Volume 10: Petroleum Technology最新文献

{"title":"Drilling Performance Evaluation Through Bit Cutters Reconfigurations and Micro Fractures Initiation","authors":"A. Abugharara, Oluwafemi Tytler, S. Butt","doi":"10.1115/omae2022-79273","DOIUrl":"https://doi.org/10.1115/omae2022-79273","url":null,"abstract":"\u0000 Drilling operations of petroleum wells are primarily applied to create channels through subsurface formations for oil and gas production. For best drilling performance, drilling parameters including weight on bit (WOB), rotary speed in Revolutions per Minute (rpm), drilling Fluid Rates (FR), etc. need to be applied optimally to enhance drilling performance, to reduce cost, and to minimize wear of downhole tools. In this research, the drilling performance was evaluated based on examining the Drilling Rate of Penetration (ROP) in granite blocks through changing the face of a multi diameter Polycrystalline Diamond Compact (PDC) bit into three different design scenarios including the Flat Base bit (FB), Drilling Hole Opener bit (DHO), and Coring Hole Opener bit (CHO). All input drilling parameters were kept constant and the only variable was the bit configuration.\u0000 The purpose of this research was to evaluate the change in the ROP and to establish an investigation on why ROP varies when bit is reconfigured just by repositioning cutters. By linking the ROP variation to the bit configuration, a possible phenomenon of creating micro fracturing could be the reason for the ROP enhancement. Taking the FB as a baseline, results showed an increase in ROP using DHO and CHO over FB bit. The idea behind this could lay behind initiating micro fractures resulting a weaker rock portion by the 1st drill path to be drilled by the upper part of the bit.\u0000 Based on the averaged results, ROP of DHO increased by 37.5 % at 5 kN and by 47.1 % at 10 kN. Similarly, the ROP of CHO increased by 12.5% at 5 kN and by 11.8 % at 10kN indicating that initiation of micro fractures could play a role in the enhancement of the ROP.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127370110","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":"Off-Bottom Plug Placement: On the Effects of Pulling Out of the Hole","authors":"A. Ghazal, I. Karimfazli","doi":"10.1115/omae2022-78930","DOIUrl":"https://doi.org/10.1115/omae2022-78930","url":null,"abstract":"\u0000 Several cement plugs are often placed along cased oil and gas wells, commonly using the balanced-plug technique, to ensure proper abandonment. The placement process starts with the injection of cement slurry into wells that are otherwise filled with lighter wellbore fluids. The injector is pulled out of the hole when the cement slurry is levelled in the injection tube and the annular space between the injector and casing walls (from hereon referred to as POOH). Successful placement is achieved if the plug remains in place after the POOH. In our previous works, we investigated the hydrodynamics of the early stages of the balanced-plug method and provided a mechanistic description of the events that would lead to the accumulation of the injected fluid. In this work, we focus on the hydrodynamics of the final stage of the balanced-plug method. We study the impact of POOH on the lower interface of the injected cement layer. We develop a two-dimensional (2D) model that is representative of the process and conduct numerical simulations, using OpenFOAM, to explore the deformation of the lower interface of the cement plug at different POOH velocities and for different distances between the injector tip and the lower interface of the cement plug.\u0000 We show that the injector pullout creates vortices at the injector tip, leaving a trail of vortices within the viscoplastic layer as the injector is pulled away from the interface. Our preliminary results suggest that the interface evolves approximately independently of the injector pullout when the initial distance between the injector and the bottom interface of the cement plug is sufficiently large. Here, the development of instabilities at the interface is reminiscent of the Rayleigh-Taylor instability (RTI) irrespective of the pullout velocity. We show, however, that the injector pullout promotes the mixing of fluids when the interface is close to the injector initially. Reduced POOH velocity appears to enhance the mixing close to the interface.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122842967","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":"Feasibility of Riser Emergency Disconnections During Drilling MPD Operations With Surface Back Pressure","authors":"L. Richa, G. Venero, Roberto Carvalho","doi":"10.1115/omae2022-80858","DOIUrl":"https://doi.org/10.1115/omae2022-80858","url":null,"abstract":"\u0000 Managed-Pressure Drilling (MPD) techniques are used by operators to reduce the non-productive time associated with kicks, losses and well-control events. There are different MPD techniques applied to work reservoirs where fluid loss are common, or where the fracture gradient and the pore pressure are close [1].\u0000 MPD techniques on deep water drilling operations can lead to extreme scenarios for the riser integrity, with low effective tension scenarios for Floating Mud Cap Drilling (FMCD) up to high effective tension for Pressurized Mud Cap Drilling (PMCD) and Surface Back Pressure (SBP). Feasibility of drilling operations using MPD techniques will depend, among other factors, on the feasibility of the riser disconnection on an emergency scenario, which present restrictions due to the distribution of effective tension and axial forces along the riser. Recoil analysis is required to define safe windows for emergency disconnection during MPD operations.