NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued) During 2008, incurred claims and claims expense related to prior years was primarily composed of net decreases in auto reserves of $27 million offset by increases in homeowners reserves of $124 million due to catastrophe loss reestimates, and increases in other reserves of $55 million.
The $27 million favorable decreases in auto reserves and $55 million unfavorable increases in other reserves includes $45 million of IBNR losses reclassified from auto reserves to other reserves to be consistent with the recording of excess liability policy premiums and losses.
Incurred claims and claims expense includes unfavorable catastrophe loss reestimates of $125 million, net of reinsurance and other recoveries, primarily attributable to increased claim loss and expense reserves for litigation filed in conjunction with a Louisiana deadline for filing suits related to Hurricane Katrina.
During 2007, incurred claims and claims expense related to prior years was primarily composed of net decreases in auto reserves of $311 million due to claim severity development that was better than expected, offset by increases in homeowners reserves of $115 million due to catastrophe loss reestimates, and increases in environmental reserves of $63 million.
Incurred claims and claims expense includes unfavorable catastrophe loss reestimates of $127 million, net of reinsurance and other recoveries, primarily attributable to increased claim loss and expense reserves for 2005 catastrophe events.
During 2006, incurred claims and claims expense related to prior years was primarily composed of net decreases in auto reserves of $737 million due to claim severity development that was better than expected, and late reported loss development that was better than expected due to lower frequency trends in recent years, decreases in homeowners reserves of $244 million due to catastrophe loss reestimates, claim severity development and late reported loss development that were better than expected, and decreases in other reserves of $122 million due to catastrophe loss reestimates and commercial lines loss development that was better than expected, offset by increases in asbestos reserves of $86 million.
Claims and claims expense during 2006 includes favorable catastrophe loss reestimates of $223 million, net of reinsurance and other recoveries, including a $63 million reduction in the Company’s accrual for an assessment from FL Citizens and $62 million due to recoupments of prior year assessments from FL Citizens and Louisiana Citizens Property Insurance Corporation (‘‘LA Citizens’’).
Management believes that the reserve for property-liability claims and claims expense, net of recoverables, is appropriately established in the aggregate and adequate to cover the ultimate net cost of reported and unreported claims arising from losses which had occurred by that date based on available facts, technology, laws and regulations.
For further discussion of assessments from FL Citizens and LA Citizens, and asbestos and environmental reserves, see Note 13.8.
Reserve for Life-Contingent Contract Benefits and Contractholder Funds At December 31, the reserve for life-contingent contract benefits consists of the following:
## Table 0 ##
DEVON ENERGY CORPORATION AND SUBSIDIARIES NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued) Proved Undeveloped Reserves The following table presents the changes in Devon’s total proved undeveloped reserves during 2012 (in MMBoe).
## Table 1 ##
At December 31, 2012, Devon had 840 MMBoe of proved undeveloped reserves.
This represents a 7 percent increase as compared to 2011 and represents 28 percent of its total proved reserves.
Drilling and development activities increased Devon’s proved undeveloped reserves 203 MMBoe and resulted in the conversion of 90 MMBoe, or 12 percent, of the 2011 proved undeveloped reserves to proved developed reserves.
Costs incurred related to the development and conversion of Devon’s proved undeveloped reserves were $1.3 billion for 2012.
Additionally, revisions other than price decreased Devon’s proved undeveloped reserves 16 MMBoe primarily due to its evaluation of certain U. S.  onshore dry-gas areas, which it does not expect to develop in the next five years.
The largest revisions relate to the dry-gas areas at Carthage in east Texas and the Barnett Shale in north Texas.
A significant amount of Devon’s proved undeveloped reserves at the end of 2012 largely related to its Jackfish operations.
At December 31, 2012 and 2011, Devon’s Jackfish proved undeveloped reserves were 429 MMBoe and 367 MMBoe, respectively.
Development schedules for the Jackfish reserves are primarily controlled by the need to keep the processing plants at their 35,000 barrel daily facility capacity.
Processing plant capacity is controlled by factors such as total steam processing capacity, steam-oil ratios and air quality discharge permits.
As a result, these reserves are classified as proved undeveloped for more than five years.
