In addition, the Company has reclassified the following amounts from “Distributions from other invested assets” included in cash flows from investing activities to “Distribution of limited partnership income” included in cash flows from operations for interim reporting periods of 2013: $33,686 thousand for the three months ended March 31, 2013; $9,409 thousand and $43,095 thousand for the three months and six months ended June 30, 2013, respectively; and $5,638 thousand and $48,733 thousand for the three months and nine months ended September 30, 2013, respectively.
B.
Investments.
Fixed maturity and equity security investments available for sale, at market value, reflect unrealized appreciation and depreciation, as a result of temporary changes in market value during the period, in shareholders’ equity, net of income taxes in “accumulated other comprehensive income (loss)” in the consolidated balance sheets.
Fixed maturity and equity securities carried at fair value reflect fair value remeasurements as net realized capital gains and losses in the consolidated statements of operations and comprehensive income (loss).
The Company records changes in fair value for its fixed maturities available for sale, at market value through shareholders’ equity, net of taxes in accumulated other comprehensive income (loss) since cash flows from these investments will be primarily used to settle its reserve for losses and loss adjustment expense liabilities.
The Company anticipates holding these investments for an extended period as the cash flow from interest and maturities will fund the projected payout of these liabilities.
Fixed maturities carried at fair value represent a portfolio of convertible bond securities, which have characteristics similar to equity securities and at times, designated foreign denominated fixed maturity securities, which will be used to settle loss and loss adjustment reserves in the same currency.
The Company carries all of its equity securities at fair value except for mutual fund investments whose underlying investments are comprised of fixed maturity securities.
For equity securities, available for sale, at fair value, the Company reflects changes in value as net realized capital gains and losses since these securities may be sold in the near term depending on financial market conditions.
Interest income on all fixed maturities and dividend income on all equity securities are included as part of net investment income in the consolidated statements of operations and comprehensive income (loss).
Unrealized losses on fixed maturities, which are deemed other-than-temporary and related to the credit quality of a security, are charged to net income (loss) as net realized capital losses.
Short-term investments are stated at cost, which approximates market value.
Realized gains or losses on sales of investments are determined on the basis of identified cost.
For nonpublicly traded securities, market prices are determined through the use of pricing models that evaluate securities relative to the U. S.  Treasury yield curve, taking into account the issue type, credit quality, and cash flow characteristics of each security.
For publicly traded securities, market value is based on quoted market prices or valuation models that use observable market inputs.
When a sector of the financial markets is inactive or illiquid, the Company may use its own assumptions about future cash flows and risk-adjusted discount rates to determine fair value.
Retrospective adjustments are employed to recalculate the values of asset-backed securities.
Each acquisition lot is reviewed to recalculate the effective yield.
The recalculated effective yield is used to derive a book value as if the new yield were applied at the time of acquisition.
Outstanding principal factors from the time of acquisition to the adjustment date are used to calculate the prepayment history for all applicable securities.
Conditional prepayment rates, computed with life to date factor histories and weighted average maturities, are used to effect the calculation of projected and prepayments for pass-through security types.
Other invested assets include limited partnerships, rabbi trusts and an affiliated entity.
Limited partnerships and the affiliated entity are accounted for under the equity method of accounting, which can be recorded on a monthly or quarterly lag.
C.  Uncollectible Receivable Balances.
The Company provides reserves for uncollectible reinsurance recoverable and premium receivable balances based on management’s assessment of the collectability of the outstanding balances.
Such reserves are presented in the table below for the periods indicated.
## Table 0 ##
have been authorized to be granted as share options or share awards to non-employee directors of the Company.
At December 31, 2013 there were 403,949 remaining shares available to be granted under the 2003 Director Plan.
Board actions in 2001, 2000 and 1999, which were not approved by shareholders, awarded options to nonemployee directors.
The Board actions were designed to award non-employee directors, whose services are considered essential to the Company’s continued success, with the option to purchase common shares to increase their ownership interest in the Company and to align such interests with those of the shareholders of the Company.
Under Board actions in 2001, 2000 and 1999; 40,000, 30,000 and 26,000 common shares, respectively, were granted as share options to non-employee directors of the Company.
Options and restricted shares granted under the 2010 Employee Plan, the 2002 Employee Plan and the 1995 Employee Plan vest at the earliest of 20% per year over five years or in accordance with any applicable employment agreement.
