Good day, ladies and gentlemen, and thank you for standing by. Welcome to EnCana Corporation's Year-End and Fourth Quarter 2007 Financial and Operating Results Conference Call. As a reminder, today's call is being recorded. At this time, all participants are in a listen-only mode. Following the presentation, we will conduct a question-and-answer session. [Operator Instructions]. I would now like to turn the conference call over to Mr. Paul Gagne, Vice President of Investor Relations, EnCana. Please go ahead, Mr. Gagne.

Thank you, operator, and welcome everyone to our discussion of EnCana's 2007 fourth quarter and year-end results. Before we get started, I must refer you to the advisory on forward-looking statements contained in the news release, as well as the advisory on page one of EnCana's annual information form dated February 23, 2007, the latter, which is available on SEDAR. I would also like to draw your attention, in particular, to the material factors and assumptions in those advisories. In addition, I want to remind everyone that EnCana reports its financial results in U.S. dollars and operating results according to U.S. protocols, which means that production volumes and reserve amounts are reported on an after royalties basis. Accordingly, any reference to dollars, reserves, or production information in this call will be in U.S. dollars and U.S. protocols, unless otherwise noted. Randy Eresman, will start-off with an overview of our results and then turn the call over to Sherri Brillon, Executive Vice-President of Strategic Planning and Portfolio Management to provide further highlights on our reserve additions. Brian Ferguson, Chief Financial Officer, will then turn over... will then discuss in more detail our financial performance. Following some closing comments from Randy, our leadership team will then be available for questions. I will now turn the call over to Randy Eresman, President and CEO.

Thank you, Paul, and thank you everyone for joining us today. This conference call highlights our performance in 2007, my second year as CEO. As you saw in our new release this morning, EnCana performed very well in 2007 achieving strong overall results. It was a year in which we met or exceeded virtually all of our targets, which we believe is a reflection of the merits associated with EnCana’s strategy, execution, and our disciplined approach to the business. During the year, we accomplished several major strategic milestones. We began the year with the completion of the transaction with ConocoPhillips that gave us 50% ownership interest in two US refineries. It positioned us to pursue a clear, low-risk development plan for our oil resources at Foster Creek and Christina Lake. In East Texas, we solidified our position in the Deep Bossier play in the Amoruso Field with the acquisition of our partner’s interest in the area, a play that we believe will in time become one of EnCana's top resource plays. At Jonah, we had a significant improvement in performance resulting from enhancements made to both the completion technique and to the compression and gathering system. These changes allowed us to increase production by 20% from 2006 levels, averaging about 560 million cubic feet per day for the year. During the year, we expanded our exploration land base in and around several of our key resource plays in both Canada and United States, ensuring a steady supply of future drilling opportunities. Although we succeeded in growing at a significant pace this past year, EnCana's goal is not about being the biggest, it's about having the highest quality assets. As such, we will continue to be disciplined in our approach to acquisitions and divestitures, always with the goal of improving the…

