- Liquidity of $321.1 million, including cash and short-term investments
- Sold Glasscock County, Texas assets for $19.4 million
- Announced sale of Giddings Area assets for $400 million
Financial Results for the Third Quarter of 2016
The Company reported a net loss for the third quarter of 2016 (“3Q16”) of $148.8 million, or $10.62 per share, as compared to a net loss of $9.4 million, or $0.77 per share, for the third quarter of 2015 (“3Q15”). Adjusted net loss1 (non-GAAP) for 3Q16 was $35.1 million, or $2.50 per share, as compared to adjusted net loss1 (non-GAAP) of $14.9 million, or $1.23 per share, for 3Q15. Cash flow from operations for 3Q16 was $24.1 million as compared to $26.4 million for 3Q15. EBITDAX2 (non-GAAP) for 3Q16 was $18.4 million as compared to $28.7 million for 3Q15.
For the nine months ended September 30, 2016, net loss attributable to Company stockholders was $265 million, or $20.72 per share, as compared to net loss of $51 million, or $4.19 per share, for the same period in 2015. Adjusted net loss1 (non-GAAP) for the nine-month period in 2016 was $96.1 million, or $7.52 per share, as compared to adjusted net loss1 (non-GAAP) of $48.5 million, or $3.99 per share, for the same period in 2015. Cash flow from operations for the nine-month period in 2016 was $8 million as compared to $55 million during the same period in 2015. EBITDAX2 (non-GAAP) for the nine-month period in 2016 was $41.3 million as compared to $91.4 million for the same period in 2015.
The key factors affecting the comparability of financial results for 3Q16 versus 3Q15 were:
- Oil and gas sales for 3Q16, excluding amortized deferred revenues, decreased $7.5 million compared to 3Q15. Production variances accounted for a $5.7 million decrease and price variances accounted for a $1.8 million decrease. Average realized oil prices were $40.62 per barrel in 3Q16 versus $43.26 per barrel in 3Q15, average realized gas prices were $2.94 per Mcf in 3Q16 versus $2.71 per Mcf in 3Q15, and average realized natural gas liquids (“NGL”) prices were $13.14 per barrel in 3Q16 versus $11.01 per barrel in 3Q15. Amortized deferred revenue in 3Q16 totaled $0.4 million as compared to $0.8 million in 3Q15.
- Oil, gas and NGL production per barrel of oil equivalent (“BOE”) decreased 10% in 3Q16 as compared to 3Q15, with oil production decreasing 11% to 9,935 barrels per day, gas production decreasing 19% to 13,989 Mcf per day, and NGL production increasing 9% to 1,685 barrels per day. Oil and NGL production accounted for approximately 83% of the Company’s total BOE production in 3Q16 versus 82% in 3Q15. After giving effect to the sale of interests in certain wells in Glasscock County, Texas in July 2016 and the sale of selected leases and wells in South Louisiana in September 2015, oil, gas and NGL production per BOE decreased 7% in 3Q16 as compared to 3Q15. See accompanying tables for additional information about the Company’s oil and gas production.
- Production costs in 3Q16 were $17.8 million versus $20.7 million in 3Q15 due to lower oilfield service costs. Production costs on a BOE basis, excluding production taxes, decreased 3% to $12.25 per BOE in 3Q16 versus $12.68 per BOE in 3Q15.
- Interest expense for 3Q16 was $26.6 million versus $13.6 million for 3Q15. The increase was due primarily to $13.9 million of incremental interest expense on funded indebtedness incurred under a second lien term loan credit facility issued in connection with a refinancing in March 2016 (the “Refinancing”). For 3Q16, the Company elected to pay interest on the term loan facility in-kind and resulted in an increase in the principal amount of the term loan to $377.2 million.
- The Company accounts for the warrants issued in connection with the Refinancing as derivative instruments and carries the warrants as a non-current liability at their fair value. The Company recorded a $123.4 million loss on change in fair value in 3Q16 due primarily to the impact on the valuation model of a 211% increase in the market price of the Company’s common stock from $27.46 at June 30, 2016 to $85.44 at September 30, 2016.