\u0000 The critical parameters during emergency disconnection of a riser with MPD have been studied based on recoil analyses, which were performed for ultra-deep water for a range of SBP scenarios and for a non-pressurized operation with equivalent bottomhole pressure. Numerical simulations are applied for solving the transient problem of the riser disconnection in the time domain, considering the mud outflow, the riser dynamics, the vessel response and detailed tensioning system model to properly capture the system behaviour during the disconnection.\u0000 Individual and comparative results are presented, and conclusions describes the influence of the SBP usage for the riser integrity during an emergence disconnection.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129152218","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":"Investigation on Fiber Assisted Multistage Fracturing of Horizontal Well in Tight Low Permeability Sandstone Reservoirs","authors":"Lufeng Zhang","doi":"10.1115/omae2022-79132","DOIUrl":"https://doi.org/10.1115/omae2022-79132","url":null,"abstract":"Tight sandstone reservoirs, widely distributed in the world, are the important oil and gas exploration and exploitation area in the future and have a favorable development prospect. Multistage fracturing of horizontal well is a necessary technology to inspiring the production potential and enable commercial productivity for tight reservoirs. Due to the multiple functions, degradable fiber is widely applied during hydraulic fracturing. On the one hand, fiber can enhance the sand patch profile when it was injected into the fracture with the carrier fluid; On the other hand, fiber aggregation can accelerate the formation of temporary plugging agent, which is conducive to the uniform propagation of fractures. In this paper, we conducted a series of experiments to evaluate the properties of fiber in detail. Moreover, the pilot application of fiber which was injected during the whole hydraulic fracturing was also carried out. The laboratory evaluation experiments mainly achieved the following findings: 1. The length, diameter and density of fibers are approximately 6mm, 10μm and 1.24 g/cm3, respectively. 2. The fiber can be well dispersed in high viscosity slick water with almost no settlement. 3. Under high closure pressure, the conductivity of fiber and proppant mixture is higher than that of pure proppant. Furthermore, the field case shows that the fiber assisted fracturing makes the permeability-challenged formations economically recoverable, which deepens the understanding the effect of fibers and provides fundamental for field treatment design.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"62 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114697016","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 More Accurate Approach for the Design of Subsea Chemical Storage Systems Regarding Volume Requirements of Valve Leakage Tests","authors":"L. C. Sevillano, S. Sangesland, Tor Berge Gjersvik, A. Faanes","doi":"10.1115/omae2022-80637","DOIUrl":"https://doi.org/10.1115/omae2022-80637","url":null,"abstract":"\u0000 Subsea production systems require different chemicals to be injected into the wells, Xmas trees, manifolds, or flowlines to prevent or mitigate flow assurance issues, such as hydrate formation. Moving the chemical injection system subsea is one of the initiatives of the oil and gas industry to reduce field development costs and debottleneck topside facilities. Different studies present the potential benefits of adopting this technology, and the technological readiness level of the different concepts.\u0000 One premise for successfully adopting a subsea chemical storage and injection system is to have sufficient storage capacity and an efficient re-filling strategy. To achieve that, it is essential to have an accurate estimate of the required volume of injected chemicals during the service life of a well. One of the procedures which demands most of the injected volume of chemicals is the equalizing of pressures across a valve after a leak test has been performed. One single tree can easily have more than a dozen valves needed to be tested periodically.\u0000 The modelling of fluid behavior when equalizing the pressure across the valve to estimate the required volume of injected chemicals may be simplified, for instance, by employing an ideal gas law approach. However, a more sophisticated approach employing equations of state capable of determining properties based on fluid composition might be needed to properly simulate the behavior of reservoir fluids with changing composition and under different pressure and temperature conditions.\u0000 For the gas-producer wells modelled in the study cases of this paper, the results obtained indicate a clear difference in estimated chemical injection volumes when using the proposed equations of state approach instead of the simplified ideal gas approach. This equation of state method may be used to design more accurately the volume capacity of a subsea chemical storage and injection system, in particularly as the subsea production system’s demands evolve with time.