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BP is selling its 27.5% stake in the Shell-led Shearwater field to private-equity-backed producer Tailwind Energy for an undisclosed sum. Shearwater is in the UK North Sea and currently produces about 18,000 BOE/D. BP had agreed in January 2020 to divest Shearwater along with its Andrew projects to Premier Oil for $625 million, but the deal was never finalized. Later in the year, Premier merged with Chrysaor Holdings. The combined entity was renamed Harbour Energy.
Soroush, Mohammad (RGL Reservoir Management, University of Alberta) | Mohammadtabar, Mohammad (RGL Reservoir Management, University of Alberta) | Roostaei, Morteza (RGL Reservoir Management) | Hosseini, Seyed Abolhassan (RGL Reservoir Management, University of Alberta) | Mahmoudi, Mahdi (RGL Reservoir Management) | Keough, Daniel (Precise Downhole Services Ltd) | Cheng, Li (University of Alberta) | Moez, Kambiz (University of Alberta) | Fattahpour, Vahidoddin (RGL Reservoir Management)
Abstract Distributed Temperature Sensing (DTS) system using optical fiber has been deployed for downhole monitoring over two-decades. Several technological advancements led to a wide acceptance of this technology as a reliable surveillance technique. This paper presents a comprehensive technical review of all the applications of the DTS, with focus on oil and gas industrial deployments. The paper starts with the advantages of the DTS over other methods and an overview of the DTS basics, including theory, the DTS components, deployment types, fiber types, design and limitations. Then, it is followed by the oil and gas applications of the DTS including hydraulic fracturing (during and after fracturing), well treatment/stimulation (acid injection, fluid distribution, diversion monitoring), inorganic (scaling) and organic (wax/asphaltene/hydrate) deposition detection, leak detection (in well and pipeline), flow monitoring (rate monitoring, water/steam injection and SAGD monitoring, CO2 storage monitoring, zonal contribution determination, gas lift optimization) and reservoir/fluid characterization (facies, porosity, permeability and fluid composition determination). This study reviews the historical development, applications and limitations of the DTS systems. The paper mainly focusses on deployment techniques, the application of the DTS for the prediction and surveillance of the non-thermal and thermal producer/injector wells, hydraulically fractured wells and those wells with treatments. The paper provides a concise review using several field cases from over two hundred published papers of Society of Petroleum Engineering (SPE) and journal databases. The application of the DTS in downhole monitoring can be divided into the qualitative and quantitative applications. In quantitative approaches, numerical models should be combined with the DTS data. This study discusses case by case worldwide field applications of DTS along with proposed modeling methods and interpretations. It also summarizes main challenges, including the fiber reliability, longevity, and operational limitations such as the installation and the complexity of quantitative approaches. This study is the foundation for an ongoing study on wellbore and reservoir surveillance through real-time distributed fiber optic sensing recordings along the wellbore. It summarizes the historical development and limitations to identify the existing gaps and reviews the lessons learned through the two decades of the application of the DTS in production performance.
The UK's Oil and Gas Authority (OGA) has awarded Eni a carbon dioxide (CO2) appraisal and storage license that will allow Eni to reuse and repurpose depleted hydrocarbon reservoirs in the Liverpool Bay area of the East Irish Sea to permanently store CO2 captured in northwest England and North Wales. The UK license, the first of its kind for Eni, includes a 6-year appraisal term that allows assessments and planning that may lead to a subsequent application to the OGA for a storage permit and associated approvals required before any storage operations can begin. The planned storage scheme will reuse reservoirs from the Hamilton, Hamilton North, and Lennox fields and associated infrastructure as part of a collaborative effort with industrial companies to capture and transport CO2 from existing industries and future hydrogen production sites for fuel switching, heating, power, and transportation for UK targets. The licenses do not convey permission for development activities such as drilling and injection testing. These will require further consents from the OGA.
This paper describes the first successful attempt on the continental shelf offshore UK to map carbon dioxide (CO2) in real time while logging during a drilling campaign in the East Irish Sea. Reservoirs in this sea's basin contain varying proportions of CO2, nitrogen (N2), and hydrogen sulfide (H2S), in addition to oil and methane. Two of these wells develop the Rhyl gas field. Downhole-fluid-analysis (DFA) technologies were deployed with a wireline-formation-testing (WFT) tool to measure CO2 content accurately downhole. The Rhyl field was discovered in 2009 and received development approval in 2012.
