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So with this backdrop, I'm happy to report that our portfolio -- the indispensable natural gas infrastructure performed even better than expected this past year as we once again came in at the top of our guidance ranges for key financial metrics. In fact, we achieved an all-time record for adjusted EBITDA in 2018 even in the face of asset sales totaling more than $4.6 billion over the past 2.5 years, and these transactions continue to reduce our commodity exposure and continue to improve our leverage metrics for WMB. And all the while, we funded growth over the past two years without the need for equity issuance.

So, as you may recall, we started 2018 setting delivery records on Transco, which would now, in 2019 eclipsed once again during the record cold snap that impacted our markets last week. And in 2018, Northwest Pipeline also hit an all-time record for annual throughput, eclipsing the prior record by 5%. So we are seeing the impact of all this increased demand showing up on our pipelines obviously. We had a timely and crisp execution on the critically important WPZ roll-up transaction, reestablishing Williams as a simplified C-Corp with investment-grade credit.

We continue to make great progress overcoming a highly challenging regulatory and permitting environment, placing critical new Transco projects in services like Garden State, Atlantic Sunrise and just recently the Gulf Connector. And we continue to make progress advancing the extensive next generation of Transco, fully contracted projects like Southeastern Trail, Rivervale South to Market, Leidy South, Northeast Supply Enhancement, Gateway and several other Transco projects that we've not gone public with yet.

Late in the year, we saw the beginnings of the accelerated Northeast G&P growth. We expect to continue for many years to come as the takeaway cloud finally has begun to lift off this basin. We expected our -- sorry, we expanded our ESG disclosures on our website, kicked off project to further expand our ESG disclosures in 2019 and further strengthened our exceptional Board of Directors with two new appointments.

We continued to exercise capital discipline passing up many opportunities, but executing on others like our entry into the DJ Basin, which was funded through our exit from our legacy Four Corners position and we are now set for continued value creating portfolio optimization here as we begin 2019. And once again, despite increasing commodity price volatility in the liquids markets our low-cost natural gas based business strategy has us positioned well for further predictable growth here in 2019, and importantly, today we are reaffirming the 2019 guidance that we provided in May of last year.

So with that quick look-back at a very busy 2018, let's move to Slide 2 and take a closer look at our financial performance versus 2018 -- for 2018 versus our guidance. Here on Slide 2, you can see that we've shown how we finished the year relative to our 2018 guidance ranges. Although our GAAP net income was affected by a large impairment on our Barnett gathering system, you can see that adjusted net income exceeded the midpoint of guidance and our adjusted EPS, which was at the high end of guidance showed strong growth in 2018 of 25% over the 2017 EPS.

Despite selling $1.3 billion in assets that was not accommodated for in our plan back when we made that guidance, our adjusted EBITDA, DCF and dividend coverage ratio all reflected strong performance at the high end of our guidance range. You can see that our growth CapEx spending came in about $300 million under guidance and that was primarily driven by shifts of capital out of 2018 and now into 2019, so when we get to our 2019 guidance you'll see an uptick, which was just the timing of that $300 million moving from 2018 to '19. And finally, with respect to leverage you can see a nice outperformance with year-end leverage at 4.8x. So once again, as was the case in 2017, our financial performance was quite good as compared to our guidance. It was another year where we delivered on expectations, including steady, predictable and growing cash flows, while improving the balance sheet.

On the next couple of slides we'll quickly break down the major drivers of our financial performance for the fourth quarter and the full year, so let's move on to Slide 3. First, looking at the fourth quarter GAAP numbers on the upper portion of the slide, we see that the year-over-year comparisons were affected by some large accounting entries, which have been adjusted out of our non-GAAPs. Specifically, in 2017 we had some large positive accounting entries related to Tax Reform; and this year we have a large revaluation on our Barnett gathering system, somewhat offset by gains on asset sales.

Looking at adjusted EBITDA in the lower portion of the slide, we see that the nearly $1.2 billion of adjusted EBITDA was up little more than 3% versus 2017, but up 9% if you normalize for revenue recognition changes and the sale of our Four Corners system. Looking at the bridge then, once adjusted for the revenue recognition changes and the loss of Four Corners, which are shown in gray, you can see that our adjusted EBITDA increased almost $100 million where strong increases in our Northeast and Atlantic-Gulf segments were somewhat offset by a lower quarter in the West. So it's really great to see the Northeast and Atlantic-Gulf adjusted EBITDA numbers growing by 28% and 22% respectively. Atlantic Sunrise was a big driver of course for Atlantic-Gulf and the Northeast saw about a 13% increase in volumes led by increases in Northeast Pennsylvania area, but also we saw good growth in Southwestern, Marcellus and the Utica area as well.

