越感兴趣的话题。在断层/盐穹探测(Amin et al. 2015, Guitton et al. 2017)和速度采集(Smith 2017)等地震解释中，已经成功实施了几年。最近，机器学习也被引入到地震处理算法中，如去噪、正则化和断层扫描(Araya-Polo et al. 2018)。摘要提出了一种利用监督式机器学习算法的去混算法。该方法结合了监督学习的两个主要功能，分类和回归，以实现对脱混过程的最大控制。首先，讨论了混合采集和传统的去混合方法，然后介绍了机器学习算法以及这些机器学习方法如何有助于改进现有的去混合算法。最后，给出了合成数据示例来说明机器学习解混方法。
{"title":"Classification and Suppression of Blending Noise Using Convolutional Neural Networks","authors":"Baardman Rolf, C. Tsingas","doi":"10.2118/194731-MS","DOIUrl":"https://doi.org/10.2118/194731-MS","url":null,"abstract":"\u0000 Over the last few years, machine learning has become more and more a topic of interest in the seismic industry. In seismic interpretation like fault/salt dome detection (Amin et al. 2015, Guitton et al. 2017) and velocity picking (Smith 2017), there already have been successful implementations for some years now. Recently, machine learning was introduced in seismic processing algorithms like denoising, regularization and tomography (Araya-Polo et al. 2018) as well.\u0000 In this abstract a deblending algorithm is proposed that utilizes supervised machine learning algorithms. The method combines the two main functionalities of supervised learning, classification and regression to achieve maximum control on the deblending process. First, blended acquisition and conventional deblending methods are discussed, followed by an introduction to machine learning algorithms and how these machine learning methods can contribute to improve existing deblending algorithms. Finally, synthetic data examples are shown to illustrate the machine learning deblending approach.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82587587","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}
With the development of many kinds of oilfields, deep well, high deviated well and cluster well are increasing rapidly. Sucker rod pumping still remains a major artificial lift method. There are such problems as severe rod/tubing wearing and shortened rod/tubing life in high deviated rod-pumped wells, and the mechanism and prevention of rod/tubing wearing have not been understood properly. In order to understand the mechanism of rod/tubing wearing, a lateral load calculation model of rod/tubing is solved in this paper. The calculation results show that both the magnitude and direction of lateral force change dynamically with time and space in one stroke cycle. To better describe the rod/tubing wearing phenomenon, the lateral load is divided into two parts: the primary normal vector related to wellbore trajectory and axial force, and the secondary normal vector only related to wellbore trajectory and invariant with time. The three-dimensional and dynamic nature of lateral force can account for the rod/tubing wearing partially. The results of mathematical model show that the magnitude of lateral force at the same depth may differ greatly at different times, and its direction may also change periodically. It is likely to be bidirectional rod/tubing wearing when the primary normal force direction changes periodically. Simulation results show that the direction of lateral force is very likely to change periodically below the neutral point of rod string. This finding has accounted for the common double-faced and multi-faced rod/tubing wearing on the lower rod string. The periodic change of lateral force direction will cause rod/tubing collision, which is also an important cause for the rod/tubing wear below the neutral point. It is assumed qualitatively that the production parameters such as pump depth, stroke, stroke frequency and pump diameter are the major factors of the rod/tubing wearing according to field experience. In this paper, mathematic model is used to analyze the impact of these parameters on lateral force and the quantitative analysis is also conducted which provide theoretical foundation for the design of anti-wear production parameters. The mathematic model and method proposed in this paper are favorable to better accounting for the important phenomenon of rod/tubing wearing in rod-pumped deviated wells. They are capable of the quantitative calculation of lateral forces under different parameter conditions and the anti-wear design. This model has been applied to hundreds of highly deviated wells at Jidong Oilfield, prolonging rod/tubing life 58 days in average.
