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Press release from Marketwire
Freehold Royalties Ltd. Announces 2012 Fourth Quarter Results and Year-end Reserves
Thursday, March 07, 2013
Freehold Royalties Ltd. Announces 2012 Fourth Quarter Results and Year-end Reserves17:01 EST Thursday, March 07, 2013CALGARY, ALBERTA--(Marketwire - March 7, 2013) - Freehold Royalties Ltd. (Freehold) (TSX:FRU) today announced 2012 fourth quarter results and reserves as at December 31, 2012.Results at a GlanceThree Months EndedTwelve Months EndedFINANCIAL HIGHLIGHTSDecember 31December 31($000s, except as noted)20122011Change20122011ChangeGross revenue45,79445,3041%168,134157,9106%Net income13,43116,033-16%46,32855,259-16%Per share, basic and diluted ($)0.200.26-23%0.710.92-23%Cash flow from operating activities38,18332,59517%138,132118,37017%Per share ($)0.580.547%2.131.978%Capital expenditures7,74310,910-29%36,74625,64943%Property and royalty acquisitions (net)243(195)-60,8527,467-Dividends paid in cash (1)21,06015,26238%81,43667,20421%Dividends paid in shares (DRIP) (1)6,67210,232-35%27,41433,490-18%Average DRIP participation rate (%) (2)2440-40%2533-24%Dividends declared (3)27,78725,5859%109,568100,9689%Per share ($) (4)0.420.420%1.681.680%Long-term debt, period end18,00048,000-63%18,00048,000-63%Shares outstanding, period end (000s)66,27061,1418%66,27061,1418%Average shares outstanding (000s) (5)66,09160,8119%64,88060,0228%OPERATING HIGHLIGHTSAverage daily production (boe/d) (6) (7)9,5107,77322%8,8507,47618%Average realized price ($/boe) (6)51.5561.90-17%51.0056.31-9%Operating netback ($/boe) (6) (8)44.5956.56-21%45.0951.65-13%(1)Excludes dividend declared in December and paid in January.(2)Participation in Freehold's dividend reinvestment plan (DRIP) ranged between 17% and 41% in 2012 and is subject to change monthly at the participants' discretion.(3)Includes dividend declared in December and paid in January.(4)Based on the number of shares issued and outstanding at each record date.(5)Weighted average number of shares outstanding during the period, basic.(6)See Conversion of Natural Gas to Barrels of Oil Equivalent (boe).(7)Our production mix in 2012 was approximately 36% natural gas and 64% liquids (34% light and medium oil, 25% heavy oil, and 5% NGL). (8)See Non-GAAP Financial Measures.March Dividend Announcement The Board of Directors has declared the March dividend of $0.14 per share, which will be paid on April 15, 2013 to shareholders of record on March 31, 2013. Including the April 15 payment, our 12-month trailing cash dividends total $1.68 per share. This dividend is designated as an eligible dividend for Canadian income tax purposes. Over the past 16 years, we have paid out over $1.1 billion to our shareholders.2012 Fourth Quarter Highlights Freehold delivered strong operational results in the fourth quarter of 2012. Robust production volumes drove increases in revenue and cash flow from operating activities despite lower average realized prices. Average production for the fourth quarter was 22% higher than last year. Drilling activities, including flush production from newly completed horizontal wells, accounted for about two-thirds of the increase; prior period adjustments (650 boe per day versus 350 boe per day in fourth quarter last year) and acquisitions during 2012 accounted for the remainder. Dividends for the fourth quarter of 2012 totalled $0.42 per share, unchanged from last year. Average DRIP participation was 24% in the fourth quarter of 2012 (Q4 2011 - 40%), allowing us to retain $6.7 million (Q4 2011 - $10.2 million) in dividend payments by issuing shares from treasury. Net income of $13.4 million was 16% lower than last year, mainly as a result of increased depletion and depreciation expense, higher royalty expense, and higher operating expense due to a higher production base. Non-cash charges (excluding current income tax) included in net income amounted to $18.1 million (Q4 2011 - $22.3 million). Net capital expenditures on our working interest properties totalled $7.7 million in the fourth quarter (Q4 2011 - $10.9 million), the majority of which was incurred on horizontal drilling and multi-stage fracture well completions in southeast Saskatchewan. Long-term debt was $18.0 million at December 31, 2012, down $7.0 million from the third quarter as excess funds from operations were applied to debt repayment. 2012 Year-end Reserves and Land Highlights Freehold's reserves data is presented on a net basis (our share of working interest properties minus royalties payable to others, plus royalties receivable on our royalty lands). Freehold is unique in that the majority of our assets are royalty interests. However, under National Instrument 51-101, royalty interests cannot be included under gross reserves. This causes our gross reserves to be lower than our net reserves and makes it difficult for investors to compare our reserves to others in our industry. We believe the most appropriate measure of reserves for Freehold is net reserves. Reserve values do not include potential reserve additions that may occur as a result of future drilling on most of our royalty lands.Net proved plus probable reserves at December 31, 2012 totalled 24.4 MMboe, with reserves assigned to 22,589 wells. Net proved plus probable royalty interest reserves increased 10% year-over-year, and net proved plus probable working interest reserves increased 12%. Approximately 62% of our net reserves are in the proved category, and 93% of our net proved reserves are producing. On a boe basis, net reserves are 60% liquids (30% heavy oil, 24% light and medium oil, 6% natural gas liquids) and 40% natural gas. Net proved plus probable reserve additions totalled 5.3 MMboe (45% liquids). Drilling on our royalty lands added 1.0 MMboe (19%) of net proved plus probable reserves, development activities added 0.8 MMboe (15%), and acquisitions added 3.5 MMboe (66%). Based on this, we replaced approximately 167% of 2012 production. Freehold's finding costs are calculated based on net reserves. In 2012, finding and development costs for net proved plus probable reserves were $21.37 per boe, while acquisition costs were $17.47 per boe and the all-in finding, development and acquisition (FD&A) cost was $18.80 per boe (including changes in future development capital). Based on an operating netback of $45.09 per boe in 2012, these activities resulted in a recycle ratio of 2.4 times the capital invested, and a three-year average recycle ratio of 2.1. Our land holdings as at December 31, 2012 encompassed 3.0 million gross acres, up 9% from last year mainly as a result of acquisitions. Royalty interests comprised 94% of our acreage. Our undeveloped land was independently valued by Seaton-Jordan & Associates Ltd., at $80.2 million. Royalty Interest Activity On an equivalent net basis, 85% of the royalty wells drilled on our lands during 2012 were oil wells (2011 - 78%) due to the oil-prone nature of our lands. As well, over 66% of the equivalent net wells drilled on our royalty lands in 2012 were horizontal wells, up from 59% last year.Our royalty lands give us exposure to several of the attractive resource plays employing horizontal drilling, including Bakken and Mississippian light oil in southeast Saskatchewan, heavy oil in the Lloydminster area, and Cardium light oil in west-central Alberta. Over one quarter of the royalty wells drilled in the fourth quarter of 2012 had a Cardium target. Continued success with horizontal drilling (for both oil and liquids-rich natural gas) is positive and bodes well for improved well productivity. As at December 31, 2012, there were 99 (5.9 equivalent net) licensed drilling locations on our royalty lands, compared with 106 (5.4 equivalent net) at the same time last year. We view continued well licence activity as a positive indicator of the ongoing and future development potential on our royalty lands.ROYALTY INTEREST WELLS DRILLEDThree Months Ended December 31Twelve Months Ended December 312012201120122011GrossEquiv. Net (1)GrossEquiv. Net (1)GrossEquiv. Net (1)GrossEquiv. Net (1)Non-unitized572.61024.923111.630114.4Unitized (2)300.1600.42001.23221.3Total872.71625.343112.862315.7(1)Equivalent net wells are the aggregate of the numbers obtained by multiplying each gross well by our royalty interest percentage.(2)Unitized wells are in production units wherein we generally have small royalty interests in hundreds of wells.Working Interest Activity Our development plans are primarily oil related, and are focused almost entirely on our own mineral title lands, where we have chosen to invest our own capital on attractive, low-risk opportunities. In the fourth quarter of 2012, capital expenditures amounted to $7.7 million, the majority of which was spent to complete, equip, and tie-in wells drilled in southeast Saskatchewan during the third quarter. We participated in the drilling of seven (1.3 net) wells with a 100% success rate. In Saskatchewan, we participated in the drilling of two (0.3 net) vertical and one (0.1 net) horizontal Frobisher oil wells, as well as two (0.6 net) Bakken horizontal oil wells. In Alberta, we participated in one (0.1 net) horizontal Viking light oil well at Redwater and one (0.2 net) horizontal Cardium oil well at Minnehik Buck Lake. This drilling activity had little effect on production levels in the fourth quarter but is expected to add to our production base in 2013.WORKING INTEREST WELLS DRILLED (1)Three Months Ended December 31Twelve Months Ended December 312012201120122011GrossNetGrossNetGrossNetGrossNetOil71.393.83613.52911.1Natural gas------30.4Other--10.110.620.1Total71.3103.93714.13411.6(1)Excludes royalty interest portion on properties where Freehold has both a working interest and a royalty interest. The royalty interest portion is included in equivalent net wells in the Royalty Interest Wells Drilled table above.Operating Expense Total operating expense of $4.8 million ($5.51 per boe) was 28% higher than the fourth quarter last year (4% higher on a per boe basis). The increase correlates to the increase in working interest production volumes, as we do not incur operating expense on our royalty interest production.GROSS REVENUE BY PRODUCTThree Months EndedTwelve Months EndedDecember 31December 31($000s)20122011Change20122011ChangeRoyalty InterestOil20,50325,419-19%87,72185,2313%NGL1,5122,014-25%6,8876,4956%Natural gas3,8313,40213%10,50115,581-33%Other (1)556808-31%2,5253,206-21%Total royalty interest revenue26,40231,643-17%107,634110,513-3%Working InterestOil17,80111,84750%55,57740,78636%NGL476655-27%1,8702,100-11%Natural gas9789226%2,6403,447-23%Other (1)137237-42%4131,064-61%Total working interest revenue19,39213,66142%60,50047,39728%TotalOil38,30437,2663%143,298126,01714%NGL1,9882,669-26%8,7578,5952%Natural gas4,8094,32411%13,14119,028-31%Other (1)6931,045-34%2,9384,270-31%Total gross revenue45,79445,3041%168,134157,9106%(1)Other includes potash, sulphur, lease rentals, and other revenue for royalty interest, and processing fees, interest, and other revenue for working interest.Fourth Quarter Production Average production in the fourth quarter of 2012 was 1,737 boe per day higher than last year. Oil and natural gas liquids (NGL) production rose 22%, and natural gas production rose 26%. Royalty