OKLAHOMA CITY, Nov. 9, 2015 /PRNewswire/ -- New Source Energy Partners L.P., a Delaware limited partnership (OTC: NSLP) (the "Partnership" or "New Source"), today announced financial and operating results for the quarter ended September 30, 2015.
Third Quarter and Year to Date 2015 Results Summary
Management Commentary
"The third quarter of 2015 continued to be challenging for the industry and the Partnership," said Kristian Kos, Chairman and CEO. "During the second quarter of 2015, markets indicated that commodity pricing had moved off of the lows seen in the first quarter and that the rig count had stabilized. However, the upward trend was reversed in the third quarter, and we again experienced both commodity pricing pressure and a declining rig count, which have both, adversely affected the Partnership's third quarter results."
"We are in ongoing discussions with our reserve based lending group in regards to the borrowing base deficiency resulting from the October redetermination. We believe these discussions have been constructive and we expect that we will enter into a forbearance agreement in the very near future."
Exploration and Production Operational Results
The following table reflects production, pricing and cost for the Exploration and Production ("E&P") division for the periods presented below.
| Three Months Ended |
Nine Months Ended |
||||||||||||||||||
| September 30, 2015 |
June 30, 2015 |
September 30, 2014 |
September 30, |
||||||||||||||||
| 2015 |
2014 |
||||||||||||||||||
| Production volumes: |
|||||||||||||||||||
| Oil (Bbls) |
9,815 |
36,083 |
39,990 |
83,459 |
124,296 |
||||||||||||||
| Natural gas (Mcf) |
525,171 |
531,216 |
960,434 |
1,793,145 |
2,876,478 |
||||||||||||||
| NGLs (Bbls) |
168,286 |
172,722 |
227,439 |
530,697 |
674,717 |
||||||||||||||
| Total production volumes (Boe) |
265,630 |
297,341 |
427,501 |
913,014 |
1,278,426 |
||||||||||||||
| Average daily volumes (Boe) |
2,887 |
3,267 |
4,647 |
3,344 |
4,683 |
||||||||||||||
| Average price: |
|||||||||||||||||||
| Oil (per Bbl) |
$ |
57.67 |
$ |
45.67 |
$ |
94.97 |
$ |
46.80 |
$ |
97.72 |
|||||||||
| Natural gas (per Mcf) |
2.24 |
2.64 |
3.86 |
2.47 |
4.49 |
||||||||||||||
| NGL (per Bbl) |
12.38 |
13.13 |
35.40 |
13.91 |
38.62 |
||||||||||||||
| Total, excluding derivatives (per Boe) |
14.40 |
17.89 |
36.40 |
17.21 |
39.99 |
||||||||||||||
| Cash received (paid) on derivative settlements (per Boe) (1) |
9.19 |
7.15 |
(0.79) |
7.57 |
(2.93) |
||||||||||||||
| Total, including derivatives (per Boe) |
$ |
23.59 |
$ |
25.04 |
$ |
35.61 |
$ |
24.78 |
$ |
37.06 |
|||||||||
| Average production costs (per Boe) |
$ |
14.97 |
$ |
12.81 |
$ |
11.45 |
$ |
12.97 |
$ |
10.88 |
|||||||||
| Average production tax (per Boe) |
$ |
0.74 |
$ |
0.95 |
$ |
1.56 |
$ |
0.87 |
$ |
1.83 |
|||||||||
| (1) |
Excludes cash received on settlement of derivative contracts prior to their contractual maturity. |
Derivative Position
In the second quarter of 2015, the Partnership monetized certain open derivative contracts for the periods October 2015 through December 2015 and calendar year 2016. On October 2, 2015, all remaining open derivatives for the periods October 2015 through calendar year 2016 were monetized.
Credit Facility
As a result of the semi-annual redetermination on October 9, 2015, the borrowing base was reduced to $24.0 million from $49.0 million due to continued declines in oil, natural gas and NGL prices and the resulting impact on our reserves. The reduced borrowing base results in a borrowing base deficiency of $25.0 million. Our credit facility requires any deficiency to be settled in full within 30 days or in equal installments over a 90-day period. During a deficiency, an additional 2% is applied to the interest rate on the outstanding balance under the credit facility, not to exceed the maximum rate as defined in the credit agreement. Our lenders also have the option to cause the liquidation of collateral in order to satisfy the deficiency.
