Table of Contents Index to Financial Statements The following table provides an overall and categorical summary of our natural gas, oil and NGL reserves, as of fiscal year-end 2018 based on average fiscal year prices, and our well count, net acreage and PV-10 as of December 31, 2018, and sets forth 2018 annual information related to production and capital investments for each of our operating areas: ​2018 PROVED RESERVES BY CATEGORY AND SUMMARY OPERATING DATA  Appalachia Northeast Southwest Other  (2) Total Estimated proved reserves: Natural gas  (Bcf) : Developed 3,327  1,068   – 4,395  Undeveloped 1,039  2,610  – 3,649  4,366  3,678  – 8,044  Crude oil  (MMBbls) : Developed – 17.9  0.1  18.0  Undeveloped – 51.0  – 51.0  – 68.9  0.1  69.0  Natural gas liquids  (MMBbls) : Developed – 175.5  – 175.5  Undeveloped – 401.6  – 401.6  – 577.1  – 577.1  Total proved reserves  (Bcfe)  $^{(3)}$: Developed 3,327  2,229  1  5,557  Undeveloped 1,039  5,325  – 6,364  4,366  7,554  1  11,921  Percent of total 37%  63%  0%  100%  Percent proved developed 76%  30%  100%  47%  Percent proved undeveloped 24%  70%  0%  53%  Production  (Bcfe) 459  243  244  (4) 946  Capital investments  (in millions) $ 422  $ 691  $ 118  (5) $ 1,231  Total gross producing wells  (6) 666  466  17  1,149  Total net producing wells  (6) 592  333  14  939  Total net acreage 184,024  297,445  166,120  (7) 647,589  Net undeveloped acreage 73,174  220,331  153,159  (7) 446,664  PV-10: Pre-tax  (in millions)  (8) $ 3,054  $ 3,470  $ – $ 6,524  PV of taxes  (in millions) (8) (245) (280) – (525) After-tax  (in millions) (8) $ 2,809  $ 3,190  $ – $ 5,999  Percent of total 47%  53%  0%  100%  Percent operated  (9) 99%  100%  100%  99%  (1) The Fayetteville Shale E&P assets and associated reserves were divested on December 3, 2018. (2) Other reserves and acreage consists primarily of properties in Colorado. Production and capital investing includes Fayetteville Shale. (3) We have no reserves from synthetic gas, synthetic oil or nonrenewable natural resources intended to be upgraded into synthetic gas or oil. We used standard engineering and geoscience methods, or a combination of methodologies in determining estimates of material properties, including performance and test date analysis offset statistical analogy of performance data, volumetric evaluation, including analysis of petrophysical parameters (including porosity, net pay, fluid saturations (i.e., water, oil and gas) and permeability) in combination with estimated reservoir parameters (including reservoir temperature and pressure, formation depth and formation volume factors), geological analysis, including structure and isopach maps and seismic analysis, including review of 2-D and 3-D data to ascertain faults, closure and other factors. (4) Includes 243 Bcf of natural gas production related to our Fayetteville Shale operations which were sold on December 3, 2018. (5) Other capital investments includes $33 million related to our Fayetteville Shale operations which were sold on December 3, 2018, $60 million related to our water infrastructure project, $16 million related to our E&P service companies and $9 million related to our exploration activities. (6) Represents producing wells, including 394 wells in which we only have an overriding royalty interest in Northeast Appalachia, used in the December 31, 2018 reserves calculation. (7) Excludes exploration licenses for 2,518,519 net acres in New Brunswick, Canada, which have been subject to a moratorium since 2015. (8) Pre-tax PV-10 (a non-GAAP measure) is one measure of the value of a company’s proved reserves that we believe is used by securities analysts to compare relative values among peer companies without regard to income taxes. The reconciling difference in pre-tax PV-10 and the after- tax PV-10, or standardized measure, is the discounted value of future income taxes on the estimated cash flows from our proved natural gas, oil and NGL reserves. (9) Based upon pre-tax PV-10 of proved developed producing activities. 8