production volumes were 594 boe per day higher than last year, mainly as a result of royalty interests acquired during 2012 (which were 90% natural gas) and prior period adjustments due to the ongoing work of our audit team. Natural gas production was up 30%, while oil and NGL production declined 2%. Working interest production volumes were 1,143 boe per day higher than last year as a result of high activity levels in 2012 and flush production from newly completed wells in southeast Saskatchewan. Oil and NGL production was up 69% and natural gas production was up 12%. AVERAGE DAILY PRODUCTIONRoyalty InterestWorking InterestTotalThree months ended December 31201220112012201120122011Oil (bbls/d)3,1903,2622,5611,4615,7514,723NGL (bbls/d)26725288106355358Total oil and NGL (bbls/d)3,4573,5142,6491,5676,1065,081Natural gas (Mcf/d)17,10513,1983,3152,95220,42016,150Oil equivalent (boe/d)6,3085,7143,2022,0599,5107,773Commodity Prices In the fourth quarter of 2012, the benchmark West Texas Intermediate (WTI) crude oil price averaged US$88.18 per barrel, 6% lower than the prior year. Prices deteriorated during the quarter, and WTI also continues to trade at a discount to Brent crude, the global benchmark. Historically, WTI has traded at a slight premium over Brent; however during the last two years, WTI has traded consistently at a discount to Brent as a result of market access constraints. Crude oil supply in North America is growing, primarily from the Canadian oil sands and tight oil plays in western Canada, North Dakota, Montana, and Texas, and global demand remains strong. However, refinery outages and pipeline bottlenecks in the U.S. Midwest have severely reduced access to the Texas and Louisiana Gulf Coast where there is greater refinery demand. Growing supplies of light crude oil from the United States and a lack of spare pipeline capacity has blends like Edmonton Par and Western Canadian Select (WCS) being steeply discounted against WTI. The widening differentials have been an ongoing issue for Canadian producers throughout 2012 and are expected to remain a concern in 2013. Natural gas, because it is less readily transported abroad, is subject to supply and demand factors within North America. Although the low price environment of the past three years has served to curtail dry gas drilling, horizontal well technology in shale gas plays and liquids-rich gas development led to record North American production in 2012. The average benchmark AECO natural gas price was 14% lower in the fourth quarter of 2012 versus Q4 2011. The pricing outlook is bearish in the near term due to the oversupply situation. Longer-term, we believe demand growth, driven by the phasing out of coal-fired power plants in favour of cleaner-burning natural gas, increasing transportation and industrial use, and developing offshore markets, will support stronger natural gas pricing. Our average selling prices reflect product quality and transportation differences from benchmark prices. In the fourth quarter of 2012, our average realized oil price was $72.40 (Q4 2011 - $85.78) per barrel and our average realized natural gas price was $2.56 (Q4 2011 - $2.91) per Mcf.Guidance Update The following table compares changes in our key operating assumptions during 2012 to our actual results for the year. Compared to our November guidance:Average production for the fourth quarter was 856 boe per day higher than the third quarter of 2012 and annual production came in 3% above guidance, mainly due to prior period adjustments and flush production from successful drilling in Southeast Saskatchewan. Average oil prices were slightly lower than our assumptions, while natural gas prices were slightly higher. General and administrative costs per boe were lower than forecast as a result of higher a production base. Capital expenditures were $1.7 million higher than forecast, as we completed and equipped more oil wells than anticipated in the fourth quarter. 2012 Key Operating AssumptionsPrevious GuidanceAnnual Average2012 Actual ResultsNov. 8, 2012Aug. 9, 2012May 9, 2012Mar. 14, 2012Daily productionboe/d8,8508,6008,3008,1007,600WTI oil priceUS$/bbl94.20(1)95.0093.00100.00100.00Western Canada Select (WCS)Cdn$/bbl73.08(1)75.0072.0075.0081.00AECO natural gas priceCdn$/Mcf2.39(1)2.252.252.002.50Exchange rateCdn$/US$1.001.001.001.001.00Operating costs$/boe4.824.804.804.804.60General and administrative costs (2)$/boe2.392.653.003.003.00Capital expenditures$ millions36.735303030Dividends paid in shares (DRIP)$ millions27.427272727Long-term debt at year end$ millions1818211815Cash taxes paid in 2012$ millions220.127.116.11--Weighted average shares outstandingmillions64.965656565(1)As reported by the Canadian Association of Petroleum Producers (CAPP).(2)Excludes share based and other compensation. 2013 Key Operating Assumptions (1)Guidance UpdatedAnnual AverageMarch 7, 2013November 8, 2012Daily productionboe/d8,5008,400WTI oil priceUS$/bbl95.0095.00Western Canada Select (WCS)Cdn$/bbl71.0076.00AECO natural gas priceCdn$/Mcf3.103.25Exchange rateCdn$/US$1.001.00Operating costs$/boe5.005.00General and administrative costs (2)$/boe2.602.60Capital expenditures$ millions3033Dividends paid in shares (DRIP) (3)$ millions2828Long-term debt at year end$ millions4848Cash taxes payable in 2013 for 2012 tax year (4)$ millions2325Cash taxes payable for 2013 tax year (instalments) (4)$ millions2525Weighted average shares outstandingmillions6767(1)A sensitivity analysis of the potential impact of key variables on funds from operations per share is provided in our 2012 Annual MD&A. (2)Excludes share based and other compensation. (3)Assumes average 25% participation rate in Freehold's dividend reinvestment plan, which is subject to change at the participants' discretion.(4)Corporate tax estimates will vary depending on commodity prices and other factors. As 2012 capital was ahead of guidance, we have revised our 2013 capital budget to $30 million. Our development plans are primarily oil related, focused almost entirely on our mineral title lands, and include approximately 40 gross (13 net) wells. Roughly half of our capital will be deployed in southeast Saskatchewan (light oil), with the balance allocated to our expanding mineral title opportunity base in both the Lloydminster area (heavy oil) and western Alberta (Cardium oil). Almost half of our total capital for the year will be spent in the first quarter of 2013, with area allocations similar to our annual budget. Spending may be adjusted as the year progresses, depending on the operating environment and well results. Based on this level of capital investment, anticipated drilling activity by lessees on our royalty lands, and normal production declines (and excluding any potential acquisitions), we expect 2013 production to average approximately 8,500 boe per day. On a boe basis, production volumes for 2013 are expected to be approximately 64% oil and NGL and 36% natural gas. We continue to maintain our royalty focus with royalty production accounting for 67% of forecasted 2013 production. In February 2013, we remitted $23 million for estimated 2012 corporate taxes. We expect to pay approximately $25 million for the 2013 tax year by way of monthly instalments. The large cash outlay for income taxes in 2013 is an anomaly that we have prepared for and have the financial capacity to handle. We expect our tax bill will normalize in 2014, at approximately 20% of pre-tax cash flow. As our results demonstrate, we continue to benefit from activity on our oil-weighted asset base, and from relatively strong, if somewhat volatile, crude oil pricing. Of significance, natural gas accounted for 36% of production volumes in the fourth quarter (Q4 2011 - 35%), but only 11% of gross revenue (Q4 2011 - 10%). Clearly, we would benefit from any improvement in natural gas prices. However, despite a significant decline in revenue from natural gas, we have been able to maintain a steady monthly dividend rate of $0.14 ($1.68 annually) per share since January 2010. Recognizing the cyclical nature of the oil and gas industry, we continue to closely monitor commodity prices and industry trends for signs of deteriorating market conditions. We caution that it is inherently difficult to predict activity levels on our royalty lands since we have no operational control. As well, significant changes (positive or negative) in commodity prices (including Canadian oil price differentials), foreign exchange rates, or production rates may result in adjustments to the dividend rate. In particular, our 2013 forecast for Western Canada Select pricing assumes an improvement in the second half of the year, but it is possible that the North American infrastructure constraints will become a longer-term issue for western Canadian production. Based on our current guidance and commodity price assumptions, and assuming there are no significant changes in the current business environment, we expect to maintain the current monthly dividend rate through 2013, subject to the Board's quarterly review and approval. Succession Planning After more than 16 years with Freehold and 29 years with Rife Resources Ltd. (the Manager of Freehold), Mr. William O. Ingram has announced that he plans to retire as President and CEO in May 2013. Mr. Ingram will step down as a director of Freehold but will continue to serve on the boards of Rife and Canpar Holdings Ltd. As well, Dr. P. Michael Maher, who has been a director of Freehold since 1996, will be retiring from the Board in May. The directors of Freehold thank Dr. Maher and Mr. Ingram for their many years of service to Freehold, and wish them both well in their retirement. Following the retirement of Mr. Ingram in May, the Board plans to appoint Mr. Thomas J. Mullane as President and CEO, and he will stand for election as a director of Freehold at the annual meeting of shareholders to be held on May 15, 2013. Mr. Mullane joined Freehold in 2012 as Executive Vice-President and Chief Operating Officer, and brings a solid background of industry experience and knowledge at a senior level that will be an asset to Freehold in the years to come. Land and Reserves Freehold is unique in that the majority of our assets are royalty interests. However, under National Instrument 51-101, royalty interests cannot be included under gross reserves. This causes our gross reserves to be lower than our net reserves and makes it difficult for investors to compare our reserves and finding and development costs to others in our industry. We believe the most appropriate measure of reserves and finding and development costs for Freehold is on a net basis. As at year-end 2012, our undeveloped land was independently valued at $80.2 million by Seaton-Jordan & Associates Ltd. Our total land holdings encompass approximately three million gross acres, 94% of which are royalties. Of this, our mineral title lands (including royalty assumption lands), which we own in perpetuity, cover more than 630,000 acres; all but approximately 107,000 gross acres of which are currently leased to third parties. In addition, we have gross overriding royalty interests in nearly 2.2 million acres. These royalty interest lands are significant to Freehold. The majority of these lands are leased to third party operators. As