Thanks Randy, and good morning everyone. In 2007, EnCana added 3.6 trillion cubic feet equivalent of proved reserves. Overall, our reserve life index remained at about 12 years. Finding and development costs were $1.65 per 1,000 cubic feet equivalent, a decrease of 17% from 2006. EnCana’s three-year average finding and development cost is about $1.60 per 1,000 cubic feet equivalent, which we believe represents top quartile performance in our peer group and is representative of our longer-term track record. For our natural gas programs, finding and development cost were about $2.40 per 1,000 cubic feet, a decrease of 11% from 2006, again a very competitive result. Our reserves continue to be 100% externally evaluated by independent qualified reserve evaluators, not just reviewed or audited. By commodity and by geographical region, revisions to opening balances were positive. Substantial additions and positive revisions in Canada were largely attributable to development drilling and optimization activities in Cutbank Ridge, Bighorn, coalbed methane, and Shallow Gas with respect to natural gas, and in Christina Lake and Foster Creek with respect to crude oil. In the United States, substantial natural gas additions and positive revisions were largely attributable to development drilling and optimization activities in Jonah, Piceance, and Fort Worth. In total, drill bit additions, that is extensions, discoveries, and revisions, are 3.4 trillion cubic feet equivalent or about 10% higher than in 2006, while the associated capital expenditures in 2007 are $5.6 billion or down approximately 8% year-over-year. Natural gas related drill bit additions of some 2 trillion cubic feet were equally split between Canada and the United States, approximately 90% of which were from our key resource plays. While we are focused almost entirely on North America and predominantly in natural gas, our operations are diversified across the continent located within most of the major and emerging producing basins. This diversification reduces operating risk in our portfolio and exposes us to opportunities created by ourselves as well as others. This diversification is also reflected in the average production efficiency we achieved for our natural gas portfolio of about $6300 per thousand cubic feet per day. For 2008, this figure is estimated to be about $6100 per thousand cubic feet per day. Overall, I believe that this figure highlights the relatively low cost organic growth capability associated with our asset base. I will now turn the call over to Brian Ferguson, our Chief Financial Officer, who will discuss our financial results in more detail.

Thanks, Sherri. Good morning everyone. I'm excited to talk to you about our excellent 2007 financial results. For the year, cash flow exceeded our budget and we beat our guidance to the market. Operating earnings were very strong. We continued our industry leading cost performance, despite the skyrocketing Canadian dollar. Our total price realizations benefited from our hedging strategies, increasing our overall netbacks by about $1 per thousand cubic feet equivalent for the year. Cash flow exceeded total capital investments, excluding A&D activity, by more than $2.4 billion, which was enough to fund share purchases under our normal course issuer bid of 5%, and we doubled our annual... our quarterly dividend in 2007 to an annual amount of $0.80 per share. As Randy mentioned, we have doubled the quarterly dividend again this year. Now, focusing on our fourth quarter, cash flow of $1.9 billion increased $173 million, primarily due to an increase in netbacks after hedging, higher volumes from upstream operations, and our new downstream division added another $180 million of operating cash flow before tax in the quarter. Operating earnings of $849 million were up a $174 million from 2006. Increases in upstream and downstream operating results that I outlined in the cash flow were somewhat reduced by higher DD&A, which is largely due to the foreign exchange, high Canadian dollar, and a $44 million impairment of our France assets. Net earnings were $1.082 billion in the quarter, up $419 million from 2006. In addition to the items I just mentioned, net earnings increased due to a federal tax rate recovery and a realized foreign exchange gain variance from the prior year. Offsetting the positive variance is a swing in the unrealized mark-to-market gains, reducing net earnings by about $460 million [ph] after-tax in the fourth quarter. For the…

Okay. Thank you, Brian. As I stated earlier, our 2007 results are very positive, a credit to our strategy and to our teams across all of EnCana. I would like to take this opportunity to thank them all for a tremendous year for delivering on our goals and for the way they've represented EnCana in all the communities we conduct business. They have done so with pride and in a professional, caring, and respectful manner. Thank you for your contributions in 2007, and I look forward to another strong year ahead. During 2007, we continued to demonstrate what we believe to be industry-leading performance in the development of unconventional natural gas and in situ oil recovery. We believe that strength, stability, and profitability of our approach to these businesses is becoming clear and better recognized by both industry and investors. We’re continuing to focus on a moderate, sustainable pace of growth, capital discipline and return of excess cash to shareholders during through an ongoing program of share purchases and planned dividend increases. This is our strategy, this is our business, and this is our culture. For 2008, our operating challenge remains excellence in execution and that continues to be our focus. Overall, our shareholders should expect the same consistent and disciplined approach that we have demonstrated over the past years to continue in 2008 and into the future. Our spending and production growth plans are consistent with our strategy of executing with excellence and generating sustainable growth. In 2008, we expect total production to average about 4.6 billion cubic feet equivalent per day, which is about a 5% increase over 2007. Natural gas production is expected to grow by 6% year-over-year to about 3.8 billion cubic feet per day. Overall, we expect that our key resource plays will continue to drive growth with production forecast to increase by 13%. Operationally, we are very happy with the current run rate for operations and the resulting production growth and flexibility that it provides in allocating capital. Commodity prices have been volatile, but we remain bullish on natural gas in North America. I'm often asked how we would react to an increase in gas prices. My answer should not be a surprise. If short-term commodity prices exceed our expected range for the year and we generate greater cash flow than forecast, we expect to use those incremental proceeds to buy back additional shares or pay down debt. f we believe that a longer-term structural change occurs in North American commodity prices and the potential exists for our margins to expand on a sustainable basis, we plan to use that additional free cash flow to increase our dividend. This is how we believe that we can best create sustainable value for our shareholders. Thank you for joining us today. Our team is now ready to take your questions. Question and Answer

