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Ohio Utica Shale

Halcon Resources plans 500 Utica wells, Ohio oil rail terminal

By Bob Downing Published: August 3, 2013

From Texas-based Halcon Resources on  Thursday:

Halcon Resources Announces Second Quarter 2013 Financial Results and Provides Updated Outlook


Company Announces Utica/Point Pleasant Discovery Well in Trumbull County, Ohio; Kibler 1H Tested at Rate of 2,233 Boe/d (75% liquids)

Company Currently Producing ~35,000 Boe/d

New Company Record 3,317 Boe/d IP Rate in Williston Basin

HOUSTON, August 1, 2013 (GLOBE NEWSWIRE) -- Halcón Resources Corporation (NYSE:HK) ("Halcón" or the "Company") today announced its second quarter 2013 financial results and provided an updated outlook.

Revenues for the second quarter of 2013 increased to $214.3 million, compared to $23.3 million for the three months ended June 30, 2012. Net production for the period increased 646% year-over-year to an average of 29,165 barrels of oil equivalent per day (Boe/d). Second quarter 2013 production was comprised of 83% oil, 5% natural gas liquids (NGLs) and 12% natural gas.

The Company realized 97% of the average NYMEX oil price, 35% of the average NYMEX oil price for NGLs and 91% of the average NYMEX natural gas price during the second quarter of 2013, excluding the impact of derivatives.

Halcón reported net income available to common stockholders, after assumed conversions, of $37.3 million, or $0.08 per diluted share for the quarter. After adjusting for selected items (primarily related to the non-cash impact of derivatives), the Company reported net income for the three months ended June 30, 2013 of $16.8 million, or $0.04 per diluted share, compared to net income of $2.8 million, or $0.02 per diluted share in the comparable quarter of 2012 (see Selected Item Review and Reconciliation table for additional information).

Halcón reported cash flow from operations before changes in working capital of $122.7 million, or $0.28 per diluted share for the three months ended June 30, 2013 (see Condensed Consolidated Statements of Cash Flows for a reconciliation to net cash provided by operating activities). After adjusting for selected items (see Condensed Consolidated Statements of Cash Flows and Selected Item Review and Reconciliation table for additional information), cash flow from operations before changes in working capital was $122.7 million for the quarter, or $0.28 per diluted share, compared to $0.2 million, or $0.00 per diluted share for the same period of 2012.

After adjusting for selected items (see Selected Operating Data table for additional information), lease operating expense per unit for the quarter decreased by 45% to $11.99 per Boe, versus the comparable period of 2012. During the second quarter of 2013, total operating costs per unit (including lease operating expense, workover and other expense, taxes other than income, gathering and other and general and administrative expense), after adjusting for selected items (see Selected Operating Data table for additional information), decreased by 42% to $31.07 per Boe, compared to the second quarter of 2012.

Floyd C. Wilson, Chairman and Chief Executive Officer, commented, "We continue to make progress on all fronts. Operationally, we are generating better returns on the wells we have recently drilled in our core areas by focusing on improving recoveries and reducing costs. As is our practice, our portfolio management process is underway and we expect to be a more concentrated oil company by the end of this year."

Liquidity and Capital Spending

Halcón received net proceeds from a perpetual convertible preferred stock offering of $335.5 million during the period, which were used to repay a portion of the outstanding borrowings under its senior secured revolving credit facility.

As of June 30, 2013, the Company had liquidity of $508.9 million, which consisted of $3.1 million in cash and $505.8 million in undrawn capacity on its senior secured revolving credit facility.

During the second quarter of 2013, Halcón incurred capital costs of $468 million on drilling and completions, $39 million on leasehold acquisitions and $113 million on infrastructure, seismic and other. In addition, approximately $58 million was incurred to acquire producing assets.

Recent Developments

On July 15, 2013, the Company closed on the acquisition of 18,569 net acres from a non-operated working interest partner on its operated acreage in the New Home II area in Williams County, North Dakota for approximately $76 million, including closing adjustments. The acquired interests are currently producing approximately 900 Boe/d (90% oil). This transaction had an effective date of March 1, 2013.

In addition, on July 19, 2013, Halcón closed on the sale of 24,189 net acres in Fayette and Gonzales Counties, Texas for proceeds of approximately $144 million, before pre-closing and post-closing adjustments. These assets produced an average of 1,811 Boe/d in the second quarter of 2013 from the Eagle Ford formation. Proved reserves and PV10 associated with these assets as of December 31, 2012, as estimated by the independent reserve engineering firm Netherland, Sewell & Associates, Inc., were 3.6 million barrels of oil equivalent (MMboe) and $95.1 million, respectively. As a result of this divestiture, the borrowing base on the Company's revolving credit facility was reduced by $40 million to $810 million. This transaction had an effective date of January 1, 2013.