Options granted under the 1995 Director Plan vested at 50% per year over two years.
Options and restricted shares granted under the 2003 Director Plan generally vest at 33% per year over three years, unless an alternate vesting period is authorized by the Board.
Options and restricted shares granted under the 2009 Director Plan will vest as provided in the award agreement.
The 2001, 2000 and 1999 Board actions vest at 33% per year over three years.
All options are exercisable at fair market value of the stock at the date of grant and expire ten years after the date of grant.
For share options and restricted shares granted under the 2010 Employee Plan, the 2002 Employee Plan, the 1995 Employee Plan, the 2009 Director Plan, the 2003 Director Plan and the 1995 Director Plan, sharebased compensation expense recognized in the consolidated statements of operations and comprehensive income (loss) was $31,844 thousand, $31,984 thousand and $17,693 thousand for the years ended December 31, 2013, 2012 and 2011, respectively.
The corresponding income tax benefit recorded in the consolidated statements of operations and comprehensive income (loss) for share-based compensation was $5,458 thousand, $2,792 thousand and $4,164 thousand for the years ended December 31, 2013, 2012 and 2011, respectively.
For the year ended December 31, 2013, share-based compensation awards granted were 274,715 restricted shares, granted on February 20, 2013, May 15, 2013, September 12, 2013 and November 20, 2013, with a fair value of $122.755, $135.805, $138.695 and $157.080 per share, respectively.
No share options were granted during the year ended December 31, 2013.
For share options granted during previous years, the fair value per option was calculated on the date of the grant using the Black-Scholes option valuation model.
The following assumptions were used in calculating the fair value of the options granted:
## Table 1 ##
The Company recognizes, as an increase to additional paid-in capital, a realized income tax benefit from dividends, charged to retained earnings and paid to employees on equity classified non-vested equity shares.
In addition, the amount recognized in additional paid-in capital for the realized income tax benefit from dividends on those awards is included in the pool of excess tax benefits available to absorb tax deficiencies on share-based payment awards.
For the years ended December 31, 2013, 2012 and 2011, the Company recognized $237 thousand, $162 thousand and $136 thousand, respectively, of additional paid-in capital due to tax benefits from dividends on restricted shares.
The following discusses the underwriting results for each of our segments for the periods indicated.
U. S.  Reinsurance.
The following table presents the underwriting results and ratios for the U. S.  Reinsurance segment for the periods indicated.
## Table 2 ##
Premiums.
Gross written premiums increased by 38.1% to $1,809.7 million in 2013 from $1,310.7 million in 2012, primarily due to the impact of a large Florida quota share reinsurance contract, new business opportunities, particularly for contracts with catastrophe exposed risks and higher subject premium on casualty quota share business as rates began to rise in these markets.
Excluding the impact of the Florida quota share reinsurance contract, gross written premiums increased 17.8%.
Net written premiums increased by 38.3% to $1,807.1 million in 2013 compared to $1,306.5 million in 2012, which is in line with the increase in gross written premiums.
Premiums earned increased 18.0% to $1,671.5 million in 2013 compared to $1,416.4 million in 2012.
Premiums earned were only minimally impacted by the Florida quota share reinsurance contract that affected written premiums.
The change in premiums earned was relatively comparable to net written premiums, excluding the Florida quota share reinsurance contract.
Gross written premiums decreased by 2.7% to $1,310.7 million in 2012 from $1,346.8 million in 2011, primarily due to the non-renewal of a large Florida quota share reinsurance contract, partially offset by increased new business and higher premium rates on renewals, particularly for contracts with catastrophe exposed risks.
Net written premiums decreased by 2.8% to $1,306.5 million in 2012 compared to $1,344.3 million in 2011, which is in line with the decrease in gross written premiums.
Premiums earned increased by 7.9% to $1,416.4 million in 2012 compared to $1,312.7 million in 2011.
The variance difference between premiums earned and net written premiums is primarily attributable to the non-renewal of the large Florida quota share reinsurance contract, which had a larger negative impact on gross and net written premiums, increases in new business, rate increases on renewals, particularly for catastrophe exposed contracts and changes in the mix of business.