So as we look at the results for the West, you have to be mindful of the pretty dramatic effect that the sale of Four Corners had on our reported gathering volumes. So specifically, if you look at our analyst package, you'll see that the West gathering volumes are down about 22% sequentially from 3Q and that our full year 2018 volumes are down about 4% from 2017. However, if you exclude the Four Corners volumes, then we are flat year-to-year and down only 3% versus the third quarter of 2018, and of course that was impacted we did have some freeze-offs in Wyoming here in the fourth quarter of 2018.

Additionally another big driver for the West in fourth quarter of 2018 related to about $25 million unfavorable swing in the EBITDA of our NGL marketing business, which was driven by the drop in the value of the inventory that we hold per line fill primarily out West. The value of this near-constant inventory changes every quarter as we mark this product to market prices from one quarter to another.

So now let's turn to the full year 2018 results and go to Slide 4. Starting with our GAAP results in the upper portion of the slide, we see that the large accounting entries we discussed on the prior slide are also driving the year-over-year comparisons. So again, tax reform entries, gains on sales of assets and impairment entries make it a little tough to see the performance of the ongoing business. So let's look at the adjusted numbers where these items have been excluded. First off, I'd just highlight again that 25% growth in adjusted EPS, which grew from $0.79 -- sorry, which grew to $0.79 from $0.63 in the prior year.

Looking at the bridge on adjusted EBITDA, you see in grey the effects of lost EBITDA from the Geismar assets we sold in 2017, the changes in revenue recognition accounting rules and the loss of EBITDA from the Four Corners assets we sold in 2018. So once again, adjusted for revenue recognition changes and the lost EBITDA from sold assets you can see that our adjusted EBITDA increased a little more than $300 million, driven by strong increases in our Northeast and Atlantic-Gulf segments. Growing volumes in the Northeast Pennsylvania and Southwest Marcellus and the Utica areas, all drove the higher Northeast segment results. The Atlantic-Gulf segment growth was again driven by Atlantic Sunrise, but a number of other projects that came on for a partial year in 2017 also drove higher results in 2018.

So now let's move on to Slide 5 and quickly recap some of the more significant and recent business developments. This slide showcases our recent accomplishments demonstrating strong project execution, continued permitting successes, operational excellence and strategic transactions at the corporate level. Our teams have done an outstanding job of bringing key expansion projects into service like Transco's Atlantic Sunrise and Gulf Connector projects, one other project that I'll highlight on the list is our Norphlet project in the deepwater Gulf of Mexico. It's great to see some major new deepwater volumes coming mid-year as our Norphlet project serving Shell's Appomattox field in the Eastern Gulf gets up and running. With the completion of these three projects, the majority of our project execution risk that is behind our growth drivers for 2019 have been squared away.

So on the permitting front we have also seen great progress despite the difficult environment. Northeast Supply Enhancement received its FERC FEIS. This was a critical permitting step for a project that will support the conversion of heating oil to clean burning natural gas for the New York City and the Long Island areas. Transco's gateway expansion was another project that hit a key milestone, receiving FERC approval to expand existing pipeline to help New York and New Jersey meet growing natural gas demand needs in time for the 2021 winter. And most recently our Southeastern Trails project cleared the environmental assessment hurdle at FERC. This is another example of Transco's tremendous advantage of having existing right-of-ways in all of the right places.

Operationally, our Northeast G&P segment increased gathering volumes by 13% from fourth quarter of 2017 to fourth quarter of 2018 and this was driven primarily by several gathering expansions of our Susquehanna system, as well as incremental takeaway capacity for Northeast Pennsylvania. We will continue to see volume growth on our Northeast systems into 2019 and beyond. Our Transco expansions helped Transco deliver a record amount of natural gas setting its peak day mark of 15.68 million dekatherms on January 21st of this year.

Transco also set a new three-day mark from January 30 to February 1st, the recent project conditions across the country and an important reminder of the vital role transmission pipelines play and delivering natural gas to keep millions of Americans safe and secure, and I want to take a moment to recognize the great employees that are there, working behind the scenes to make that happen, it's not a simple task and it takes a lot of dedication and we certainly have that from our employees here at Williams.

