|Theme||Visible||Selectable||Appearance||Zoom Range (now: 0)|
Directional drilling and measurement-while-drilling technology has become so democratized in the Texas shale sector that no provider holds more than 8% of the market share. Results to date are compared with previous performance in the Gulf of Thailand (GoT). The purpose of this paper is to demonstrate how inaccuracy in standard directional-surveying methods affects wellbore position and to recommend practices to improve surveying accuracy for greater confidence in lateral spacing. Wellbore position is computed from survey measurements taken by a measurement-while-drilling (MWD) tool in the bottomhole assembly (BHA).
JPT Technology Minute Poll: To Which of the Top Five UN Sustainability Development Goals Do You Think the Oil and Gas Industry Will Contribute the Most? The papers identified in the article cover sustainable development of oil and gas resources in various aspects. Flaring and emissions challenges have recently made news headlines around the world. The goal of this article is to engage you with this important topic by presenting a selection of recent SPE papers which address these challenges through various approaches. Operators face a dilemma in balancing the need for mud weight (MW) to remain below the fracture gradient to avoid losses, while also providing sufficient density to block influxes into the well. JPT Technology Minute Poll: Which Technology Would You Choose for Offshore Compression?
The offshore drilling contractor’s latest effort to curb emissions relies on technology developed during the US space shuttle program and could become commercial by 2022. The complete paper highlights examples of nonmetallic materials selection and qualification for upstream water-injection and producer and hydrocarbon wells and presents suggestions for future progress. Autonomous Inflow Control Valve technology demonstrates significant benefits within first year. For the offshore sector, the collapse in oil demand and prices came just as the market was beginning to look up. Now many companies are focused on survival.
Directional drilling is defined as the practice of controlling the direction and deviation of a wellbore to a predetermined underground target or location. This section describes why directional drilling is required, the sort of well paths that are used, and the tools and methods employed to drill those wells. Field developments, particularly offshore and in the Arctic, involve drilling an optimum number of wells from a single platform or artificial island. Directional drilling has helped by greatly reducing the costs and environmental impact of this application. A well is directionally drilled to reach a producing zone that is otherwise inaccessible with normal vertical-drilling practices.
The complete paper highlights examples of nonmetallic materials selection and qualification for upstream water-injection and producer and hydrocarbon wells and presents suggestions for future progress. Autonomous Inflow Control Valve technology demonstrates significant benefits within first year. For the offshore sector, the collapse in oil demand and prices came just as the market was beginning to look up. Now many companies are focused on survival. This article discusses how various market segments, regions, and companies are faring in “the new reality.”
This one-day course is an introduction to the emerging fibre optic technologies of Distributed Temperature Sensing (DTS) as well as related Distributed Acoustic (DAS) and Distributed Chemical Sensing (DCS). This programme looks at how these technologies work, and their application to the oil and gas industry. Such systems have been utilised in shallow steam injection wells as well as high-cost horizontal and multilateral wells where re-entry with a logging tool is difficult, if not impossible. This class also includes an overview of PLATO software for managing DTS data and computing flow, plus a hands-on demonstration of DTS hardware.
Autonomous Inflow Control Valve technology demonstrates significant benefits within first year. For the offshore sector, the collapse in oil demand and prices came just as the market was beginning to look up. Now many companies are focused on survival. This article discusses how various market segments, regions, and companies are faring in “the new reality.” For the upstream industry, where improvement in efficiency or production can drive significant financial results, there is no question that the size of the digital prize is huge.
Wellbore instability has been experienced in areas of the Marcellus Shale and can become particularly troublesome in the superlaterals that are becoming more prevalent in that play. Often the instability while drilling these very long lateral wells is minimal; problems are more likely to occur while tripping out after reaching TD. The most common instability events when pulling out of the hole appear to be tight hole, pack-off and stuck pipe. These problems often worsen with time, indicating there is some time-dependence to the failure mechanism.
In order to develop effective mitigation strategies to combat the instability, it is imperative that the failure mechanism be correctly identified. Previous publications (Kowan and Ong, 2016; Addis et al. 2016; Riley et al. 2012) have suggested that bedding planes may play a role in some of the drilling problems experienced in the Marcellus Shale. In this paper, we will present a case study from the Marcellus that shows conclusive proof of weak bedding plane failure along a lateral well, where thousands of feet of anisotropic failure were captured with a LWD image log.
