Exhibit 99.1

NEWS RELEASE

Trans Energy, Inc.

210 Second Street

PO Box 393

St. Marys, WV 26170

Company contact:

John G. Corp

304-684-7053

www.transenergyinc.com

TRANS ENERGY, INC. PROVIDES OPERATIONS UPDATE

1^st Quarter 2013 Marcellus Production Up 78.7%

Natural Gas Hedges In Place

ST. MARYS, WEST VIRGINIA, May 30, 2013 — Trans Energy, Inc. (OTCQB: TENG), a pure play Marcellus Shale exploration and production company, today provided an operations update on the company’s activities.

Summary Highlights

First Quarter Production Volumes

Trans Energy posted a substantial increase in net production volumes from its Marcellus wells for the first quarter of 2013, compared to the comparable period a year earlier. The production volumes shown below exclude results from the company’s shallow wells, which were sold in a transaction that closed on January 24, 2013, as was previously announced.

The main factor that drove increased net production volumes during the first quarter of 2013 is the fact that Trans Energy grew the number of net horizontal Marcellus wells to 6.2 wells in the quarter from 3.6 net horizontal Marcellus wells in the year ago period. Trans Energy’s Dewhurst 110H and 111H wells and Anderson 5H and 7H wells were brought online in September 2012, and the two Doman wells were brought online in January 2013. Enhanced completion techniques further drove production volumes, as these new wells posted 30 day initial production rates that averaged 7,449 Mcfe/d, representing an increase of more than 70% compared to the 30-day IP rates of the company’s previous nine horizontal Marcellus wells. After adjusting for the increase in average lateral length of the wells in the 2012 drilling program, the 30-day IP rates of these six wells represent an increase of 57% compared to the adjusted 30-day IP rates of the previous nine horizontal Marcellus wells. The initial EURs per 1,000 feet of lateral that have been assigned by the company’s independent engineers average more than 2.2 Bcfe on these last six wells, compared to approximately 1.9 Bcfe on wells that were drilled previously.

John Corp, President of Trans Energy, commented, “We stepped up our capital spending program during 2012, and the results for this quarter show that we were effective at putting the previous round of financing to work. We’ve continued to enhance our drilling techniques, and we are already getting better production and reserves as a result. The highly successful wells from our 2012 program enabled us to increase production by more than 75% on an Mcfe basis, even with some wells being shut in during the quarter due to issues on the Williams pipeline. With those issues now resolved, and an additional $25 million from our lender to finance our share of the 2013 program, we are putting that money in the ground as quickly as we can, so as to position ourselves to report strong production growth once again as the next crop of wells comes online later this year and into early 2014.”

Wells Status Update

Trans Energy currently has two rigs running. The first rig spud the Freeland 1H in early March and upon completion of that well it will move over to the Freeland 2H, which is located on the same pad in Marion County. The second rig spud the Goshorn 3H in early April and will move over to the Goshorn 4H in Marshall County, once complete. At that point, the rig is expected to move to the Graff pad in Tyler County to complete two wells there. The company expects to stimulate the two wells on each of the Freeland, Goshorn and Graff pads simultaneously. These wells are also being drilled on 500 foot spacing, whereas all of the company’s previous wells have been drilled on spacing of 750 feet or greater.

Initial well log results on the Freeland wells suggest that the Marcellus formation is thicker in this area than in the company’s leasehold in Wetzel or Marshall Counties. The Goshorn 3H and 4H represent the third and fourth wells to be drilled on the Goshorn pad, but will be the first to be fractured simultaneously. As detailed in the following table, the company has plans to complete and bring into sales eight wells during this calendar year:

As mentioned above, several of the company’s wells experienced periods when they were shut in during the quarter due to operational issues with the Williams pipeline in Marshall and Wetzel Counties. Heavier than anticipated liquid volumes on the pipeline prompted Williams to require the company to curtail production from its Wetzel County wells beginning in March of 2013. Additionally, beginning in late March, 2013, Williams forced the company to shut in production from its Wetzel wells completely due to a pipeline rupture in Marshall County. This rupture also forced the shut in of several other company wells in Marshall County. As of May 27^th, these issues have been resolved and the company has been allowed to bring all of its wells back online.

Drillable Inventory

Corp continued, “Our focused drilling program has demonstrated strong results across our acreage position in Marshall and Wetzel counties, and we plan to continue that success later this year in Marion and Tyler counties. However, as many of you know, West Virginia is a state that does not have “forced pooling.” Therefore, we view our drillable inventory different than other oil and natural gas companies.”

“We first map the wellbores that can be drilled across our company’s leasehold. We then choose to report our inventory of wells only when we believe that we hold title to 100% of the acreage that would be required to apply for the permit to drill the well. We further take into account the topography as well as any issues related to coal mines when we map the actual locations for proposed wells.”

“The net result is that when we talk about drillable locations at Trans Energy, we are talking about wells that are one hundred percent ready to drill with the issuance of a required permit. Based on 750 foot spacing, we have 188 drillable locations. When you downspace to 500 foot spacing that number increases to 285 ready to drill locations. Our inventory of “potential” wellbores – a term used more often by others in the industry – would be significantly higher at both 750 foot and 500 foot spacing.”

“Below is a list that incorporates the title and topography issues mentioned above. The list also incorporates only those wells that have lateral lengths over 3,000 feet, with a minimum of two such wells for each pad site.”

Hedging Update

On May 9^th, the company’s subsidiary, American Shale Development, entered into costless collars covering approximately 85% of its expected natural gas production from wells that were considered PDP as of that date. Neither oil nor natural gas liquids have been hedged, but the BTU associated with the company’s ethane production was essentially hedged, since it is sold as part of the natural gas stream. The costless collars consist of long put options with a strike price of $4.00 per MMBtu and offsetting short calls with a strike price of $4.28 per MMBtu. The aforementioned volumes are hedged beginning with the June 2013 contract and ending with the April 2015 contract, as shown in the table below:

Additional information regarding Trans Energy, including maps, investor presentations, news releases and videos can be found at the Company’s website www.transenergy.com. Trans Energy will regularly update information on the website to provide investors with the most up to date information on the Company and its operations.

About Trans Energy, Inc.

Trans Energy, Inc. (OTCQB: TENG) is a pure play Marcellus Shale oil and gas exploration and development company, headquartered in the Appalachian Basin. Further information can be found on the Company’s website at www.transenergyinc.com.

Safe Harbor Statement under the Private Securities Litigation Reform Act of 1995—Forward-looking statements in this release do not constitute guarantees of future performance. Such forward-looking statements are subject to risks and uncertainties that could cause our actual results to differ materially from those anticipated. Forward-looking statements in this document include statements regarding the Company’s exploration, drilling and development plans, the Company’s expectations regarding the timing and success of such programs. Factors that could cause or contribute to such differences include, but are not limited to, fluctuations in the prices of oil and gas, uncertainties inherent in estimating quantities of oil and gas reserves and projecting future rates of production and timing of development activities, competition, operating risks, acquisition risks, liquidity and capital requirements, the effects of governmental regulation, adverse changes in the market for the Company’s oil and gas production, dependence upon third-party vendors, and other risks detailed in the Company’s periodic report filings with the Securities and Exchange Commission. For a more detailed discussion of the risks and uncertainties of our business, please refer to our Annual Report on Form 10-K for the fiscal year ended December 31, 2011 filed with the Securities and Exchange Commission. We assume no obligation to update any forward-looking information contained in this press release or with respect to the announcements described herein.