And speaking of records our Northwest Pipeline also hit an all-time annual record delivery of 820 trillion BTUs versus the previous annual record of 781 trillion BTUs. So a tremendous job our Northwest team as well as they overcome some major supply outages in Canada from third-party pipelines coming in and we're able to manage around that and keep the heat on for our resonance in the Northwest area as well.

Looking down the list, you'll see our Bluestem project, which we announced yesterday afternoon. Let's move to slide six to take a closer look at the newly announced project Bluestem. We've got some good detail on this slide about this exciting new project, which will provide all new connectivity between vast Western NGL supplies and premium Gulf Coast markets. This strategic partnership provides for a great opportunity to really strengthen and expand our NGL transportation and fractionation business. We are pleased to partner with Targa on this NGL infrastructure solution that creates an integrated solution, and a platform for growth for both parties.

Expanding our NGL pipeline business to interconnect the Targa's strategically positioned Grand Prix pipeline will provide Williams and our customers with access to Mont Belvieu while opening up additional markets for Conway attracting new volumes to both our Overland Pass Pipeline system and to Conway fractionation and storage assets, and will provide Williams with 80,000 barrels to 120,000 barrels a day of firm access to Mont Belvieu. Additionally, this delivers a long-term infrastructure solution for NGLs from our Opal, Echo Springs, Willow Creek and our new Rocky Mountain Midstream systems in the DJ Basin, while also creating a platform for growth offering us the opportunity to gain incremental downstream revenues as we expand our G&P business. We are targeting an in-service date of the first quarter of 2021 for this project.

Additionally, I would point out that in connection with this project, Williams will also have an option to purchase initially a 20% equity interest in one of Targa's recently announced new fractionation trains, train seven or eight in Mont Belvieu. Our goal is to be well aligned with Targa in maximizing the value of our collective assets in Conway and Mont Belvieu and the piping in between, and to offer attractive service offerings to our processing customers in the West. We expect our investment in these NGL Logistics projects to be $350 million to $400 million with most of that spending that will occur in 2020.

And now let's move on to the next slide to review our 2019 financial guidance. As we previously discussed, we are reaffirming our 2019 financial guidance with the exception of growth capital expenditures. Of course, much has changed since we originally issued 2019 guidance last May, specifically, we sold our large-scale Four Corners system and entered into the DJ Basin where the system there that we now operate was still in the early stages of its continuing expansion and development. And we and our producing customers of course saw a 28% decrease in crude and NGL prices from August until year-end.

Really the key point here is that the stability and predictability of our natural gas infrastructure focused strategy has allowed our 2019 guidance to hold in there very well even as we've continued to optimize the portfolio and have seen lower pricing environment for our producing customers. As a result, our 2019 guidance for financial performance remains unchanged. And much of the project execution risk for 2019 is already put crisply behind us, ASR Gulf Connector and our Norphlet facilities, as I mentioned earlier, all now completed. So as I previously mentioned, we are revising growth capital expenditure guidance from $2.6 billion to a range of $2.7 billion to $2.9 billion, and that's really just the timing shift of some of the amounts we didn't spend in 2018 that got shifted into 2019.

The last thing I will say about 2019 is that we remain very focused on improving our credit metrics. To that end, we will continue to exercise capital discipline and to pursue portfolio optimization transactions, much like you saw in 2018. And of course, our strong cash flows and continued string of asset sales has allowed us to fund the equity side of our growth capital needs.

So, with that update, let's move on to the last slide, Slide number 8 and wrap up and then we'll take your question. On this last slide, we've again just laid out a few of the highlights from 2018, which was a very important year for Williams. It was a year where we beat guidance, returned to a simplified C-Corp investment-grade infrastructure company, completed the largest project ever on Transco, progressed on deleveraging the Company and made continued progress in optimizing our portfolio. Also in this last slide, we've summarized some of the things on our mind here for 2019. We look forward to another year of strong natural gas demand growth. We also look forward to showing how our business can deliver cash flow stability and predictability during times when the crude markets are volatile and sagging.