[Operator Instructions]. And our first question comes from Brian Singer with Goldman Sachs.

Thank you. Good morning.

Good morning.

Randy, just following up on your last couple of sentences there, if short-term commodity prices increase, you buy back stock or pay down debt and longer term you would increase the dividend, no increase in drilling mentioned there. Can you talk to the constraints rig permitting people potentially and why you wouldn't do that even if your long-term gas price forecast increase based on your rate of return decisions?

As we’ve talked about in recent years, we believe that having a long-term sustainable growth rate at about 5% allows us the greatest amount of flexibility in our portfolio to create the largest long-term return to the shareholder, and that by using excess or free cash flow to buy back shares we'll generate a significant overall per share growth for the company. Having that level of flexibility has been a tremendous asset to the company in portfolio management in this past year, and we expect that on a going forward basis it will create many, many opportunities for us to maximize profitability from our portfolio.

If service costs do begin to tick up again, would you be prepared to lay down rigs or you would just maintain your level of activity and use the additional cash flow for drilling, without an increase in --?

If we saw the activity levels getting into the pace of growth that we saw in 2005 and 2006, we would definitely not try to chase production. We would tend to try to manage the situation as best we can and we would give up production growth for profitability in that scenario. And then, what we have done in other hand… another situation when activity levels tend to fall as they are in Western Canada, EnCana is the company that's basically drilling right through it, taking advantage of those lower costs.

Right. I apologies if this was discussed earlier. Costs seem to tick up a bit during the quarter, LOE, DD&A, SG&A. Could you speak to what drove that?

Yes, as Brian Ferguson pointed our, the cost increases that we saw fourth quarter over fourth quarter were primarily due to the significant run-up in the Canadian dollar against the US dollar, that had the majority impact, but then we also have long-term in the sense that we charged against operating cost and because of depreciation of the cash share price throughout the year that had a cost impact on operating costs, but when you remove those two items and compare it to 2004, you we’d actually found that our operating costs would have been down. And all of this was within in our guidance range anyways. So it shouldn't be really unexpected.

Okay, last question. Should we expect any additional acquisition activity or should we look at your acquisition as one-time?

Brian, we don't have anything that's a major plan right now. If there were opportunities that came up throughout the year we would certainly look at them, but you would have to consider the same kind of opportunities that we've been looking for in the past. These have been in joint operations that we know very well. And since most of the operations that EnCana has were effectively close to 100%, there aren't that many of those kind of opportunities in our portfolio.

Great, thank you.

Thank you.

Our next question comes from Mark Gilman with Benchmark.

Guys, good afternoon. I had a couple of things. Randy, I just want to clarify that I heard you correctly. In terms of your comment about first quarter this year, production has been roughly comparable, I think you said to the year-ago, which would imply some fairly significant… a fairly significant decline from fourth quarter. Is that indeed what you indicated?