The Partnership does not currently have sufficient cash resources to repay, or additional collateral to cure, the borrowing base deficiency. If the Partnership is unable to successfully negotiate a forbearance agreement, obtain a waiver of compliance or cure the borrowing base deficiency, an event of default under the credit facility would occur on November 9, 2015. In an event of default, the administrative agent may, and at the request of majority of lenders, declare the outstanding balance under the credit facility immediately due and payable. The Partnership is in discussions with the lenders under the credit facility and expects to enter into a forbearance arrangement by November 9, 2015.
Going Concern
The Partnership's financial statements have been prepared assuming that it will continue as a going concern, which contemplates the realization of assets and the liquidation of liabilities in the normal course of business. As a result of the substantial drop in oil, natural gas, and NGL prices, and related significant drop in rig count, our revenue, profitability and cash flow have been significantly affected. The Partnership has violated debt covenants on certain of its oilfield service related debt, which results in this debt being classified as current and could require us to have to pay amounts outstanding sooner than anticipated based on the original maturity. In addition to debt violations regarding certain oilfield services related debt, as noted above, the Partnership's borrowing base was reduced from $49.0 million to $24.0 million at the October 2015 redetermination. While we are evaluating strategic alternatives, there can be no assurance that the Partnership will be successful in these efforts or that it will have sufficient funds to cover its operational and financial obligations over the next twelve months, which raises substantial doubt as to its ability to continue as a going concern.
Oilfield Services Results
Adjusted EBITDA for the Oilfield Services ("OFS") division was approximately $1.1 million in the third quarter of 2015 compared to approximately $0.9 million in the second quarter of 2015. Revenue was approximately $16.3 million for the third quarter of 2015 with an average weekly rig count of 533 compared to approximately $18.8 million in the second quarter of 2015 with an average weekly rig count of 557.
"The sequential decline in revenue is a direct reflection of the current downturn we are experiencing in the industry," said Dikran Tourian, President and Chief Operating Officer. "In the second and third quarters, we implemented extensive cost cutting measures, including a significant number of layoffs. However, the approximately 60% decline in rig count since October 2014 and resulting lower demand for oilfield services coupled with increasing pricing pressure for our services have negated much of the positive effects of these measures."
Use of Non-GAAP Financial Measures
New Source presents Adjusted EBITDA, which is a non-GAAP financial measure, in this press release. New Source defines Adjusted EBITDA as earnings before interest expense, taxes, depreciation, depletion and amortization, accretion expense, impairment, non-cash compensation expense, transaction fees, (gain) loss on derivative contracts net of cash received (paid) on settlement of derivative contracts and other non-recurring gains and losses.
New Source believes that the presentation of this non-GAAP financial measure provides useful information to investors in assessing our results of operations. The tables included in this press release provide reconciliations of this non-GAAP financial measure to its most directly comparable financial measures calculated and presented in accordance with GAAP. Non-GAAP financial measures should not be considered as an alternative to GAAP measures such as net income or any other measure of liquidity or financial performance calculated and presented in accordance with GAAP. Investors should not consider Adjusted EBITDA in isolation or as a substitute for analysis of the Partnership's results as reported under GAAP. Because Adjusted EBITDA may be defined differently by other companies in our industry, New Source's definitions may not be comparable to similarly titled measures of other companies, thereby diminishing their utility.
Maintenance capital expenditures represent the amount of capital expenditures necessary to maintain the revenue generating capabilities of the Partnership's assets at current levels over the long term. We consider maintenance capital expenditures to be capital expenditures required to replace revenue generating assets (including production and producing reserves from our oil and natural gas operations and vehicles and other equipment from our oilfield services operations) on an individualized basis.
The following tables present a reconciliation of Adjusted EBITDA to net loss, the most directly comparable financial measure calculated and presented in accordance with GAAP.