We continue to be pleased with the opportunities we are closing on in the DJ Basin. Thanks for the great work of our Rocky Mountain Midstream team that has done a great job of establishing themselves in the area as well with our customers up there. As an example, we just executed a new gas gathering and processing agreement for an additional 5,200 acre dedication, that is fully permitted in the DJ. To support this development, we'll be expanding our gathering, compression services in the basin as we expect to open up additional near and long term opportunities for our Midstream Services in the DJ and we will have two new processing train starting up this year as well, one of which is entering the commissioning stage and the other at Kingsburg where construction activity is progressing according to plan.

Look forward to another year of advancing the important Transco projects that you are aware of, and to introducing you to new opportunities for the nation's largest and fastest growing natural gas pipeline and we look forward to another year of strong Northeast G&P volume growth. And last but not least, we will continue to delever. We will do this through solid execution of our business plan, which allows us to reinvest excess cash flows into new growth opportunities. But we will also continue to vigorously pursue portfolio optimization activities in support of this efforts delever.

And finally, I also want to let you know that we've taken a look at the timing of our Annual Analyst Day and we'll be making a shift from the May timeframe to something later in the year. The major driver of this move is to really make sure that our Analyst Day follows up our annual board strategy session which is in August. So we think that's a nice move to governance and simplifying our internal process to be able to roll right from our annual board strategy session into guidance.

So with that, let's go ahead and turn it over for Q&A.

Questions and Answers:

Operator

Thank you. (Operator Instructions) And we'll take our first question from Shneur Gershuni of UBS.

Alan Armstrong -- President and Chief Executive Officer

Good morning, Shneur.

Shneur Gershuni -- UBS -- Analyst

Good morning. Just wanted to start off on the new project that you announced last night. On a go-forward basis, do you expect to aggregate more barrels? And could you see a need for greater than a 20% stake in a frac? And also, any sense on what the stack rate would be to get the Y-grade all the way to Mont Belvieu?

Alan Armstrong -- President and Chief Executive Officer

I would say first of all on the volume growth, yes, we did build in the flexibility in our relationship with Targa to build expand our volumes as we need to, both on transport capacity as well as on the investment in the fractionator. So, and I would say that we definitely are seeing a lot of opportunity to continue to pick up new barrels out of both the DJ and the Rockies. And so we're pretty excited about that. And obviously, we like the fact that Conway becomes an important center now as we open that up to new market. So we're pretty excited about that alternative.

Shneur Gershuni -- UBS -- Analyst

Okay.

Alan Armstrong -- President and Chief Executive Officer

And then on the -- I would just say on the rate, we're not going to disclose that, but I would say it's very competitive and we're very excited about it, about the way that rate is structured and again I think Targa saw this as a long-term strategic relationship with us and likewise, and so we see this as a great opportunity to maximize the combination of our assets at Conway and Belvieu.

Shneur Gershuni -- UBS -- Analyst

That makes sense. And given your new partnership with Targa, do you see an opportunity to expand the relationship with respect to gas takeaway out of the Permian, given that both companies have been exploring different gas takeaway solutions?

Chad J. Zamarin -- Senior Vice President, Corporate Strategic Development

Yeah, hi. This is Chad Zamarin. I would just say that -- we continue to, I think, if you look at our recent announcement with Brazos Midstream system in the Permian we continue to focus on the Permian and I would just say, we're going to continue to be disciplined and there have been two projects that have been announced coming out of the Permian to move gas to the Gulf Coast. But, we continue to look at options, the Brazos system provides us much like the move that we made into the DJ and the ability to move downstream from that position, the Brazos system provides us with an opportunity to continue to develop projects that would move to the Gulf Coast. And I would say that we are likely if we do move forward the project of that sort to partner with others in order to make it a most efficient project. So we continue to work in that manner.

Shneur Gershuni -- UBS -- Analyst

Great. And one final question. When I think about your CapEx guidance for 2019, I know it technically goes up from the prior guidance. But when I think about it on an apples-to-apples basis, you have some rollover from 2018 into 2019 and you've just announced new projects. So, it would kind of seem like on an apples-to-apples basis your CapEx is actually declining versus prior expectations. Can you give us a little bit of color around that? Is it cost related? Is it due to some of the asset sales, just trying to understand the subtle changes?

Alan Armstrong -- President and Chief Executive Officer

Yeah, I would just say, first of all, most importantly the Bluestem most of that capital for Bluestem will be spent in 2020. So that's primarily why you're not seeing much driver in that. So it's not -- frankly, it's not all that complicated, because it really is just quite a bit of pushing. There's a lot of -- in a budget that size, obviously, there's a lot of things moving around from time to time, but they tend to find themselves toward the mean and that's precisely the way this came out this year as well.

