Exhibit 99.1

INFORMATION REGARDING PENN VIRGINIA CORPORATION

AND THE ACQUISITION PROPERTIES

This Exhibit 99.1 sets forth certain information regarding PVA and the properties to be acquired in connection with the Acquisition.

Our current focus is on drilling unconventional horizontal development wells in shale formations principally in the Eagle Ford Shale play in South Texas, where we are the operator on 42,430 gross (35,020 net) acres located primarily in Lavaca and Gonzalez Counties. Since 2010, we have drilled and completed 70 gross (58.9 net) wells in the Eagle Ford Shale play. We also have 8,045 net acres in the horizontal Granite Wash play in the Mid-Continent region and pursue select drilling opportunities in the play through participation in wells drilled by our joint venture partner.

During the quarter ended December 31, 2012, our average daily production rate was 15,444 BOEPD, which was 39% oil, 17% NGLs and 44% natural gas. As we continue to develop our Eagle Ford Shale assets, we expect oil, and to a lesser extent NGLs, to comprise a greater percentage of our daily production.

The following table sets forth by region our proved reserves and reserves to production ratio as of December 31, 2012, as well as our average daily production for the quarter ended December 31, 2012:

We believe our pending acquisition, or the Acquisition, of Eagle Ford Hunter, Inc., or Eagle Hunter, represents both a strategic and transformative acquisition for us. Eagle Hunter owns 40,565 gross (19,037 net) acres of producing oil, NGL and natural gas properties, which are located in Gonzales and Lavaca Counties, Texas and are largely contiguous to our current leaseholds. Eagle Hunter’s average daily production for the month of February 2013 was 3,173 BOEPD, of which 90% was oil. As of March 31, 2013, there were 46 gross (22.1 net) producing wells and seven gross wells awaiting completion.

For the year ended December 31, 2012, the Eagle Hunter assets had revenues of $72.1 million and direct operating expenses of $10.3 million. As of December 31, 2012, proved reserves associated with the Eagle Hunter assets were approximately 12.0 MMBOE, of which 37% were proved developed reserves and 96% were oil and NGLs. Included in the proved reserve estimates were 44 gross proved developed wells and 51 gross proved undeveloped locations. During the quarter ended December 31, 2012, the average daily production rate was 2,710 BOEPD, which was 89% oil, 6% NGLs and 5% natural gas.

The following table sets forth information relating to Eagle Hunter’s proved reserves as of December 31, 2012:

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PV-10 is the present value of estimated future revenues to be generated from the production of proved reserves, before income taxes, net of estimated production and future development costs, using prices and costs as of the date of estimation without future escalation, without giving effect to financial hedging activities, non-property related expenses such as general and administrative expenses, debt service and depreciation, depletion and amortization, and discounted using an annual discount rate of 10%. Standardized measure is the present value of estimated future cash inflows from proved natural gas and oil reserves, less future development and production costs and future income tax expenses, discounted at 10% per annum to reflect timing of future cash flows and using the same pricing assumptions as are used to calculate PV-10. Standardized measure differs from PV-10 because standardized measure includes the effect of future income taxes.

PV-10 is considered a non-GAAP measure. We believe the presentation of the PV-10 value is relevant and useful to our investors because it presents the discounted future net cash flows attributable to our proved reserves before taking into account corporate income taxes. We believe investors and creditors utilize our PV-10 value as a basis for comparison of the relative size and value of our reserves to other companies. Neither PV-10 value nor standardized measure reflects the impact of financial hedging transactions.

Following the consummation of the Acquisition, we will have a larger consolidated position of approximately 83,000 gross (54,000 net) acres in the Eagle Ford Shale play. We plan to operate four rigs on the operated portion of our leaseholds, and we believe that Eagle Hunter’s operating partner plans to continue a two-rig program. As of March 31, 2013, we would have had an interest in 117 gross (82.0 net) producing wells and up to an estimated 640 additional gross (420 net) drilling locations. This new combined acreage position will afford us a multi-year inventory of identified locations in an area familiar to us and where we have experience and institutional knowledge of the geology, reservoir characteristics and current industry best practices in drilling and completion techniques. Further, we believe that the Acquisition will enable us to leverage our increased scale and reduce our operating costs and development capital expenditures per well. We anticipate spending approximately $385 million on drilling and completions in 2013 and anticipate bringing a total of 62 gross (39.3 net) wells online by year-end.

After giving effect to the Acquisition, on a pro forma basis, our proved reserves as of December 31, 2012 would have been approximately 125.5 MMBOE, of which 41% would have been proved developed reserves and 46% would have been oil and NGLs. Our Eagle Ford Shale proved reserves would have been approximately 38.2 MMBOE, which would have comprised 30% of our total proved reserves. The pro forma PV-10 value of our proved reserves as of December 31, 2012 would have been $933.2 million. Our pro forma average daily production rate for the quarter ended December 31, 2012 would have been 18,154 BOEPD, consisting of 47% oil, 15% NGLs and 38% natural gas. PV-10 is considered a non-GAAP measure. A reconciliation of our pro forma PV-10 to standardized measure, assuming that Eagle Hunter’s tax rates would be the same as ours, is as follows:

Description of Properties

Pro Forma Overview of Properties

The following map shows our asset base, on a pro forma basis, after giving effect to the Acquisition. For a further description of our historical activity in each of these regions, please see the information that follows this map.

