Exhibit 99.1

14701 St. Mary’s Lane, Suite 275

Houston, Texas 77079

Ph: (713) 722-6500 Fax: (713) 722-6620

www.pennvirginia.com

FOR IMMEDIATE RELEASE

PENN VIRGINIA CORPORATION ANNOUNCES THIRD QUARTER 2016 RESULTS

HOUSTON, TX — (Marketwired - November 14, 2016) – Penn Virginia Corporation (“Penn Virginia” or the “Company”) today reported financial and operational results for the three months ended September 30, 2016.

Key Highlights for Third Quarter 2016

Management Comment

John A. Brooks, Interim Principal Executive Officer and Chief Operating Officer commented, “Penn Virginia has achieved substantial improvements to its cost structure by virtue of the restructuring that was completed on September 12, 2016. These changes have helped lower our fixed and variable costs. We also continue to improve our drilling and completion techniques and overall ability to develop our high value acreage position. Our strong balance sheet post-restructuring, combined with our significantly improved liquidity and low-cost drilling inventory of oil-rich acreage in Gonzales and Lavaca Counties, provide Penn Virginia with a considerable runway to execute on our high rate-of-return drilling locations at current commodity prices. Our most recent lower Eagle Ford slickwater completion design which targets pumping 2,000 pounds of proppant per foot of lateral, has performed exceedingly well. In fact, the Hawg Hunter three-well pad, where we used this technique most recently, is our highest producing pad to date. These 3 wells’ combined 24-hour IPs (Initial Production) totaled 11,532 BOEPD, with a 30-day IP rate of 5,583 BOEPD and 561,000 BOE produced in their first eight-and-a-half months, of which 90% was oil. We intend to apply the same slickwater completion methodology to the two upcoming Sable and Axis pads, and we anticipate continued advancements to our completion design.

Mr. Brooks continued, “While watching commodity prices closely, we anticipate resuming our development program running a one to two-rig program in 2017, targeting the drilling of 16 to 19 net lower Eagle Ford wells, with 13 to 16 net wells turned to sales during the year. We expect this activity to be achieved within operating cash flow. We plan to concentrate our activity within our two-string, lower Eagle Ford area of development within Gonzales County and northwestern Lavaca County. We also plan to test our slickwater completion methodology down-dip in our three-string lower Eagle Ford higher pressured acreage as well as the upper Eagle Ford which is prevalent across our acreage. We are paying attention to results and activity by our competitors and remain optimistic about the potential of the area. We recognize the significant advantage our clean balance sheet offers us relative to our peer group and while we have considerable flexibility to advance development, we will be intentional with our acceleration as we further derisk our inventory and/or respond to commodity prices.”

Third Quarter 2016 Financial Results

Overview of Results

Following emergence from bankruptcy on September 12, 2016, Penn Virginia adopted fresh start accounting and the full cost method of accounting for oil and gas properties which resulted in the Company becoming a new entity for financial reporting purposes. References to “Successor” relate to the financial position and results of operations of the reorganized Penn Virginia from September 13, 2016 to September 30, 2016. References to “Predecessor” relate to the financial position of Penn Virginia before application of fresh start accounting prior to and including September 12, 2016. As a result of the application of fresh-start accounting and the effects of the implementation of our Plan of Reorganization, financial results for the Successor from and after September 13, 2016 are not comparable to financial results of the Predecessor prior to that date.

Total production in the third quarter of 2016 was 979 MBOE or 10,629 BOEPD with 70% of production comprised of oil, 183 MBOE of which was attributable to the Successor and 796 MBOE of which was attributable to the Predecessor.

Total product revenues for the third quarter were $6.3 million in the Successor period and $27.0 million in the Predecessor period for a total of $33.3 million. Total direct operating expenses (general and administrative expense (excluding equity-classified share-based compensation), lease operating expense, gathering, processing and transportation expense and severance and ad valorem taxes) for the third quarter were $3.2 million in the Successor period and $16.1 million in the Predecessor period for a total of $19.3 million. For 2017, management expects that gathering, processing and transportation expense will be reduced to approximately $2.90 to $3.30 per BOE as a result of the restructuring of the Company’s midstream contracts. Additionally, management anticipates lease operating expense from $5.00 to $5.50 per BOE for 2017 and cash general and administrative expense to be approximately $16 million to $19 million.

Operating income in the third quarter was $1.1 million in the Successor period with a loss of $7.7 million in the Predecessor period for a combined operating loss for the third quarter of $6.6 million.