As previously disclosed, a marketing process to divest approximately 4,500 Boe/d of conventional production is currently underway.

On a pro forma basis, after adjusting for the aforementioned acquisition and divestiture, Halcón is currently producing approximately 35,000 Boe/d, which represents a 25% increase compared to the Company's average net daily production for the second quarter.

On July 31, 2013, Halcón's Board of Directors declared a quarterly dividend on shares of its 5.75% Series A Cumulative Perpetual Convertible Preferred Stock equal to accrued dividends from the issue date of June 18, 2013 through September 1, 2013. The dividend will be paid on September 3, 2013 to holders of record on August 15, 2013. The dividend payments on all of the outstanding Series A Cumulative Perpetual Preferred Stock will total approximately $4.1 million, and will be paid in shares of common stock having a fair market value (as determined under the certificate of designation governing such preferred stock) equal to the aggregate dividend amount. The Company will pay cash in lieu of issuing any fractional shares.

Bakken/Three Forks

Halcón operated an average of seven rigs in the Williston Basin during the second quarter. The following table contains detailed second quarter 2013 operated well data related to Halcón's Williston Basin assets:


    Wells   2Q13 vs. 1Q13   2Q13 vs. 1Q13
  Wells Put Online Avg. IP Avg. IP Rate Avg. 30 Day Avg. 30 Day Rate
  Spud (POL) Rate (Boe/d) Variance Rate (Boe/d) Variance
Fort Berthold            
Bakken 12 6 2,557 +51% 1,464 +65%
Three Forks 2 2 2,308 +58% 968 +43%
Bakken 2 2 1,401 +23% 723 +52%

The Company also participated in 80 non-operated wells during the quarter with an average working interest of approximately 5%.

The ongoing implementation of drilling and completion modifications continues to yield positive results. The performance of wells that have been completed with modified completion techniques is currently above previously published type curve estimates.

Halcón's average initial production (IP) rate for the two most recently completed Bakken wells put online in the Fort Berthold area is greater than 3,000 Boe/d. A new Company record was recently set with a 3,317 Boe/d IP on a Bakken well in this area.

Halcón currently has approximately 150,000 net acres in the Williston Basin and expects to operate an average of six rigs in the basin for the remainder of 2013.

There are currently 114 Bakken wells producing, 14 Bakken wells being completed or waiting on completion and 5 Bakken wells being drilled on Halcón's operated acreage in the Williston Basin. Similarly, there are currently 35 Three Forks wells producing, 4 Three Forks wells being completed or waiting on completion and 2 Three Forks wells being drilled on Halcón's operated acreage.

El Halcón

The Company operated an average of four rigs, spud 16 wells and brought 4 wells online in El Halcón during the quarter.

The average IP rate for the wells put online in the second quarter was 822 Boe/d. Two of the four wells brought online during the quarter were partially drilled out of the target zone, resulting in lower IP rates and a lower second quarter average IP rate. The average IP rate for the two wells put online in the quarter that were drilled in the target zone was 1,016 Boe/d. Halcón has determined that there is a limited sweet spot where the laterals for the wells drilled in this play need to be landed and the Company has adjusted its drilling plans accordingly.

Halcón is making progress towards its goal of leasing 100,000 to 150,000 net acres in El Halcón. The Company has redirected capital from the Woodbine play to El Halcón where it expects to operate an average of three to four rigs for the rest of 2013. As previously disclosed, Halcón expects to have data from a 330 square mile 3-D seismic survey spanning across portions of Leon, Madison and Grimes Counties in-house by the end of 2013 to aid in the further development of the Woodbine play.

Year-to-date, the Company has become a more efficient operator in El Halcón by decreasing the drilling days per well, drilling longer laterals and increasing the length of the frac stages while maintaining the total amount of proppant. The average number of feet drilled per day for the last five wells is 36% higher than the first five wells Halcón drilled in the play this year. Recently, Halcón set a Company record by reaching the target depth on a well in 10.75 days by drilling an average of 1,656 feet per day including a 9,157 foot lateral.

There are currently 14 Eagle Ford wells producing, 9 wells being completed or waiting on completion and 4 wells being drilled.

Utica/Point Pleasant

The Company operated an average of two rigs in in Ohio and Pennsylvania during the three months ended June 30, 2013.

