The biggest drilling company appears interested in becoming the most innovative. It is testing inventions ranging from a blowout preventer that is not hydraulically powered to power systems designed like a hybrid car. The session will cover an area of growing interest, given increasing concern about wellbore integrity and well control. As with other MPD systems, SMD technology offers early detection of influxes (kicks) and minimizes downhole losses to weak subsurface formations. The paper demonstrates the successful application of advanced automated managed-pressure-drilling (MPD) technologies on the Dover well close to Fort McMurray, Alberta, Canada.
Moving their directional drillers into their Houston real-time remote operations centers has improved drilling efficiency for two of the top shale producers. The contract is helping to solidify Europe’s offshore sector as the focal point for the rise of automated drilling technology. This paper presents a case history of drilling automation system pilot deployment, including the use of wired drillpipe, on an Arctic drilling operation. In this paper, the application of a real-time T&D model is demonstrated. The process of T&D analysis was automated, and the time and cost required to run physical models offline was reduced or, in some cases, eliminated.
Showing concern for the high emission of green house gases, the governments all over the world are coming up with more stringent rules to check the emission level. Steam Assisted Gravity Drainage is a highly energy intensive process where huge amount of steam is generated by heating natural gas or coal thereby generating a very large share of green house gases. Therefore, solar energy seems to be lucrative in the following ways: world areas with abundant solar irradiation level can be tapped to reduce the fossil fuel consumption, minimizing the cost spent on fossil fuel and the emissions level at the same time. Concentrated Solar Power (CSP) looks a very promising technique but it comes with its own limitations mainly due to the requirement for huge area for setting up the solar collectors. Water Soluble Carbon-N115 is a sub-micrometer particle that has size less than the wavelength of light. Due to this reason, instead of scattering light, it absorbs light. The nano-particle gets enveloped in a thin layer of steam when put in a water bath. The vapour is released after reaching liquid-air interface and the nano-particles revert back to the solution to repeat the vaporization process and they exchange heat with the fluid, slightly raising the fluid temperature resulting in boiling of the fluid volume as a parallel effect. The paper discusses a model incorporating this nano-particle for the reduction of solar field footprint by more than a quarter and thereby reducing the cost and operational area. The paper also suggests the places across the globe where the proposed method can be deployed for generating steam and ultimately injecting it for producing oil above the surface from a tar-sand reservoir.
Xiong, Hao (University of Oklahoma) | Huang, Shijun (China University of Petroleum, Beijing) | Devegowda, Deepak (University of Oklahoma) | Liu, Hao (China University of Petroleum, Beijing) | Li, Hao (University of Oklahoma) | Padgett, Zack (Univiersity of Oklahoma)
Hao Xiong, University of Oklahoma; Shijun Huang, China University of Petroleum, Beijing; Deepak Devegowda, University of Oklahoma; Hao Liu, China University of Petroleum, Beijing; and Hao Li and Zack Padgett, University of Oklahoma Summary Steam-assisted gravity drainage (SAGD) is the most-effective thermal recovery method to exploit oil sand. The driving force of gravity is generally acknowledged as the most-significant driving mechanism in the SAGD process. However, an increasing number of field cases have shown that pressure difference might play an important role in the process. The objective of this paper is to simulate the effects of injector/producer-pressure difference on steam-chamber evolution and SAGD production performance. A series of 2D numerical simulations was conducted using the MacKay River and Dover reservoirs in western Canada to investigate the influence of pressure difference on SAGD recovery. Meanwhile, the effects of pressure difference on oil-production rate, stable production time, and steam-chamber development were studied in detail. Moreover, by combining Darcy's law and heat conduction along with a mass balance in the reservoir, a modified mathematical model considering the effects of pressure difference is established to predict the SAGD production performance. Finally, the proposed model is validated by comparing calculated cumulative oil production and oil-production rate with the results from numerical and experimental simulations. The results indicate that the oil production first increases rapidly and then slows down when a certain pressure difference is reached. However, at the expansion stage, lower pressure difference can achieve the same effect as high pressure difference. In addition, it is shown that the steam-chamber-expansion angle is a function of pressure difference. Using this finding, a new mathematical model is established considering the modification of the expansion angle, which (Butler 1991) treated as a constant. With the proposed model, production performance such as cumulative oil production and oil-production rate can be predicted. The steam-chamber shape is redefined at the rising stage, changing from a fanlike shape to a hexagonal shape, but not the single fanlike shape defined by (Butler 1991). This shape redefinition can clearly explain why the greatest oil-production rate does not occur when the steam chamber reaches the caprock.