The Company recognized a $1.15 billion gain in Reorganization items, net in the third quarter of the Predecessor period primarily as a result of a gain on the settlement of liabilities subject to compromise and a gain on adjustments related to fresh start accounting, offset in part by expenses related to professional fees and other expenses related to the emergence from bankruptcy.

Capital Resources and Liquidity

Upon emergence from bankruptcy on September 12, 2016, Penn Virginia entered into a new $200 million revolving credit facility and received $50 million of proceeds in connection with the rights offering. It provides for a revolving commitment and has an initial borrowing base of $128 million. As of September 30, 2016 Penn Virginia’s revolving credit facility had a balance of $54.4 million reflecting liquidity at the end of the third quarter of $84.1 million including $14.0 million in cash. As of November 11, 2016, the Company’s liquidity was $96.6 million, with $39.0 million drawn on its revolving credit facility and $7.6 million of cash.

Upon emergence from bankruptcy, 678,048 shares were reserved for unresolved claims. Since that time, 75,867 shares have been issued and 602,181 shares remain in reserve for issuance on account of unresolved claims or will be distributed to shareholders on a pro rata basis upon final resolution of all outstanding claims. Total shares outstanding as of November 11, 2016 were 14,992,018, inclusive of the aforementioned shares.

The Company’s initial capital expenditure plan for the remainder of 2016 and 2017 is expected to be primarily funded with operating cash flow. The Company does have flexibility given its excellent balance sheet to potentially accelerate its drilling activities depending on the outlook for commodity prices.

Eagle Ford Shale Operational Update

Third Quarter 2016 Update

Third quarter production from the Company’s Eagle Ford operations was 889 MBOE or 9,659 BOEPD. Approximately 75% of third quarter Eagle Ford production was from crude oil, 15% was from natural gas liquids (NGLs) and 10% was from natural gas. Production from Eagle Ford operations was 91% of total Company production for the third quarter and was derived from 301 operated and 36 outside-operated legacy wells. The Company did not drill or complete a well during the third quarter and the last completed well was brought to sales in February 2016.

Well Cost Reductions and Improved Well Results

Reflecting improvements to well design, operational efficiencies and lower industry oil field service costs, the Company estimates gross well costs for a 6,000-foot lateral, 24-stage well with two-strings of casing in the lower Eagle Ford shale to be $4.8 to $5.0 million. This is estimated to yield an approximate 50% rate of return at $50 WTI oil price and $3.00 Henry Hub natural gas price. At $40 WTI oil price, these wells still support a rate of return of just over 20%. This estimated gross well cost (including facilities cost) is approximately 10% to 15% lower than this same typical well design one-year prior.

Recent Eagle Ford Well Results    

Below are the production results and related operating information with respect to the Company’s 2-string lower Eagle Ford wells:

Penn Virginia switched to slickwater completions in the third quarter of 2015. Since that time, the Company has completed 18 wells in the lower Eagle Ford, the latest being the three-well Hawg Hunter pad which commenced production in February 2016. As a group, these 18 gross wells had average 24-hour IPs of 2,083 BOEPD per well and an average 30-day IP rate of 1,066 BOEPD per well over an average of 21 frac stages, with 92% of production from crude oil. The Hawg Hunter pad was completed with the Company’s most recent completion design, targeting 500,000 pounds of proppant per stage, with an average of 28 stages per well. The 24-hour IP of these 3 wells was 11,532 BOEPD and its 30-day IP rate was 5,583 BOEPD. This is the best performing Eagle Ford pad drilled and completed by the Company to date.

Drilling Program Outlook

For the remainder of 2016, Penn Virginia has launched a one-rig development program and has scheduled to complete the 3-well Sable pad and drill the 3-well Axis pad. In 2017, the Company plans to drill 16 to 19 net wells, with 13 to 16 net wells turned to sales by the end of 2017. Management expects that approximately 85% of the Company’s $95 million to $115 million planned 2017 expenditures will be directed to development drilling and completion expenditures under this program. Under this program, management expects production of 3,600 to 3,900 MBOE in 2017 with approximately 70% to 72% of production comprised of oil.

Management expects production will decline in the fourth quarter 2016 until new wells are turned to sales and production growth to commence in first quarter 2017. Management expects production in the fourth quarter 2017 will be approximately 10 to 15 percent higher than third quarter 2016 production levels and for the liquids composition to rise steadily through the year.

