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Collaborating Authors
Oil & Gas
Abstract While developing an offshore well in Brazil, the integrity of a well under construction became compromised resulting from channel communication after cementing the production liner. Leaks in producing wells can cause formation damage, loss of production, and increase tubular corrosion. This paper discusses the application of a new resin for a casing-leakage problem caused by a channel after the primary cementing operation. Conventional cements and slurries are commonly used to repair this challenge; however, these solutions are limited, at best. Depending on the channel size, well integrity can be restored with cement, but only if the channel is large enough to allow a sufficient volume of slurry to enter. The new epoxy resin exhibits exceptional resistance to contamination, including oil-based and water-based fluids, tailored mechanical properties, very-low yield point, as well availability of solids-free designs, making the resin an ideal candidate for a wide range of remedial operations throughout the life of the well. When the challenge is outside the capabilities of either conventional solution (Portland cement/microfine cement), another method is necessary to squeeze off the leak. Recent developments have shown that resins are an excellent alternative for these types of challenges. A new resin design has overcome this limitation and is helping ensure wellbore integrity, thereby contributing to environmental sustainability and social responsibility, while acting as an annular barricade against water and gas leaks. The liner-hanger leak was repaired in one attempt using the new epoxy resin and squeeze techniques. Well integrity was restored, and the operator was able to perform the completion operation without any signs of leakage. The new epoxy resin has become the primary solution and offers three primary benefits for restoring wellbore-integrity applications, including solids-free liquid with high-penetration capabilities and tailored mechanical properties to withstand a variety of wellbore challenges and enable customization and optimization for specific pumping operations.
- South America > Brazil (0.67)
- North America > United States > Pennsylvania (0.28)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > West Virginia > Appalachian Basin > Utica Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Utica Shale Formation (0.99)
- North America > United States > Ohio > Appalachian Basin > Utica Shale Formation (0.99)
- North America > United States > New York > Appalachian Basin > Utica Shale Formation (0.99)
Abstract Hybrid enhanced oil recovery (EOR) as polymer-assisted carbonated waterflood (PCWF) improves mobilities of both aqueous and oleic phases. The process introduces synergetic effect modifying reservoir wettability and fluids’ viscosity. These effects are the results of polymer rheology, geochemical reactions, and interphase transport of CO2 in crude oil/brine/mineral system. In this study, its performance is compared to waterflood, polymer flood, and carbonated waterflood. Firstly, polymer injection of PCWF raises the viscosity of aqueous solution over 4 cp despite of chemical and mechanical degradations. Secondly, PCWF contributes to considerable calcite dissolution increasing molality of Ca by 400%. It triples equivalent fraction of Ca and the reservoir is modified toward more water-wet condition. Lastly, PCWF allows CO2 to be transferred from aqueous solution to oleic phase. This transport reduces oil viscosity with 8% while pressurized system by polymer injection viscofies oil. As a result, PCWF recovers additional oil with 14.5%, 9.5%, and 2% over waterflood, polymer flood, and carbonated waterflood after 1.5 pore volume injection. Despite of the synergetic effects, PCWF requires operating cost to consume polymer and CO2. To improve oil production and economic efficiency of PCWF, robust optimization with multiple heterogeneous permeable fields is performed. Optimum injection designs of PCWF increases net present value with 36% over waterflood.
- Europe (1.00)
- North America > United States > Texas (0.46)
- North America > United States > Oklahoma (0.46)
- (2 more...)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.88)
- Geology > Mineral > Carbonate Mineral > Calcite (0.63)
Abstract At mature field stage, new wells may need to cross reservoirs with different pressure gradient levels. This phenomenon may increase due to the field development strategy. This approach for Roncador development led to a wide range of reservoir pressure at its mature stage. We found that our development of the Managed Pressure Drilling - MPD technique has helped to overcome the problems that arise due to that field development strategy. At Roncador field we build a trajectory that crosses multiple reservoirs before reaching the objective reservoir, we add to that difficult the occurrence of multiple reservoirs producing by different systems. So at the same region we experience reservoirs with wide gradient pressure levels. The MPD approach is a drilling process that controls the annular pressure profile throughout the wellbore. The objective is to ascertain the downhole pressure and to manage the annular pressure profile. With downhole pressure control in mind, we than developed the well design and project to minimize difficulties that usually arise during drilling and casing setting of new wells at mature fields. This MPD strategy led to shorter drilling times, thus saving on CAPEX needed to develop a mature filed or early production strategies. When a complex pressure profile arises, it possible to save time and money on sandstone reservoir wells with this MPD variety.