Shneur Gershuni -- UBS -- Analyst

All right. That makes perfect sense. Thank you very much guys. Really appreciate the color.

Alan Armstrong -- President and Chief Executive Officer

Thanks, Shneur.

Operator

(Operator Instructions) We'll take our next question from Christine Cho with Barclays.

Christine Cho -- Barclays -- Analyst

Good morning, everyone.

Alan Armstrong -- President and Chief Executive Officer

Good morning.

Christine Cho -- Barclays -- Analyst

Just wanted to make sure I understand this agreement with Targa. Are the economics here really going to be driven by the volume growth out of the Rocky Mountain Midstream JV? And also any color around when you expect to achieve that EBITDA multiple of 6 times and what sort of volume growth we should assume is underpinning those economics?

Micheal G. Dunn -- Chief Operating Officer

Hi, Christine. It's Michael. Just to start on the first part of that, we see a lot of growth, not only from the Rocky Mountain Midstream, but we've got barrels on our Rockies plants that are already out there that will be moving on the Bluestem pipeline eventually. And as you know, we've got the partnership on the OPPL system. And we'll continue to move those Rocky barrels -- Rockies barrels down the OPPL system to Conway and then further south on Bluestem. And with our 2021 in-service date on Bluestem coinciding with Targa's build to the north with us, we would expect a lot of those barrels to move South and ultimately get to a 6 times multiple on that and really a lot of that's driven by timing of the barrels coming out of Rocky Mountain Midstream, frankly, but we do see some pretty significant growth in the Rocky Mountain Midstream assets, especially, what the agreement that we just executed and so we would anticipate approaching that 6 times multiple pretty quickly.

Christine Cho -- Barclays -- Analyst

And just to clarify, the volumes coming out of like your existing plans, are those priced off -- those are priced off Conway, right? And so to the extent that you can bring them down to Belvieu that's going to be margin that you keep for yourself. Is that how I should think about it?

Alan Armstrong -- President and Chief Executive Officer

There is a variety -- for our own equity barrels today, we have the option of either Conway or Belvieu at a differential in price. So today we do have that option for those barrels up to an amount that we can move under the existing exchange agreement. So, I would just say that we do have Belvieu access for those barrels today to the degree it's available, but for the Rocky Mountain Midstream barrels that's a different story in terms of being able to include those, because we're limited on capacity on Overland Pass right now. So, as Overland Pass opens up, that allows us to make a very nice margin by making these investments on the downstream.

Christine Cho -- Barclays -- Analyst

Got it. Okay. And then just switching over to the Northeast, the process -- like you know the gathering volumes have been great, but the processing volumes have been flattish for the last year. What do you think we need to see to have these volumes increase?

Micheal G. Dunn -- Chief Operating Officer

Well, Christine, I would say, we do expect those volumes to increase. We have line of sight to what the producers are doing, there's a lot of drilling activity behind our processing plant, that will be coming online this year. It's a little bit delayed from where we had thought it would have been last year. And that's really coinciding very nicely with the completion of growth TXP-2. And so, we have very good confidence that our current capacity will be filled probably in the second quarter and that's about the time that TXP-2 at Oak Grove comes online. So, we anticipate certainly filling TXP-1 this year and TXP-2 will start processing gas shortly after that.

Christine Cho -- Barclays -- Analyst

Got it. Thank you.

Alan Armstrong -- President and Chief Executive Officer

Thanks, Christine. I would just add to that question and it's a good observation on your part. I would just add, we've got several significant upstream projects like Checkmark Pipeline and some other projects that are -- that we have to get completed before we can bring those new processing -- those volumes into processing. So there's quite a bit of infrastructure having to happen upstream to be able to get some of the new drilled volumes from Southwestern and other customers into the front of Oak Grove and where we're nearing completion on a lot of that work.

Micheal G. Dunn -- Chief Operating Officer

And Christine, I probably should add to that, we have minimum volume commitments. Whenever we agree to go deploy capital there at those processing facilities, we have MVCs to back that up, and so that's why it gives us a lot of confidence that those volumes are going to show.

Operator

Our next question comes from Jeremy Tonet with JPMorgan.