No. Sorry, Mark, if I said that I didn't mean to. We would expect it to be relatively flat from fourth quarter 2007 to first quarter. That's generally a pretty normal event in our industry.

Okay, thanks. That helps a lot. Secondly, is it possible to give us a rough idea what the year-end '07 reserve numbers might look like under the new Alberta loyalty regime, assuming a similar price level?

No. We haven't done that yet because the regulations have not been put into... I guess into effect yet, and there are still some changes that are likely to occur before they are finalized. We have done some preliminary assessments and the impact for us because the majority of our land-basin activity is on land that we own, pretty simple, the impact for us is not all that significant.

Okay. Finally, just one other one on the reserve picture, is it possible perhaps to give us an idea for the natural gas reserve increases, how they break down between increase and recovery rate on the one hand versus increase and in-place type assessments on the other?

I don't think we have that kind of detail just readily available. It'd be something we could provide more if you want to have a detailed discussion on a play-by-play basis outside this conference call.

Okay, Randy. Thanks very much.

Okay. Thanks, Mark.

And our next question comes from Stephen Calderwood with Raymond James.

Yes, good morning. I noticed... well, everyone has noticed your increase in capital or sort of an operating cost in Q4. And as you mentioned, it's well within the context of your guidance. In fact, on the gas side, it looks like your full year operating costs were about $0.03 lower than your guidance of $0.85. So I guess at least a question if I could on the future guidance, you are calling for $0.95 operating cost in 2008. Is most of that increase in operating cost again due to foreign exchange or do you characterize certain amount of that increase due to cost inflation?

I'm going to turn that over to Brian Ferguson to get a little bit more detail on it, but there are a number of things that continue to influence operating cost. Certainly, one of them is just energy cost in general being higher. That flows through because there is a lot of transportation related activity when it comes from operating cost. We've also seen a pretty strong uptick in property taxes in the last couple of years, and that's is having fairly significant influence, particularly in our Canadian operations. And for some additional detail regarding FX I am going to turn it over to Brian.

Hi, Steve. The [inaudible] that we are forecasting in increase is labor component as well in 2008 versus 2007, but again the lion’s share of the increase is related to the US Canadian-dollar. We saw it averaging about $0.93 last year in 2007 and we are forecasting $1. As I said, we will see what happens there. Again, I would emphasize that you have to distinguish between the economic versus the reported, the actual reporting disclosure impact in our Canadian operations, because we report in US dollars we won't see quite the same impact. There is also probably a slightly higher impact from property and mineral taxes.

And that's your...

We're also forecasting our stock price to go up, so we've built that in as well.

Stephen, this is a great opportunity for me to also mention that despite the increases that we have observed in operating costs and likely industry will be exposed to the same ones. EnCana continues to have amongst the very lowest operating cost in the industry and that's a direct relationship of the unconventional resource plays that we pursue in their low cost nature.

Okay, great. If I may ask, you mentioned your recent success at drilling in the Amoruso Field, and I just wonder if you're still planning on drilling outside the core areas there? I think you are planning on drilling a well in Louisiana?

I am going to have Jeff Wojahn, our President for US division, speak to that.

Hi, Steve. It’s Jeff. We have plans… I think it was stated said earlier that we are going to drill three or four exploration wells on the Jurassic Trend or on the Amoruso Trend. We haven't drilled any yet or spud any, but that's our intent. We do as you know have a very large lion position on the trend, 180,000, 190,000 acres. So we would like to get around to valuating that land, and we have some exiting prospects developed. So as we have results I think we'll keep you posted.

Do you mean later in 2008?

In 2008, yes.

Thank you.

Thank you.

If there are no more questions from the financial community, then we will now take questions from the media. [Operator Instructions]. Please standby for the next question. Our next question comes from Pat Roche with Nickle's Energy Group.