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"43 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124451828","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 Methane Absorption for Offshore Gas Influx Management","authors":"Shahriar Mahmud, Yuanhang Chen","doi":"10.1115/omae2022-78721","DOIUrl":"https://doi.org/10.1115/omae2022-78721","url":null,"abstract":"\u0000 During oil and gas drilling operations, formation gas (mostly methane) may enter the wellbore annulus or the drilling riser. This gas influx may get absorbed into the surrounding mud causing complexity for kick detection. Absorption mass transfer experiments of methane into four different fluid systems were performed. The continuous phase for all these fluids was Internal olefins (IO) which is widely used within the drilling industry as a base fluid. Two of the fluids were emulsions (Water as the second phase) and the other fluid comprised of Internal Olefins with Suspentone. Ultrahigh purity methane was used as the absorbing gas phase. The system pressure was kept at 100psi (0.689MPa) with a superficial velocity of 0.009 m/s. Volumetric mass transfer coefficients (kLa) from these experiments were individually determined using a bubble column with an internal diameter of 0.0381m. The volume of the liquid was kept constant during each of the tests. It was observed that methane in pure IO has the highest kLa value while its value is the lowest when it was flown through the IO/Water/suspentone fluid system. The reduction of kLa values was attributed to the increase of viscosity of the fluid and reduction of interfacial area of the IO due to the addition of water.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126494182","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 Study of Newtonian Laminar Annular Horizontal Displacement Flows With Rotating Inner Cylinder","authors":"Hee-Hyo Jung, I. Frigaard, RuiZi Zhang, A. Renteria","doi":"10.1115/omae2022-79753","DOIUrl":"https://doi.org/10.1115/omae2022-79753","url":null,"abstract":"\u0000 During the primary cementing of oil and gas wells, it is increasingly becoming common to slowly rotate the inner casing to aid the mud displacement. We present an experimental study of laminar horizontal displacement of Newtonian fluids with rotating inner cylinder with the experimental setup detailed in (Renteria et al., J. Fluid Mech, 905, 2020). Inner cylinder rotation is able to distort the axial flow to helical. When the rotational viscous force dominates buoyancy force, the displacing fluid follows the helical flow path and displaces the in situ fluid azimuthally around the annulus. The dimensionless rotational speed is defined as the ratio of rotational velocity and axial velocity, which determines the degree of azimuthal dispersion. Even in a buoyancy-dominant displacement, inner cylinder rotation acts to increase the dispersion. Displacement efficiency analysis shows that increasing rotational speed results in improved displacement. For high eccentricity cases, bottom side residual fluids are observed, which can easily be removed by rotating the inner cylinder. In practice, where the entire length of casing is rotated, the effect of rotation is expected to be more significant and improve the displacement.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134325350","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":"Activation of Local Bentonite for Oil and Gas Industry Application","authors":"A. Al-Yami, Ali Al-Safran","doi":"10.1115/omae2022-81446","DOIUrl":"https://doi.org/10.1115/omae2022-81446","url":null,"abstract":"\u0000 Magzoub, et al 20171 have proposed a method of converting calcium bentonite to sodium bentonite. The method will require a reactor for upscaling. The method involves preparation of soda ash solution, heating, mixing for at least 24 hours and finally removing impurities and drying out. Besun et al. 19972 have proposed a method that will require also a reactor facility to upscale. Starch has to be added in water then bentonite is added in a separate water solution. Both were mixed and heated to form a structure of bentonite-starch gel. The formed gel has 20% starch and 80% bentonite. Bentonite is used in different applications such as drilling fluid, leaching earth, and animal feed additive.3 Sodium bentonite is more attractive in applications such as drilling due to its high swelling and good fluid loss control which makes it always in high demand. 4 & 5 The objectives of this study are to investigate and characterize local calcium bentonite in Saudi Arabia and to find optimum method to activate it for application in drilling fluids and cementing.\u0000 The characterization performed utilized XRF, XRD, and ESEM backscattered electron images along with EDS spectra for samples collected from different depths (5 meter and 7-meter samples). API testing including viscosity and fluid loss measurements were also conducted in the characterization phase. Activation was done utilizing cost effective additives such as soda ash. The activated bentonite was testing using standard testing procedures for drilling fluids and cementing such as rheology, fluid loss control, settling, compressive strength and thickening time tests.\u0000 The characterization concluded that the samples consisted mainly of Na-montmorillonite with appreciable amounts of impurities of quartz, kaolinite, illite, albite, calcite, and hematite. Compared to API reference sample, the local bentonite samples had less Na-montmorillonite contents, which probably needs some treatments to improve their quality. From this characterization, we can tell that activation of the 7 meter will be easier than the 5-meter bentonite because the Sodium Montmorillonite content is higher. The activation effort was focused on the 7-meter local bentonite sample since it showed better properties in terms of viscosity build up and fluid loss control. A new cost-effective activation method was conducted compared to the previous methods in the literature. Soda ash is an important step to convert or to increase the Na/Ca ratio to ensure higher swelling capacity.