Exhibit 99.1

Black Elk Energy Offshore Operations, LLC Reports First Quarter 2013

Financial and Operational Results

Houston, May 28, 2013

Black Elk Energy Offshore Operations, LLC today announces financial and operational results for the quarter ended March 31, 2013. Some of the highlights include:

Financial Results

Oil and natural gas production. Total oil, natural gas and plant product production of 1,104 MBoe decreased 446 MBoe, or 29%, during the three months ended March 31, 2013 compared to the same period in 2012 as a result of downtime in the fields requiring hot work, which was delayed due to the BSEE requirements for approval after the West Delta 32 incident, in addition to pipeline repairs and winter weather.

Total revenues. Total revenues for the three months ended March 31, 2013 of $60.0 million decreased $16.2 million, or 21%, over the comparable period in 2012.

Revenues, excluding the realized and unrealized revenues from commodity hedge contracts, decreased $15.6 million, or 19%, for the three months ended March 31, 2013 compared to the same period in 2012 as a result of lower oil, gas and plant product production due to the West Delta 32 incident, pipeline repairs and winter weather and lower oil and plant product prices, partially offset by higher gas prices.

We entered into certain oil and natural gas commodity derivative contracts in 2013 and 2012. We realized gains on these derivative contracts in the amounts of $0.3 million for the three months ended March 31, 2013 and $1.5 million for the three months ended March 31, 2012. We recognized unrealized losses of $6.2 million for the three months ended March 31, 2013 and $6.7 million in the same period of 2012.

Excluding hedges, we realized average oil prices of $109.78 per barrel and $114.42 per barrel and gas prices of $3.60 per Mcf and $2.55 per Mcf for the three months ended March 31, 2013 and 2012, respectively. Average prices realized from the sale of gas on a first-quarter basis reflected the economic turnaround that began during 2012. Oil prices were lower on a quarter basis compared to 2012. We expect commodity prices to remain volatile in the future.

Operating Expenses

Lease operating costs. Our lease operating costs for the three months ended March 31, 2013 were $43.2 million, or $39.13 per Boe. For the three months ended March 31, 2012, our lease operating costs were $43.2 million, or $27.90 per Boe. Lease operating expenses remained relatively flat for the three months ended March 31, 2013 compared to the same period in 2012. The increase in cost per Boe during 2013 was primarily attributable to decreased production.

Workover costs. Our workover costs for the three months ended March 31, 2013 were $2.1 million, a decrease of $0.5 million compared to the first three months in 2012. For the three months ended March 31, 2013, Eugene Island 240, West Cameron 20/45, High Island A283, South Timbalier 190/203 and Vermilion 119/120/124 were the primary workover expense projects.

Exploration. Our exploration expenses for the three months ended March 31, 2012 were $0.9 million. There were no exploration costs for the same period in 2013. Exploration costs for 2012 included expenses to drill a non-operated well, South Pelto 13, which was unsuccessful.

Depreciation, depletion, amortization and impairment. DD&A expense was $11.6 million, or $10.47 per Boe, for the three months ended March 31, 2013 and $12.4 million, or $7.98 per Boe, for the three months ended March 31, 2012. The decrease in DD&A for the three months ended March 31, 2013 was a result of lower production and reduced asset basis as a result of the impairments recorded in 2012. Depletion is recorded based on units of production and DD&A expense includes depletion of future asset retirement obligations. We recorded a $33.0 million impairment for the three months ended March 31, 2013 and no impairment for the same period in 2012.

General and administrative expenses. G&A expense was $10.7 million, or $9.69 per Boe, for the three months ended March 31, 2013 and $6.4 million, or $4.15 per Boe, for the same period in 2012. The increase in G&A expense for the three months ended March 31, 2013 was due to an increase in staff and related administrative costs, in addition to higher legal fees, severance costs, consultant expenses and insurance costs.

Gain on involuntary conversion of asset. On September 27, 2012, an incident occurred on our High Island 443 A-2 ST well which required the closing of the blind/shear rams to properly shut in and maintain control of the well due to several days of unsuccessful attempts to repair a small hydrocarbon leak on a conductor riser. Additional surface diagnostics found the inner casing strings to be most likely compromised. On October 12, 2012, the BSEE advised us to plug and abandon the well. We filed an insurance claim and costs were reimbursed by our insurance company. We recorded a gain of $2.4 million for additional proceeds that were received in May 2013.