{"title":"Research and Application of Rod/Tubing Wearing Prediction and Anti-Wear Method in Sucker Rod Pumping Wells","authors":"Ruidong Zhao, Jinya Li, Zhen Tao, Meng Liu, Junfeng Shi, C. Xiong, Hongxing Huang, Chengyang Sun, Yufeng Zhang, Xiaowen Zhang","doi":"10.2118/194955-MS","DOIUrl":"https://doi.org/10.2118/194955-MS","url":null,"abstract":"\u0000 With the development of many kinds of oilfields, deep well, high deviated well and cluster well are increasing rapidly. Sucker rod pumping still remains a major artificial lift method. There are such problems as severe rod/tubing wearing and shortened rod/tubing life in high deviated rod-pumped wells, and the mechanism and prevention of rod/tubing wearing have not been understood properly.\u0000 In order to understand the mechanism of rod/tubing wearing, a lateral load calculation model of rod/tubing is solved in this paper. The calculation results show that both the magnitude and direction of lateral force change dynamically with time and space in one stroke cycle. To better describe the rod/tubing wearing phenomenon, the lateral load is divided into two parts: the primary normal vector related to wellbore trajectory and axial force, and the secondary normal vector only related to wellbore trajectory and invariant with time.\u0000 The three-dimensional and dynamic nature of lateral force can account for the rod/tubing wearing partially. The results of mathematical model show that the magnitude of lateral force at the same depth may differ greatly at different times, and its direction may also change periodically. It is likely to be bidirectional rod/tubing wearing when the primary normal force direction changes periodically. Simulation results show that the direction of lateral force is very likely to change periodically below the neutral point of rod string. This finding has accounted for the common double-faced and multi-faced rod/tubing wearing on the lower rod string. The periodic change of lateral force direction will cause rod/tubing collision, which is also an important cause for the rod/tubing wear below the neutral point. It is assumed qualitatively that the production parameters such as pump depth, stroke, stroke frequency and pump diameter are the major factors of the rod/tubing wearing according to field experience. In this paper, mathematic model is used to analyze the impact of these parameters on lateral force and the quantitative analysis is also conducted which provide theoretical foundation for the design of anti-wear production parameters.\u0000 The mathematic model and method proposed in this paper are favorable to better accounting for the important phenomenon of rod/tubing wearing in rod-pumped deviated wells. They are capable of the quantitative calculation of lateral forces under different parameter conditions and the anti-wear design. This model has been applied to hundreds of highly deviated wells at Jidong Oilfield, prolonging rod/tubing life 58 days in average.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"44 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86867222","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}
D. Gromakovskii, M. Palanivel, Alfredo López, V. Mikaelyan
Acidizing/acid fracturing is an established method of production stimulation in carbonate reservoirs. Over time, reservoirs become depleted, gas production declines, and flowback initiation can require additional time and costs. Energizing/foaming the stimulation fluid was determined to efficiently improve stimulation results and enhance post-treatment well cleanup. The gases most commonly used to energize the treatment fluids include nitrogen (N2) and carbon dioxide (CO2). This paper presents and discusses the results of an effectiveness study of foamed acidizing treatments performed using multistage completions; successful production outcomes were achieved in depleted reservoirs. The Design-Execution-Evaluation (DEE) cycle begins with a Multistage Fracturing (MSF) well evaluation to determine whether the well is a candidate for foamed treatment. This evaluation includes studies of the reservoir data (reservoir pressure, lithology, and permeability), completion data [including fracture ports and openhole (OH) packers placement versus hole size, reservoir net pay, and lithology], and offset wells stimulation results. Foamed MSF treatments are designed to help enhance post-stimulation performance regarding cost, operational efficiency, and completion limitations. Post-job evaluation includes highlighting the treatment as well as production analysis using a numerical simulator. The post-job evaluation also serves as an input to the design of upcoming treatments. Foamed multistage acidizing using CO2 foam proved to be successful in terms of post-treatment kickoff, cleanup, and production compared to conventionally treated wells. This success can be attributed to the following effects: Faster post-fracture cleanup as a result of the decreased liquid volume pumped into the reservoirHigher productivity resulting from acid placement benefits enabled by introducing CO2 foam (diversion, retardation)Well delivery time reduction because the post-treatment N2 lift was eliminated as a result of CO2 energy stored in the wellbore and the reservoir This paper presents the study of CO2 MSF treatments compared to conventionally treated MSF wells. The study results can be used to further optimize treatment designs and improve field execution of upcoming MSF operations as well as help reduce overall well delivery time.
{"title":"Efficient CO2 Multistage Acid Stimulation in Deep Hot-Gas Reservoirs","authors":"D. Gromakovskii, M. Palanivel, Alfredo López, V. Mikaelyan","doi":"10.2118/195097-MS","DOIUrl":"https://doi.org/10.2118/195097-MS","url":null,"abstract":"\u0000 Acidizing/acid fracturing is an established method of production stimulation in carbonate reservoirs. Over time, reservoirs become depleted, gas production declines, and flowback initiation can require additional time and costs. Energizing/foaming the stimulation fluid was determined to efficiently improve stimulation results and enhance post-treatment well cleanup. The gases most commonly used to energize the treatment fluids include nitrogen (N2) and carbon dioxide (CO2). This paper presents and discusses the results of an effectiveness study of foamed acidizing treatments performed using multistage completions; successful production outcomes were achieved in depleted reservoirs.\u0000 The Design-Execution-Evaluation (DEE) cycle begins with a Multistage Fracturing (MSF) well evaluation to determine whether the well is a candidate for foamed treatment. This evaluation includes studies of the reservoir data (reservoir pressure, lithology, and permeability), completion data [including fracture ports and openhole (OH) packers placement versus hole size, reservoir net pay, and lithology], and offset wells stimulation results. Foamed MSF treatments are designed to help enhance post-stimulation performance regarding cost, operational efficiency, and completion limitations. Post-job evaluation includes highlighting the treatment as well as production analysis using a numerical simulator. The post-job evaluation also serves as an input to the design of upcoming treatments.\u0000 Foamed multistage acidizing using CO2 foam proved to be successful in terms of post-treatment kickoff, cleanup, and production compared to conventionally treated wells. This success can be attributed to the following effects: Faster post-fracture cleanup as a result of the decreased liquid volume pumped into the reservoirHigher productivity resulting from acid placement benefits enabled by introducing CO2 foam (diversion, retardation)Well delivery time reduction because the post-treatment N2 lift was eliminated as a result of CO2 energy stored in the wellbore and the reservoir\u0000 This paper presents the study of CO2 MSF treatments compared to conventionally treated MSF wells. The study results can be used to further optimize treatment designs and improve field execution of upcoming MSF operations as well as help reduce overall well delivery time.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"83 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87651584","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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