a royalty owner, we have no operational control over the operator's future development activities. As such, the extent of drilling and development activity in future years can be difficult to predict. However, these operators have historically invested significant amounts to generate future reserve additions, and production from which Freehold receives certain royalties. Reserve values do not include potential reserve additions that may occur as a result of future drilling on most of our royalty lands. In addition, based on an internal estimate, we have estimated the net present value of the future royalty revenue from our potash reserves at $20.7 million before tax (discounted at 10%).Our oil and gas reserves were independently evaluated by Trimble Engineering Associates Ltd. (Trimble) as at December 31, 2012. The evaluation was conducted in accordance with the standards contained in the COGE Handbook and the reserve definitions contained in National Instrument 51-101. Our Reserves Committee met with Trimble to review the findings and procedures, and the reserves report has been accepted by our Board. Summary oil and gas reserves information is provided below. Complete reserves disclosure as required under National Instrument 51-101 will be included in our Annual Information Form.Summary of Oil and Gas ReservesAs of December 31, 2012Forecast Prices and Costs (1)Light and Medium OilHeavy OilTotal Crude OilGross (2)Net (3)Gross (2)Net (3)Gross (2)Net (3)Reserves Category(Mbbls)(Mbbls)(Mbbls)(Mbbls)(Mbbls)(Mbbls)ProvedDeveloped producing1,7543,4908274,1502,5817,640Developed non-producing7364-67370Undeveloped--28232823Total proved1,8263,5548564,1782,6827,733Probable1,3462,3019163,1972,2625,498Total proved plus probable3,1735,8551,7717,3764,94413,231Natural GasNatural Gas LiquidsOil EquivalentGross (2)Net (3)Gross (2)Net (3)Gross (2)Net (3)Reserves Category(MMcf)(MMcf)(Mbbls)(Mbbls)(Mboe)(Mboe)ProvedDeveloped producing4,02433,6281468413,39814,085Developed non-producing597947790209Undeveloped-4,314-4628788Total proved4,08338,7361548933,51615,082Probable3,04220,2121244762,8939,343Total proved plus probable7,12558,9492771,3696,40924,425(1)Numbers may not add due to rounding. (2)Gross reserves are our share of working interest properties before deduction of royalties payable to others. Gross reserves exclude royalty interests.(3)Net reserves are defined as our share of working interest properties minus royalties payable to others, plus royalties receivable on our royalty lands. The reserves data below is presented on a net basis (our share of working interest properties minus royalties payable to others, plus royalties receivable on our royalty lands). Summary of Net Present Values of Future Net RevenueAs of December 31, 2012Forecast Prices and Costs ($000s) (1)Before Income Taxes, Discounted at (% per year)0%5%10%15%20%ProvedDeveloped producing730,246537,722431,272364,055317,704Developed non-producing4,2592,7731,9861,5171,211Undeveloped23,32816,18511,8188,9586,987Total proved757,833556,679445,076374,529325,902Probable564,863295,635193,236142,680112,973Total proved plus probable1,322,696852,314638,312517,209438,875After Income Taxes, Discounted at (% per year) (2)Reserves Category0%5%10%15%20%ProvedDeveloped producing616,012453,317363,687307,156268,186Developed non-producing3,1942,0601,4581,099865Undeveloped17,43412,0708,7896,6395,158Total proved636,639467,447373,934314,894274,210Probable420,690219,454142,981105,24083,075Total proved plus probable1,057,329686,902516,915420,134357,284(1)Based on the December 31, 2012 escalated oil and gas price forecasts by an independent qualified reserves evaluator. Future net revenue values do not represent fair market value. Reserve values do not include potential reserve additions that may occur as a result of future drilling on our royalty lands. Columns may not add due to rounding.(2)The after-tax net present value calculation reflects the tax burden on the properties on a standalone basis, utilizing our tax pools to the maximum depreciation rate as currently permitted. It does not consider the corporate-level tax situation, or tax planning. It does not provide an estimate of the value at the corporate level, which may be significantly different. See our financial statements and accompanying MD&A for additional tax information. Total Future Net Revenue (Undiscounted)As of December 31, 2012 Forecast Prices and Costs ($000s) (1)Reserves CategoryProved ReservesProved Plus Probable ReservesRoyalty income660,2661,136,234Revenue from working interest properties269,358506,074Royalty expense on working interest properties(40,759)(83,190)Operating costs(121,380)(214,202)Development costs(1,441)(12,560)Well abandonment and reclamation costs(8,212)(9,661)Future net revenue before income taxes757,8331,322,696Future income taxes (2)(121,194)(265,367)Future net revenue after income taxes (2)636,6391,057,329(1)Future net revenue calculation includes future capital expenditures required to bring booked non-producing and undeveloped reserves on production. Future net revenue values do not represent fair market value. Reserve values do not include potential reserve additions that may occur as a result of future drilling on our royalty lands. Columns may not add due to rounding.(2)The after-tax net present value calculation reflects the tax burden on the properties on a standalone basis, utilizing our tax pools to the maximum depreciation rate as currently permitted. It does not consider the corporate-level tax situation, or tax planning. It does not provide an estimate of the value at the corporate level, which may be significantly different. See our financial statements and accompanying MD&A for additional tax information.Future Development Costs (Undiscounted) ($000s)Forecast Prices and Costs (1)Proved ReservesProved Plus Probable Reserves20137735,53820145196,525201529131201629117201730119Remainder61130Total1,44112,560(1)The source of funding for future development costs includes internally generated cash flow, debt or a combination of both. Disclosed reserves and future net revenue will not be materially affected by the costs of funding the future development expenditures. Columns may not add due to rounding.Reserve Life IndexAs of December 31, 2012 (1)Proved ProducingTotal ProvedProved Plus ProbableNet reserves (Mboe)14,08515,08224,425Net production (Mboe)2,5182,5462,878Reserve life index (years)22.214.171.124(1)Reflects the theoretical production life of a property if the remaining reserves were produced out at current rates. The index is calculated by dividing the reserves in the selected reserve category at a certain date by the estimated production for the first year's production period (calculated by dividing the Trimble forecast of 2013 net production into the remaining net reserves). Reconciliation of Net Reserves (1)By Principal Product TypeForecast Prices and Costs (1)Light and Medium OilHeavy OilProved PlusProved PlusProvedProbableProbableProvedProbableProbable(Mbbls)(Mbbls)(Mbbls)(Mbbls)(Mbbls)(Mbbls)December 31, 20113,4451,8855,3304,5332,8417,373Extensions569426995324199523Improved recovery------Technical revisions319(178)142167(74)93Discoveries------Acquisitions8716525346232278Dispositions------Economic factors163195-5Production(883)-(883)(897)-(897)December 31, 20123,5542,3015,8554,1783,1977,376Natural GasNatural Gas LiquidsProved PlusProved PlusProvedProbableProbableProvedProbableProbable(MMcf)(MMcf)(MMcf)(Mbbls)(Mbbls)(Mbbls)December 31, 201132,56017,11349,6738024051,206Extensions8105231,333422769Improved recovery------Technical revisions771(1,677)(906)42(31)11Discoveries------Acquisitions11,7654,26316,02820675281Dispositions------Economic factors(21)(10)(31)---Production(7,149)-(7,149)(198)-(198)December 31, 201238,73620,21258,9498934761,369Oil EquivalentProved PlusProvedProbableProbable(Mboe)(Mboe)(Mboe)December 31, 201114,2067,98222,189Extensions1,0717381,809Improved recovery---Technical revisions657(562)95Discoveries---Acquisitions2,3001,1833,483Dispositions---Economic factors17119Production(3,169)-(3,169)December 31, 201215,0829,34324,425(1)Net reserves are our share of working interest properties minus royalties payable to others, plus royalties receivable on our royalty lands. Numbers may not add due to rounding.Finding, Development and Acquisition (FD&A) Costs (1)Net Proved Reserves201220112010Three-Year ResultsFinding and development expenditures ($000s)36,74625,64918,05480,449Change in future development capital estimates ($000s)(934)1,556(59)563Net reserve additions by development (Mboe)1,0715814652,117Finding and development costs ($/boe)33.4546.8138.6738.27Acquisition expenditures ($000s)60,8527,46738,600106,919Net reserve additions by acquisition (Mboe)2,3001038573,260Acquisition costs ($/boe)26.4672.4245.0532.80Total expenditures ($000s)97,59833,11656,654187,368Change in future development capital estimates ($000s)(934)1,556(59)563Net reserve additions (Mboe)3,3716841,3225,377Finding, development and acquisition costs ($/boe)28.6850.6742.8134.95Net Proved Plus Probable Reserves201220112010Three-Year ResultsFinding and development expenditures ($000s)36,74625,64918,05480,449Change in future development capital estimates ($000s)1,9164,959356,910Net reserve additions by development (Mboe)1,8091,0859503,845Finding and development costs ($/boe)21.3728.2019.0422.72Acquisition expenditures ($000s)60,8527,46738,600106,919Net reserve additions by acquisition (Mboe)3,4832071,3525,042Acquisition costs ($/boe)17.4736.1228.5621.21Total expenditures ($000s)97,59833,11656,654187,368Change in future development capital estimates ($000s)1,9164,959356,910Net reserve additions (Mboe)5,2921,2922,3028,886Finding, development and acquisition costs ($/boe)18.8029.4724.6321.86(1)Freehold did not incur any exploration expenditures in any of the applicable years. In calculating finding and development costs, NI 51-101 requires that the exploration and development costs incurred in the year and the change in estimated future development costs be aggregated and then divided by the applicable reserve additions. The calculation specifically excludes the effects of acquisitions on both reserves and costs. We believe that by excluding the effects of acquisitions, the provisions of NI 51-101 do not fully reflect Freehold's ongoing reserve replacement costs. Because acquisitions can have a significant impact on annual reserve replacement costs, excluding these amounts could result in an inaccurate portrayal of Freehold's cost structure. Accordingly, we also provide costs that incorporate all acquisitions during the year. The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserves additions for that year.Recycle Statistics, Net Proved Plus Probable Reserves($ per boe, except as noted)201220112010Three-Year ResultsOperating netback (1) (4)45.0951.6544.0846.81Finding, development and acquisition costs (2) (4)18.8029.4724.6321.86Recycle ratio (times) (3)188.8.131.52.1(1)Total revenue, less operating costs and royalty expenses.(2)Development expenditures, plus change in future capital, plus acquisition costs; divided by net reserves added through development and acquisition activities.