Hi. I’ve just got a couple of hopefully brief questions. First question is your Canadian gas production is forecast to be down about 5% for this year. Can you give me a breakdown by property, how much of the decrease will occur at which property in Canada?

Okay--.

Gas production?

I'm not sure that I will be able do that right off the top of my head here, but I can generally say that in the Foothills Region, we are continuing to see some growth. It really is largely driven by our BC properties, and in our plains division, our more matured natural gas properties are in somewhat of a decline. I’m going to turn it over to Don Swystun to elaborate on that. And Mike McAllister is here and he is sitting in for Mike Graham, he can maybe provide a little bit more color on the production changes in his division… the Foothills division.

Hi, Don Swystun for the plains. Just… obviously our biggest producing resource play is the shallow gas and we produced around 726 million a day in '07 and we are targeting right now about 675 million a day for '08. So that's the decrease you will see.

This is Mike McAllister with the Foothills division. Our production growth will be larger in BC than in Alberta, but I think across the entire division we’ll slightly flat to a little bit increasing. Our biggest growth areas would be in Cutbank Ridge and as well as in Greater Sierra a little bit.

And my next question is you are forecasting a 23% increase in U.S. gas production. How much of this is due to the Bossier acquisition?

I'll turn it over to Jeff Wojahn to answer that.

Yes. Hi, Pat. It's Jeff.

Hi, Jeff.

I would like to give you kind of a perspective of where we are and where we're going because I get this question a fair amount, but last year our production averaged for the year 1340 million cubic feet a day, where our current production is just over 15.10 million [inaudible] cubic feet a day and we are forecasting to average for the year in the 15 to 16 range. So of that 23%, we have already experienced 14% or 15% as we've gone through. So it’s a function of a growing profile and also a function of the acquisition at Amoruso that we conducted in the fourth quarter last year. The primary growth areas for the remainder of the year will be from the East Texas area complemented by our Fort Worth program our Jonah and Piceance areas.

Thanks. And my third question was sort of tying the two together to some extent. You mentioned… Randy, you mentioned the low rig count in Canada and the high rig count in the U.S., and I know this was happening before Alberta announced its royalty changes and it has been the case for some time. I guess we've had a slowdown here now for the past 1.5 years at least, that the U.S. just keeps on at the same fairly rapid pace. Can you tell us a little bit about the reasons for that? How much is due to dollar, how much is due to the other factors, can you just discuss those?

The differences as you point out that started to emerge prior to the royalty review were largely due to the Canadian dollar. If you look back four or five years, the Canadian dollar has appreciated like 40%, 50%. So that has had a significant impact. Of course, that does increase the purchasing power to some extent of the Canadian dollar, but that takes a longer period time before it moves through. The other impact of course has been that operating costs in Canada have been... tend to move higher because of the strong level of activity throughout all of Alberta, the construction activity and the activity related to oil sands. Despite having a fall-off in conventional oil and gas activity, we haven't yet seen labor costs coming down to a degree that they would need to be in order to have activity pick-up significantly. And then, there are some other issues as well. A number of the targets that Canadian companies have been chasing in the last number of years tend to be a little bit smaller in nature when we compare it to the kind of targets that we have in our U.S. activity. So production efficiency tends to be a lot better in our U.S. operations in general. And so that would tend to be one of the reasons why U.S. activity levels are higher than Canadian. But then you really have to go back a little bit farther and say, part of this was definitely caused by the changes to the royalty trust, which has reduced the activity level there and then the impact that, that had subsequently on the junior sector. So a lot of things have changed. We can't point at one individual thing. And then, the changes to... pending changes to royalties just are one more compounding effect.

Okay, just one last question with a very quick answer. Can you give any kind of ballpark estimates when you would be able say something about BC shale gas?

We certainly have a few more wells into the play by the end of this winter's drilling season, but I'm not sure if at that point it will be enough information for us to make any significant determination. It is an early life exploration play as far as we're concerned.

Okay. Thanks very much.

