Chesapeake Granite Wash Trust (CHKR)
Q4 2012 Earnings Conference Call
February 11, 2013 10:00 AM ET
Nick Dell'Osso – Executive Vice President and CFO
Steve Dixon – Executive Vice President and COO
Sarah Newell – Vice President, Bank of New York Mellon Trust Company
Justin Albert – Raymond James
Minyoung Sohn – Arrowpoint Partners
» Chesapeake Granite Wash Trust CEO Discusses Q2 Results - Earnings Call Transcript
» NovaGold Resources' CEO Discusses Q4 2012 Results - Earnings Call Transcript
Good morning and welcome to the Chesapeake Granite Wash Trust Distribution Conference Call. This is Nick Dell'Osso, Executive Vice President and Chief Financial Officer at Chesapeake Energy. Also, joining me for the call this morning is, Steve Dixon, Executive Vice President and Chief Operating Officer of Chesapeake, and via teleconference is Sarah Newell, Vice President of Bank of New York Mellon Trust Company, the trustee for Chesapeake Granite Wash Trust.
I have a few prepared remarks, and then we will take any questions you may have. Please note that today's call will contain certain forward-looking statements and assumptions that are subject to inherent risks and uncertainties. The actual results may differ materially from those projected in the forward-looking statements. Additional information about risk factors and other factors that could potentially affect the Trust and its financial results are included in the Trust's press release issued last Friday, and in the Trust filings with the SEC.
As a reminder, CHKR is a statutory Trust, which is required to distribute all cash flow after expenses. The trust has no employees or officers and Chesapeake Energy as the sponsor of the trust is responsible for operating the properties, in which the trust has an interest in fulfilling certain drilling commitments, which is also detailed in the trust's filings with the SEC.
As stated in the press release on Friday, the distribution for the three-month period ended November 30, 2012 from CHKR will be $0.67 per common unit and approximately $0.38 per subordinated unit. Worth noting, Chesapeake Energy owns 100% of the subordinated units. The distribution will be paid on March 1, 2013, to unit holders of record at the close of business on February 19, 2013.
The calculated distribution for this period is approximately $0.60 per unit, however since this is below the predetermined subordination threshold for the quarter of $0.67 per unit, the distribution per subordinated unit will be reduced in order to make a distribution of $0.67 per common unit.
Now I’ll turn it over to Steve Dixon.
Thanks, Nick. For the three month period of September 1 to November 30 of 2012, total sales volumes attributed to the trust royalty interest were 151,000 barrels of oil, that’s up from a 146,000 or 3% quarter-over-quarter increase, 329,000 barrels of natural gas liquids, that’s up from 288,000 or that’s a 14% quarter-over-quarter increase and 3.06 billion cubic feet of natural gas, and that’s down from 3.204 billion cubic feet, a 4% quarter-over-quarter decrease. This were total sales of approximately 990,000 barrels equivalent or BOE and that’s up from 968,000 barrels equivalent or about 2% quarter-over-quarter.
The production mix in the fourth quarter was 15% oil, 33% NGLs and 52% natural gas. Realized prices for the period were $86.26 per barrel of oil, $31.92 per barrel of natural gas liquids and $1.94 per Mcf for natural gas. These prices include the effects of transportation and third-party deductions.
When comparing quarter-over-quarter changes in realized price for 2012 fourth quarter, unhedged realized oil prices were higher by $2.04 per barrel, natural gas liquid prices were higher by $4.43 per barrel and natural gas prices were higher by $0.22 per Mcf.
Turning to hedges, the actual NYMEX oil prices were above swap contract prices held by the trust. This results in a realized loss on oil contracts of approximately $609,000 for the period. These fixed oil swap contracts were initially established to hedge approximately 50% of projected oil and natural gas liquids volumes.
The use of crude oil derivates to partially mitigate the price risk of NGL production is subject to basis risk to the extent oil and NGL prices are not highly correlated. The initial forecasted revenue of the trust assumed in NGL price of 49% of WTI, actual results were lower at 37%. The trust has no natural gal hedges in place.
Turning to drilling results in the Trust AMI, during the quarter Chesapeake brought online 9 gross operated wells. These 9 gross wells equated to approximately 9 development wells towards Chesapeake's overall commitment of 118 development wells under the development agreement with the trust. Due January, Chesapeake has now drilled 58 equivalent wells and is ahead of schedule in meeting this 118 development well commitment to the trust. Chesapeake is currently operating 4 rigs in the Trust AMI and this level of drilling is consistent with the original drilling plans outlined in the trust SEC filings.
We will now take any questions you may have. Operator, please open up the line for Q&A.
Thank you. (Operator Instructions) We will take our first question from Justin Albert with Raymond James.
Justin Albert – Raymond James
Hey guys, how are you?