(3)Operating netback divided by the average cost of acquiring and developing new reserves. (4)Operating netback is based on gross production, while development and acquisition costs are based on net reserves. Land Holdings As of December 31, 2012(gross acres) (1)DevelopedUndevelopedTotalMineral title lands (2)367,071168,364535,435Royalty assumption lands (3)73,94020,88294,822Total title lands (4)441,011189,246630,257Gross overriding royalty (GORR) lands (5)1,571,533603,5482,175,081Total royalty lands2,012,544792,7942,805,338Working interest properties147,78140,253188,034Total land holdings2,160,325833,0472,993,372Land Holdings by ProvinceRoyalty InterestWorking InterestTotal AcreageDevelopedUndevelopedDevelopedUndevelopedDevelopedUndevelopedGross (1)Gross (1)Gross (1)NetGross (1)NetGross (1)Gross (1)Alberta1,537,959380,780111,67216,79326,6955,4801,649,631407,475Saskatchewan294,474199,02516,7035,0627,4274,417311,177206,452Ontario88,858184,834----88,858184,834British Columbia84,99626,57119,2471,2656,131101104,24332,702Manitoba6,2571,58415937--6,4161,584Total2,012,544792,794147,78123,15740,2539,9982,160,325833,047(1)Gross acres are the total number of acres in which we have an interest.(2)The royalties received from the sale of oil, natural gas and potash produced from the leased mineral title lands are determined by the individual lease agreements. All but approximately 107,000 gross acres of our mineral title lands are currently leased to third parties.(3)Mineral title properties owned by a number of third party oil and gas companies in respect of which gross overriding royalties, varying from 4.7% to 6.5%, have been reserved to Freehold.(4)Title lands are held in perpetuity. (5)Gross overriding royalty lands consist of properties leased by a number of third party oil and gas companies in respect of which contractual royalties or net profits interests have been reserved to Freehold.Quarterly Review20122011Q4Q3Q2Q1Q4Q3Q2Q1FINANCIAL ($000s, except as noted)Revenue, net of royalty expense43,83240,29434,49843,03644,21734,61439,56035,322Dividends declared27,78727,61627,39926,76625,58525,32225,11124,950Per share ($) (1)0.420.420.420.420.420.420.420.42Net income (2)13,43111,9757,86213,06016,03311,29016,71711,219Per share, basic and diluted ($) (2)0.200.180.120.210.260.190.280.19Cash flow from operating activities38,18336,21227,40236,33532,59530,25531,42424,096Per share ($)0.580.550.420.580.540.500.530.41Funds from operations (3)31,47526,27220,52225,61338,24528,77233,89127,322Per share ($) (3)0.480.400.310.410.630.480.570.46Dividends paid in shares (DRIP)6,6727,0136,9406,78910,2328,7657,7986,695Average DRIP participation rate (%) (4)2425252640353127Property and royalty acquisitions (net)24310,789(99)49,919(195)7,29744321Capital expenditures7,7439,1606,59813,24510,9105,5374,5374,665Long-term debt18,00025,00023,00018,00048,00051,00054,00061,000Shares outstandingWeighted average, basic (000s)66,09165,67765,15962,57160,81160,19859,71659,343At quarter end (000s)66,27065,87965,44064,99361,14160,49259,95459,536OPERATING ($/boe, except as noted)Daily production (boe/d) (5)9,5108,6548,5018,7337,7737,1957,4457,490Royalty interest production (%)6668767474727776Average selling price51.5551.7145.7454.8061.9052.8057.6152.51Operating netback (3)44.5945.5940.6449.4856.5646.8653.8248.96Operating expenses5.515.023.964.685.285.434.573.44Working interest properties16.3615.4716.4717.8619.9119.4719.7314.32Net general and administrative expenses (6)2.251.882.133.312.052.162.363.75BENCHMARK PRICESWTI crude oil (US$/bbl)88.1892.2293.49102.9394.0689.75102.5694.02Exchange rate (Cdn$/US$)1.011.010.991.000.981.021.031.01Edmonton Par crude oil (Cdn$)83.9984.3383.9592.1897.3591.74103.0787.97Western Canada Select (WCS) (Cdn$/bbl)69.4369.9971.2981.6185.4870.6382.0970.19WTI/Edmonton Par differential ($/bbl)(4.19)(7.89)(9.54)(10.75)3.291.990.51(6.05)Edmonton Par/WCS differential (Cdn$/bbl)(14.56)(14.34)(12.66)(10.57)(11.87)(21.11)(20.98)(17.78)AECO natural gas (Cdn$/Mcf)3.002.191.832.523.473.723.743.77SHARE TRADING PERFORMANCEHigh ($)22.4520.3419.6721.5919.7521.5823.2822.93Low ($)19.6217.8317.2519.1614.5116.0419.3719.86Close ($)22.4019.7618.4419.5919.4116.3619.6422.75Volume (000s)7,4355,6567,4838,0767,1147,7805,3177,921(1)Based on the number of shares issued and outstanding at each record date. (2)Net income and net income per share for the three months ended March 31, 2011 have been restated for revisions made to deferred tax.(3)See Non-GAAP Financial Measures.(4)Average participation in Freehold's DRIP ranged between 24% and 40% over the past eight quarters and is subject to change at the participants' discretion.(5)Reported production for a period may include minor adjustments from previous production periods.(6)Excludes share based and other compensation.Consolidated Balance SheetsDecember 31December 31($000s) (unaudited)20122011AssetsCurrent assets:Cash$ 102$ 164Accounts receivable23,22534,76323,32734,927Deposit on acquisition-5,000Exploration and evaluation assets25,90525,045Petroleum and natural gas interests399,005363,967$ 448,237$ 428,939Liabilities and Shareholders' EquityCurrent liabilities:Dividends payable$ 9,278$ 8,560Accounts payable and accrued liabilities12,74314,883Current taxes payable23,095-Current portion of share based and other compensation payable2,1083,87647,22427,319Asset retirement obligation16,71414,282Share based and other compensation payable1,2901,289Long-term debt18,00048,000Deferred income tax liability49,19459,163Shareholders' equity:Shareholders' capital422,728323,115Contributed surplus2,0361,480Deficit(108,949)(45,709)315,815278,886$ 448,237$ 428,939Consolidated Statements of Income and Comprehensive IncomeThree Months EndedYear ended(unaudited)December 31December 31($000s, except per share and weighted average data)2012201120122011Revenue:Royalty income and working interest sales$ 45,794$ 45,304$ 168,134$ 157,910Royalty expense(1,962)(1,087)(6,474)(4,197)43,83244,217161,660153,713Expenses:Operating4,8203,77215,59812,782General and administrative1,9721,4687,7467,029Share based and other compensation9991,2682,3712,190Interest and financing4216102,2352,907Depletion and depreciation16,37213,60364,57649,251Accretion of asset retirement obligation10783381344Management fee1,0728573,8083,40125,76321,66196,71577,904Income before taxes18,06922,55664,94575,809Income tax:Current expense5,0638027,79280Deferred expense (recovery)(425)6,443(9,175)20,4704,6386,52318,61720,550Net income and comprehensive income$ 13,431$ 16,033$ 46,328$ 55,259Net income per share, basic and diluted$ 0.20$ 0.26$ 0.71$ 0.92Weighted average number of shares:Basic66,090,96960,811,30064,880,03860,021,736Diluted66,194,50360,886,21864,979,07460,093,840Consolidated Statements of Cash FlowsThree Months EndedYear endedDecember 31December 31($000s) (unaudited)2012201120122011Operating:Net income$ 13,431$ 16,033$ 46,328$ 55,259Items not involving cash:Depletion and depreciation16,37213,60364,57649,251Share based and other compensation9991,2682,3712,190Deferred income tax expense (recovery)(425)6,443(9,175)20,470Accretion of asset retirement obligation10783381344Shares issued in lieu of management fee1,0728573,8083,401Expenditures on share based and other compensation--(3,883)(2,440)Expenditures on reclamation(81)(42)(524)(245)Changes in non-cash working capital6,708(5,650)34,250(9,860)38,18332,595138,132118,370Financing:Issuance of shares, net of issue costs--67,597-Long-term debt(7,000)(3,000)(30,000)(17,000)Dividends paid(21,060)(15,262)(81,436)(67,204)(28,060)(18,262)(43,839)(84,204)Investing:Deposit on acquisition-(5,000)5,000(5,000)Property and royalty acquisitions(243)195(60,852)(7,467)Capital expenditures(7,743)(10,910)(36,746)(25,649)Change in reclamation fund---2,725Changes in non-cash working capital(2,149)1,358(1,757)980(10,135)(14,357)(94,355)(34,411)Decrease in cash(12)(24)(62)(245)Cash, beginning of period114188164409Cash, end of period$ 102$ 164$ 102$ 164Consolidated Statements of Changes in Shareholders' EquityYear endedDecember 31($000s) (unaudited)20122011Shareholders' capital:Balance, beginning of year$ 323,115$ 286,224Shares issued for dividend reinvestment plan27,41433,490Shares issued in lieu of management fee3,8083,401Shares issued for equity offering70,725-Issue costs, net of tax effect(2,334)-Balance, end of year422,728323,115Contributed surplus:Balance, beginning of year1,4801,084Share based compensation expense556396Balance, end of year2,0361,480Deficit:Balance, beginning of year(45,709)-Net income and comprehensive income46,32855,259Dividends declared(109,568)(100,968)Balance, end of year(108,949)(45,709)Total shareholders' equity$ 315,815$ 278,886Forward-Looking Statements This news release offers our assessment of Freehold's future plans and operations as at March 7, 2013, and contains forward-looking statements that we believe allow readers to better understand our business and prospects. These forward-looking statements include our expectations for the following:our outlook for commodity prices including supply and demand factors relating to crude oil, heavy oil, and natural gas; light/heavy oil price differentials; changing economic conditions; foreign exchange rates; drilling activity during the fourth quarter of 2012 adding to our production base in 2013; industry drilling, development activity on our royalty lands, our exposure in emerging resource plays, and the potential impact of horizontal drilling on production and reserves; development of working interest properties; participation in the DRIP and our use of cash preserved through the DRIP; estimated capital budget and expenditures and the timing thereof; long-term debt at year end; average production and contribution from royalty lands; key operating assumptions; acquisition opportunities; amounts and rates of income taxes and timing of payment thereof; maintaining our monthly dividend rate through 2013 and our dividend policy; and the appointment of Thomas J. Mullane as President and CEO and his standing for election as a director of Freehold. In addition, statements relating to "reserves" and the future net revenue associated with such reserves are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves described exist in the quantities predicted or estimated and can be profitably produced in the future. Such statements are generally identified by the use of words such as "anticipate", "continue", "estimate", "expect", "forecast", "may", "will", "project", "should", "plan", "intend", "believe", and similar expressions (including the negatives thereof). By their nature, forward-looking statements are subject to numerous risks and uncertainties, some of which are beyond our control, including the impact of general economic conditions, industry conditions, volatility of commodity prices, lack of pipeline capacity; currency fluctuations, imprecision of reserve estimates, royalties, environmental risks, taxation, regulation, changes in tax or other legislation, competition from other industry participants, the lack of availability of qualified personnel or management, stock market volatility, and our ability to access sufficient capital from internal and external sources. Risks are described in more detail in our AIF. In this news release, we make references to "flush" production rates, which is the first yield from a flowing oil well during its most productive period. Such "flush" production rates are not determinative of future production rates. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. Readers are cautioned not to place reliance on such rates in estimating future production rates for Freehold. With respect to forward-looking statements contained in this news release, we have made assumptions regarding, among other things, future commodity prices, future capital expenditure levels, future production levels, future exchange rates, future tax rates, future participation rates in the DRIP and use of cash preserved through the DRIP, future legislation, the cost of developing and producing our assets, our ability and the ability of our lessees to obtain equipment in a timely manner to carry out development activities, our ability to market our oil and gas successfully to current and new customers, our expectation for the consumption of crude oil and natural gas, our expectation for industry drilling levels, our ability to obtain financing on acceptable terms, and our ability to add production and reserves through development and acquisition activities. The key operating assumptions with respect to the forward-looking statements referred to above are detailed in the body of this news release. You are cautioned that the assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should not be placed on forward-looking statements. Our actual results, performance, or achievement could differ materially from those expressed in, or implied by, these forward-looking statements. We can give no assurance that any of the events anticipated will transpire or occur, or if any of them do, what benefits we will derive from them. The forward-looking information contained in this document is expressly qualified by this cautionary statement. Our policy for updating forward-looking statements is to update our key operating assumptions quarterly and, except as required by law, we do not undertake to update any other forward-looking statements. You are further cautioned that the preparation of financial statements in accordance with IFRS requires management to make certain judgments and estimates that affect the reported amounts of assets, liabilities, revenues, and expenses. These estimates may change, having either a positive or negative effect on net income, as further information becomes available and as the economic environment changes. Conversion of Natural Gas To Barrels of Oil Equivalent (BOE) To provide a single unit of production for analytical purposes, natural gas production and reserves volumes are converted mathematically to equivalent barrels of oil (boe). We use the industry-accepted standard conversion of six thousand cubic feet of natural gas to one barrel of oil (6 Mcf = 1 bbl). The 6:1 boe ratio is based on an energy equivalency conversion method primarily applicable at the burner tip. It does not represent a value equivalency at the wellhead and is not based on either energy content or current prices. While the boe ratio is useful for comparative measures and observing trends, it does not accurately reflect individual product values and might be misleading, particularly if used in isolation. As well, given that the value ratio, based on the current price of crude oil to natural gas, is significantly different from the 6:1 energy equivalency ratio, using a 6:1 conversion ratio may be misleading as an indication of value.Non-GAAP Financial Measures Within this news release, references are made to terms commonly used as key performance indicators in the oil and gas industry, such as operating income, netback, funds from operations, funds from operations per share, finding, development and acquisition (FD&A) costs, recycle ratio, and net asset value. We believe that these measures are useful supplemental measures for management and investors to analyze operating performance, financial leverage, and liquidity, and we use these terms to facilitate the understanding and comparability of our results of operations and financial position. However, these terms do not have any standardized meanings prescribed by GAAP and therefore may not be comparable with the calculations of similar measures for other entities. Operating income, which is calculated as gross revenue less royalties and operating expenses, represents the cash margin for product sold. Operating netback, which is calculated as average unit sales price less royalties and operating expenses, represents the cash margin for product sold, calculated on a per boe basis Funds from operations is a financial term commonly used in the oil and gas industry. It is a key measure of our ability to generate cash, finance operations, and pay monthly dividends. Funds from operations as presented is not intended to represent operating cash flow or operating profits for the period nor should it be viewed as an alternative to net income or other measures of financial performance calculated in accordance with GAAP. We define funds from operations as net income adjusted for non-cash depletion and depreciation, share based and other compensation, deferred tax expense/recovery, accretion of asset retirement obligation, and management fee, and further adjusted for expenditures on reclamation. We consider funds from operations to be a key measure of operating performance as it demonstrates Freehold's ability to generate the necessary funds to fund capital expenditures and repay debt. We believe that such a measure provides a better assessment of Freehold's operations on a continuing basis by eliminating certain non-cash charges. From a business perspective, the most directly comparable measure of funds from operations calculated in accordance with GAAP is net income. Funds from operations per share is calculated based on the weighted average number of shares outstanding consistent with the calculation of net income per share. A reconciliation of funds from operations to net income is provided below.Reconciliation of Net Income to Funds from OperationsThree Months EndedTwelve Months EndedDecember 31December 312012201120122011Net income13,43116,03346,32855,259Adjust for non-cash items:Depletion and depreciation16,37213,60364,57649,251Share based and other compensation9991,268(1,512)(250)Deferred income tax (recovery)(425)6,443(9,175)20,470Accretion of asset retirement obligation10783381344Management fee1,0728573,8083,401Adjust for cash item:Expenditures on reclamation(81)(42)(524)(245)Funds from operations31,47538,245103,882128,230Per share0.480.631.602.14In addition, we refer to various per boe figures, such as revenues and costs, operating netback, FD&A costs, and NAV, also considered non-GAAP financial measures, which provide meaningful information on our operational performance. We derive per boe figures by dividing the relevant revenue or cost figure by the total volume of oil and gas production during the period, with natural gas converted to equivalent barrels of oil as described above.Availability on SEDAR Freehold's 2012 audited financial statements and accompanying Management's Discussion and Analysis (MD&A) are being filed today with Canadian securities regulators and will be available at www.sedar.com and on our website at www.freeholdroyalties.com. Our Annual Information Form (including reserves disclosure required under National Instrument NI 51-101) is expected to be filed next week. FOR FURTHER INFORMATION PLEASE CONTACT: Contact Information: Freehold Royalties Ltd.Karen TaylorManager, Investor Relations and Corporate Secretary403.221.0891 or Toll Free: 1.888.257.1873403.221.0888 (FAX)firstname.lastname@example.com


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Opal Prisma socks in red
Opal Prisma socks in purple
Baby Stuff
Textured baby cardigan in cream DK.
This hat and socks set is made from the left over yarn from my husband's socks. The yarn is Opal Rainforest Tiger.
Devan cardi, from Knitty, knitted in Opal Sugar Almond Pink 4-ply sel-patterning sock yarn. The back of the cardi is knitted in a solid light pink.
Bigga Booga Bags
These Bigga Booga Bags are an adaptation of the Booga Bag from Black Sheep Bags. The Bigga Booga Bag is wide enough to hold an A4 folder.
When I returned to knitting I made quite a few items for other people. This Bigga Booga bag was the first thing I made for myself. The yarn is Debbie Bliss' Maya, in shade 15, with a contrasting top in purple. Sadly the Maya range has been discontinued, although I have squirreled away enough of the purple to make myself a jacket for next winter.
This Bigga Booga bag made for a friend's birthday. It is made from Noro Kureyon 147. Some of the colours in this variegated yarn were rather muddy, so these were used to knit the base. The little drawstring bag is designed to hold a wallet or mobile phone, and keys.
Crocheted Jacket
This is the start of a jacket for myself, made with Colinette Lasso in 'fresco', using a 5mm hook. The stitch used is Half Treble htr (UK) / Half Double Crochet hdc (US). I have made a paper pattern, using an existing jacket as a template. At the end of each row of crochet the crochet is laid upon the pattern and I then decide if any shaping in needed. I would never have had the confidence to try this without Debbie Stoller's book The Happy Hooker.

subset: commoncrawl


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The reason I chose this poem is because this past Sunday, I went to the Holocaust Museum with my family. My daughter loves butterflies, or as she calls them "boo-flies", so I was immediately drawn to all the butterflies they had on display and for sale. My daughter of course loved them all, too. Then, in a small corner of the book case, I saw a little frame with this poem. It touched me so much as I reflected on this young boy in a concentration camp. I hope you enjoy the poem and may you also reflect on those who died.
The Butterfly / Pavel Friedman
The last, the very last,
So richly, brightly, dazzlingly yellow.
Perhaps if the sun's tears would sing
against a white stone. . . .
Such, such a yellow
Is carried lightly 'way up high.
It went away I'm sure because it wished to
kiss the world good-bye.
For seven weeks I've lived in here,
Penned up inside this ghetto.
But I have found what I love here.
The dandelions call to me
And the white chestnut branches in the court.
Only I never saw another butterfly.
That butterfly was the last one.
Butterflies don't live in here,
in the ghetto.
Pavel Friedman: Friedman was a young poet, who lived in the Theresienstadt Ghetto. Little is know of the author, but he is presumed to have been 17 years old when he wrote "The Butterfly". It was found amongst a hidden cache of children's work recovered at the end of the Second World War. He was eventually deported to Auschwitz where he died on September 29, 1944.
**If you would like your poem to be featured on Poetry Friday, please send me an email at: booksintheburbs(at)gmail(d0t)com.
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Minimum Qualifications
Prospective students in the online certificate program must meet the following minimum qualifications in order to enroll in online courses at Massachusetts Maritime Academy (MMA):
Applications for Admission
Complete applications for admission will consist of the following documents. Only complete application packages will be considered for acceptance.