Thank you.

Our next question comes from Ian McKinnon with Bloomberg News.

Hi, a couple of quick questions. Randy, any size and scope on divestitures this year, after you said Leor acquisition, you would look at maybe selling up to $500 million. I'm wondering if you've got any better clarity on that issue?

Yes. Our intention at this point in time to look at a potential disposition of $500 million worth of assets. We've got I think about half of them already targeted for sales, the other half we're in the process of putting together packages that will be... that will come out throughout the year.

And any areas like Canada, U.S., where are you looking at selling assets?

Well, we have some reason is in both Canada and United States to sell some of our smaller and more scattered assets. I think we would consider to be non-core, due to the packages themselves could end up being quite a bit larger or smaller than that $500 million depending on how we view the market conditions and the opportunities at the time.

Okay. The other question I have, you said you're bullish on natural gas prices into '08. Given that most people think the U.S. is heading into a recession or is in recession, I'm just wondering why you're “bullish?”

Okay. So there is a lot of reasons beyond the issue, whether or not the U.S. is moving towards a recession. Some of those issues of course are related to Canadian supply making it into the U.S. markets. That we expect would be off as much as 1 bcf per day over the course of the next year. We've also seen L&G imports coming in at a much lower level that we saw during the 2006 year and that's a direct result of increased demand for L&G on a worldwide basis. But also because the switches occurred this past year where the winter in Europe tends to be... is tending to be a lot colder than it was previously and so there is a stronger demand in Europe and higher prices. So those cargos simply are not making it here. And then we're also seeing what appears to be a slowing in the overall production growth in the United States, at the same time that we're seeing continual increases in electrical demand. So nothing for us in the near-term suggesting anything other than a positive impact on natural gas, and sort of the proof that you have right now is the way in which natural gas storage levels have continued to drop at a fairly significant pace relative to last year and moving closer and closer to that five-year average. So all of that is tending to have an impact on the market and people are starting to see an uptick in futures prices for natural gas.

Thank you so much for your time.

Thank you.

And our next question comes from Jon Harding with The National Post.

Good morning. Two questions please. The first is, with this declining business climate that you're seeing in [inaudible] in Canada, I'm wondering with your opportunities that you see in the U.S. is it still strategically and financially advantageous for EnCana to be based in Canada? Can you comment on that?

We are a Canadian headquartered company. Our head office staff are all located here, and it's quite an effective place to run our overall business. Despite all of the other impacts that are happening in the industry, EnCana still has a very, very strong and very, very profitable production base in Canada and we see tremendous amount of opportunities for growth in unconventional natural gas place both in Alberta and in British Columbia. And we do see a long-term business with our steam-assisted gravity drainage oil recovery.

Okay. The second thing I want to ask is The Bow, the office tower. Is that still on track? Are you still planning for a 2010, 2011 move in?

I believe so. I am going to have Gerry Protti give some color to the answer.

Hi, Jon. Yes, we're still on track. As you know, we've got a large excavation underway and all of the planning is following the correct schedule. So we still plan to be in, in 2011.

Okay. There are... and comment or not on this, but there are rampant rumors in Calgary Downtown that the building is not progressing as planned.

Those are not true. We are moving ahead.

Okay. Thank you.

Our next question comes from Norval Scott with The Globe and Mail.

Good morning. Randy, you mentioned that people need to work together to re-establish the competitiveness of Alberta conventional oil and gas. I was wondering what you think actually needs to be done for that to happen?

Well, there are just a litany of issues that need to be worked through in order to make the Canadian oil and gas industry, particularly in Alberta, more profitable or profitable enough to incent the activity levels. And since it is not just one thing as I outlined before, it’s a number of different issues related to… primarily related to expectations that need to be worked through, and the more effectively that those can be worked through, the level of activity can be increased again.

Do you have any expected timeline for recovery in the sector? When will these issues might be worked through?

