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Supplemental Information on Oil and Gas Exploration and Productions Activities (Unaudited) | 12 Months Ended
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Dec. 31, 2015
Extractive Industries [Abstract] |
Supplemental Information on Oil and Gas Exploration and Productions Activities (Unaudited) | The Partnership prepared the following oil and gas information in accordance with the authoritative guidance for oil and gas extractive activities. Capitalized Costs (in thousands):
| For the Years Ended December 31,
| 2015 |  | 2014
Proven properties | $ | 199,404 |  |  | $ | 392,153 |
Unproven properties | — |  |  | 46,400 |
Total property, plant, and equipment | 199,404 |  |  | 438,553 |
Accumulated depreciation, depletion, and amortization | (60,542 | ) |  | (18,993 | )
Net capitalized costs | $ | 138,862 |  |  | $ | 419,560 |
Costs incurred for property acquisitions, exploration, and development (in thousands):
| For the Years Ended December 31,
| 2015 |  | 2014
Property acquisitions |  |  |
Proven properties | $ | — |  |  | $ | 298,627 |
Unproven properties | — |  |  | 40,800 |
Development | 29,080 |  |  | 5,340 |
Total | $ | 29,080 |  |  | $ | 344,767 |
Results of Operations for Producing Activities (in thousands):
| For the Years Ended December 31,
| 2015 |  | 2014
Production revenue | $ | 49,201 |  |  | $ | 48,834 |
Royalty and overriding royalty revenue (1) | 4,364 |  |  | 10,732 |
Total oil and gas related revenue | 53,565 |  |  | 59,566 |
Operating costs and expense: |  |  |
Depreciation, depletion and amortization | 40,772 |  |  | 23,936 |
Property, franchise and other taxes | 5,210 |  |  | 5,529 |
Production costs | 12,871 |  |  | 12,544 |
Impairment of oil and gas properties | 367,576 |  |  | — |
Total operating costs and expense | 426,429 |  |  | 42,009 |
Total income from operations | $ | (372,864 | ) |  | $ | 17,557 |
(1) | Includes $0.4 million and $1.9 million for the years ended December 31, 2015 and 2014, respectively of nonproduction revenues including lease bonus payments
Estimated Proved Reserves Proved reserves are those quantities of crude oil and natural gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations prior to the time at which contracts providing the right to operate expire, unless evidence indicates renewal is reasonably certain. In connection with the estimation of proved reserves, the term "reasonable certainty" implies a high degree of confidence that the quantities of crude oil, natural gas liquids and/or natural gas actually recovered will equal or exceed the estimate. The Partnership estimated proved reserves as of December 31, 2015 and 2014 were prepared by Netherland, Sewell & Associates, Inc., the Partnership’s independent reserve engineer. To achieve reasonable certainty, Netherland Sewell employed technologies that have been demonstrated to yield results with consistency and repeatability. The technologies and economic data used in the estimation of the Partnership’s proved reserves include, but are not limited to, well logs, geologic maps including isopach and structure maps, analogy and statistical analysis, and available downhole and production data and well test data. Netherland Sewell prepared its report covering properties representing 100% of the Partnership’s estimated proved reserves as of December 31 2015 and 2014. Prices were calculated using the unweighted average of the first-day-of-the-month pricing for the twelve months ended December 31, 2015 and 2014. These prices were then adjusted for transportation and other costs. There can be no assurance that the proved reserves will be produced as estimated or that the prices and costs will remain constant. There are numerous uncertainties inherent in estimating reserves and related information and different reserve engineers often arrive at different estimates for the same properties. A copy of Netherland Sewell’s summary report is included as Exhibit 99.2 to this Annual Report on Form 10-K. The following tables shows our estimated domestic proved reserves and reserve additions and revisions:
|  | Crude Oil (MBbl) |  | NGLs (MBbl) |  | Natural Gas (MMcf)(2) |  | Total Proved Reserves (MBoe)(3)
December 31, 2014 |  | 9,983 |  |  | 1,229 |  |  | 14,370 |  |  | 13,607 |
Revisions of previous estimates |  | (1,451 | ) |  | 89 |  |  | 701 |  |  | (1,244 | )
Extensions, discoveries and other additions |  | 776 |  |  | 60 |  |  | 541 |  |  | 926 |
Sales of properties |  | (98 | ) |  | — |  |  | (62 | ) |  | (108 | )
Production |  | (1,136 | ) |  | (156 | ) |  | (2,226 | ) |  | (1,663 | )
December 31, 2015 (1) |  | 8,074 |  |  | 1,222 |  |  | 13,324 |  |  | 11,518 |
Proved developed reserves as of December 31, 2015 |  | 7,862 |  |  | 1,196 |  |  | 13,157 |  |  | 11,251 |
Proved undeveloped reserves as of December 31, 2015 |  | 212 |  |  | 26 |  |  | 167 |  |  | 267 |
Proved developed reserves as of December 31, 2014 |  | 8,930 |  |  | 1,098 |  |  | 13,161 |  |  | 12,221 |
Proved undeveloped reserves as of December 31, 2014 |  | 1,053 |  |  | 131 |  |  | 1,209 |  |  | 1,386 |
(1) | Includes reserves attributable to the Partnership's 51% member interest in BRP LLC.
(2) | Natural gas is converted on the basis of six Mcf of gas per one Bbl of oil equivalent. This ratio reflects an energy content equivalency and not a price or revenue equivalency.
(3) | Includes 10,063 MBoe of estimated proved reserves attributable to the Partnership’s non-operated working interests in oil and natural gas properties in the Williston Basin, approximately 3% of which were proved undeveloped reserves.
The standardized measure of discounted future net cash flows from our estimated proved oil and gas reserves is as follows (in thousands):
| For the Years Ended December 31,
| 2015 |  | 2014
Future cash inflows | $ | 364,352 |  |  | $ | 920,454 |
Less related future: |  |  |  |
Production costs | (164,649 | ) |  | (312,666 | )
Development and abandonment costs | (7,826 | ) |  | (20,072 | )
Future net cash flows before 10% discount | 191,877 |  |  | 587,716 |
Discount to present value at a 10% annual rate | (75,524 | ) |  | (282,519 | )
Total standardized measure of discounted net cash flows | $ | 116,353 |  |  | $ | 305,197 |
The table below is a summary of the changes in the standardized measure of discounted future net cash flows for our proved oil and gas reserves during the year ended December 31, 2015 (in thousands):
Beginning of the period | $ | 305,197 |
Revisions to previous estimates: |
Changes in prices and costs | (188,946 | )
Changes in quantities | (11,750 | )
Changes in future development costs | (12,202 | )
Previously estimated development costs incurred during the period | 29,080 |
Additions to proved reserves from extensions, discoveries and improved recovery, less related costs | 11,928 |
Purchases and sales of reserves in place, net | (3,851 | )
Accretion of discount | 31,795 |
Sales of oil and gas, net of production costs | (35,112 | )
Production timing and other | (9,786 | )
Net increase (decrease) | (188,844 | )
End of period | $ | 116,353 |

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