This image provided confirmation of the presence and failure of weak bedding planes in the Marcellus Shale. The image was also used to validate an existing geomechanical model for the area and gave the operator more confidence in the mitigation strategies developed from that geomechanical model, which had been based on the assumption that weak bedding was contributing to difficulty experienced on multiple lateral wells when tripping out of the hole.
This case study will begin with an overview of the geomechanical model, including the drilling history, stress/pore pressure model and rock properties. Next, some highlights from the image log, showing anisotropic bedding plane failure, will be featured as well as a comparison of the image to the geomechanical model. This case study will conclude with a review of proposed mitigation strategies that could be implemented by the operator to limit the risks posed by weak beds and minimize instability, when drilling laterals in this area, or similarly complex areas, of the Marcellus Shale.
Reservoir navigation, often referred to as geosteering, is commonly used to optimize the placement of highly deviated wells. This technology has contributed significantly to the prolongation and economic well-being of mature hydrocarbon provinces around the world and been a major enabler for the commercial success of unconventional reservoirs.
The reservoir information and analysis obtained during reservoir navigation is extensive and very valuable, yet is known to sometimes remain unused. Part of the reason is the complexity of reservoir navigation data and the limitations that many geosteering software applications cannot integrate the information provided from this data to update seismic-based 3D models.
This paper demonstrates a fast and effective method of utilizing spatial reservoir navigation information to improve the three-dimensional understanding of producing reservoirs. Reservoir navigation interpretations from one or more wells can be used as inputs. The results include updated structure maps, refined gross rock volume (eg shale volume in unconventional reservoirs), updated values for porosity and water saturation and ultimately a revised volumetrics calculation. The results can be compared with calculations from other methods such as material balance and decline curves. Analyzing conflicting field data and reconciling them creates opportunities for improved drilling opportunities and better reservoir development. Datasets used in the paper show some specific examples of how the 3D workflows lead to better field developments with enhanced drilling operations and improving recovery factors.
In the future, significant technical developments are expected in the type and complexity of reservoir navigation data originating from logging while drilling (LWD) tools. These data types will easily be included in the new 3D workflows without introducing undue complexity.
Integrating reservoir navigation interpretations into sub-surface 3D models can be of benefit for real time drilling operations and also for field studies. The method uses a 3D workflow that can be completed easily and is fast enough to update models in real time. It is therefore useful for the purposes of improving architectural and geomorphological understanding of an area larger in scale than just the immediate active well. This creates an information rich environment with insightful information during geosteering real time jobs for better decisions. Additionally, the analysis method can be performed as a field study. This more comprehensive approach allows integration with other information after drilling operations have ceased to improve resource recovery and pick better future drilling targets.
Deep water projects are presently complex, where more drilling challenges can be encountered and higher uncertainty increases the risk of problems during the well construction phase, especially due to the narrow pressure window environments. Managed Pressure Drilling (MPD) is one of the technologies that is currently gaining acceptance since demonstrating that it helps control these problems, minimizes the risks, and optimizes the overall well construction process in deep water applications. MPD is being used not only during the drilling phase, including techniques such as Constant Bottom Hole Pressure (CBHP) and Pressurized Mud Cap Drilling (PMCD), but also is being implemented because of the benefits of identifying and controlling formation influxes while drilling and/or during connections, controlling wellbore pressures during connections, and while tripping in and out of the hole. Continuous circulation systems (CCS) are also widely used in exploratory wells to enhance control of the wellbore pressure during connections and are being used either in conjunction or without MPD. Once the well has been drilled and the completion has been run in hole, the next step is cementing the casing or liner in place. Managed Pressure Cementing (MPC) can also be implemented and brings additional benefits during this phase such as more precise control of the pressures, allowing the use of lighter fluids, and better monitoring of the overall process. Different case histories from several areas will be described in this paper to illustrate the drivers, implementation, and results of the various MPD techniques that can be used during the well construction phase including CBHP, PMCD, CCS, and MPC. The paper will also highlight the synergies among these different technologies and how they would further benefit deep water operations.