| Reconciliation of Adjusted EBITDA to Net Loss: |
|||||||||||||||
| Three Months Ended |
Nine Months Ended |
||||||||||||||
| September 30, |
September 30, |
||||||||||||||
| 2015 |
2014 |
2015 |
2014 |
||||||||||||
| (in thousands) |
|||||||||||||||
| Net loss |
$ |
(61,528) |
$ |
(2,996) |
$ |
(228,556) |
$ |
(2,943) |
|||||||
| Interest expense |
832 |
1,458 |
3,929 |
3,442 |
|||||||||||
| Depreciation, depletion and amortization |
5,329 |
17,760 |
23,675 |
37,329 |
|||||||||||
| Accretion expense |
70 |
77 |
203 |
219 |
|||||||||||
| Impairment |
49,141 |
— |
191,949 |
— |
|||||||||||
| Non-cash compensation expense |
929 |
1,262 |
5,251 |
1,906 |
|||||||||||
| Transaction fees |
— |
392 |
1,052 |
3,624 |
|||||||||||
| Gain on investment in acquired business |
— |
— |
— |
(2,298) |
|||||||||||
| (Gain) loss on derivative contracts, net |
(1,794) |
(3,768) |
(1,951) |
760 |
|||||||||||
| Cash received (paid) on settlement of derivative contracts (1) |
2,442 |
(338) |
10,781 |
(3,750) |
|||||||||||
| Settlement reserve |
1,500 |
— |
1,500 |
— |
|||||||||||
| Bad debt expense |
1,397 |
— |
1,475 |
— |
|||||||||||
| Write-off of deferred offering costs |
1,005 |
— |
1,005 |
— |
|||||||||||
| Other |
1,697 |
41 |
2,771 |
41 |
|||||||||||
| Change in fair value of contingent consideration |
— |
5,404 |
— |
4,493 |
|||||||||||
| Adjusted EBITDA |
$ |
1,020 |
$ |
19,292 |
$ |
13,084 |
$ |
42,823 |
|||||||
| Cash paid for interest |
$ |
927 |
$ |
1,140 |
$ |
3,032 |
$ |
2,999 |
|||||||
| Maintenance capital expenditures (2) |
$ |
63 |
$ |
5,104 |
$ |
1,254 |
$ |
12,752 |
|||||||
| (1) |
The three-month period ended September 30, 2015 includes $1.1 million related to early settlement of our derivative contracts. The nine-month period ended September 30, 2015 includes $5.0 million related to early settlement of our derivative contracts. |
| (2) |
Amounts reflect capital expenditures during the period presented. Future maintenance capital expenditures will vary depending on various factors, including, but not limited to, maintenance schedules and the timing of capital projects. Estimated maintenance capital expenditures for the three months ended September 30, 2015 relates to the OFS division. Of the estimated maintenance capital expenditures for the nine months ended September 30, 2015, approximately $0.8 million relates to the E&P division and approximately $0.5 million relates to the OFS division. |
| Reconciliation of Adjusted EBITDA by Segment to Net Loss by Segment: |
|||||||||||||||
| Three Months Ended |
Nine Months Ended |
||||||||||||||
| September 30, 2015 |
September 30, 2015 |
||||||||||||||
| E&P |
OFS |
E&P |
OFS |
||||||||||||
| (in thousands) |
|||||||||||||||
| Net loss |
$ |
(55,386) |
$ |
(6,142) |
$ |
(145,163) |
$ |
(83,393) |
|||||||
| Interest expense |
317 |
515 |
2,418 |
1,511 |
|||||||||||
| Depreciation, depletion and amortization |
2,916 |
2,413 |
11,196 |
12,479 |
|||||||||||
| Accretion expense |
70 |
— |
203 |
— |
|||||||||||
| Impairment |
49,141 |
— |
125,165 |
66,784 |
|||||||||||
| Non-cash compensation expense |
11 |
918 |
726 |
4,525 |
|||||||||||
| Transaction fees |
— |
— |
1,052 |
— |
|||||||||||
| Gain on derivative contracts, net |
(1,794) |
— |
(1,951) |
— |
|||||||||||
| Cash received on settlement of derivative contracts |
2,442 |
— |
10,781 |
— |
|||||||||||
| Settlement reserve |
— |
1,500 |
— |
1,500 |
|||||||||||
| Bad debt expense |
1,203 |
194 |
1,203 |
272 |
|||||||||||
| Write-off of deferred offering costs |
— |
1,005 |
— |
1,005 |
|||||||||||
| Other |
1,031 |
666 |
1,663 |
1,108 |
|||||||||||
| Adjusted EBITDA |
$ |
(49) |
$ |
1,069 |
$ |
7,293 |
$ |
5,791 |
|||||||
Conference Call
A conference call for investors will be held Monday, November 9, 2015, at 10:00 a.m. Central Time (11:00 a.m. Eastern Time) to discuss the Partnership's third quarter 2015 results. Hosting the call will be Kristian B. Kos, Chairman and Chief Executive Officer and Dikran Tourian, President and Chief Operating Officer.
The call can be accessed live over the telephone by dialing (877) 407-4018, or for international callers, (201) 689-8471. A replay will be available shortly after the call and can be accessed by dialing (877) 870-5176 or for international callers, (858) 384-5517. The pass code for the replay is 13624342. The replay will be available until November 23, 2015.