Applicants will also be asked to complete a "Pollution Survey" available on the program's website. This survey will not be used to determine a student's eligibility for the program, but is used for program assessment and reporting purposes.
Applicants will be notified of their enrollment status at the email address provided in their applications. Applications for admission will be accepted on a continuous basis.
Course Registration
Once you have been accepted into the Pollution Compliance for Seafarers certificate program, you must register for a specific course.
How to Register for a Course
Course registration will take place during the Registration Period indicated for each course in the table below. You must first apply for admission to the program. To do so, visit the program website (www.maritime.edu/seafarers) and click the "Apply Online" link. Complete and submit the online application form. We will notify you of your registration status within 8-10 business days of receiving your application.
Once you are accepted and a course becomes available, you can register online for the course. During the registration period for the course you wish to take, go to the program website (www.maritime.edu/seafarers) and click on the title of the course currently being offered. This will take you to a course description and a link to MMA's online registration.
Class size is limited to 20 students per course. When no more seats are available, applicants will be placed on a waiting list and notified if a seat becomes available. If no seats become available before the first day of class, students from the waiting list will not be enrolled in the course.
Students do not need to complete the courses in the order shown below, although we recommend doing so. Students are not permitted to enroll in multiple courses or to register for future courses in advance. Students may only enroll for a course during the course registration period indicated for that course, and students will only be registered for one course at a time.
Students withdrawing after the first day of class but prior to this date will receive a "W" on their transcript. A "W" does not affect the student grade point average (GPA).
General Course Policies
Courses usually require 10-15 hours of student activity per week. This time is spent reading materials online, completing projects and assigned activities, interacting with faculty and peers, taking exams and quizzes, etc. Successful course completion will depend upon a student's motivation to dedicate 10-15 hours per week to the course. Failure to do so may result in a course grade reduction and/or failure in the course.
It is essential that you are able to log into the course at least once per week, although most courses will require you to log in more frequently. Failure to log into your course at least once per week can result in a grade reduction and/or removal from the course with a failing grade. In other words, participation in your online course is mandatory, and failure to engage frequently and conscientiously will result in a lower grade or course failure. Once a student receives a non-passing grade (below a "C") or is removed from a course, that student may not enroll in any future courses until two years have elapsed since the start date of the failed course.
Participants will receive a grade for each course in which they register. Pass/no-pass options are not available, and MMA courses cannot be audited (i.e., taken for no grade). Once a student enrolls in a course, that student must earn a course grade of "C" or above to enroll in subsequent courses. Course grades are based on a variety of assignments and criteria, including projects, activities, exams, homework, participation, and meeting deadlines. Each instructor may use a different combination of assignments to assess students' understanding of course material, and course policies will be described in the syllabus for the course. The instructor has sole authority to issue the final grade. In addition to these general requirements, each course instructor may establish his/her own course requirements.
Failing grades: If you receive a failing grade in a single course, you will not be permitted to enroll in another course until two years have elapsed since the start date of the failed course.
Students who fail to log in at least once per week without receiving advance permission from the instructor will be dis-enrolled from the course.
Course withdrawal: Once the course has begun, you may withdraw from the course by notifying the instructor of your intention to do so. You will receive a "W" on your transcript if you complete this process within the first 5 days of the course. After this time, any withdrawal will result in a grade on your transcript. The grade will reflect your calculated score at the end of the course, taking into account zero points awarded for incomplete work.
Given the relatively short duration of each course and the limited period over which courses may be offered, no grades of "Incomplete (I)" will be given.
Hardware and Software Requirements
Technical Requirements
1. Computer requirements: System requirements for PC:
Recommended Browsers: PC:
All students are expected to adhere to MMA standards for academic honesty and professional conduct. Failure to observe these standards or failure to maintain appropriate, respectful communication practices will result in disenrollment and failure for the course.
Depending upon the severity and nature of the incident, a student may be barred from future MMA enrollment. Any incidents warranting further action will be brought to the attention of appropriate campus officials.
Although you will be required to participate in an online learning community, which implies some casual interaction to facilitate online learning activities, you will not be asked to divulge any personal information that you do not wish to share. All personal information collected by surveys or by MMA administration is considered confidential and is not disclosed to third parties except for research purposes, wherein all identifying information is removed and no individual information is disclosed. We adhere to all FERPA requirements, including additional regulations as established by MMA.
Written and signed consent must be given by the student before any records will be released to a third party.
Affirmative Action and Disability Statement
It is the policy of MMA not to discriminate on the basis of race, creed, religion, color, gender, sexual orientation, age, disability, veteran status, marital status, or national origin in its admissions, employment, and other activities. Questions or concerns regarding disability accommodations may be directed to Anne Walsh Folino, Director of ADA Compliance and Affirmative Action, 508-830-5000, extension 1409. Reasonable accommodations will be made for any enrolled students with disabilities.
Although any materials generated during the course may be used for educational purposes in the course itself, students retain copyrights on all documents and communications they produce.
Students may print and view materials made available within the course according to fair use policies established for online instruction. Such materials may be used only for informational and non-commercial purposes, with appropriate copyright notices provided when applicable.
Course materials may not be "mirrored," "derivatized," or reproduced on any website or electronic media resource not currently owned and maintained by Massachusetts Maritime Academy.
All courses in the Pollution Compliance for Seafarers online certificate program are offered free of charge during the period October 27, 2008, to October 2, 2010. This program is made possible by a grant from the National Fish and Wildlife Foundation's Seafarer's Environmental Education Fund with the oversight of the United States Coast Guard.
After October 2, 2010, regular tuition, fees, and other associated costs apply.
Contact Information
Questions and comments about the program may be directed to:
Email: email@example.com
Website: www.maritime.edu/seafarers
Mailing Address:
Online Certificate Program
c/o Kim Barrett
101 Academy Drive
Massachusetts Maritime Academy
Buzzards Bay, MA 02532
last updated 12-3-2010 by email@example.com


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July 28, 2015
Registration may also be done via mail. Mail-in registration forms are available at post offices, banks, libraries or HERE.
The Lancaster County election commissioner and two Lincoln-area colleges will hold voter registration drives.
The drives will be held Monday, which is on Constitution Day.
Booths will be set up on the Lincoln campuses of Nebraska Wesleyan University and Doane College. Any Nebraska resident who has moved, changed his or her name, will be 18 years old on or before Nov. 6 or who wants to change party affiliation may register to vote at the booths.
Election Commissioner Dave Shively also reminds residents that they may register to vote at the election commissioner's office through Oct. 26
Click Here to access the online Public Inspection File
Viewers with disabilities can get assistance accessing this station's FCC Public Inspection File by contacting the station with the information listed below. Questions or concerns relating to the accessibility of the FCC's online public file system should be directed to the FCC at 888-225-5322, 888-835-5322 (TTY), or email@example.com.


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In America the United States Supreme Court has found and held that all parents have the right to the care, custody, control, and companionship of their children unless they are proven unfit. "the interest of parents in the care, custody and control of their children–is perhaps the oldest of the fundamental liberty interests recognized by this Court." Troxel vs Granville 530 US 57 (2000)
Furthermore, North Carolina's own courts have found, "`[i]n order to justify depriving a parent of the custody of a child in favor of third persons there must be substantial reasons or, as various courts have put it, the reasons must be real, cogent, weighty, strong, powerful, serious, or grave.' 67 C.J.S. Parent and Child § 12, page 651." James v. Pretlow, supra. Nor is the fact that a parent or parents seeking to retain custody of their child, or to obtain custody of their child, may not be as able financially to take care of the child as the party seeking to defeat their custody sufficient to justify the court's depriving the parents of custody and awarding it to some third person. 2 Nelson, Divorce & Annulment, § 15.15, p. 245 (2d ed. rev. 1961).
As a result of the "deep and meaningful relationship" existing between parent and child, the preliminary determination required by the relevant constitutional provisions "must not be lightly undertaken" and "must be supported by clear and convincing evidence." Id. At 53, 550 S.E.2d at 503 (citing Santosky v. Kramer, 455 U.S. 745, 747-48, 71 L. Ed. 2d 599, 603, 102 S. Ct. 1388, 1391-92 (1982)).
Parental rights may only be terminated if the specific criteria in GS 7B-1111 are met, being a resident of another country and poverty are not legal reasons for terminating parental rights, in fact 7B-1111 specifically states that poverty cannot be used as a reason for terminating parental rights, so DSS' claim that the children are better off with their foster parents because the father does not have running water in Mexico is in error…running water is not a requirement of parenting. So were our ancestors unfit because they did not have running water? My grandparents did not have running water, or an indoor bathroom until 1984, yet I was always clean, well fed, and loved and so was their house and clothes.
Amish people do not have running water, so should the state rush in and remove their child and call them unfit, based solely on that?
I would also like to mention that Mexico does have an issue with running water, it is not just this father's home, but millions of Mexican residents that lack running water, through no fault of their own, so should America go in a take all Mexican children from their homes? Running water does not determine whether you are a good parent, who adequately provides care to your children and should not be used in this case to deny, by all accounts, a healthy, loving parent child relationship. If DSS can take these children from this father for this reason, they can take a child for any reason without justification.
The grounds for terminating parental rights in North Carolina are:
§ 7B‑1111. Grounds for terminating parental rights.
(a) The court may terminate the parental rights upon a finding of one or more of the following:
(1) The parent has abused or neglected the juvenile. The juvenile shall be deemed to be abused or neglected if the court finds the juvenile to be an abused juvenile within the meaning of G.S. 7B‑101 or a neglected juvenile within the meaning of G.S. 7B‑101. (There has been absolutely no abuse or neglect alleged against this father!)
(2) The parent has willfully left the juvenile in foster care or placement outside the home for more than 12 months without showing to the satisfaction of the court that reasonable progress under the circumstances has been made in correcting those conditions which led to the removal of the juvenile. Provided, however, that no parental rights shall be terminated for the sole reason that the parents are unable to care for the juvenile on account of their poverty. (This father has not willfully left his children in foster care or a placement outside the home, in fact he has fought to have his children place with him, he was deported and unwillingly separated from his children and wife.)
