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Supplemental Oil and Gas Disclosures (Unaudited) (Tables) | 12 Months Ended
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Dec. 31, 2016
Summary of Estimated Quantities of Proved Developed Oil and Natural Gas Reserves | Estimated quantities of proved oil and gas reserves are summarized as follows:
| Reserves
| Oil (a) (Barrels) |  | Gas (Mcf)
| (In thousands)
Consolidated entities: |  |  |
Year-end 2013 | 5,824 |  |  | 13,630 |
Revisions of previous estimates | 608 |  |  | 293 |
Extensions and discoveries | 2,191 |  |  | 774 |
Acquisitions | 85 |  |  | 31 |
Sales | (105 | ) |  | (218 | )
Production | (931 | ) |  | (1,861 | )
Year-end 2014 | 7,672 |  |  | 12,649 |
Revisions of previous estimates | (855 | ) |  | (1,675 | )
Extensions and discoveries | 224 |  |  | 173 |
Acquisitions | — |  |  | — |
Sales | (704 | ) |  | (1,223 | )
Production | (1,158 | ) |  | (1,967 | )
Year-end 2015 | 5,179 |  |  | 7,957 |
Revisions of previous estimates | (11 | ) |  | 631 |
Extensions and discoveries | 29 |  |  | — |
Acquisitions | — |  |  | — |
Sales | (4,460 | ) |  | (3,756 | )
Production | (291 | ) |  | (996 | )
Year-end 2016 | 446 |  |  | 3,836 |
Our share of ventures accounted for using the equity method: |  |  |
Year-end 2013 | — |  |  | 2,332 |
Revisions of previous estimates | — |  |  | (382 | )
Production | — |  |  | (199 | )
Year-end 2014 | — |  |  | 1,751 |
Revisions of previous estimates | — |  |  | (320 | )
Production | — |  |  | (168 | )
Year-end 2015 | — |  |  | 1,263 |
Revisions of previous estimates | — |  |  | 79 |
Production | — |  |  | (143 | )
Year-end 2016 | — |  |  | 1,199 |
Total consolidated and our share of equity method ventures: |  |  |
Year-end 2014 |  |  |
Proved developed reserves | 5,269 |  |  | 12,599 |
Proved undeveloped reserves | 2,403 |  |  | 1,801 |
Total Year-end 2014 | 7,672 |  |  | 14,400 |
Year-end 2015 |  |  |
Proved developed reserves | 5,179 |  |  | 9,220 |
Proved undeveloped reserves | — |  |  | — |
Total Year-end 2015 | 5,179 |  |  | 9,220 |
Year-end 2016 |  |  |
Proved developed reserves | 446 |  |  | 5,035 |
Proved undeveloped reserves | — |  |  | — |
Total Year-end 2016 | 446 |  |  | 5,035 |
_____________________
(a) | Includes natural gas liquids (NGLs).
Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development Activities | Costs incurred in oil and gas property acquisition, exploration and development activities, whether capitalized or expensed, follows:
| For the Year
| 2016 |  | 2015 |  | 2014
| (In thousands)
Consolidated entities: |  |  |  |  |
Acquisition costs |  |  |  |  |
Proved properties | $ | — |  |  | $ | — |  |  | $ | 2,001 |
Unproved properties | 15 |  |  | 4,832 |  |  | 25,666 |
Exploration costs | 21 |  |  | 17,922 |  |  | 39,399 |
Development costs | 537 |  |  | 27,609 |  |  | 40,277 |
| $ | 573 |  |  | $ | 50,363 |  |  | $ | 107,343 |
Estimates of Future Cash Flows from Proved Developed Oil and Natural Gas Reserves | Estimates of future cash flows from proved oil and gas reserves are shown in the following table. Estimated income taxes are calculated by applying the appropriate tax rates to the estimated future pre-tax net cash flows less depreciation of the tax basis of properties and the statutory depletion allowance.