Supplementary Information on Oil and Gas Producing Activities (Unaudited) Changes in the Standardized Measure of Discounted Future Net Cash Flows
## Table 3 ##
## Table 4 ##
The significant increase in proved reserves from 2010 to 2011 was primarily due to the Eagle Ford shale acquisitions.
Also, synthetic crude oil reserves increased, primarily because of the inclusion of additional lease portions in the Jackpine mine and technical and economic reevaluations at year end.
The above estimated quantities of net proved liquid hydrocarbon and natural gas reserves are forward-looking statements and are based on a number of assumptions, including (among others) commodity prices, presently known physical data concerning size and character of the reservoirs, economic recoverability, technology developments, future drilling success, industry economic conditions, levels of cash flow from operations, production experience and other operating considerations.
The above estimated quantities of synthetic crude oil reserves are forward-looking statements and are based on presently known physical data, economic recoverability and operating conditions.
To the extent these assumptions prove inaccurate, actual recoveries and development costs could be different than current estimates.
For additional details of the estimated quantities of proved reserves at the end of each of the last three years, see Item 8.
Financial Statements and Supplementary Data – Supplementary Information on Oil and Gas Producing Activities.
Preparation of Reserve Estimates Our estimation of economically producible volumes of liquid hydrocarbons and natural gas is a highly technical process performed primarily by in-house teams of reservoir engineers and geoscience professionals.
All estimates of reserves are made in compliance with SEC Rule 4-10 of Regulation S-X.
Liquid hydrocarbon, natural gas and synthetic crude oil reserve estimates are reviewed and approved by our Corporate Reserves Group, which includes our Director of Corporate Reserves and her staff of Coordinators.
Reserve estimates are developed and reviewed by Qualified Reserve Estimators (“QRE”).
QREs are engineers or geoscientists with a minimum of a Bachelor of Science degree in the appropriate technical field, have a minimum of three years of industry experience with at least one year in reserve estimation and have completed Marathon Oil’s Qualified Reserve Estimator training course.
The Reserve Coordinators review all reserve estimates for all fields with proved reserves greater than 3 mmboe at a minimum of once every three years.
Any change to proved reserve estimates in excess of 2.5 mmboe on a total field basis, within a single month, must be approved by Corporate Reserves Group management.
All other proved reserve changes must be approved by a Reserve Coordinator.
Our Director of Corporate Reserves, who reports to our Chief Financial Officer, has a Bachelor of Science degree in petroleum engineering and a Master of Business Administration.
Her 37 years of experience in the industry include 26 with Marathon Oil.
She is active in industry and professional groups, having served on the Society of Petroleum Engineers (“SPE”) Oil and Gas Reserves Committee (“OGRC”), chairing in 2008 and 2009.
As a member of the OGRC, she participated in the development of the Petroleum Resource Management System.
She chaired the development of the OGRC comments on the SEC’s proposed modernization of oil and gas reporting and was a member of the American Petroleum Institute’s Ad Hoc group that provided comments on the same topic.
Estimates of synthetic crude oil reserves are prepared by GLJ Petroleum Consultants of Calgary, Canada, third-party consultants.
Their reports for all years are filed as exhibits to this Annual Report on Form 10-K.
The engineer responsible
MARATHON OIL CORPORATION Notes to Consolidated Financial Statements anticipated sale proceeds included cash received at closing, a minimum amount due at the earlier of first gas or December 31, 2012, and a range of contingent proceeds subject to the timing of first commercial gas.
The fair value of the total proceeds was measured using an income method that incorporated a probability-weighted approach with respect to timing of first commercial gas and an associated sliding scale on the amount of corresponding consideration specified in the sales agreement: the longer it takes to achieve first gas, the lower the amount of the consideration.
Because a portion of the proceeds is variable in timing and amount depending upon timing of first commercial gas, the inputs to the fair value calculation were classified as Level 3 inputs.
Impairments of several other long-lived assets held for use in our E&P segment that were evaluated in 2011, 2010 and 2009 were a result of reduced drilling expectations, reduction of estimated reserves or declining natural gas prices, and are also reported above.
The fair values of those assets were measured using an income approach based upon internal estimates of future production levels, commodity prices and discount rate, which are Level 3 inputs.
Natural gas prices began declining in September 2011 and have continued to decline in 2012.
Should natural gas prices remain depressed, an impairment charge related to our natural gas assets may be necessary.

