Production in January 2013, based on field estimates, was approximately 49,700 boepd (83% light oil and liquids), up from our fourth quarter 2012 average production of 47,192 boepd. In January, our Bakken business unit produced approximately 19,800 boepd and our Cardium business unit produced approximately 20,800 boepd, with the remainder of the production generated by our southeast Saskatchewan Conventional and AB/BC business units. During the month of January, production was negatively impacted by approximately 600 boepd due to restrictions at third-party facilities in the Cardium.
Currently we have 13 rigs operating in the field, with 6 in the Cardium, 4 in the Bakken, 1 in Southeast Saskatchewan, 1 in Swan Hills and 1 in a new play area. Drilling activity year to date has resulted in 39 (30 net) wells drilled, comprised of 13 (11 net) in the Bakken, 12 (10 net) in the Cardium, 9 (5 net) in our Saskatchewan Conventional business unit and 5 (4 net) on our emerging plays. Currently, we have 48 (36 net) wells at various stages of completion waiting to be brought on production.
With our active program at the end of 2012 generating strong production growth leading into year-end, we anticipate a base production profile that will have steeper declines in the first part of this year, followed by lower declines in the later part of the year. We have forecasted an average production decline rate from December 2012 to December 2013 of 39%. On a quarterly basis, our base production decline from fourth quarter 2012 to fourth quarter 2013 is expected to be 31%, normalizing the impacts of our strong production additions during December 2012. We now forecast 2014 base declines to range from 28% to 33%.
Our 2013 capital expenditure plan of $675 million is more balanced throughout the year, which will help us reduce production volatility and manage declines while delivering anticipated year-over-year average production growth of 8% to 12%.
REALIZED PRICES AND COMMODITY DIFFERENTIALS
North America is currently experiencing infrastructure challenges resulting from growth in domestic production of oil and gas due to the development of oil sands assets and the application of horizontal multi-stage fracturing technology. The impact has been felt across the continent through lower realized oil and gas prices, with WTI prices trading at a discount to Brent pricing and North American natural gas trading well below world prices. To compound the problem, increased production from Western Canada and the mid-western United States has resulted in additional discounts for crude produced in Canada. The biggest impact has been on the price other producers receive for heavy crudes, where discounts of 25% to 35% of WTI have been experienced. The current differential for our light oil production is approximately 7% off WTI, allowing us to benefit from realized pricing that is more favourable than our internal 2013 forecast of US$90/bbl WTI with a 10% differential.
Consistent with the rest of our industry, commodity price volatility will impact our results and we will continue to take steps to mitigate commodity price risks and attempt to optimize our rates of return.
DIVIDEND REINVESTMENT PROGRAM AND SHARE DIVIDEND PLAN
PetroBakken has a DRIP in place that is available only to Canadian PetroBakken shareholders. Our SDP is now available to both Canadian shareholders and most non-Canadian shareholders. The DRIP and the SDP allow shareholders to effectively receive their monthly PetroBakken dividends as PetroBakken shares at a 5% discount to the market price at the date of the dividend payment. Current combined DRIP and SDP participation is approximately 30%.
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