Jeremy Tonet -- JPMorgan -- Analyst

Hi. Good morning. Maybe just kind of linking up on that last point there -- thanks. There's been kind of concern with regards to producer activity in the Northeast and some producers kind of, you know, taking in that growth rate focusing more on free cash flow. I was wondering if you guys could address how you see that impacting your footprint, because it seems like some of the guys behind your systems might be taking a bit of a different task than others there. If you could expand on that what gives you guys the confidence in the Northeast growth as you expected?

Alan Armstrong -- President and Chief Executive Officer

Sure. I'll just take that at a high level and then Michael can fill in with some details if required. First of all, I think, not all producers out there created equal and certainly not all acreage is created equal. And so, for instance, if you look at Cabot, which is one of the primary drivers of our growth, they continue to show a very strong growth profile, because they've got markets established upwards toward 4 Bcf a day of markets that they've established. And so, they've done a great job of getting the markets out in front of them and we're working furiously to keep our gathering system expanded to keep up with them.

So, that's very obvious to us where that growth is coming from in that area, as well as the Bradford County area continues to grow very rapidly for us as well. And so, as Michael pointed out earlier, we have a lot of transparency into that growth in that area. And then, as you move into the South, I would just say that, while there has been some folks pulling back a little bit on volume growth, as Micheal mentioned, those MVCs that people have made to us, they're going to work hard obviously to fill those up. There being very successful with the production behind there, and I would just tell you the 15% CAGR that we put out there earlier, we had quite a bit of room, if you will, between what producers were forecasting at that point versus that 15%. And so we still feel very confident in that 15% CAGR that we put out earlier based on the detailed work that we do with the producers.

I would say, as I've mentioned earlier, probably the one of more positive things about that growth that's occurred is the Encino acquisition from Chesapeake on that Utica acreage, which was a very large pieces of volume and acreage behind us that was declining previously and now with their activities, we're actually starting to see that grow. So that's a really big positive for us in terms of offsetting some of the declines that existed out there.

Jeremy Tonet -- JPMorgan -- Analyst

That's very helpful. Thanks. Just wanted to turn to Atlantic-Gulf here real quick, and you had quite a nice quarter there. And was wondering, is this kind of a something that's run rate level for you guys or is there still more kind of Sunrise is not fully baked in for the quarter and you continue to see growth there or how should we think about that segment?

Micheal G. Dunn -- Chief Operating Officer

Yeah, this is Michael again. I would say, the majority of the quarter, we saw the Atlantic Sunrise revenues in there came online October 6th, is when we started charging full rate for Atlantic Sunrise. But recall earlier in 2018 we were also charging for some interim capacity that we were able to achieve there. We were able to bring the full volume on October 6. So basically you would see the fourth quarter having the majority of the revenue in there for Atlantic Sunrise. And if you recall, it's a revenue payment -- or sorry a capacity payment. And our revenue throughput although very strong throughout the fourth quarter, doesn't drive a lot of the revenue differences there, because of the capacity reservation charges that Transco enjoys.

Jeremy Tonet -- JPMorgan -- Analyst

That's helpful. That's it from me.

Alan Armstrong -- President and Chief Executive Officer

Thank you, Jeremy.

Operator

And from RBC Capital Markets we'll hear from T J Schultz.

Torrey Joseph Schultz -- RBC Capital Markets -- Analyst

Great. Just one thing on that last point on the Chesapeake Utica acreage now with Encino. Can you frame any better that rate of change you're expecting from an asset that was in decline now sounds like more activity, just any notable color from early days with Encino in place?

Alan Armstrong -- President and Chief Executive Officer

Well, there, there is still on their process deciding how aggressively they want to go after it. But I think it's a -- the big shift of course is a, the available capital that Encino has through the Canadian pension fund. And so they're anxious to put that capital to working and drive the returns on that. So it takes a while to get ramp back up from the declines that had been occurring in the area, but we're working with them to make sure that we keep the infrastructure out in front of them right now.

So I think, it's a question of how many rigs that they're going to run in the area right now. I think they're planning -- they've got two and planning on maybe go into three at this point. And so that's what will drive that and of course, they're very efficient, they've got a lot of the team that was already existing there, very efficient operators and with three rigs that will be growing pretty rapidly in that area.

Torrey Joseph Schultz -- RBC Capital Markets -- Analyst

Okay. Great. Thanks. Just one more on Gulf East, if you could just clarify a little on Appomattox. It sounds like coming on, a little sooner than expected. If you could just remind me the status of the Norphlet Pipeline option to you and just in general what you're expecting from the ramp in that area this year. Thanks.