| At Year-End
| 2016 |  | 2015 |  | 2014
| (In thousands)
Consolidated entities: |  |  |  |  |
Future cash inflows | $ | 24,304 |  |  | $ | 216,588 |  |  | $ | 665,657 |
Future production and development costs | (2,988 | ) |  | (93,623 | ) |  | (271,735 | )
Future income tax expenses | (3,926 | ) |  | (22,218 | ) |  | (106,002 | )
Future net cash flows | 17,390 |  |  | 100,747 |  |  | 287,920 |
10% annual discount for estimated timing of cash flows | (7,077 | ) |  | (33,951 | ) |  | (124,079 | )
Standardized measure of discounted future net cash flows | $ | 10,313 |  |  | $ | 66,796 |  |  | $ | 163,841 |
Our share in ventures accounted for using the equity method: |  |  |  |  |
Future cash inflows | $ | 2,010 |  |  | $ | 2,283 |  |  | $ | 6,186 |
Future production and development costs | (216 | ) |  | (245 | ) |  | (664 | )
Future income tax expenses | (537 | ) |  | (774 | ) |  | (2,098 | )
Future net cash flows | 1,257 |  |  | 1,264 |  |  | 3,424 |
10% annual discount for estimated timing of cash flows | (585 | ) |  | (562 | ) |  | (1,649 | )
Standardized measure of discounted future net cash flows | $ | 672 |  |  | $ | 702 |  |  | $ | 1,775 |
Total consolidated and our share of equity method ventures | $ | 10,985 |  |  | $ | 67,498 |  |  | $ | 165,616 |
Changes in Standardized Measure of Discounted Future Net Cash Flow | Changes in the standardized measure of discounted future net cash flow follows:
| For the Year
| Consolidated |  | Our Share of Equity Method Ventures |  | Total
| (In thousands)
Year-end 2013 | $ | 135,553 |  |  | $ | 1,300 |  |  | $ | 136,853 |
Changes resulting from: |  |  |  |  |
Net change in sales prices and production costs | (1,064 | ) |  | 1,571 |  |  | 507 |
Net change in future development costs | 1,308 |  |  | — |  |  | 1,308 |
Sales of oil and gas, net of production costs | (63,192 | ) |  | (787 | ) |  | (63,979 | )
Net change due to extensions and discoveries | 58,228 |  |  | — |  |  | 58,228 |
Net change due to acquisition of reserves | 2,778 |  |  | — |  |  | 2,778 |
Net change due to divestitures of reserves | (5,804 | ) |  | — |  |  | (5,804 | )
Net change due to revisions of quantity estimates | 15,303 |  |  | (343 | ) |  | 14,960 |
Previously estimated development costs incurred | 15,497 |  |  | — |  |  | 15,497 |
Accretion of discount | 18,067 |  |  | 210 |  |  | 18,277 |
Net change in timing and other | 4,198 |  |  | 115 |  |  | 4,313 |
Net change in income taxes | (17,031 | ) |  | (291 | ) |  | (17,322 | )
Aggregate change for the year | 28,288 |  |  | 475 |  |  | 28,763 |
Year-end 2014 | 163,841 |  |  | 1,775 |  |  | 165,616 |
Changes resulting from: |  |  |  |  |
Net change in sales prices and production costs | (136,536 | ) |  | (1,112 | ) |  | (137,648 | )
Net change in future development costs | 92 |  |  | — |  |  | 92 |
Sales of oil and gas, net of production costs | (31,732 | ) |  | (428 | ) |  | (32,160 | )
Net change due to extensions and discoveries | 11,747 |  |  | — |  |  | 11,747 |
Net change due to acquisition of reserves | — |  |  | — |  |  | — |
Net change due to divestitures of reserves | (15,855 | ) |  | — |  |  | (15,855 | )
Net change due to revisions of quantity estimates | (15,164 | ) |  | (267 | ) |  | (15,431 | )
Previously estimated development costs incurred | 15,096 |  |  | — |  |  | 15,096 |