- North America > United States > Texas (0.69)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean (0.26)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.55)
- Geology > Geological Subdiscipline > Geomechanics (0.47)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Block P-36 > Roncador Field > Maastrichtian Formation (0.99)
- South America > Brazil > Campos Basin (0.99)
- South America > Brazil > Brazil > South Atlantic Ocean > Santos Basin (0.99)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Operations (1.00)
- (5 more...)
Effect of Microstructure on Hydrogen Diffusivity, Trapping and HIC Resistance in Two API X65 Steels
Pereira, Viviam Serra Marques (University of São Paulo) | Hincapie-Ladino, Duberney (University of São Paulo) | Nishikawa, Lucas Pintol (University of São Paulo) | Goldenstein, Helio (University of São Paulo)
Abstract The paper compares Hydrogen Induced Cracking (HIC) resistance and Hydrogen Permeation (HP) results for two API X65 microalloyed steels, with different contents of Mn and Nb: one containing low Mn and high Nb (L-Mn) and the other, high Mn and low Nb (H-Mn). The main objective is to correlate the microstructural differences between these steels with hydrogen diffusion and trapping behavior and hydrogen-induced cracking resistance. Both steel plates were characterized with optical and scanning electron microscopy in their transverse sections, in relation to the rolling direction. HIC resistance tests were made in accordance with the NACE TM0284-11 standard; samples obtained from the transverse section were also submitted to Hydrogen Permeation tests, based on the ASTM G148-97 standard. NACE solution A saturated with H2S was used in the two procedures. Besides, Thermal Desorption Spectroscopy measurements were made, in order to show which steel trapped more hydrogen atoms, and carbides/carbonitrides volume fractions were estimated with ThermoCalc software. The L-Mn steel presents a homogeneous microstructure through the plate thickness, composed of refined ferrite and small pearlite islands. The H-Mn steel has a heterogeneous microstructure through the plate thickness, composed of ferrite and pearlite bands, and presents centerline segregation. Hydrogen permeation tests showed that, despite all the microstructural differences, the hydrogen effective diffusion coefficient (Deff) was almost the same for both steels – the Deff obtained for the L-Mn steel is slightly higher than for the H-Mn steel. Contrary to expectations, the L-Mn steel presented higher hydrogen subsurface concentration (C0) and number of trapping sites per unit volume (Nt) values. Thermal Desorption Spectroscopy analysis confirmed that the L-Mn steel traps more H atoms than the H-Mn one. These results, along with the similar Deff values, can be explained by the presence of nanoprecipitates of microalloying elements, which, according to ThermoCalc simulations, appear in higher volume fraction in the L-Mn steel. Finally, the HIC tests results showed that the L-Mn steel has a better performance in sour environments; this behaviour is related with its special microstructural features.
- Materials > Metals & Mining > Steel (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Analytical and Experimental Analysis of Friction Forces inside Curved Pipes
de Menezes, Eduardo A. W. (Department of Mechanical Engineering, UFRGS) | Geiger, Filipe P. (Department of Mechanical Engineering, UFRGS) | Basso, Eduardo D. (Department of Mechanical Engineering, UFRGS) | Perondi, Eduardo A. (Department of Mechanical Engineering, UFRGS) | Wildner, Fabiano D. (Department of Mechanical Engineering, UFRGS) | Laranja, Rafael A. C. (Department of Mechanical Engineering, UFRGS) | Becker, Tiago (Department of Mechanical Engineering, UFRGS) | Marenco, Javier (Universidade de la República) | Santos, Hugo F. L. (Petrobras)
Abstract In-pipe robots are a powerful tool for hydrate plug removal inside ultra-deep water pipes. These robots may operate with energy supplied by umbilical cables immersed in oil. Present work focus on the development of a general strategy for computing the required forces for pulling such cables confined in ducts of generic length and geometry. Based on mathematical models obtained from specialized literature, a computational algorithm was designed to evaluate the static friction force related to the cumulative effects along the arbitrary set of curves present in a generic pipe. This computational routine can calculate the static friction forces associated to a cable inside a given pipe, whose coordinates are fed by the user. To evaluate the simulation performance, the achieved results were compared with that ones obtained through experimental tests performed using a cable with polymeric coating positioned inside ducts. Different geometries, load and lubricating conditions were tested, and the analytical model could estimate with reasonable accuracy the required force to move an umbilical cable inside pipes.