Alan Armstrong -- President and Chief Executive Officer

Sure. Thank you, TJ. Yeah, we have completed all of our work and the pipeline option then it gets triggered, just ahead of production coming online. So we're in those discussions and that's all pretty, I would say, that's very clean, very baked and there is not a whole lot to happen there other than us making decision to exercise that. So really just a matter of Shell doing their work on Appomattox and being ready to flow. And so that's what will drive the timing on that is their work on the Appomattox platform and getting that ready to flow. And they've done a great job really great execution on Shell team on being so far ahead of schedule as to what they had planned originally and our team did a nice job as well having our side of the infrastructure done.

So we're excited about a lot of -- lot of volumes just from the field proper, but a lot of new work going on by both Shell and other producers in the area and acreage around that would be nice tie-backs to the Northwest -- to our infrastructure out there. So I think that's going to wind up being even bigger than we had originally planned in terms of the number of fields and new development that's going on out there, both, again both by Shell and Chevron's activity in the area as well.

Torrey Joseph Schultz -- RBC Capital Markets -- Analyst

Okay. Thank you.

Operator

Our next question is from Dennis Coleman with Bank of America.

Dennis Coleman -- Bank of America -- Analyst

Yes, thank you and good morning everyone. If I can just go back to the Bluestem project to start, I wonder if you might talk a little bit, how did you sort of scope the project in terms of deciding where that connect would come and who would build what with Targa?

Alan Armstrong -- President and Chief Executive Officer

Well, I would just say that Targa had -- and this is why it turned out to be such an attractive project for both parties was because they were building up to that Kingfisher area anyway to capture other volumes in the Mid-Continent area there. So this was a low cost expansion for them to be able to pick our volumes up as well for them. So, the transaction and the rates that we enjoy were benefiting from that. And so it was just a matter of us placing the capital to build down from Conway down to where they were already going to be picking up other barrels in that area.

Dennis Coleman -- Bank of America -- Analyst

Okay. Thank you. And so are there -- there's contracts on these systems already? Is that -- there is a contract structure in place, there's shippers or is it Williams that's the shipper?

Micheal G. Dunn -- Chief Operating Officer

Yeah, on our system, it would be, it would be, of course, remember, you have Overland Pass that we own 50% with One Oak Upstream with this, that comes into the Conway area and then we would own that system 100%. We would be the -- in terms of shipping on that, we would have an exchange agreement, purchase agreement with Targa for some of those barrels. And we will have relationships with upstream producers, for instance, in the Rocky Mountain area, we'll have relationships where we will be buying their barrels that affects margin in that area. So we'll have a combination of both our own equity barrels, which are very substantial today, as well as barrels that we've been continuing to pick up in the DJ Basin and some of the surrounding area there.

Dennis Coleman -- Bank of America -- Analyst

Okay. Got it. Thanks. And then just, there is a word in the press release that I want to just try and say. You say there is an initial 20% option on one of the fracs. I guess that implies that there will be additional options potentially. Is that -- am I hearing that right?

Alan Armstrong -- President and Chief Executive Officer

Yeah. Great question. As I mentioned earlier, we structured the transaction so that we can expand both our equity investment in the frac, but that would come with additional volume commitment on our part as well. And so that's kind of how it's structured. So we built in flexibility knowing how robust we're kind of forecasting the growth in the Rocky Mountain Midstream area to be, we want to be prepared to be able to handle those incremental barrels. And so while today we don't want to make that kind of commitment without seeing the barrels actually show up, we did want to make sure that we had the capacity to allow for that growth coming from that area.

Dennis Coleman -- Bank of America -- Analyst

Okay. Great. That's helpful. Thank you. And I guess maybe just one on the leverage, it seems that further reduction is primarily a function of asset sales. So I wonder if you might talk about what kind of -- any assets that you're particularly looking at, is there a program going on now or is that going to be more opportunistic?

Alan Armstrong -- President and Chief Executive Officer

No, I would say, we are constantly looking at optimizing our portfolio and we are working really hard. I can tell you the entire team with the Board support is working hard to reduce our leverage. And so we continue to work various transactions and asset sales that would help complement that. So, to answer your question, we are actively pursuing those type of transaction.

