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Sustainability and Verb Tenses: What Do They Have in Common? The English language uses different verb tenses to indicate a verb's status; these are referred to as past, present, and future tenses. Tenses refer to time and to something that has happened, is happening, or will happen. Examples are: done, to be done, and will do. Along this line, many areas of sustainability that began as mere concepts are now either done, being done, or planned to do.
The UK’s offshore oil and gas industry has committed to halving operational emissions in the next decade, confirming its pathway to becoming a net-zero emissions basin by 2050. The UK’s leading oil and gas industry body says the industry can reduce emissions while meeting the region’s energy demand. The 33-month project will compare emissions data collected by terrestrial sensors to GHGSat's combined satellite and aircraft measurements. More than 60 producers participate in the program designed to reduce wellsite emissions. The US Environmental Protection Agency recently finalized a voluntary disclosure program for new owners of upstream oil and gas facilities designed to encourage them to find, correct, and self-report violations of the Clean Air Act, in particular those associated with emissions from storage vessels.
A simple, practical, and reliable method to detect a gas leak under the conditions of unknown inlet or outlet gas rate, or unknown inlet or outlet pressure, is highly desirable. Tube leaks present in a water-cooled sulfur recovery unit (SRU) condenser can lead to a variety of process issues, including corrosion and the oxidative formation of acidic species. This work devised a novel method to verify such leaks within a SRU condenser.
This one day training course focuses on the repair of channels, voids and leaks in a cemented wellbore. Poor cement coverage and lack of zonal isolation in the casing-borehole annulus often leads to production of undesired fluids and reduced hydrocarbons production, disposal problems, reservoir pressure decline, loss of hydrocarbon reserves and other problems. Objective of the course is to evaluate and discuss various technologies used to repair wellbore communication paths due to wellbore aging that can develop allowing fluid to migrate from the high pressure downhole strata through leakage paths in the cement containment. Poor cement coverage and inadequate zonal isolation affects nearly every aspect of a well during its life. This course will give participants a better understanding of some critical well safety and integrity issues and methods to repair wells that have reliability issues, including sustained casing pressure (SCP).
The UK’s leading oil and gas industry body says the industry can reduce emissions while meeting the region’s energy demand. The 33-month project will compare emissions data collected by terrestrial sensors to GHGSat's combined satellite and aircraft measurements. More than 60 producers participate in the program designed to reduce wellsite emissions. The US Environmental Protection Agency recently finalized a voluntary disclosure program for new owners of upstream oil and gas facilities designed to encourage them to find, correct, and self-report violations of the Clean Air Act, in particular those associated with emissions from storage vessels. A wave of satellites set to orbit the Earth will be able to pinpoint producers of greenhouse gases, right down to an individual leak at an oil rig.
The agency adopted what it calls its wellbore integrity rules as part of a much broader effort to implement aspects of Senate Bill 181, which was passed last year and requires sweeping changes in how oil and gas development is regulated. The new rules grew from recommendations made by an entity known as the State Oil and Gas Regulatory Exchange, or SOGRE, followed by extensive meetings involving the COGCC, industry, environmentalists, and others. The rules had widespread support by the time they were considered by the commission. Colorado Gov. Jared Polis said in the release, “The consensus reached by state agencies, oil and gas operators, citizen, and environmental organizations has helped to create an oil and gas regulatory environment that protects health, safety, welfare, and the environment.” Dan Haley, president and chief executive officer of the Colorado Oil and Gas Association, said in the release that, in most cases, companies already are doing what was recommended by SOGRE and the new rules will result in consistency for everybody.
The Appomattox asset, which currently has an expected production of 175,000 barrels of oil equivalent per day (boe/d), is a floating production system fed by several subsea production drill centers in the Gulf of Mexico, located in blocks MC437, 348, and 391-393. As the focus on in-situ leak detection has grown, two leak detection systems were implemented at Appomattox. Each uses an entirely different methodology for leak detection.
The Conditional Rate of Change (C-ROC) algorithm resides in the production control system and uses existing subsea pressure sensors. This algorithm was developed by Shell and is detailed in separate publications. Developed in parallel to the Appomattox project, C-ROC was added to the project later in the project lifecycle as it has become the Shell Gulf of Mexico standard for leak detection. In addition to the C-ROC method, each of the production drill centers has an Acoustic Leak Detector (ALD), provided by Naxys AS, a Baker Hughes business. These units are being piloted by Shell for the Gulf of Mexico. The ALD acoustically monitors the production manifold, wells, and associated flowline hardware at each drill center. The system is designed to distinguish the difference between background noise and actual leaks.
Implementation of each of these technologies leverage several other novel technologies and uses of existing technologies at Appomattox, including high bandwidth communications to support ALD and high-fidelity process simulation to both validate and train operations staff on the C-ROC algorithm.
This paper provides an overview of each leak detection system, details the technologies leveraged to implement these systems, and relates the project experiences thus far with each method.
Although leak incidents continue, a pipeline remains the most reliable mode of transportation within the oil and gas industry. It becomes even more important today because the projection for new pipelines is expected to increase by 1 billion barrels of oil equivalent (BOE) through 2035. In addition, increasing the number and length of subsea tiebacks faces new challenges in terms of data acquisition, monitoring, analysis, and remedial actions. Passive leak-detection methods commonly used in the industry have been successful with some limitations, in that they often cannot detect small leaks and seeps. In addition to a thorough review of related topics, this study investigates how to create a framework for a smart pigging technique for pipeline leak detection as an active leak-detection method.
Numerical modeling of smart pigging for leak detection requires two crucial components: detailed mathematical descriptions for fluid-solid and solid-solid interactions around pig and network modeling for the calculation of pressure and rate along the pipeline using iterative algorithms. The first step of this study is to build a numerical model that shows the motion of a pig along the pipeline with no leak (i.e., at a given injection rate, a pig first accelerates until it reaches its terminal velocity, beyond which the pig moves at a constant velocity). The second step is to construct a network model that consists of two pipeline segments (one upstream and the other downstream of the leak location) through which the pig travels and at the junction of which fluid leak occurs. By putting these multiple mechanisms together and using resulting pressure signatures, this study presents a new method to predict the location and size of a leak in the pipeline.
Vazquez, Maria Leticia (Schlumberger) | Marie, Mostafa (SUCO) | Salama, Ehab (SUCO) | AbdelRahman, Ahmed (SUCO) | Vago, Bronislav (SUCO) | Ziada, Khaled (Schlumberger) | Sharab, Mahmoud (Schlumberger) | Sabanegh, Nader (Schlumberger) | Ikhsanov, Meirbek (Schlumberger)
Suez Oil Company in Egypt encountered well integrity issues due to a suspected leak in a 3 ½-in completion, in a gas well in Desouq, Nile Delta Region. This led to well closure and consequent loss of production. (
Chevron experienced four casing leaks in subsea deepwater environments with an estimated cost of $80 million to remediate the wells. A similar incident at BHP resulted in parted casing and cost the company an estimated $21 million. This paper describes the investigative techniques which led to the conclusion of heat checking as the likely root cause of the casing leaks and the development of a 3D static FEA model which predicts downhole casing temperature. The model was validated by historical data analysis of more than 20 deepwater wells and found strong correlations between predicted downhole casing temperature and casing leak incidents. The results provided confidence for the implementation of a drilling parameter window and real-time temperature prediction algorithm to monitor and mitigate the potential for heat checking. The intent of this paper is to share with industry the recent realization and understanding of heat checking as a casing failure mode and mitigation measures put in place to manage a known but not necessarily widely monitored risk.