b'NamibiaIn September 2018, we acquired a 45% non-operated participating interest in PEL 39 offshoreNamibia, which later became part of a larger strategic alliance with Shell to jointly explore in SouthernWest Africa. The block covers an area of approximately 3.1 million acres in water depth ranging from250 to 3,000 meters. The blocks provide for multiple plays targeting Cretaceous deepwater systems. Webelieve the area is positioned within the interpreted oil mature window of the Aptian source rock withreservoir sands sourced from the Orange River. In January 2019, we completed a 3D seismic surveycovering approximately 6,000 square kilometers. Processing of this data is currently underway. We arecompiling an initial inventory of prospects on the license are as will continue to refine and assess theprospectivity and petroleum systems analysis while integrating the new 3D seismic data in ourgeological evaluation during 2019 with a view to drilling as early as 2020.Our ReservesThe following table sets forth summary information about our estimated proved reserves as ofDecember 31, 2018. See Item 8. Financial Statements and Supplementary DataSupplemental Oiland Gas Data (Unaudited) for additional information.Our estimated proved reserves as of December 31, 2018, were associated with our Jubilee and theTEN fields in Ghana and the U.S. Gulf of Mexico as well as our share of our equity methodinvestment in the Ceiba Field and Okume Complex in Equatorial Guinea. Our estimated provedreserves as of December 31, 2017, were associated with our Jubilee and the TEN fields in Ghana aswell as our share of our equity method investment in the Ceiba Field and Okume Complex inEquatorial Guinea. Our estimated proved reserves as of December 31, 2016 were associated with ourJubilee and TEN fields in Ghana.Summary of Oil and Gas Reserves2018 Net Proved Reserves(1) 2017 Net Proved Reserves(1) 2016 Net Proved Reserves(1)Oil, Oil, Oil,Condensate, Natural Condensate, Natural Condensate, NaturalNGLs Gas(2) Total NGLs Gas(2) Total NGLs Gas(2) Total(MMBbl) (Bcf) (MMBoe) (MMBbl) (Bcf) (MMBoe) (MMBbl) (Bcf) (MMBoe)Reserves CategoryProved developed . . . . 82 57 91 59 38 65 64 13 66Proved undeveloped(3) . 45 28 50 23 11 24 10 2 11Total Kosmos . . . . . . . . 127 85 141 82 49 89 74 15 77Equity methodinvestment(4) . . . . . 24 14 27 19 13 21Total reserves . . . . . . . . 151 99 167 100 61 110(1) Our reserves associated with the Jubilee Field are based on the 54.4%/45.6% redetermination split, between the WCTP Block and DT Block.Totals within the table may not add as a result of rounding.(2) These reserves include the estimated quantities of fuel gas required to operate the Jubilee and TEN FPSOs during normal field operationsand the associated gas forecasted to be exported from TEN. This volume of associated gas is included as of December 31, 2017 as a result ofthe finalization of the TEN Associated-Gas Gas Sales Agreement (TAG GSA). If and when a subsequent gas sales agreement is executedfor Jubilee, a portion of the remaining Jubilee gas may be recognized as reserves. If and when a gas sales agreement and the relatedinfrastructure are in place for the TEN fields non-associated gas, a portion of the remaining gas may be recognized as reserves.(3) All of our proved undeveloped reserves are expected to be developed within six years or less. Proved undeveloped reserves expected to bedeveloped beyond five years are related to long-term projects which will be completed under a continuous drilling program.(4) We disclose our share of reserves that are accounted for by the equity method.Changes for the year ended December 31, 2018, include an addition of 51.1 MMBoe as a result ofthe acquisition of DGE. Changes at Greater Jubilee include a revision of 9.4 MMBbl related to strongfield performance, positive drilling results and increased original oil in place, partially offset by6.4 MMBbl of net Jubilee production during 2018. Changes at TEN include a positive revision24'