Derivatives Update

The Company hedged a substantial portion of its developed oil production in the early part of its reorganization process which has helped to shield its revenues from some of the volatility that has been witnessed in the marketplace. The Company’s hedge position will be actively reviewed going forward.

Please see the Derivatives table below for our current derivative positions.

Third Quarter 2016 Conference Call

A conference call and webcast, during which management will discuss third quarter 2016 financial and operational results, is scheduled for Tuesday, November 15, 2016 at 11:00 a.m. ET. Prepared remarks will be followed by a question and answer period. Investors and analysts may participate via phone by dialing toll free 1-877-407-9167 (international: 1-201-493-6754) five to 10 minutes before the scheduled start of the conference call, or via webcast with presentation slides by logging on to the Company’s website, www.pennvirginia.com, at least 15 minutes prior to the scheduled start of the call to download and install any necessary audio software. An on-demand replay of the webcast will be available at the Company’s website beginning approximately 24 hours after the webcast. The replay can also be accessed at http://pennvirginia.equisolvewebcast.com/q3-2016.

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Penn Virginia Corporation is an independent oil and gas company engaged in the exploration, development and production of oil, NGLs and natural gas in various domestic onshore regions of the United States, with a primary focus in the Eagle Ford Shale in south Texas. For more information, please visit our website at www.pennvirginia.com.

Certain statements contained herein that are not descriptions of historical facts are “forward-looking” statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Because such statements include risks, uncertainties and contingencies, actual results may differ materially from those expressed or implied by such forward-looking statements. These risks, uncertainties and contingencies include, but are not limited to, the following: potential adverse effects of the completed Chapter 11 proceedings on our liquidity, results of operations, brand, business prospects, ability to retain financing and other risks and uncertainties related to our emergence from Chapter 11; the ability to operate our business following emergence from Chapter 11; our ability to satisfy our short-term and long-term liquidity needs, including our inability to generate sufficient cash flows from operations or to obtain adequate financing to fund our capital expenditures and meet working capital needs; negative events or publicity adversely affecting our ability to maintain our relationships with our suppliers, service providers, customers, employees, and other third parties; new capital structure and the adoption of fresh start accounting, including the risk that assumptions and factors used in estimating enterprise value vary significantly from the current estimates in connection with the application of fresh start accounting; plans, objectives, expectations and intentions contained in this press release that are not historical; our ability to become listed on the OTCQX or a national securities exchange; our ability to execute our business plan in the current depressed commodity price environment; the decline in and volatility of commodity prices for oil, natural gas liquids, or NGLs, and natural gas; our ability to develop, explore for, acquire and replace oil and natural gas reserves and sustain production; our ability to generate profits or achieve targeted reserves in our development and exploratory drilling and well operations; any impairments, write-downs or write-offs of our reserves or assets; the resumption of our drilling program; the projected demand for and supply of oil, NGLs and natural gas; our ability to contract for drilling rigs, supplies and services at reasonable costs; our ability to obtain adequate pipeline transportation capacity for our oil and gas production at reasonable cost and to sell the production at, or at reasonable discounts to, market prices; the uncertainties inherent in projecting future rates of production for our wells and the extent to which actual production differs from estimated proved oil and natural gas reserves; drilling and operating risks; our ability to compete effectively against other oil and gas companies; leasehold terms expiring before production can be established and our ability to replace expired leases; environmental obligations, costs and liabilities that are not covered by an effective indemnity or insurance; the timing of receipt of necessary regulatory permits; the effect of commodity and financial derivative arrangements; the occurrence of unusual weather or operating conditions, including force majeure events; our ability to retain or attract senior management and key employees; counterparty risk related to the ability of these parties to meet their future obligations; compliance with and changes in governmental regulations or enforcement practices, especially with respect to environmental, health and safety matters; physical, electronic and cybersecurity breaches; litigation that impacts us, our assets or our midstream service providers; uncertainties relating to general domestic and international economic and political conditions; and other risks set forth in our filings with the Securities and Exchange Commission (SEC).

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. All subsequent written and oral forward-looking statements attributable to Penn Virginia or persons acting on its behalf are expressly qualified in their entirety by these cautionary statements. The statements in this release speak only as of the date of this release. 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, except as may be required by applicable law.

PENN VIRGINIA CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - unaudited

(in thousands, except per share data)

PENN VIRGINIA CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS - unaudited

(in thousands)

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - unaudited

(in thousands)