It is important to note that the Kibler 1H (100% WI), located in Trumbull County, Ohio, tested at a rate of 2,233 Boe/d (75% liquids), assuming full ethane recovery, which compares favorably to the other highly productive wells in the play. This discovery well for the Utica/Point Pleasant play in Trumbull County tested at 860 barrels of condensate per day and 4.5 million cubic feet of natural gas per day (1,350 BTU). Based on composition analysis and assuming 27% gas shrink, Halcón estimates the well would produce an additional 821 barrels of NGLs per day. The Kibler 1H was drilled to a total measured depth of 14,257 feet, had an effective lateral length of 6,734 feet and was completed with 26 frac stages. The Company has significant holdings in Trumbull and Mahoning Counties, Ohio and believes there is potential to drill hundreds of wells on its acreage in the area over time.

The process of delineating Halcón's Utica/Point Pleasant acreage position is essentially complete. The Company has finished drilling its first nine wells and is evaluating results. There is currently one Utica/Point Pleasant well producing, four wells that have been tested and are shut-in awaiting infrastructure, two wells being tested and two wells resting. Halcón expects to operate a minimum of one rig in the play throughout the remainder of 2013 and anticipates seven of the nine wells drilled to be flowing into sales pipelines by the end of the year.

The Company currently has approximately 142,000 net acres leased or under contract. As previously disclosed, Halcón is focused on building an inventory of approved/permitted multi-well pads in preparation for a full scale development program and will target lateral lengths between 7,000 and 9,000 feet where possible.

The Company's midstream subsidiary, Halcón Field Services (HFS), has entered into an exclusive arrangement with the Ohio Commerce Center (OCC), a 516 acre mixed used industrial site located in Lordstown, Ohio, to develop an oil storage and rail-loading facility. HFS and the OCC have obtained a variance from the Village of Lordstown to permit the planned facility. OCC has over 12,000 feet of recently installed loop track and direct access to Class 1 rail service, making it an ideal location for low cost rail services to support the rapid production growth expected in the northern tier of the Utica/Point Pleasant play. HFS plans to build the terminal at the OCC in phases, the first of which is expected to go into service by the end of 2013. At scale, HFS anticipates the facility would accommodate unit train loads at the rate of 140,000 barrels of oil or condensate per day.

In addition, HFS continues to engage in discussions for a potential joint venture to develop a high pressure, rich gas gathering system and scaled cryogenic gas processing for Halcón's oil and gas assets in Ohio and Pennsylvania. This joint venture would allow for enhanced third-party volumes and shared capital costs for HFS' infrastructure build out.


The following guidance incorporates the aforementioned divestment of certain properties in Fayette and Gonzales Counties, Texas and the acquisition of acreage and production from a non-operated working interest partner in the Williston Basin.


    Full Year
  Q3 '13E 2013E
Production (Boe/d)    
Low 34,000 30,000
High 36,000 34,000
% Oil   83%
% NGLs   5%
% Gas   12%
Operating Costs and Expenses ($/Boe)    
Lease Operating    
Low   $11.00
High   $13.00
Production Taxes    
Low   $7.00
High   $8.00
Cash G&A    
Low   $9.00
High   $11.00
Drilling & Completion Capex - Excluding A&D ($ in billions) (1) $1.375
(1) Excludes discretionary capital related to leasehold acquisitions, infrastructure and other.

Note: Guidance is forward-looking information that is subject to a number of risks and uncertainties, many of which are beyond the Company's control. Guidance has not been adjusted to include the potential impact of the planned divestiture of 4,500 Boe/d of conventional production.



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Ohio Environmental Protection Agency.

Ohio State University Extension.

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Ohio Oil and Gas Association, a Granville-based group that represents 1,500 Ohio energy-related companies.

Ohio Oil & Gas Energy Education Program.

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Marcellus and Utica Shale Resource Center by Ohio law firm Bricker & Eckler.

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Chesapeake Energy Corp,the Oklahoma-based firm is the No. 1 driller in Ohio.

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National Geographic's The Great Shale Rush.

The Ohio Environmental Council, a statewide eco-group based in Columbus.

Buckeye Forest Council.

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Stop Fracking Ohio.

People's Oil and Gas Collaborative-Ohio, a grass-roots group in Northeast Ohio.

Concerned Citizens of Medina County, a grass-roots group.

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Fracking: Gas Drilling's Environmental Threat by ProPublica, an online journalism site.

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Allegheny Front, environmental public radio for Western Pennsylvania.