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"178 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132582721","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":"Plug Cementing Stability","authors":"Anastasia Vogl, Nile Waldal, P. Sarmadi, A. Fershtman, Rodrigo S. Mitishita, I. Frigaard","doi":"10.1115/omae2022-79290","DOIUrl":"https://doi.org/10.1115/omae2022-79290","url":null,"abstract":"\u0000 Off bottom plugs are set in both well drilling (kick-off plugs) and in well decommissioning (abandonment plugs). In both cases a dense fluid (cement slurry) is placed over less dense well-bore fluids. In the case of kick-off plugs, viscous pills are commonly used, which can help stabilize this mechanically unstable situation. Abandonment plugs however are often set on top of the freshwater that is used to clean the well prior to abandonment. This is the current practice for many wells in Northwestern Canada. It is a mystery how such cement plugs are able to stay in place for a time sufficient for the cement to thicken and hydrate, but field evidence suggests they do.\u0000 In this paper we explore the mechanically unstable scenario of a heavy yield-stress fluid placed on top of a less dense Newtonian fluid in a cylindrical pipe, dimensionally scaled to represent an off-bottom plug. We present details of the experimental setup and its calibration. We then explore the buoyancy-driven exchange flows that occur in transitional parametric regimes between flow and no-flow states, by using both computer modelling and physical experimentation. 3D numerical simulation, using a Volume of fluid method, is carried out to capture the interface between the fluids. The 3D model provides us with a more detailed analysis of the concentration and velocity profiles, along with comparisons to snapshots of the experimental results. The aim is to explore the phenomenology of these unstable flows and be able to estimate timescales of the destabilization. Preliminary results are presented.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"39 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114599952","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":"Order Reduction of a Transient Model of Viscous Pressure Loss Gradient in Laminar Flow for Non-Newtonian Fluid Flowing in Circular Pipes","authors":"E. Cayeux","doi":"10.1115/omae2022-78633","DOIUrl":"https://doi.org/10.1115/omae2022-78633","url":null,"abstract":"\u0000 When circulating non-Newtonian fluids in pipes, the flowrate may vary because of inherent fluctuations of the mudpumps, swab and surge due to axial displacement of the drill-string, variations caused by a positive displacement motor (PDM) while drilling. Steady state estimations of viscous pressure loss gradients are not anymore valid under accelerated flowrate conditions. It is possible to precisely calculate the dynamic response in transient conditions, but such numerical calculations tend to be slow and incompatible with real-time constraints when used during a drilling operation. It is therefore desirable to derive a reduced order model that is fast, yet accurate.\u0000 Numerical schemes utilized to estimate viscous pressure gradients under fluctuating flowrate conditions need to solve a larger problem than just the evolution of the pressure drop. Indeed, they need to calculate the whole fluid velocity field in a cross-section. However, when only the pressure gradient is of interest, a reduced order model would be sufficient. To find a possible reduced order dynamic model that mimics the dynamic response of the advanced numerical model, the method of sparse identification of non-linear dynamic (SINDy) is used on synthetic datasets generated using the advanced model. The SINDy method allows to discover the non-linear ordinary differential equation (ODE) that models precisely the dynamic that is observable from the synthetic dataset. Nevertheless, the calibrated parameters of the discovered non-linear ODE are only valid for specific a fluid density and rheological behavior. Therefore, the method is applied multiple times on various combinations of fluid densities and fluid rheological behavior parameters, and an interpolator function is generated. The interpolator is built using radial basis functions. The interpolator can then be used to find the correct parameters of the non-linear ODE as a function of the current rheological behavior of the fluid that flows in a pipe section and the dynamic pressure gradients can be estimated as a function of the fluctuating flowrate by solving a simple ODE, for example by using the Runge-Kutta method.\u0000 The reduced order model is very efficient, yet accurate, and can therefore be used in a real-time context. This is possible because many high-quality simulations are made upfront and used by machine learning methods (SINDy and radial basis functions) to discover a non-linear ODE and its associated parameter interpolator. The application of these two machine learning methods results in a solution that has good generalization capabilities. The reason for providing good estimation of the dynamic response outside the domain of the training examples is due to the ability of the SINDy method to extract ODEs that represent a good approximation of the real physical behavior of the system.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124454104","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}