Tables referenced above, in order (Table 0 first):
<table><tr><td></td><td>Years Ended December 31,</td></tr><tr><td>(Dollars in thousands)</td><td>2013</td><td>2012</td></tr><tr><td>Reinsurance receivables and premium receivables</td><td>$29,905</td><td>$32,011</td></tr></table>
<table><tr><td></td><td colspan="3">Years Ended December 31,</td></tr><tr><td></td><td>2013</td><td>2012</td><td>2011</td></tr><tr><td>Weighted-average volatility</td><td>-</td><td>26.16%</td><td>26.46%</td></tr><tr><td>Weighted-average dividend yield</td><td>-</td><td>2.00%</td><td>2.00%</td></tr><tr><td>Weighted-average expected term</td><td>-</td><td>6.69 years</td><td>6.73 years</td></tr><tr><td>Weighted-average risk-free rate</td><td>-</td><td>1.33%</td><td>2.80%</td></tr></table>
<table><tr><td></td><td colspan="3">Years Ended December 31,</td><td colspan="2">2013/2012</td><td colspan="2">2012/2011</td></tr><tr><td>(Dollars in millions)</td><td>2013</td><td>2012</td><td>2011</td><td>Variance</td><td>% Change</td><td>Variance</td><td>% Change</td></tr><tr><td>Gross written premiums</td><td>$1,809.7</td><td>$1,310.7</td><td>$1,346.8</td><td>$499.0</td><td>38.1%</td><td>$-36.1</td><td>-2.7%</td></tr><tr><td>Net written premiums</td><td>1,807.1</td><td>1,306.5</td><td>1,344.3</td><td>500.6</td><td>38.3%</td><td>-37.8</td><td>-2.8%</td></tr><tr><td>Premiums earned</td><td>$1,671.5</td><td>$1,416.4</td><td>$1,312.7</td><td>$255.1</td><td>18.0%</td><td>$103.7</td><td>7.9%</td></tr><tr><td>Incurred losses and LAE</td><td>814.7</td><td>1,050.4</td><td>1,034.1</td><td>-235.7</td><td>-22.4%</td><td>16.3</td><td>1.6%</td></tr><tr><td>Commission and brokerage</td><td>366.9</td><td>350.6</td><td>327.8</td><td>16.3</td><td>4.6%</td><td>22.8</td><td>7.0%</td></tr><tr><td>Other underwriting expenses</td><td>47.2</td><td>44.8</td><td>39.3</td><td>2.4</td><td>5.4%</td><td>5.5</td><td>14.0%</td></tr><tr><td>Underwriting gain (loss)</td><td>$442.8</td><td>$-29.4</td><td>$-88.5</td><td>$472.2</td><td>NM</td><td>$59.1</td><td>-66.8%</td></tr><tr><td></td><td></td><td></td><td></td><td></td><td>Point Chg</td><td></td><td>Point Chg</td></tr><tr><td>Loss ratio</td><td>48.7%</td><td>74.2%</td><td>78.8%</td><td></td><td>-25.5</td><td></td><td>-4.6</td></tr><tr><td>Commission and brokerage ratio</td><td>21.9%</td><td>24.8%</td><td>25.0%</td><td></td><td>-2.9</td><td></td><td>-0.2</td></tr><tr><td>Other underwriting expense ratio</td><td>2.9%</td><td>3.1%</td><td>2.9%</td><td></td><td>-0.2</td><td></td><td>0.2</td></tr><tr><td>Combined ratio</td><td>73.5%</td><td>102.1%</td><td>106.7%</td><td></td><td>-28.6</td><td></td><td>-4.6</td></tr><tr><td>(NM, not meaningful)</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td colspan="2">(Some amounts may not reconcile due to rounding.)</td><td></td><td></td><td></td><td></td><td></td><td></td></tr></table>
<table><tr><td><i>(In millions)</i></td><td>2011</td><td>2010</td><td>2009</td></tr><tr><td>Sales and transfers of oil and gas produced, net of production and administrative costs</td><td>$-7,922</td><td>$-6,330</td><td>$-4,876</td></tr><tr><td>Net changes in prices and production and administrative costs related to future production</td><td>12,313</td><td>9,843</td><td>4,840</td></tr><tr><td>Extensions, discoveries and improved recovery, less related costs</td><td>1,454</td><td>1,268</td><td>1,399</td></tr><tr><td>Development