A statistical analysis of well production rates from UK oil and gas fields – Implications for carbon capture and storage

Abstract

. (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.

Impact of Maximum Allowable Cost on CO2 Storage Capacity in Saline Formations

“…Mathias et al showed that the injection rate statistics from Hosa et al are very similar to bulk fluid production rates (i.e., combined volumetric rates of oil, water, and gas at reservoir conditions) from 104 offshore U.K. oil and gas fields. By averaging production rates over a 10 year period, Mathias et al showed that 50% of the production wells studied produced bulk fluid at a rate of less than 3.5 million barrels per year. Assuming a CO 2 density of 650 kg/m 3 , this volumetric rate converts to around 0.35 megaton/year.…”

“…However, when many wells are 69 applied in close proximity, the pressure interference between wells causes individual injection wells 70 4 to act as if contained within completely confined saline formation units [12,13] Mathias et al [19] showed that the injection rate statistics from Hosa et al [18] are very similar to 124 bulk fluid production rates (i.e., combined volumetric rates of oil, water and gas at reservoir 125 conditions) from 104 offshore UK oil and gas fields. By averaging production rates over a ten year 126 period, Mathias et al [19] showed that 50% of the production wells studied produced bulk fluid at a likely to achieve injection rates greater than 1 Mt/year. Based on these studies, we will consider is approximately inversely proportional to the injection rate.…”

The impact of time-varying CO2 injection rate on large scale storage in the UK Bunter Sandstone

“…In this study we consider a base case scenario of 24 MtCO 2 injection per year in the eld, which is split evenly between the 12 injection sites. While studies by Noy et al [9] and Farhat et al [22] consider higher rates of injection per site at 5 MtCO 2 /year, on average, industry practice in the North Sea would suggest an injection rate per site to be 1-2 MtCO 2 /year [44,45,40].…”

Heat transport and pressure buildup during carbon dioxide injection into depleted gas reservoirs

“…These parameters are considered to be typical of many depleted gas reservoirs around the UK continental shelf. The constant CO 2 injection rate of 0.3 Mt year −1 is based on a recommendation made by Mathias et al (2013b), following a statistical analysis of historical oil and gas production rates in the UK continental shelf. The numerical models employ a radial grid, discretized using 200 equal intervals in log 10 space, from r w to r e .…”