- Research Report > New Finding (0.40)
- Research Report > Experimental Study (0.40)
Abstract An offshore flow system is designed to operate at steady state. However, it is possible that this condition does not exist. The stability of an offshore flow system depends on the set of parameters that defines the operational state and can be numerically determined. The stationary solution is given as initial condition for the numerical simulation; if the numerical solution does not go away from the initial condition with time, the stationary solution is stable and it is the system steady state. If the numerical solution goes away with time, the stationary state is unstable, there is no steady state and an oscillatory solution develops. As a numerically cost efficient alternative to time simulations, the linear stability theory is a powerful technique to identify the stable and unstable regions. This paper presents the main features of a stability solver developed for oil production systems. Numerical results are presented for two oil fields. Stability maps are obtained and compare to field data. The comparison showed an excellent agreement with the operational conditions presented.
- South America > Brazil (1.00)
- North America > United States (0.93)
Risk Mitigation on Deepwater Drilling Based on 3D Geomechanics and Fit-For-Purpose Data Acquisition
Pedroso, C. A. (Queiroz Galvão Exploração & Produção) | Salies, J. B. (Queiroz Galvão Exploração & Produção) | Holzberg, B. B. (Schlumberger) | Frydman, M. (Schlumberger) | Pastor, J. A. S. C. (Schlumberger)
Abstract Drilling horizontal wells in shallow and poorly consolidated reservoirs in deepwater scenarios involves risky operations due to the narrow mud weight window. Risks include severe drilling fluid losses, wellbore instability, and fault reactivation, which, in the worst case, may connect reservoir to the sea floor. This work presents a case study of risk reduction based on geomechanics, which includes concepts of fault reactivation while drilling, permitted plastified area around the wellbore, and fit-for-purpose data acquisition, which allowed a recalibration of the model and timely changes on the drilling plan. The study started with a full 3D geomechanical characterization, which is an advanced way to determine stress distribution in a field, in particular, along the faults. Based on this study, it was possible to locate and avoid zones of higher risks of losses and fault reactivation, mitigating drilling risks. From the study, it was also possible to identify the main uncertainties of the model, which allowed a fit-for-purpose data acquisition plan. The most important missing information was a calibration point for the minimal horizontal stress in the reservoir. Previous drilling experience in the area and geomechanics modelling were not conclusive about losses mechanisms, and the upper limits for horizontal drilling were also not clear. In addition, borehole instability had been shown to be an issue on offset wells; therefore, lower limits for drilling were unclear too. It was decided to drill a pilot hole down to the reservoir, set a packer in the caprock and perform a series of minifrac tests. The measured minimal horizontal stress in the reservoir was revealed to be lower than initially expected, which implied the need to recalibrate the model and make important adjustments to the drilling plan. The model was recalibrated and the safe mud weight window was found to be even narrower. It was identified that a lower and unprecedented mud weight had to be used in the horizontal section, which was an additional risk. To evaluate this risk, the concept of permitted plastified area around the wellbore was used, and a lower mud weight was selected under a risk analysis manner. Based on the study, drilling risks were mitigated and horizontal drilling was performed successfully, with minimal losses and controlled wellbore collapse.
- Europe (0.94)
- South America > Brazil > Rio de Janeiro (0.46)
- North America > United States > Colorado (0.28)
- North America > United States > Texas (0.28)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.46)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Area do 1-RJS-366 > Frade Block > Frade Field (0.99)
- South America > Brazil > Brazil > South Atlantic Ocean > Santos Basin (0.99)
- South America > Argentina > Tierra del Fuego > Magallanes Basin > San Martin Field (0.99)
- South America > Argentina > Tierra del Fuego > Austral Basin > San Martin Field (0.99)
Abstract Traditionally, Pressure Transient Analysis (PTA) has been performed following a deterministic agenda. However, parameters used to quantify permeability and reservoir geometry might be plagued with uncertainty, unavailable or utterly unreliable. Given a set of uncertain rock and fluid data modeled as probability density functions (PDFs), this paper shows that by preserving two quantities in the log-log pressure-derivative domain, one can promptly build permeability and reservoir dimensions PDFs consistent with the well-test pressure history.
