The envisioned role of hydrogen in the energy transition – or the concept of hydrogen economy – has varied through the years. While in the past hydrogen was mainly considered...

. (2015) 'Impact of maximum allowable cost on CO2 storage capacity in saline formations.', Environmental science and technology., 49 (22).pp. 13510-13518. Further information on publisher's website:http://dx.doi.org/10.1021/acs.est.5b02836Publisher's copyright statement:This document is the Accepted Manuscript version of a Published Work that appeared in nal form in Environmental Science and Technology, copyright c American Chemical Society after peer review and technical editing by the publisher. To access the nal edited and published work see http://dx.doi.org/10.1021/acs.est.5b02836.Additional information: Use policyThe full-text may be used and/or reproduced, and given to third parties in any format or medium, without prior permission or charge, for personal research or study, educational, or not-for-prot purposes provided that:• a full bibliographic reference is made to the original source • a link is made to the metadata record in DRO • the full-text is not changed in any way The full-text must not be sold in any format or medium without the formal permission of the copyright holders.Please consult the full DRO policy for further details.

In a high permeability reservoir, significant pressure drop can occur in a horizontal well, causing nonuniform inflow due to the variation in pressure drawdown along the well. A mathematical model is described for investigating how perforation distribution affects the performance of a horizontal well producing under steady state inflow. The model couples the Darcy flow into each perforation with the one-dimensional momentum equations for pipe flow. The perforated well is treated like a pipe manifold with Tjunctions representing the perforations along the wellbore. A number of examples are presented demonstrating how the model may be used to determine the optimal perforation distribution for different production requirements.

. (2013) 'A statistical analysis of well production rates from UK oil and gas elds implications for carbon capture and storage.', International journal of greenhouse gas control., 19 . pp. 510-518. Further information on publisher's website:http://dx.doi.org/10.1016/j.ijggc.2013.10.012Publisher's copyright statement: NOTICE: this is the author's version of a work that was accepted for publication in International Journal of Greenhouse Gas Control. Changes resulting from the publishing process, such as peer review, editing, corrections, structural formatting, and other quality control mechanisms may not be reected in this document. Changes may have been made to this work since it was submitted for publication. A denitive version was subsequently published in International Journal of Greenhouse Gas Control, 19, 2013Control, 19, , 10.1016Control, 19, /j.ijggc.2013.012. Additional information:Use policyThe full-text may be used and/or reproduced, and given to third parties in any format or medium, without prior permission or charge, for personal research or study, educational, or not-for-prot purposes provided that:• a full bibliographic reference is made to the original source • a link is made to the metadata record in DRO • the full-text is not changed in any way The full-text must not be sold in any format or medium without the formal permission of the copyright holders.Please consult the full DRO policy for further details. The number of wells required to dispose of global CO 2 emissions by injection into geological 11 formations is of interest as a key indicator of feasible deployment rate, scale and cost. Estimates 12 have largely been driven by forecasts of sustainable injection rate from mathematical modelling of 13 the CO 2 injection process. Recorded fluid production rates from oil and gas fields can be considered 14 an observable analogue in this respect. The article presents statistics concerning Cumulative 15 average Bulk fluid Production (CBP) rates per well for 104 oil and gas fields from the UK offshore 16 region. The term bulk fluid production is used here to describe the composite volume of oil, gas and 17 water produced at reservoir conditions. Overall, the following key findings are asserted: (1) CBP 18 statistics for UK offshore oil and gas fields are similar to those observed for CO 2 injection projects 19 worldwide. (2) 50% probability of non-exceedance (PNE) for CBP for oil and gas fields without 20 water flood is around 0.35 Mt/yr/well of CO 2 equivalent.

SPE Members*Now with BHP Petroleum Pty. Ltd. Abstract From an analysis of the constant volume depletion experiments performed on 80gas-condensates, it is concluded that serious problems exist in the detection of the actual volume of retrograde liquid in the PVT cell. The measured liquid volume is usually only a fraction of that required to give realistic liquid densities. The frequently observed concave shape of the retrograde liquid saturation curve close to the dew point is not real and is the result of experimental error. It is recommended that the data quality be improved by directly measuring the retrograde liquid density because it provides an excellent control over the liquid saturation, especially when this saturation is low. The properties of the fluid initially in the PVT cell are normally determined mathematically. However, this often only approximates the true properties and deviations can have consequences for the derived liquid properties. The direct measurement of the composition and propertie scan easily solve this problem and is therefore strongly recommended. The analysis of the experiments leads to the following statements for constant volume depletion experiments . liquid densities are monotonically decreasing with pressure . B: and R: are both monotonically increasing with pressure. Here B: is defined as the inverted partial density of the C5+ component fraction in the liquid, while R: is the mass ratio of the C4- fraction over the C5+ mass fraction. Introduction The importance of a good knowledge of the phase behaviour and compositional properties of reservoir fluids for the development of gas-condensate reservoirs and the subsequent processing of the well stream is widely recognised. Substantial financial investment is made on the acquisition of reliable samples of a reservoir fluid and on measuring the phase behaviour or PVT propertiest. Great reliance is placed directly on the resulting data and often even more on a derived equation of state'mathematical representation. In this paper we address the subject of the quality of experimental PVT data obtained from the standard experiment performed on gas-condensates, the constant volume depletion(CVD). The experiment is related directly to the way the information is applied by reservoir engineers (reservoir material balance calculations and numerical reservoir simulations) and also serves to provide a set of data on which to base the development of a mathematical model of the fluid. This so called equation of state model is then used for all kinds of purposes, eg separator design, gas processing plant design, compositional simulations, vertical performance calculation setc. Recently a variation of the black oil PVT representation in terms of masses of pseudocomponents was presented which derives its parameters directly from experimental data without the need for equation of state simulations of separator systems etc., and which allows black oil reservoir simulations to be conducted with improved accuracy, especially for gas-condensates. P. 525^