• At Umbach, there are 30.4 net producing and non-producing horizontal wells with 21,749 Mboe of 2P  reserves plus 73.4 net future horizontal drilling locations with 53,519 Mboe of 2P reserves. Associated 2P  FDC was $484.0 million net. • At Umbach, 53 net 2P horizontal drilling locations were assigned an average of 4.4 Bcf gross raw gas on the  100% working interest lands, an increase of 26% from 3.5 Bcf gross raw gas assigned in 2013. On the 60%  working interest lands, 20.4 net 2P horizontal drilling locations were assigned an average of 3.2 Bcf gross  raw gas, an increase of 7% from 3.0 Bcf gross raw gas assigned in 2013. • At Umbach, 2P reserves were recognized in the upper Montney only on 18% or 25.5 net sections of Storm’ s  141 net sections in the area with DPIIP averaging 43 Bcf gross raw gas per section in the upper Montney  (total net DPIIP 1.1 Tcf on 25.5 net sections). Forecast recovery of DPIIP totals 40% for 2P reserves. • The forecast decline in 2015 is 35% for wells on production at December 31, 2014 (decline from January  2015 to December 2015). (1)  The all-in calculation reflects the result of Storm’ s entire capital investment program as it takes into account the effect of  acquisitions, dispositions and revisions, as well as the change in FDC.  All amounts are stated in Canadian dollars unless otherwise specified. Where applicable, natural gas has been  converted to barrels of oil equivalent ("Boe") based on 6 Mcf:1 Boe. The Boe rate is based on an energy equivalent  conversion method primarily applicable at the burner tip and does not recognize a value equivalent at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different  than the energy equivalency of the 6:1 conversion ratio, utilizing the 6:1 conversion ratio may be misleading as an  indication of value. Production volumes and revenues are reported on a company gross basis, before deduction of  Crown and other royalties, unless otherwise stated. Unless otherwise specified, all reserves volumes are based on  "company gross reserves" using forecast prices and costs. The oil and gas reserves statement for the year ended  December 31, 2014, which will include complete disclosure of oil and gas reserves and other information in  accordance with NI 51-101, will be contained within the Annual Information Form which will be available on SEDAR. References to estimates of oil and gas classified as DPIIP are not, and should not be confused with, oil and gas  reserves. 11  Numbers in this table may not add due to rounding.  Gross Company Interest Reserves as at December 31, 2014  (Before deduction of royalties payable, not including royalties receivable)  Light Crude Oil  (Mbbls) Sales Gas  (Mmcf)  NGL  (Mbbls)  6:1 Oil Equivalent  (Mboe)  Proved producing  940  62,696  2,098  13,487  Proved non-producing  -  10,676  373  2,153  Total proved developed  940  73,372  2,471  15,640  Proved undeveloped  300  222,301  6,560  43,911  Total proved  1,240  295,673  9,032  59,551  Probable additional  846  144,778  3,498  28,473  Total proved plus probable  2,086  440,452  12,530  88,024  INFORMATION REGARDING DISCLOSURE ON OIL AND GAS RESERVES AND RESOURCES