Accretion of discount | 22,600 |  |  | 286 |  |  | 22,886 |
Net change in timing and other | 4,018 |  |  | (210 | ) |  | 3,808 |
Net change in income taxes | 48,689 |  |  | 658 |  |  | 49,347 |
Aggregate change for the year | (97,045 | ) |  | (1,073 | ) |  | (98,118 | )
Year-end 2015 | 66,796 |  |  | 702 |  |  | 67,498 |
Changes resulting from: |  |  |  |  |
Net change in sales prices and production costs | (3,585 | ) |  | (60 | ) |  | (3,645 | )
Net change in future development costs | — |  |  | — |  |  | — |
Sales of oil and gas, net of production costs | (5,663 | ) |  | (208 | ) |  | (5,871 | )
Net change due to extensions and discoveries | 410 |  |  | — |  |  | 410 |
Net change due to acquisition of reserves | — |  |  | — |  |  | — |
Net change due to divestitures of reserves | (63,535 | ) |  |  |  | (63,535 | )
Net change due to revisions of quantity estimates | 1,304 |  |  | 63 |  |  | 1,367 |
Previously estimated development costs incurred | — |  |  | — |  |  | — |
Accretion of discount | 2,992 |  |  | 113 |  |  | 3,105 |
Net change in timing and other | (128 | ) |  | (80 | ) |  | (208 | )
Net change in income taxes | 11,722 |  |  | 142 |  |  | 11,864 |
Aggregate change for the year | (56,483 | ) |  | (30 | ) |  | (56,513 | )
Year-end 2016 | $ | 10,313 |  |  | $ | 672 |  |  | $ | 10,985 |
Information About Results of Operations of Oil and Natural Gas Interests | Information about the results of operations of our oil and gas interests follows:
| For the Year
| 2016 |  | 2015 |  | 2014
| (In thousands)
Consolidated entities |  |  |  |  |
Revenues | $ | 10,111 |  |  | $ | 51,553 |  |  | $ | 82,919 |
Production costs | (4,392 | ) |  | (19,820 | ) |  | (19,727 | )
Exploration costs | (124 | ) |  | (11,864 | ) |  | (17,416 | )
Depreciation, depletion, amortization | (2,157 | ) |  | (28,774 | ) |  | (29,442 | )
Non-cash impairment of proved oil and gas properties and unproved leasehold interests | (612 | ) |  | (164,831 | ) |  | (32,665 | )
Oil and gas administrative expenses | (8,700 | ) |  | (11,700 | ) |  | (17,000 | )
Accretion expense | (56 | ) |  | (144 | ) |  | (121 | )
Income tax (expense) benefit | (20 | ) |  | 14,717 |  |  | 13,398 |
Results of operations | (5,950 | ) |  | (170,863 | ) |  | (20,054 | )
Our share in ventures accounted for using the equity method: |  |  |  |  |
Revenues | $ | 284 |  |  | $ | 428 |  |  | $ | 786 |
Production costs | (76 | ) |  | (102 | ) |  | (105 | )
Oil and gas administrative expenses | (35 | ) |  | (51 | ) |  | (95 | )
Income tax (expense) benefit | — |  |  | 21 |  |  | (235 | )
Results of operations | $ | 173 |  |  | $ | 296 |  |  | $ | 351 |
Total results of operations | $ | (5,777 | ) |  | $ | (170,567 | ) |  | $ | (19,703 | )
Consolidated Entities |
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure | Capitalized costs related to our oil and gas producing activities classified as assets held for sale at year-end 2016 are as follows:
| At Year-End
| 2016 |  | 2015
| (In thousands)
Consolidated entities: |  |  |
Unproved oil and gas properties | $ | 374 |  |  | $ | 19,441 |
Proved oil and gas properties | 5,159 |  |  | 119,414 |
Total costs | 5,533 |  |  | 138,855 |
Less accumulated depreciation, depletion and amortization | (4,751 | ) |  | (58,242 | )
| $ | 782 |  |  | $ | 80,613 |

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