Campos and Santos Basins: 40 Years of Reservoir Characterization and Management of Shallow- to Ultra-Deep Water, Post- and Pre-Salt Reservoirs - Historical Overview and Future Challenges
Bruhn, Carlos H. L. (Petrobras E&P) | Pinto, Antonio C. C. (Petrobras E&P) | Johann, Paulo R. S. (Petrobras E&P) | Branco, Celso C. M. (Petrobras E&P) | Salomão, Marcelo C. (Petrobras E&P) | Freire, Ednilson B. (Petrobras E&P)
Petrobras found almost 100 hydrocarbon accumulations in the Campos and Santos basins, between 50 and 300 km off the Brazilian coast (under water depths from 80 to 2,400 m), which produce from very different types of reservoirs, including mostly (1) pre-salt coquinas and microbialites, (2) post-salt calcarenites, and (3) post-salt siliciclastic turbidites. These different types of reservoirs, containing also different types of hydrocarbons and contaminants provided many challenges for their production development, related to distinct tools and workflows for reservoir (static/dynamic) characterization and management, seismic reservoir characterization and monitoring, recovery methods (water injection, WAG, etc.), well spacing, well types and geometries, subsea systems, and processing capacity of production units. Since the first oil and gas discoveries in the Campos (1974) and Santos (1979) basins, Petrobras continuously moved to aggressive exploration and production from shallow- to deep- and ultra-deep waters. During the last 40 years, the activities of reservoir characterization and management have also continuously evolved. Four major phases can be depicted: (1) shallow water fields developed with a large number of vertical or deviated wells (e.g. Namorado, and Pampo, Campos Basin); (2) deep water fields, still developed with a large number of wells, but now combining vertical/deviated and horizontal wells (e.g. Marlim and Albacora, Campos Basin); (3) deep to ultra-deep water, post-salt fields, containing light to heavy oil (13-31 °API) in siliciclastic turbidites and carbonates, developed with a relatively small number of mostly horizontal wells (e.g. Marlim Sul, and Barracuda, Campos Basin); (4) ultra-deep water, pre-salt fields with very thick (up to 400-500 m), light oil (27-30 °API) carbonate reservoirs, developed with largely-spaced vertical and deviated wells (e.g. Lula, and Buzios, Santos Basin).
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean (1.00)
- South America > Brazil > Brazil > South Atlantic Ocean (0.85)
- Phanerozoic > Mesozoic > Cretaceous > Lower Cretaceous (0.68)
- Phanerozoic > Cenozoic (0.68)
- Geology > Structural Geology > Tectonics > Salt Tectonics (1.00)
- Geology > Rock Type > Sedimentary Rock (1.00)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment > Deep Water Marine Environment (0.88)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > South America Government > Brazil Government (0.48)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.34)
- South America > Brazil > Sergipe > South Atlantic Ocean > Sergipe-Alagoas Basin > Guaricema Field (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Merluza Field > Juréia Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Marlim Sul Field > Macae Formation (0.99)
- (18 more...)
Investigation of Electroless Nickel-Phosphorus Coating as an Alternative to Corrosion/Fouling Resistant Alloys in Downhole Service
Zhu, Da (RGL Reservoir Management Inc.) | Uzcategui, Alberto (RGL Reservoir Management Inc.) | Gong, Lu (University of Alberta) | Qiu, Xiaoyong (University of Alberta) | Huang, Jun (University of Alberta) | Sun, Chong (University of Alberta) | Luo, Jing-Li (University of Alberta) | Zeng, Hongbo (University of Alberta)
Abstract Harsh physical and chemical environments found in downhole operations have traditionally required the use of exotic corrosion-resistant materials, which are expensive, difficult to source and challenging to machine. This paper evaluates high-phosphorous electroless nickel (EN) coating as an alternative to these materials. The performance of this coating on carbon steel is compared to the performance of corrosion resistant alloys for fouling and surface characterization, and adhesion of inorganic and organic materials in a series of laboratory and field tests. In this paper, we first describe the complex and hostile thermal-chemical environment that exists for well completions commonly used in oil and gas production. The chemistry, physics and engineering governing principles of corrosion and fouling are reviewed. The set-up of the laboratory facilities and test procedures for fouling are described in detail. The performance of EN coated carbon steel is compared to several corrosion resistant alloys commonly used in downhole operations: 13Cr-L80, 28Cr-L80, 316L stainless steel, and Inconel 625. Examination of these specimens indicates the extent of corrosion and accumulation of fouling substances on EN coated and uncoated carbon steel at each time point.
- Materials > Metals & Mining > Steel (1.00)
- Energy > Oil & Gas > Upstream (1.00)