Exploration in 2018 got off to a strong start when the Chevron-operated Ballymore well encountered 205 m of net oil pay in the US Gulf of Mexico. Drilled by Pacific Drilling’s Sharav deepwater drillship, the well reached a total depth of 8,898 m. Global discovered oil and gas resources and big project sanctions are expected to remain on the upswing through next year, according to separate industry outlooks from Rystad Energy and Wood Mackenzie. Internalizing lessons from a difficult last few years, operators are choosing investments more wisely and now better prepared to deal with volatile oil markets, the consultancies concluded. "Portfolios are set to weather low prices, and the recent slide in prices justifies the sector’s conservative mindset."
This paper presents a drilling solution through application of an automated managed-pressure-drilling (MPD) technique proved to identify and react to actual wellbore pressures and detect and control gains and losses while still having the ability to maintain a constant bottomhole pressure (BHP) while drilling through tight windows. The paper demonstrates the successful application of advanced automated MPD technologies on the Dover well close to Fort McMurray, Alberta, Canada. A well in the Dover field had multiple failures in the liner that resulted in excessive sand production, causing the well to be shut in. After reviewing the options of well repair or redrilling the horizontal section to install a new slotted liner, it was determined that redrilling was the best option. After the well-schematic analysis and in collaboration with the operator, the combination of a proprietary control system and MPD techniques was recommended along with a water-based mud (WBM) weight to drill the well and still be able to maintain the BHP required to overbalance the formation.
Shell Offshore said it made a "large" deepwater discovery in the US Gulf of Mexico that it believes could be tied back to its Appomattox platform. The Anglo-Dutch firm's 100%-owned Dover well on Mississippi Canyon Block 612 encountered more than 800 ft of net pay in the Norphlet formation, marking Shell's sixth discovery in that formation since 2003. Drilled 170 miles southeast of New Orleans in 7,500 ft of water, the well reached a true vertical depth of 29,000 ft. The discovery is 13 miles from the Appomattox host platform, which recently arrived on location in the deepwater gulf. Production from the platform is expected to start before the end of next year, eventually peaking at 175,000 BOE/D.
Liang, Guangyue (Research Institute of Petroleum Exploration and Development, CNPC) | Liu, Shangqi (Research Institute of Petroleum Exploration and Development, CNPC) | Liu, Yang (Research Institute of Petroleum Exploration and Development, CNPC) | Luo, Yanyan (Research Institute of Petroleum Exploration and Development, CNPC) | Han, Bin (Research Institute of Petroleum Exploration and Development, CNPC) | Huang, Jixin (Research Institute of Petroleum Exploration and Development, CNPC) | Bao, Yu (Research Institute of Petroleum Exploration and Development, CNPC)
Steam assisted gravity drainage (SAGD) process is widely used in super heavy oil and oil sands projects. These projects generally have higher steam to oil ratio and poor economy, partly because un-uniform steam chamber along the horizontal section forms and it is hard to adjust, affecting by reservoir heterogeneity including muddy interlayer and thief zones. Therefore, it is desirable to explore realistic and promising technology measures for SAGD projects at low oil price.
In this paper, almost all the technology measures for SAGD projects were extensively and deeply investigated in terms of domestic and foreign reports, literatures and on-site experiences. The available research subjects include Xinjiang Fengcheng and Liaohe super heavy oil projects in China as well as ten oil sands project attached to eight corporations in Canada. Better yet, numerous statistics about technology application are reviewed well-by-well, and field application effects for some technologies were verified by deliberate numerical simulation.
Many realistic and enforceable technology measures were systematically analyzed and recommended. Single or multiple stage dilation start-up process assisted by waste water or polymer injection enhanced start-up process significantly. Infilling well pairs or wedge well, and sidetracking horizontal well or fishbone well effectively tapped the unswept remaining oil by steam. The other technologies further improved steam chamber conformance including non-condensable gas co-injection, ICD/FCD technology, differentiated operating pressure strategy, nitrogen plus dispersant foam profile control and other remedial measures, etc. Besides, the present situation and foreground application were summarized and evaluated for several promising new technologies to be studied such as screening low cost mixed solvent to increase solvent recovery, warm solvent gravity drainage (Nsolv) process and in-situ upgrading process assisted by electrical heater or catalytic modification to reduce the capital cost of surface facility, etc.
The paper contains some previously unpublished data of practical experiences, and the findings of this investigation add to the knowledge base information related to improving the SAGD performance and economy of super heavy oil or oil sands projects.
Shell’s Dover discovery was drilled by Transocean’s newbuild Deepwater Poseidon ultra-deepwater drillship to a true vertical depth of 29,000 ft in 7,500 ft of water. Shell Offshore said it made a “large” deepwater discovery in the US Gulf of Mexico that it believes could be tied back to its Appomattox platform. The Anglo-Dutch firm’s 100%-owned Dover well on Mississippi Canyon Block 612 encountered more than 800 ft of net pay in the Norphlet formation, marking Shell’s sixth discovery in that formation since 2003. The discovery is 13 miles from the Appomattox host platform, which recently arrived on location in the deepwater gulf. Production from the platform is expected to start before the end of next year, eventually peaking at 175,000 BOE/D.