(3) The juvenile has been placed in the custody of a county department of social services, a licensed child‑placing agency, a child‑caring institution, or a foster home, and the parent, for a continuous period of six months next preceding the filing of the petition or motion, has willfully failed for such period to pay a reasonable portion of the cost of care for the juvenile although physically and financially able to do so. (There is no evidence that this father has willfully failed to pay a reasonable portion of his children's care)
(4) One parent has been awarded custody of the juvenile by judicial decree or has custody by agreement of the parents, and the other parent whose parental rights are sought to be terminated has for a period of one year or more next preceding the filing of the petition or motion willfully failed without justification to pay for the care, support, and education of the juvenile, as required by said decree or custody agreement. (Does not apply in this case)
(5) The father of a juvenile born out of wedlock has not, prior to the filing of a petition or motion to terminate parental rights: (Does not apply to this case since the parents are, according to the article, legally married.)
a. Established paternity judicially or by affidavit which has been filed in a central registry maintained by the Department of Health and Human Services; provided, the court shall inquire of the Department of Health and Human Services as to whether such an affidavit has been so filed and shall incorporate into the case record the Department's certified reply; or
b. Legitimated the juvenile pursuant to provisions of G.S. 49‑10 or filed a petition for this specific purpose; or
c. Legitimated the juvenile by marriage to the mother of the juvenile; or
d. Provided substantial financial support or consistent care with respect to the juvenile and mother.
(6) That the parent is incapable of providing for the proper care and supervision of the juvenile, such that the juvenile is a dependent juvenile within the meaning of G.S. 7B‑101, and that there is a reasonable probability that such incapability will continue for the foreseeable future. Incapability under this subdivision may be the result of substance abuse, mental retardation, mental illness, organic brain syndrome, or any other cause or condition that renders the parent unable or unavailable to parent the juvenile and the parent lacks an appropriate alternative child care arrangement. (The reasons these children were removed from their mother were out of this fathers control, since he was no longer in the home or able to re-enter this country because of deportation, in order to care for his children. It should also be noted that these conditions did not exist when this father resided in the home, with his children)
(7) The parent has willfully abandoned the juvenile for at least six consecutive months immediately preceding the filing of the petition or motion, or the parent has voluntarily abandoned an infant pursuant to G.S. 7B‑500 for at least 60 consecutive days immediately preceding the filing of the petition or motion. (This father has not willfully abandoned his children)
(8) The parent has committed murder or voluntary manslaughter of another child of the parent or other child residing in the home; has aided, abetted, attempted, conspired, or solicited to commit murder or voluntary manslaughter of the child, another child of the parent, or other child residing in the home; has committed a felony assault that results in serious bodily injury to the child, another child of the parent, or other child residing in the home; or has committed murder or voluntary manslaughter of the other parent of the child. The petitioner has the burden of proving any of these offenses in the termination of parental rights hearing by (i) proving the elements of the offense or (ii) offering proof that a court of competent jurisdiction has convicted the parent of the offense, whether or not the conviction was by way of a jury verdict or any kind of plea. If the parent has committed the murder or voluntary manslaughter of the other parent of the child, the court shall consider whether the murder or voluntary manslaughter was committed in self‑defense or in the defense of others, or whether there was substantial evidence of other justification. (Does not apply in this case)
(9) The parental rights of the parent with respect to another child of the parent have been terminated involuntarily by a court of competent jurisdiction and the parent lacks the ability or willingness to establish a safe home. (I would say this father wants to establish and is capable of establishing a safe home for his children, but is being prevented from doing so by the state of North Carolina and DSS.)
(10) Where the juvenile has been relinquished to a county department of social services or a licensed child‑placing agency for the purpose of adoption or placed with a prospective adoptive parent for adoption; the consent or relinquishment to adoption by the parent has become irrevocable except upon a showing of fraud, duress, or other circumstance as set forth in G.S. 48‑3‑609 or G.S. 48‑3‑707; termination of parental rights is a condition precedent to adoption in the jurisdiction where the adoption proceeding is to be filed; and the parent does not contest the termination of parental rights.
(b) The burden in such proceedings shall be upon the petitioner or movant to prove the facts justifying such termination by clear and convincing evidence. (1977, c. 879, s. 8; 1979, c. 669, s. 2; 1979, 2nd Sess., c. 1088, s. 2; c. 1206, s. 2; 1983, c. 89, s. 2; c. 512; 1985, c. 758, ss. 2, 3; c. 784; 1991 (Reg. Sess., 1992), c. 941, s. 1; 1997‑390, ss. 1, 2; 1997‑443, s. 11A.118(a); 1998‑202, s. 6; 1998‑229, ss. 11, 28; 1999‑456, s. 60; 2000‑183, s. 11; 2001‑208, s. 6; 2001‑291, s. 3; 2001‑487, s. 101; 2003‑140, s. 3; 2005‑146, s. 1; 2007‑151, s. 1; 2007‑484, s. 26(a).)
A look at North Carolina law, and North Carolina and United States legal opinions easily answers this question, so why then is DSS still fighting to illegally detain these children and keep them from their father? I believe this is another demonstration of the uncontrolled and unchecked power of DSS. A prime example of DSS' total disregard for the laws of this state and country. What this case basically comes down to is the illegal taking of Senor Montes' children, not out of fear that he will hurt them, but because DSS believes that these children will be better off with someone else because their father lives in Mexico and doesn't have running water. DSS believes these children are better off being raised by strangers, then by a father who loves them so much, that even after being deported…he has still found a way to fight for custody of his children. Just because DSS disagrees with the living conditions of a foreign country, or their way of life, does not make that way of life wrong.
Deported Migrant Fights for Custody of His 3 Children
District Court Judge Michael Duncan heard for eight hours the arguments as to whether Felipe Montes, who lived in Sparta for nine years, is capable of bringing up his children in Mexico or whether it would be better to put them up for adoption.
The judge heard Thursday from the state Division of Social Services and set another hearing for May 29, when Montes' attorney, Donna Shumate, will have the chance to argue the importance of reuniting the family.
"This is a complicated, difficult case, but we expect to win. I've had the support of other attorneys in different parts of the country, and we'll prepare for our hearing," Shumate said.
Felipe Montes' nightmare began on a day in October 2010 that started out like any other. He made breakfast for his wife and children and got the kids ready for daycare. (Isn't this man entitled to citizenship since he is married to a U.S. Citizen?)
Montes, 33, was the sole provider for the family and the children's primary caregiver, as his wife – a U.S. citizen – suffers from an unspecified disabling mental illness.
Unable to get a driver's license because he was undocumented, Montes had been arrested several times for driving without a license, but continued to drive so he could work.
When he went to court to pay his fines, two U.S. Immigration and Customs Enforcement agents were waiting for him.
They handcuffed him and transferred him to a detention center in Georgia, from where he was deported to Mexico on Dec. 3, 2010, as his wife was expecting the couple's third child.
Soon after Felipe's deportation, his wife, Marie Montes, lost custody of their children due to economic difficulties and a decline in her health.
Marie, 31, told Efe that she expects to join her husband in Mexico once the judge returns custody of the children to Felipe.
"He's an excellent father," she said, and noted that Montes is "desperate" to see his kids because "he loves them with all his heart and so do I."
The woman told Efe that the DSS has not let her speak with or see her children and that has caused her stress and insomnia.
"I did what I could during the three months that I had the kids. I want them sent to him. I have health problems with my kidneys and I take medicine, but I repeat, I'm not a drug addict like say I am," the mother said.
Montes is not an isolated case, according to the Applied Research report "Shattered Families," which shows that more than 5,000 children of deported or detained immigrant parents are currently in foster homes.
DSS says the Montes children would be better off with their current foster families than with their dad in Mexico, because there is no running water where he lives. (no parental rights shall be terminated for the sole reason that the parents are unable to care for the juvenile on account of their poverty. North Carolina General Statute 7B-1111 (a)(2))


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We've now updated the Pixel Perfect Precision Handbook to version 2 – visit this blog post to download and read all about it.
We're excited to announce there's a new version of the PPP™ Handbook available to download! Over the past few months we've updated it with a new chapter as well as more advice:
- Accessibility – a whole new chapter dedicated to making your designs accessible for colour blind users.
- Adobe CS6 – updated advice for the new suite of software released.
- More pixel tips and tricks – we've added pages to some of the sections, including Text Length, Aligning Text on Buttons, Leading, Locked Layers, and Reducing Photoshop File Sizes.
- Custom fonts – a big one for us, we can now use our brand FS Me typeface in the iBook instead of Helvetica – looks so much better!
Download it now…
- iBook iPad Download (18mb)
- iBook Desktop Download (17mb)
- PDF Download (17mb)
- Extras (Scripts, Resources etc., 8mb)
And of course be sure to follow @pppustwo on Twitter for all the latest pixel news and advice!
Working with Apple iBooks Author
It's hard to believe that it's been a year since 1.0 and to reminisce, we wanted to share with you some of our experiences working with the Apple iBooks format.
We were incredibly excited when Apple released iBook Author, and having seen the impressive demos were keen to find a project to test it out on. At the time the PPP™ Handbook was receiving a refresh so it was very much in the forefront of our minds; that coupled with the fact that PDF seemed like such an oxymoron in terms of its distribution (PDF images are hardly pixel-perfect!) was enough to persuade us that iBooks, paired with the iPad, were the perfect viewing tool.
But we faced one major challenge: the current design was based on a widescreen (16:9) format, and the iBook was a more traditional 4:3; the former with a four column grid and the latter realistically only able to fit three columns. For some pages this wouldn't be a problem, but in some cases all four columns were used when presenting an idea.
However, having seen the presentation of the software we knew we had some super-duper whizzbang interactive tools to play with now! No longer constrained to static designs we jumped headfirst into these new features. With the help of then-Lead Intern™ Daniel we came up with a range of solutions for how to fit four columns into three using some of the built-in iBooks Author widgets*, which mostly revolved around trying to make the images interactive.
One of the options tried was to use the zoom tool.
We also tried a couple of versions using swipe gestures to flick between images.
However after trying out these ideas, and testing them round the studio, we realised that we were trying to force interactivity where it didn't necessarily belong! Our fixation on introducing "cool" features had led us down the wrong path entirely: our users couldn't work out how to view the content on the page. With the knowledge that this direction just wasn't going to work we started to be more creative with the layout itself, and when one proposal appeared showing the text at the bottom of the page, and more importantly three free columns above for images, we knew that we had the money shot.
