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Thank you for attending the SPE Workshop. Disruption in oil and gas production is extremely costly and a time-consuming HSE affair. Assuring flow is a multidiscipline approach to identify flow stoppage risks and devise systematic workflows and protocols can guarantee an uninterrupted flow of hydrocarbons from the reservoir to surface facilities, through pipeline to terminals and, ultimately, to refineries. This workshop centred on an integrated approach to prevent flow disruption by encompassing the industry supply chain. The aim of the workshop was to discuss how a robust strategy and building block can influence the field development plan.
The E&P industry faces numerous challenges as it addresses growing energy demand, the need for sustainable operations, declining production from older reservoirs, and new resources in harder to reach and harsher environments. The SPE Research & Development Committee (now Research Development Technical Section) identified five grand challenges for the industry and is developing white papers for each one that describe the challenge, the current state of R&D, and areas for further research. Higher Resolution Subsurface Imaging (PDF) It is hard to read road signs if you have poor eyesight, which is why driver's licenses are issued with restrictions requiring that corrective lenses must be worn. Likewise, it is hard to find and exploit subsurface resources if you can't clearly see your targets or monitor the movement of fluids in the reservoir. Challenges in Reusing Produced Water Produced water is an inextricable part of the hydrocarbon recovery processes, yet it is by far the largest volume waste stream associated with hydrocarbon recovery.
What Is Concealed Beneath the Lebanese Offshore? This article reviews exploration activities and the challenges of the subsurface formations located in offshore Lebanon. When it comes to exploration and production, well-rounded petroleum engineers are the best candidates for finding out why something is happening, how it is happening, and what you can do to better your wells. This article highlights interesting applications of machine learning in the oil and gas industry in drilling, formation evaluation, and reservoir engineering. Each project uses a data-driven model to solve a previously complex problem using machine learning to augment an existing solution.
In this paper, the authors introduce a novel semianalytic approach to compute the sensitivity of the bottomhole pressure (BHP) data with respect to gridblock properties. Although principal-component analysis (PCA) has been applied widely to reduce the number of parameters characterizing a reservoir, its disadvantages are well-recognized.
Reservoirs consisting of heterogeneous carbonates and shaly sands pose formation evaluation challenges for conventional logging-while-drilling (LWD) measurements. Magnetic resonance techniques hold promise for improving understanding of these reservoirs. Core-flow tests are usually conducted to test and model stimulation treatments at laboratory scale, to predict the performance of such treatments in carbonate reservoirs.
A new multilayer boundary‑detection service has been introduced to resolve the geological uncertainty associated with horizontal wells in Bohai Bay. Geosteering and real time reservoir characterization were used to reduce the uncertainty. Reservoirs consisting of heterogeneous carbonates and shaly sands pose formation evaluation challenges for conventional logging-while-drilling (LWD) measurements. Magnetic resonance techniques hold promise for improving understanding of these reservoirs.
Three appraisal wells drilled this year—GTA-1, Yakaar-2, and Orca-1—targeted nine hydrocarbon-bearing zones, encountering gas in high-quality reservoirs in all zones and yielding a combined 160 m of net pay. BP Appraisal Well Proves “World-Scale Gas Resource" Offshore Senegal The Yakaar-2 appraisal well encountered 30 m of net gas pay in a similar high-quality Cenomanian reservoir as the Yakaar-1 discovery well drilled in 2017.
Methane emissions from California garbage dumps far surpass emissions from oil fields, according to a NASA survey. This paper discusses studies conducted on two California offshore fields that may be abandoned in the near future. These studies examined the feasibility of repurposing these fields for offshore gas storage by using their reservoir voidage and existing pipeline facilities. If proven economic, solar EOR technology could represent an environmentally and energy friendly solution for California’s heavy oil producers. In thermal enhanced oil recovery there is one big ingredient: steam.
Carbon Capture and Sequestration (CCS) is a geologic and engineering enterprise designed to reduce atmospheric emissions of greenhouse gases (GHGs). Extensive research links the GHG concentration in the atmosphere to the observed change in global temperature patterns (IPCC, 2013; Cox et al., 2000; Parmesean and Yohe, 2003). CCS technology could play an important role in efforts to limit the global average temperature rise to below 2°C, by removing carbon dioxide originating from fossil fuel use in power generation and industrial plants.
Conventional and unconventional hydrocarbons are likely to remain the main component of the energy mix needed to meet the growing global energy demand in the next 50 years. The worldwide production of crude oil could drop by nearly 40 million B/D by 2020 from existing projects, and an additional 25 million B/D of oil will need to be produced for the supply to keep pace with consumption. Scientific breakthroughs and technological innovations are needed, not only to secure supply of affordable hydrocarbons, but also to minimize the environmental impact of hydrocarbon recovery and utilization. The lifecycle of an oilfield is typically characterized by three main stages: production buildup, plateau production, and declining production. Sustaining the required production levels over the duration of the lifecycle requires a good understanding of and the ability to control the recovery mechanisms involved. For primary recovery (i.e., natural depletion of reservoir pressure), the lifecycle is generally short and the recovery factor does not exceed 20% in most cases.