costs incurred during the period</td><td>1,899</td><td>2,546</td><td>2,786</td></tr><tr><td>Changes in estimated future development costs</td><td>-1,349</td><td>-2,153</td><td>-3,773</td></tr><tr><td>Revisions of previous quantity estimates</td><td>2,526</td><td>1,117</td><td>5,110</td></tr><tr><td>Net changes in purchases and sales of minerals in place</td><td>233</td><td>-20</td><td>-159</td></tr><tr><td>Accretion of discount</td><td>2,040</td><td>1,335</td><td>787</td></tr><tr><td>Net change in income taxes</td><td>-6,676</td><td>-4,231</td><td>-4,345</td></tr><tr><td>Timing and other</td><td>130</td><td>250</td><td>-149</td></tr><tr><td>Net change for the year</td><td>4,648</td><td>3,625</td><td>1,620</td></tr><tr><td>Beginning of the year</td><td>9,280</td><td>5,655</td><td>4,035</td></tr><tr><td>End of year</td><td>$13,928</td><td>$9,280</td><td>$5,655</td></tr></table>
<table><tr><td></td><td colspan="3">North America</td><td colspan="3">Africa</td><td rowspan="2">Europe Total</td><td></td></tr><tr><td> December 31, 2009</td><td>United States</td><td>Canada</td><td>Total</td><td>EG</td><td>Other</td><td>Total</td><td>Grand Total</td></tr><tr><td> Proved Developed Reserves</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Liquid hydrocarbons<i>(mmbbl)</i></td><td>120</td><td>-</td><td>120</td><td>83</td><td>186</td><td>269</td><td>87</td><td>476</td></tr><tr><td>Natural gas<i>(bcf)</i></td><td>652</td><td>-</td><td>652</td><td>1,102</td><td>107</td><td>1,209</td><td>50</td><td>1,911</td></tr><tr><td>Synthetic crude oil<i>(mmbbl)</i></td><td>-</td><td>392</td><td>392</td><td>-</td><td>-</td><td>-</td><td>-</td><td>392</td></tr><tr><td>Total proved developed reserves<i>(mmboe)</i></td><td>229</td><td>392</td><td>621</td><td>267</td><td>204</td><td>471</td><td>95</td><td>1,187</td></tr><tr><td> Proved Undeveloped Reserves</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Liquid hydrocarbons<i>(mmbbl)</i></td><td>50</td><td>-</td><td>50</td><td>39</td><td>42</td><td>81</td><td>15</td><td>146</td></tr><tr><td>Natural gas<i>(bcf)</i></td><td>168</td><td>-</td><td>168</td><td>586</td><td>-</td><td>586</td><td>59</td><td>813</td></tr><tr><td>Synthetic crude oil<i>(mmbbl)</i></td><td>-</td><td>211</td><td>211</td><td>-</td><td>-</td><td>-</td><td>-</td><td>211</td></tr><tr><td>Total proved undeveloped reserves<i>(mmboe)</i></td><td>78</td><td>211</td><td>289</td><td>136</td><td>42</td><td>178</td><td>25</td><td>492</td></tr><tr><td> Total Proved Reserves</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Liquid hydrocarbons<i>(mmbbl)</i></td><td>170</td><td>-</td><td>170</td><td>122</td><td>228</td><td>350</td><td>102</td><td>622</td></tr><tr><td>Natural gas<i>(bcf)</i></td><td>820</td><td>-</td><td>820</td><td>1,688</td><td>107</td><td>1,795</td><td>109</td><td>2,724</td></tr><tr><td>Synthetic crude oil<i>(mmbbl)</i></td><td>-</td><td>603</td><td>603</td><td>-</td><td>-</td><td>-</td><td>-</td><td>603</td></tr><tr><td>Total proved reserves<i>(mmboe)</i></td><td>307</td><td>603</td><td>910</td><td>403</td><td>246</td><td>649</td><td>120</td><td>1,679</td></tr></table>

Question: What was the total amount of the Total proved undeveloped reserves(mmboe) in the sections where Total proved developed reserves(mmboe) greater than 250?
Answer: 347
Reasoning program: add(211,136)