So the moral of this story, as you may have already guessed, is: just because you can, doesn't mean you should! iBooks Author contains some fun little interactive tools, but they should come with a warning label that reads "Only deploy when it actually benefits the user!".
*As an aside, we found these default widgets to be quite limiting in terms of styling; there wasn't much you could do with them outside of what iBooks Author dictates. If you want full customisation it's better to create your own HTML5 widgets using a tool such as Tumult Hype.


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Undergraduate Academic Catalog 2012-2013
Home > Undergraduate Academic Catalog 2012-2013 > Degree Course Descriptions > Course Descriptions > Civil Engineering Technology Courses > CET 4450 Pavement Design and Maintenance
CET 4450 Pavement Design and Maintenance
Prerequisites: CET 3301, CET 3302, CET 3321.
A study of the methods used to determine thickness and composition of the components of both flexible and rigid highway pavements. Class work will also include evaluation of paving materials, design of pavement drainage systems recognition of pavement distress, and the design of repair measures. Standard techniques and computer software such as that of PCA, ACPA, the Asphalt Institute and AASHTO will be utilized in pavement thickness design.
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Totally remodeled 4 bedroom 2.5 bath home. Impact windows and doors. New kitchen and bathrooms. A must see. Centrally locatedMore info Email a friend
LIVE/WORK - Beautiful 217,800 SqFt - 3/2/2 home on five acres of sunny South Florida. Includes a two car garage, fence, patio, outdoor concrete kitchenette structure with two exterior bathrooms. Five acres total, 3+ acres of shade house, loading bay, ...More info Email a friend
Hendricks Cty-2hr frm Hialeah 4/3+5acres,2garage,lake,marbel fl. $300K OBO 786-385-5925More info Email a friend
Originally Listed over $2.55M & Valued by Trulia at $2.723M this home will beAUCTIONED on Aug 15-The Published Reserve at which the Seller has to sell at or above is $1.98M plus a Buyer's Premium. (See Terms of Sale at Auction)This gated estate built in...More info Email a friend


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Edward J. Dempsey and Sadie A. Dempsey Memorial Teaching Scholarship
Scholarships applications are closed at this time.
Established in 1985 by John E. Dempsey in memory of his parents, former regent Edward J. Dempsey '01, for whom Dempsey Hall is named, and Sadie A. Dempsey.
The recipients of this scholarship shall be full-time second semester juniors in the College of Education and Human Services at the University of Wisconsin Oshkosh with a strong desire to continue their education. (Participation in athletics cannot be considered in the selection process, based on NCAA Division III guidelines.)
Applicants must either be from a family of four or more children or have at least one child of their own. These students might not otherwise have the financial means to pursue their education.
The scholarship will be awarded for the fourth and fifth years of a student's five-year teaching program.
Applications for this scholarship can be obtained from the Curriculum and Instruction Department, College of Education and Human Services.
Final selection will be made by a committee named by the Dean of the College of Education and Human Services.
The Award:
The value and/or number of scholarships will be determined annually by the committee with the UW Oshkosh Foundation and will be based upon income available for this purpose.
One-fourth of the award will be held at the Cashier's Office each semester of the student's fourth and fifth years for credit against that semester's tuition.


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How many blogs are there? 50 million and counting
Here is Technorati's latest State of the blogosphere report.
A few highlights:
On July 31, 2006, Technorati tracked its 50 millionth blog
The blogosphere is doubling about once every 6 and a half months
About 175,000 new weblogs are created each day
There are more than 2 blogs created each second of each day
about 1.6 Million postings per day, or about 18.6 posts per second.
Here is an interesting chart showing the sites most-linked-to from blogs, with The New York Times #1:
Aug 07, 2006 | E-MAIL | SAVE | PRINT
Discussion5 comments about 'How many blogs are there? 50 million and counting'
Posted by emmanuel at October 6, 2007 7:32 AM
I ran into an excellent article written by Jane Lea of Lodi California. She commented on the lack of readership and subscriptions to Marty Weybret's Lodi News Sentinel. What is really lacking at the Sentinel is true genuine leadership. Unfortunatley Marty Weybret has set himself as a self-appointed expert at leadership evaluation. Unfortunately, Marty knows little or nothing about leadership let alone effective leadership. His failing newspaper business is the product of his inability to effectively lead. Marty was raised as a rich kid in the Lodi area having his diaper changed well into his adult years. Unfortunately individuals like Marty who are raised with a silver spoon in their mouth have little or no regard for the average citizen. Marty who has done his best to redeem his tarnished image in the town of Lodi posts pictures of himself giving little trinkets and toys to underprivileged children in an attempt to give the impression that he is somewhat of a person who "puts others first." Marty's political fabrication is the laugh of the town, not only over here in Woodbridge but in the Lodi vicinity at large.
Posted by About Marty Weybret at March 20, 2010 10:22 AM
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COLUMBIA CITY ŌĆö Although VeteranŌĆÖs Day is observed Nov. 11, several schools will host veteran programs to honor service men and women.
Coesse Elementary School will once again invite parents and grandparents to its campus for a ceremony Friday at 12:45 p.m.
Peabody Public Library and Indiana Springs Middle School will hold a countywide event Sunday at 2 p.m.
This will be the 11th year for the ceremony.
Whitko High School will also recognize veterans in a program slated for Nov. 11 at 10:45 a.m.
Students will have the opportunity to hear from local veterans Wilbur Wilson and David Roth.
See FridayŌĆÖs edition of The Post & Mail for a special publication honoring veterans from the community.


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- Willamette
- Athletics
- News Archive
- 2014
- May
- Willamette at NCRC Championship Regatta
Rowing | Saturday, May 3, 2014
Bearcats Row in NCRC Championship Regatta at Dexter Lake
EUGENE, ORE. -- Willamette University participated in the Northwest Collegiate Rowing Conference (NCRC) Championship Regatta on Saturday, May 3 at Dexter Lake. The Bearcats competed in the women's varsity 4+ and the women's novice 4+.
The Bearcats placed fifth in the women's varsity 4+. Humboldt State University (Calif.) took first place in 8:52.03. University of Puget Sound was second at 9:20.79, while Lewis & Clark College finished third at 9:33.34.
Pacific Lutheran University was fourth at 9:52.43, about 6.5 seconds in front of the Bearcats, who completed the race in 9:58.98. Seattle Pacific University was nearly 10 seconds behind Willamette and placed sixth in 10:08.46.
Willamette's crew in the WV4+ featured coxswain Rachel Robinson (Jr., Bellevue, WA/Bellevue HS) along with Katy Wallner (Jr., Petaluma, CA/Petaluma HS) at stroke, Hannah Puckett (Fr., Davis, CA/Davis HS) at 3-seat, Molly Pritchard (Fr., Medford, OR/South Medford HS) at 2-seat and Sarah Fish (So., Seattle, WA/Holy Names Academy) at bow.
In the women's novice 4+, WU finished sixth. Puget Sound won the race with a time of 8:17.35. Seattle Pacific was a close second at 8:21.43. Humboldt State placed third at 8:31.85, with Pacific Lutheran in fourth at 8:39.63, Lewis & Clark in fifth at 9:02.31 and Willamette at 9:52.86.
Sidney Gallardo (Fr., Oaxaca de Juarez, Mexico/Oaxaca Christian School) was the coxswain of the Willamette WN4+. She worked with stroke Bea McAlister (So., Kenmore, WA/Inglemoor HS), 3-seat Emily Rolin (Fr., Richmond, RI/Chariho HS), 2-seat Lily Dunbar (Fr., Oakland, CA/Oakland Technical HS) and bow Jenny Duren (Fr., Redmond, WA/Inglemoor HS).
Humboldt State won the NCRC women's team title with a total of 77 points. Puget Sound took second place with 73 points.
The NCRC Championship Regatta concluded the Bearcats' 2013-14 season.
Championship Regatta
Dexter Lake
Eugene, Ore.
May 3, 2014


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Tags arabic, tamer hosny, morocco, egypt
Artists Mr Khalid, Elissa, نانسي عجرم
May 31, 2011
including music by Mr Khalid, Cheb Khaled, Elissa, and Tamer Hosni
اغنية اكثر من رائعة
This reminds me of my gf no long ago. Beautiful mix, im thankful :)
I think you didn't know the kings of "RAI", "Cheb Khaled" and "cheb Hasni" (kind of music played only in Morocco and algeria)
Cheb Khaled - Didi (Original)
youtube /watch?v=g93odzEUXg8
Cheb Hasni - Chira Li NebGhiha
youtube /watch?v=Kp1HVBsJv8E
great mix toronto
The Sketching Playlist by camillemary
(artwork by Paul de Pignol) Nine tracks including music by Ludovico Einaudi, Goldfrapp, and Soap&Skin.
drawing, sketching, haunting, study
The French Playlist by camillemary
De France Gall à Raphaël, en passant par Coeur de Pirate.
french, france, quebecois, chanson francaise, childhood
Take Apart Your Head by camillemary
Brand New, Bayside, Maximo Park, and more.
alternative rock, emo, punk, alternative, punk rock
The Hip Hop Playlist by camillemary
Seventeen tracks from old school to underground hip hop, including music by Pacewon, Notorious B.
underground, hip hop, rap, chill, high


text:
Learn more about Executive Rose:
Manufacturer: GourmetGif
Mfg Part#: 4208
Sku: 215897505
Package Weight: 10 lbs
See more in Gift Baskets
|Loaded with over ten pounds of ultra-premium dried fruits and nuts, there is no more impressive gift in it's category than the Executive Rose! This incredible design is a huge collection healthy and nutritious snacks perfect for a family or a group to share. They'll nibble for days on it's magnificent collection of Jumbo Pears, Jumbo Peaches, Fancy Apricots, Jumbo Prunes, Roasted Jumbo Almonds, Colossal Pistachios, Giant Cashews, and Hickory Smoked Extra-Large Almonds! Everything about this breathtakingly beautiful gift is BIG! Another exclusive Gourmet Gift Baskets design, there is nothing out there as impressive as the Executive Rose!