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Eagle Ford Shale

We are active in the Eagle Ford Shale play in South Texas and our current leaseholds are located primarily in Gonzales and Lavaca Counties. We own and operate a total of 42,430 gross (35,020 net) acres in the Eagle Ford Shale. Our Eagle Ford Shale oil and NGL reserves comprise approximately 21% of our total equivalent proved reserves as of December 31, 2012. In addition, according to Wright & Company Inc., our independent third-party reserve engineers, the average gross estimated ultimate recovery for our Eagle Ford Shale proved undeveloped locations with full-length laterals in Gonzales County and Lavaca County is approximately 400 MBOE and 500 MBOE, respectively.

During 2012, we invested approximately $350 million, or more than 90% of our 2012 capital program, to projects in the Eagle Ford Shale and drilled a total of 35 gross (29.5 net) wells, all but one of which was successful. We believe our project inventory in the Eagle Ford Shale provides us opportunities for continued oil and NGL-focused development over the next several years. Since December 2012, we have completed seven gross (6.5 net) Eagle Ford Shale wells, bringing our total to date to 71 gross (59.9 net) producing wells, with four gross wells being drilled and three gross wells awaiting completion. The initial 30-day average gross wellhead production rate for 68 of these wells with a 30-day production history was approximately 620 BOEPD. Our Eagle Ford Shale production was 6,872 BOEPD during the quarter ended December 31, 2012, comprised of approximately 80% oil, 11% NGLs and 9% natural gas. Our daily production from the Eagle Ford Shale for February 2013 was 7,776 BOEPD.

Mid-Continent

Our Mid-Continent efforts are focused on drilling the horizontal Granite Wash play where we have approximately 55,000 net leasehold acres across Washita, Custer, Blaine, Dewey, Caddo, Comanche, Grady and Jefferson Counties, Oklahoma and Roberts County, Texas. The Mid-Continent region contains primarily liquids-rich natural gas reserves, and represents approximately 11% of our total equivalent proved reserves as of December 31, 2012. Our Mid-Continent production was 2,892 BOEPD during the quarter ended December 31, 2012.

Activity in this region is primarily conducted through participation in wells drilled by our joint venture partner. During 2012, we invested approximately $25 million, or 6% of our 2012 capital program, to projects in this region. In 2013, we plan to invest approximately $13 million to participate in five gross (2.2 net) wells.

East Texas

In East Texas, we have approximately 33,000 net leasehold acres located in Harrison, Panola and Marion Counties. Our Carthage field in East Texas, consisting of our Cotton Valley and Haynesville Shale properties, represents approximately 50% of our total equivalent proved reserves as of December 31, 2012. Our East Texas production was 3,393 BOEPD during the quarter ended December 31, 2012 and was 70% natural gas.

Mississippi

Our Mississippi assets are located primarily in the Selma Chalk play in Marion, Lamar, Forrest and Jefferson Davis Counties where we have approximately 30,000 net leasehold acres and represent approximately 16% of our total equivalent proved reserves as of December 31, 2012. Our Mississippi production was 2,209 BOEPD during the quarter ended December 31, 2012 and was substantially all natural gas.

Appalachia

In Appalachia, we have approximately 38,000 net leasehold acres located primarily in Potter and Tioga Counties, Pennsylvania. Our Appalachian assets consist of our Marcellus Shale properties and represent less than 1% of our total equivalent proved reserves as of December 31, 2012. Our Appalachian production was 78 BOEPD during the quarter ended December 31, 2012 and was substantially all natural gas.

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Other Recent Developments

Hedging Activity

Since December 31, 2012, we have entered into several derivative financial instruments. The following table sets forth our commodity derivative positions as of March 31, 2013.

Business Strengths

We believe that we are well positioned to successfully execute the key elements of our business strategies based on the following business strengths:

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Business Strategies

We intend to pursue the following business strategies:

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The summary other financial data and key credit statistics presented as of and for the year ended December 31, 2012 are derived from our unaudited pro forma condensed consolidated financial statements. The pro forma financial data gives effect to the proposed acquisition and to the financing thereof with a combination of debt and the issuance to Magnum Hunter Resources Corporation of $40 million of our common stock. The unaudited pro forma financial data are based on certain assumptions and do not purport to be indicative of the results which actually would have been achieved if the proposed acquisition and other transactions listed above had been consummated on the dates indicated or of results that may be achieved in the future.

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FORWARD-LOOKING STATEMENTS

Some of the information included herein contains “forward-looking statements” within the meaning of Section 27A of the Securities Act, and Section 21E of the Securities Exchange Act of 1934, as amended. These statements use forward-looking words such as “may,” “will,” “should,” “could,” “achievable,” “anticipate,” “believe,” “expect,” “estimate,” “project” or other words and phrases of similar meaning. These statements discuss goals, intentions and expectations as to future trends, plans, events, results of operations or financial condition or state other “forward-looking” information. A forward-looking statement may include a statement of the assumptions or bases underlying the forward-looking statements. We believe we have chosen these assumptions or bases in good faith and that they are reasonable. However, we caution you that assumed facts or bases almost always vary from actual results, and the differences between assumed facts or bases and actual results can be material, depending on the circumstances. When considering forward-looking statements, you should keep in mind the cautionary statements in this offering memorandum and the documents we have incorporated by reference herein, including in our Annual Report on Form 10-K for the year ended December 31, 2012, or our 2012 Annual Report. These statements reflect our current views with respect to future events and are subject to various risks, uncertainties and contingencies, including, but not limited, to:

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Additional information concerning these and other factors can be found in our press releases and public periodic filings with the SEC. Many of the factors that will determine our future results are beyond the ability of management to control or predict. Readers should not place undue reliance on forward-looking statements, which reflect management’s views only as of the date hereof. Other than as required under the securities laws, we undertake no obligation to revise or update any forward-looking statements, or to make any other forward-looking statements, whether as a result of new information, future events or otherwise.

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