Interested parties may also listen to a simultaneous webcast of the conference call by logging onto the Partnership's website at www.newsource.com in the Investors-Presentations link. A replay of the webcast will also be available for approximately 30 days following the call.
About New Source Energy Partners L.P.
New Source Energy Partners L.P. is an independent energy partnership engaged in the production of its onshore oil and natural gas properties that extends across conventional resource reservoirs in east-central Oklahoma and in oilfield services that specialize in increasing efficiencies and safety in drilling and completion processes. For more information on the Partnership, please visit www.newsource.com.
Forward-Looking Statements
This news release contains "forward-looking statements" within the meaning of federal securities laws. These statements express a belief, expectation or intention and are generally accompanied by words that convey projected future events or outcomes. We have based these forward-looking statements on our current expectation and assumptions and analyses made by us in light of our experience and our perception of historical trends, current conditions and expected future developments, as well as other factors we believe are appropriate under the circumstances. However, whether actual results and developments will conform with our expectations and predictions is subject to a number of risks and uncertainties, many of which are beyond our control. For a full discussion of these risks and uncertainties, please refer to the "Risk Factors" section of the Partnership's Annual Report on Form 10-K for the year ended December 31, 2014 and the information included in the Partnership's quarterly and current reports and other public filings. These forward-looking statements are based on and include the Partnership's expectations as of the date hereof. We undertake no obligation to update or revise any forward-looking statements except as may be required by applicable law.
| New Source Energy Partners L.P. Condensed Consolidated Statements of Operations (Unaudited) |
|||||||||||||||
| Three Months Ended September 30, |
Nine Months Ended September 30, |
||||||||||||||
| 2015 |
2014 |
2015 |
2014 |
||||||||||||
| (in thousands, except per unit amounts) |
|||||||||||||||
| Revenues: |
|||||||||||||||
| Oil sales |
$ |
566 |
$ |
3,798 |
$ |
3,906 |
$ |
12,146 |
|||||||
| Natural gas sales |
1,175 |
3,711 |
4,422 |
12,928 |
|||||||||||
| NGL sales |
2,083 |
8,052 |
7,382 |
26,056 |
|||||||||||
| Oilfield services |
16,281 |
40,863 |
66,596 |
59,539 |
|||||||||||
| Total revenues |
20,105 |
56,424 |
82,306 |
110,669 |
|||||||||||
| Operating costs and expenses: |
|||||||||||||||
| Oil, natural gas and NGL production |
3,976 |
4,894 |
11,841 |
13,913 |
|||||||||||
| Production taxes |
197 |
668 |
790 |
2,339 |
|||||||||||
| Cost of providing oilfield services |
13,777 |
24,315 |
51,473 |
34,849 |
|||||||||||
| Depreciation, depletion and amortization |
5,329 |
17,760 |
23,675 |
37,329 |
|||||||||||
| Accretion |
70 |
77 |
203 |
219 |
|||||||||||
| Impairment |
49,141 |
— |
191,949 |
— |
|||||||||||
| General and administrative |
8,569 |
13,785 |
27,474 |
22,835 |
|||||||||||
| Total operating costs and expenses |
81,059 |
61,499 |
307,405 |
111,484 |
|||||||||||
| Operating loss |
(60,954) |
(5,075) |
(225,099) |
(815) |
|||||||||||
| Other income (expense): |
|||||||||||||||
| Interest expense |
(832) |
(1,458) |
(3,929) |
(3,442) |
|||||||||||
| Gain (loss) on derivative contracts, net |
1,794 |
3,768 |
1,951 |
(760) |
|||||||||||
| Gain on investment in acquired business |
— |
— |
— |
2,298 |
|||||||||||
| Other (expense) income |
(1,536) |
11 |
(1,479) |
18 |
|||||||||||
| Net loss |
(61,528) |
(2,754) |
(228,556) |
(2,701) |
|||||||||||
| Less: net income attributable to noncontrolling interest |
— |
242 |
— |
242 |
|||||||||||
| Net loss attributable to New Source Energy Partners L.P. |