Currently, the development schedule for these reserves extends though the year 2031.
Price Revisions 2012 - Reserves decreased 171 MMBoe primarily due to lower gas prices.
Of this decrease, 100 MMBoe related to the Barnett Shale and 25 MMBoe related to the Rocky Mountain area.2011 - Reserves decreased 21 MMBoe due to lower gas prices and higher oil prices.
The higher oil prices increased Devon’s Canadian royalty burden, which reduced Devon’s oil reserves.2010 - Reserves increased 72 MMBoe due to higher gas prices, partially offset by the effect of higher oil prices.
The higher oil prices increased Devon’s Canadian royalty burden, which reduced Devon’s oil reserves.
Of the 72 MMBoe price revisions, 43 MMBoe related to the Barnett Shale and 22 MMBoe related to the Rocky Mountain area.
Revisions Other Than Price Total revisions other than price for 2012 and 2011 primarily related to Devon’s evaluation of certain dry gas regions noted in the proved undeveloped reserves discussion above.
Total revisions other than price for 2010 primarily related to Devon’s drilling and development in the Barnett Shale.
In addition to cash settlements, we also recognize unrealized changes in the fair values of our oil, gas and NGL derivative instruments in each reporting period.
The changes in fair value resulted from new positions and settlements that occurred during each period, as well as the relationships between contract prices and the associated forward curves.
Including the cash settlements discussed above, our oil, gas and NGL derivatives generated net gains of $693 million, $881 million and $811 million during 2012, 2011 and 2010, respectively.
Marketing and Midstream Revenues and Operating Costs and Expenses
## Table 2 ##
2012 vs.  2011 Marketing and midstream operating profit decreased $132 million primarily due to lower natural gas and NGL prices.2011 vs.  2010 Marketing and midstream operating profit increased $32 million primarily due to higher natural gas throughput and higher NGL prices.
Lease Operating Expenses (“LOE”)

<table><tr><td> ($ in millions) </td><td> 2008</td><td> 2007</td></tr><tr><td>Immediate fixed annuities:</td><td></td><td></td></tr><tr><td>Structured settlement annuities</td><td>$6,628</td><td>$7,094</td></tr><tr><td>Other immediate fixed annuities</td><td>2,106</td><td>2,259</td></tr><tr><td>Traditional life insurance</td><td>2,723</td><td>2,593</td></tr><tr><td>Other</td><td>1,424</td><td>1,266</td></tr><tr><td>Total reserve for life-contingent contract benefits</td><td>$12,881</td><td>$13,212</td></tr></table>
<table><tr><td></td><td>U.S.</td><td>Canada</td><td>Total</td></tr><tr><td>Proved undeveloped reserves as of December 31, 2011</td><td>403</td><td>379</td><td>782</td></tr><tr><td>Extensions and discoveries</td><td>134</td><td>68</td><td>202</td></tr><tr><td>Revisions due to prices</td><td>-47</td><td>9</td><td>-38</td></tr><tr><td>Revisions other than price</td><td>-10</td><td>-6</td><td>-16</td></tr><tr><td>Conversion to proved developed reserves</td><td>-73</td><td>-17</td><td>-90</td></tr><tr><td>Proved undeveloped reserves as of December 31, 2012</td><td>407</td><td>433</td><td>840</td></tr></table>
<table><tr><td></td><td colspan="5"> Year Ended December 31,</td></tr><tr><td></td><td> 2012</td><td> Change</td><td> 2011</td><td> Change</td><td> 2010</td></tr><tr><td></td><td colspan="5"> ($ in millions)</td></tr><tr><td>Revenues</td><td>$1,656</td><td>-27%</td><td>$2,258</td><td>+21%</td><td>$1,867</td></tr><tr><td>Operating costs and expenses</td><td>1,246</td><td>-27%</td><td>1,716</td><td>+26%</td><td>1,357</td></tr><tr><td>Operating profit</td><td>$410</td><td>-24%</td><td>$542</td><td>+6%</td><td>$510</td></tr></table>

Question: What's the increasing rate of Operating profit in 2011 Ended December 31?
Answer: 0.06