I think one of the issues will be with the government dealing with the unintended consequences of the changes to the royalty regime in the province, that's definitely one. There is some landowner expectations that need to be changed in the future as well, that can allow for more activity and allow for I guess an improvement in the investment climate.

Okay. Finally--?

Gerry Protti is going to add a little bit to this as well.

Okay.

Norval, Gerry Protti here. Just to add to what the issues that Randy outlined, I think one of the areas that government, stakeholders, and the industry ought to come together and discuss is changing nature of the resource base. The conventional industry that grew this province over the last 50 years is rapidly declining and disappearing, but as Randy mentioned in the conference call, there is this huge unconventional base, be it unconventional natural gas or unconventional oil, it is an area that people don't understand as fully as they need to. The cost pressures are different, the implications the way its developed its different. And we know that there is increasing environmental pressures and trade-offs associated with it, and the balancing of the economics of that business with those environmental expectations I think will be an area that we are going to look forward to participating in the debate with government.

Okay. One final question, do you think this sector can improve without EnCana increasing its investment in oil and gas [inaudible] going to expanded its trading in Alberta? I guess what I am trying to get is does the sector rely on you?

I'm sorry, you really broke up and we couldn't understand your question at all.

Sorry. I guess I'm trying to ask to what extent does the recovery depend on EnCana coming back with investment into the sector?

I see. We're still a very strong investor in Western Canada and just an improvement in price will itself increase our activity levels on our key lands and lands are not affected by their current royalty structure. But when it comes to just the general industry issues, there need to be improvements so it can be competitive with the rest of our portfolio before we substantially increase our investment. But EnCana makes up 20% roughly of the industry activity in Western Canada. So that's a kind of influence that we could have.

Thanks very much.

Thank you.

Our next question comes from David Ebner with The Globe and Mail.

Hi, Just two questions. On the unintended consequences, what sort of tangible result are you hoping for?

Well, I'll again turn it over to Gerry Protti.

Hi, David. I think the areas that people… the industry have identified and had discussions with government had been around the economics of deep basin… gas for drilling for deep unconventional opportunities.

So I guess on that one maybe even specifically, how would you like to see maybe the proposed royalty curve change or are there drilling breaks you're looking for or well by well or...?

Well, I don't think we can get into the specifics. I think it's a question of… the fact that the government has received input from individual companies, from cap, the trade association, and they've worked through it. I think we're... our expectation is post election that we are going to sit down, look at areas like those deep gas drilling opportunities, maybe unconventional sources like development of various like mantle [ph] coal, deep oil opportunities. So what we're expecting is a round of discussions, and I suspect that through the selection period the department is working through all the different alternatives and options.

I guess you are looking for… to have the royalties lowered on all those topics?

Well, I think the royalties have been increased significantly and the royalty regime… our expectation is... will reflect the costs... the higher costs of developing those resources.

Yes. I'm not so sure they were looking for a decrease in royalty, but it certainly is important for lot of these early life players that the frond end loading of the royalty rate be less. Longer-term, we could pay higher royalty but it's really the timing of the royalties that's important.

Okay. And then on subfields with the hearing coming up next month, how confidant are you that the company can be successful, and if it is when does drilling perhaps start?

The hearing starts in mid-March, and VIS [ph] that we prepared for that David is probably one of the most extensive environmental impact statements that any company has prepared for any C application. We're hoping that in the course of the hearing that it will be clearly demonstrated to the panel and to everyone accessing it that we are very confident that we can do that infield drilling on the NWA and do it with minimum environment impact and demonstrate kind of improvements in technology as we go through.

And then, if you're successful when would you hope to start drilling?

Next year.

Okay, great. Thank you.

Okay. Thank you, everyone for joining us today to review EnCana's fourth quarter and year-end results. So our conference call is now complete.

Ladies and gentlemen, this concludes the conference call for today. You may all disconnect your lines, and have a great day.