(61,528) |
(2,996) |
(228,556) |
(2,943) |
|||||||||||
| distributions on Series A Preferred Units |
1,327 |
— |
2,315 |
— |
|||||||||||
| accretion of discount on Series A Preferred Units |
281 |
— |
457 |
— |
|||||||||||
| Net loss attributable to New Source Energy Partners L.P. common, subordinated and general partner units |
$ |
(63,136) |
$ |
(2,996) |
$ |
(231,328) |
$ |
(2,943) |
|||||||
| Net loss per unit: |
|||||||||||||||
| Net loss per general partner unit |
$ |
— |
$ |
(0.17) |
$ |
(3.03) |
$ |
(0.19) |
|||||||
| Net loss per subordinated unit |
$ |
(3.38) |
$ |
(0.17) |
$ |
(12.74) |
$ |
(0.19) |
|||||||
| Net loss per common unit |
$ |
(3.38) |
$ |
(0.17) |
$ |
(12.34) |
$ |
(0.20) |
|||||||
| New Source Energy Partners L.P. Condensed Consolidated Balance Sheets (Unaudited) |
|||||||
| September 30, 2015 |
December 31, 2014 |
||||||
| (in thousands, except unit amounts) |
|||||||
| ASSETS |
|||||||
| Current assets: |
|||||||
| Cash |
$ |
1,418 |
$ |
5,504 |
|||
| Restricted cash |
457 |
350 |
|||||
| Accounts receivable, net |
11,477 |
31,919 |
|||||
| Accounts receivable-related parties, net |
5,480 |
4,946 |
|||||
| Derivative contracts |
1,075 |
8,248 |
|||||
| Inventory |
3,557 |
4,236 |
|||||
| Prepaid expenses |
3,965 |
2,011 |
|||||
| Other current assets |
730 |
478 |
|||||
| Total current assets |
28,159 |
57,692 |
|||||
| Oil and natural gas properties, at cost using full cost method of accounting: |
|||||||
| Proved oil and natural gas properties |
333,186 |
332,413 |
|||||
| Less: Accumulated depreciation, depletion, amortization and impairment |
(289,948) |
(153,734) |
|||||
| Total oil and natural gas properties, net |
43,238 |
178,679 |
|||||
| Property and equipment, net |
66,985 |
68,886 |
|||||
| Intangible assets, net |
— |
56,377 |
|||||
| Goodwill |
— |
9,315 |
|||||
| Derivative contracts |
161 |
1,818 |
|||||
| Other assets |
1,116 |
2,779 |
|||||
| Total assets |
$ |
139,659 |
$ |
375,546 |
|||
| LIABILITIES, REDEEMABLE PREFERRED UNITS AND UNITHOLDERS' (DEFICIT) EQUITY |
|||||||
| Current liabilities: |
|||||||
| Accounts payable and accrued liabilities |
$ |
15,556 |
$ |
15,326 |
|||
| Accounts payable-related parties |
2,651 |
2,318 |
|||||
| Factoring payable |
3,653 |
13,152 |
|||||
| Contingent consideration payable |
12,913 |
11,572 |
|||||
| Current portion of long-term debt |
74,340 |
11,825 |
|||||
| Other current liabilities |
2,319 |
113 |
|||||
| Total current liabilities |
111,432 |
54,306 |
|||||
| Long-term debt |
413 |
95,218 |
|||||
| Contingent consideration payable |
— |
10,801 |
|||||
| Asset retirement obligations |
3,765 |
3,568 |
|||||
| Other liabilities |
— |
339 |
|||||
| Total liabilities |
115,610 |
164,232 |
|||||
| Commitments and contingencies |
|||||||
| Series A Preferred Units (1,930,000 units issued and outstanding at September 30, 2015) |
44,982 |
— |
|||||
| Unitholders' (deficit) equity: |
|||||||
| Common units (16,522,775 units issued and outstanding at September 30, 2015 and 16,160,381 units issued and outstanding at December 31, 2014) |
20,188 |
231,510 |
|||||
| Common units held in escrow |
(2,131) |
(6,955) |
|||||
| Subordinated units (2,205,000 units issued and outstanding at September 30, 2015 and December 31, 2014) |
(56,410) |
(28,717) |
|||||
| General partner's units (none issued and outstanding at September 30, 2015 and 155,102 units issued and outstanding at December 31, 2014) |
— |
(1,944) |
|||||
| Total New Source Energy Partners L.P. unitholders' (deficit) equity |
(38,353) |
193,894 |
|||||
| Noncontrolling interest |
17,420 |
17,420 |
|||||
| Total unitholders' (deficit) equity |
(20,933) |
211,314 |
|||||
| Total liabilities, redeemable preferred units and unitholders' (deficit) equity |
$ |
139,659 |
$ |
375,546 |
|||
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SOURCE New Source Energy Partners L.P.
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