- Gain on commodity derivatives for 3Q16 was $1.3 million (net of a $2.4 million loss on settled contracts) versus a gain on commodity derivatives in 3Q15 of $18.1 million (including a $6.4 million gain on settled contracts). See accompanying tables for additional information about the Company’s accounting for derivatives.
- Lower commodity prices negatively impacted our results of operations due to asset impairments. We recorded an impairment of proved properties of $1.1 million in 3Q16 related primarily to non-core prospects in California and the Cotton Valley area of Texas versus $3.1 million in 3Q15 related to non-core prospects in the Permian Basin and California.
- General and administrative expenses for 3Q16 were $5.6 million versus $4.6 million for 3Q15. Changes in compensation expense related to the Company’s APO reward plans accounted for $0.9 million of the increase ($1.1 million credit in 3Q16 versus $2 million credit in 3Q15), and additional expense related to issuances of restricted stock and stock options under the Company’s recent long-term incentive plan accounted for a $0.8 million increase. These increases were partially offset by reductions in salary and personnel expense.
- The Company redeemed $100 million of 7.75% Senior Notes due 2019 in a tender offer in August 2016 and recorded a gain on early extinguishment of long-term debt during 3Q16 of $4 million.
Balance Sheet and Liquidity
As of September 30, 2016, total long-term debt was $846.5 million, consisting of $351.5 million (net of $25.7 million of original issue discount and debt issuance costs) under the second lien term loan credit facility and $495 million, net of costs, of 7.75% Senior Notes due 2019 (the “Notes”). The borrowing base established by the banks under the revolving credit facility and the aggregate lender commitment was $100 million at September 30, 2016. The Company had $98.1 million of availability under the revolving credit facility after allowing for outstanding letters of credit of $1.9 million. Liquidity, consisting of cash, short-term investments and funds available on the revolving credit facility, totaled $321.1 million.
In July 2016, the Company entered into an agreement to sell 5,051,100 shares of common stock to funds managed by Ares Management, L.P. for cash proceeds of $150 million or approximately $29.70 per share, which transaction closed on August 29, 2016. In connection with the transaction, lenders under the Company’s term loan credit facility waived certain restrictions to enable the Company to use proceeds from equity issuances and specified asset sales for debt reduction and capital expenditures.
In July 2016, the Company commenced a modified “Dutch Auction” cash tender offer to purchase up to $100 million aggregate principal amount of Notes, which offer expired on August 29, 2016. The Company accepted for purchase $100 million in aggregate principal amount of Notes at a purchase price of $947.50 per $1,000 principal amount, which included an early tender premium of $30.00 for each $1,000 principal amount of Notes so purchased.
During 3Q16, the Company drilled and completed two wells in Reeves County, Texas. For the remainder of the year, the Company plans to drill four more wells in Reeves County, Texas targeting the Wolfcamp A and Wolfcamp C benches. For 2016, the Company expects to have eight wells drilled by year end, with five on production and three in various stages of completion.
The Collier 34-51 #1H, the Company’s first slick water completion, that had an initial seven day flow-back of just over 2,100 BOE per day continues to perform above our expectations. The peak 30-day production from this well averaged 2,089 BOE per day (82% Oil, 9% NGL). This well has been on production since mid-July and is currently producing at a daily rate of 1,312 BOE.
We plan to announce our 2017 capital program and annual public guidance during the first quarter of 2017.
On October 24, 2016, the Company announced that it had entered into a definitive purchase and sale agreement with a third party to sell substantially all of the Company’s assets in the Giddings Area in East Central Texas for a sale price of $400 million. The sale is subject to customary closing conditions and adjustments. The Company expects to close the sale in December 2016 and use the proceeds from the sale to fund development in the Delaware Basin and repay a portion of its outstanding indebtedness.
Scheduled Conference Call
The Company will host a conference call to discuss these results and other forward-looking items Thursday, November 3rd at 9:30 a.m. CT (10:30 a.m. ET).
A live webcast for investors and analysts will be available on the Company’s website at
Participants should call (877) 868-1835 and indicate 4131903 as the conference passcode. A replay will be available from 12:30...