Accretion expense. We recognized accretion expense of $7.5 million for the three months ended March 31, 2013 compared to $9.1 million for the three months ended March 31, 2012. The decrease in accretion expense in 2013 was primarily attributable to plugging and abandonment activity that was performed in 2012 and the extended life of the remaining assets, partially offset by increased liability, in the first three months of 2013.

Gain on sale of asset. Gain on sale of asset of $37.8 million was primarily related to the sale of four fields to Renaissance Offshore, LLC for approximately $52.5 million subject to normal purchase price adjustments on March 26, 2013.

Other operating expenses. Other operating expenses of $1.0 million for the quarter ended March 31, 2013 were related to our consolidation of Freedom Well Services, LLC. There were no other operating expenses for the same period in 2012.

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About Black Elk Energy Offshore

We are an oil and gas company engaged in the acquisition, exploitation, development and production of oil and natural gas properties. We seek to acquire and exploit properties with proved developed reserves, proved developed non-producing reserves and proved undeveloped reserves. Our strategy is to acquire and economically maximize properties that are currently producing or have the potential to produce given additional attention and capital resources. We are engaged in continual efforts to monitor and reduce operating expenses by finding opportunities to safely increase efficiencies related to staffing, transportation and operational procedures. Moreover, our ability to accurately estimate and manage plugging and abandonment costs associated with potential acquisitions increases the likelihood of achieving our target returns on investment. Our management team has extensive engineering, geological, geophysical, technical and operational expertise in successfully developing and operating properties in both our current and planned areas of operation.

We seek to acquire assets in our areas of focus from oil and gas companies that have determined that such assets are noncore and desire to remove them from their producing property portfolio or have made strategic decisions to deemphasize their offshore operations. Prior to an acquisition, we perform stringent structural engineering tests to determine whether the reservoirs possess potential upside. Each opportunity is presented, catalogued and graded by our management and risked appropriately for the overall impact to our company.

Conference Call Information. Black Elk will hold a conference call to discuss financial and operational results on Tuesday, May 28, 2013, at 4:00 p.m. Central Time. To participate, dial (800) 406-5162 in the United States or (303) 223-2681 at least ten minutes before the call begins.

Safe Harbor Statement

This press release may contain certain “forward-looking statements” relating to the business of Black Elk Energy Offshore Operations, LLC and its subsidiary companies. All statements, other than statements of historical fact included herein are “forward-looking statements.” These forward-looking statements are often identified by the use of forward-looking terminology such as “believes,” “expects” or similar expressions, and involve known and unknown risks and uncertainties. Although Black Elk believes that the expectations reflected in these forward-looking statements are reasonable, they do involve assumptions, risks and uncertainties, and these expectations may prove to be incorrect. Investors should not place undue reliance on these forward-looking statements, which speak only as of the date of this press release. Black Elk’s actual results could differ materially from those anticipated in these forward-looking statements as a result of a variety of factors, including those discussed in Black Elk’s periodic reports that are filed with the Securities and Exchange Commission and available on its website at www.sec.gov. All forward-looking statements attributable to Black Elk or persons acting on its behalf are expressly qualified in their entirety by these factors. Other than as required under the securities laws, Black Elk does not assume a duty to update these forward-looking statements.

Contact

Bruce Koch

IR@blackelkenergy.com

11451 Katy Freeway, Suite 500

Houston, Texas 77079

(281) 598-8647

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BLACK ELK ENERGY OFFSHORE OPERATIONS, LLC AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in thousands)

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BLACK ELK ENERGY OFFSHORE OPERATIONS, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(in thousands)

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How We Evaluate Our Operations:

We use a variety of financial and operational measures to assess our overall performance. Among those measures are (1) volumes of oil and natural gas produced, (2) oil and natural gas prices realized, (3) per unit operating and administrative costs and (4) Adjusted EBITDA (as defined in the following table).

The following table contains certain financial and operational data for each of the quarter ended March 31, 2013 and 2012:

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