ABSTRACT A prototypal robotic platform that consists of a small autonomous surface vehicle (ASV) and of a micro-ROV, connected by an umbilical, is described. 4G/internet connection makes it possible to operate the platform from remote location. The operator can concentrate on guiding the micro-ROV by means of visual data, while the surface vehicle automatically coordinates its movements with those of the micro-ROV. Small dimensions, low costs and easiness of use make the platform an effective tool for low-budget survey in shallow water. The mechatronic characteristics of the platform are illustrated and discussed, together with the results of functional tests. INTRODUCTION Hybrid robotic platforms that consists of an Autonomous Surface Vehicle, or ASV, and a Remotely Operated underwater Vehicles, or ROV, are a very effective solution for inspecting underwater structures in e.g. harbor areas, rivers, natural and artificial lakes. The ASV acts as a bridge for communication with a remote station, that in this way can receive data from the ROV, avoiding the necessity of a supply vessel to operate the ROV (Scaradozzi, Conte and Sorbi, 2012; Conte et al., 2016). Examples of cooperation between autonomous surface vehicles and unmanned underwater vehicles (UUV) in hybrid robotic platforms have been considered in previous paper. In (Pascoal et al., 2000; Healey, Pascoal and Santos, 2002; Ferreira et al., 2006) an ASV and an UUV are deployed and managed independently and cooperation consists in communicating through an acoustic link to exchange information and commands. The ASV serves as acoustic relay between the AUV and a supply vessel. In (Djapic and Nad, 2010), an ASV is used to carry and deploy an AUV in a mine counter-measures applicative scenario. A robotic platform consisting of an ASV that is capable of deploying and recovering an ROV has been first considered in (Conte, De Capua and Scaradozzi, 2016) and more recently in (Gray, Schwartz and Anglerfish, 2016; Sarda and Dhanak, 2017; Jung et al., 2018; Lindsø, 2018). From a commercial point of view, the C-Worker platforms of L3 Technologies have the above-mentioned characteristics and OceanScan-MST developed a device called Manta Gateway that, mounted on a buoy or ASV, acts as a bridge between Wi-Fi, mobile broadband, Iridium communications and acoustic signals for long-range underwater transmission.
This chapter discusses the determination of lithology, net pay, porosity, water saturation, and permeability from wellbore core and log data. The chapter deals with "Development Petrophysics" and emphasizes the integration of core data with log data; the adjustment of core data, when required, to reservoir conditions; and the calibration and regression line-fitting of log data to core data. The goal of the calculations is to use all available data, calibrated to the best standard, to arrive at the most accurate quantitative values of the petrophysical parameters (i.e., lithology, net pay, porosity, water saturation, and permeability). Log analysis, cased-hole formation evaluation, and production logging are not covered here. The following topics are covered in this chapter: petrophysical data sources and databases, lithology determination, net-pay (or pay/nonpay) determination, porosity determination, fluid-contacts identification, water-saturation determination, permeability ...
The goal of the net-pay calculations is to eliminate nonproductive rock intervals and, from these calculations at the various wellbores, provide a solid basis for a quality 3D reservoir description and quantitative hydrocarbons-in-place and flow calculations. The determination of net pay is a required input to calculate the hydrocarbon pore feet, FHCP, at a wellbore and its input to the overall reservoir original oil in place (OOIP) or original gas in place (OGIP) calculations. The total FHCP at a well is the point-by-point summation over the reservoir interval with Eq. 1. The top and base of the reservoir interval are defined by geologists on the basis of core descriptions and log characteristics. In the FHCP calculation, net pay, hni, at each data point has a value of either 1 (pay) or 0 (nonpay). The "net-to-gross ratio" or "net/gross" (N/G) is the total amount of pay footage divided by the total thickness of the reservoir interval (for simplicity, the well is assumed here to be vertical).
The "gold" standard for permeability is to make measurements on core samples and to determine permeability with the methods outlined in API RP 40. All other techniques are calibrated back to core measurements. However, because core measurements sample such a minute part of the reservoir, we must rely on techniques that can be applied in a widespread fashion across the reservoir. These methods rely on measurements on sidewall samples, correlation to wireline logging responses, interpretation of nuclear magnetic resonance (NMR) logs, wireline formation tester pressure responses, and drillstem tests. This technique is valid for slightly to unconsolidated sandstone rock types.
Abstract One of the critical conditions in cementing operations of gas wells, is the underbalance that generates the entry of preflush in the annular space, especially with the use of in the fluid train, therefore, trying to ensure the pore Pressure control incorporating to the fluid system, only an extensive volume of Spacer. In this way a possible gas inflow is avoided that would lead to enormous economic losses, however in terms of a good removal, just having a spacer in the preflush system would only be Fulfilling a single function that is the drag of suspended solids. in the annular space without being able to disperse and reduce its solid structures. Our methodology has been proven in fields with high GOR and good petrophysical and reservoir conditions, which intend to add a volume of washes to the preflush system, thus Hydrostatic Balance with a low Rheological Spacer volume behind the mud. The preflush system is by batch and pumped at 4.0 bpm continuous, considering a volume of 20 barrel máximum to generate a contact time greater than five minutes, thus improving the conditions of removal, diluting, dispersing and moisturizing the wellbore and casing external. It evaluates Primary cement Using bond logs that was run three days after the cementing operation. The logging results indicate an average amplitude of around 5 mV, so the 5 ½" in. Casing cement job had 90% average bond index. Good zonal isolation was achieved. In addition, Mechanical factors such as reciprocating the casing once carried to Depth, and casing centralization with Standoff greater than 80%, guarantee zonal Isolation in the área of productive. The addition of a Surfactant to the formulation of the washes favors the water wettability of the wellbore in fron of cement. The use of surfactants in preflushes entrain invading gas downhole and créate a stable foam. This foam then presents significant resistance to flow, thereby limiting upward migration (Marrast et al, 1975). With regard to the properties of grouts dominate the rheologic behavior, with filtrations less than 50 cc /30 min, and compressive strength greater than 1,100 psi