John D. Chandler -- Senior Vice President, Chief Financial Officer

But I would -- this is John Chandler. I'd go on to say, even without that, though. Again, remember we're generating around $1.2 billion of excess cash even with attractive dividend growth. And we can use that cash even on new invested dollars. So we actually are deleveraging even with investments in new projects, because we're funding so much of it with cash. So again, you know, asset sales will enhance and speed up the deleveraging, but we're deleveraging even without asset sales.

Dennis Coleman -- Bank of America -- Analyst

Right, right. Got it. That's it from me. Thanks very much.

Alan Armstrong -- President and Chief Executive Officer

Thank you.

Operator

Next we'll hear from Michael Lapides of Goldman Sachs.

Michael Lapides -- Goldman Sachs -- Analyst

Hey, guys. Two questions unrelated to each other. One, is there an update on the siting and permitting process for the Northeast Supply Enhancement that you can provide? Just in general, it seems like federal processes are kind of running as expected, but just curious given a lot of the challenges others and you all have faced in terms of building pipelines into New York and dealing with kind of state level intervenors or stakeholders?

Micheal G. Dunn -- Chief Operating Officer

Michael, this is Micheal. I will give you an update on that. This is a great project for us to be able to facilitate the reduction of emissions in New York City, as well as improve the cost profile of people's energy use there. We just recently received our final Environmental Impact Statement from the FERC and we would expect within 90 days further regulations and their practice to provide a FERC Certificate assuming the FERC Commission has approved that within 90 days.

So you would expect to see that hopefully within the 90 days and then we're in the process on the state side of getting the 401 Certifications from New Jersey and New York, both of those state agencies have scheduled public hearings for the 401 Certifications with just recently the State of New York giving the notice of complete application on our 401 Certification. And so we'll go through those processes with the State of New York as well, and once those 401 Certificates are issued by each one of the state and that allows the Corps of Engineers to issue, what's called the 404 Permit and FERC take that into consideration in order to give us the notice to proceed with construction. So we would expect all of that to occur within the next several months.

Michael Lapides -- Goldman Sachs -- Analyst

Got it. Much appreciated. And also totally different topic. Any update you can provide on the Transco rate case just in terms of whether settlement talks are under way and whether there's a potential for settlement or whether you think this goes the full litigated route?

Micheal G. Dunn -- Chief Operating Officer

Right, I can give you an update on that as well. So we would expect to see the what's called the top sheets from FERC in mid-March. And that's really their staff's reaction to our filing and basically provides the site boards if you will what we can then go to a settlement negotiations with FERC's staff and our customers on. And so the first or the -- sorry, I should say the next settlement conference is scheduled for the end of March. And so, at that point in time, we'll have a pretty good idea of how likely it is that a settlement can occur and obviously that's the path we would prefer to go down. I think that's the best for our customers and ourselves to be able to agree upon that and not litigate the case and that's what the expectation is right now for us to achieve an outcome in settlement that's satisfactory to both Williams and our customers.

Michael Lapides -- Goldman Sachs -- Analyst

Got it. Thank you, guys. Much appreciated.

Operator

With Tuohy Brothers, we'll hear from Craig Shere.

Craig Kenneth Shere -- Tuohy Brothers -- Analyst

Good morning.

Alan Armstrong -- President and Chief Executive Officer

Good morning, Craig.

Craig Kenneth Shere -- Tuohy Brothers -- Analyst

Couple of detail items and then a bigger picture question. Maybe my math is off, but it looked like there was an unusually high tax rate reflected in adjusted income. If that's correct, what was driving that?

John D. Chandler -- Senior Vice President, Chief Financial Officer

There's really a couple of things. This is John Chandler. There's a couple of things that drive that. Number one, in the fourth quarters, when we usually do tax provision reestimation for the year side, I'd encourage you to look at the entire year at the tax rate instead of just a quarter since we do have some noise around that. I'd also say we had several obviously large unusual items in the fourth quarter including impairment and other things. That when we do estimations of taxes and the impact of taxes on those unusual items we use a 25% rate, which is actually higher than our average blended rate for the quarter. So that results in some skewed tight calculations because we're using a different rate for our adjustment items or normalization items recent or standard annual rate of 25% than it would actually blended to. It's probably confusing, but I just ask you to reach out to our IR team I think they can walk you through that, but so it's really those two things the significant unusual items and the tax provision adjustments that are done in the fourth quarter.

Craig Kenneth Shere -- Tuohy Brothers -- Analyst

Thanks, John. Yeah, it looked like the EBITDA was in line, but the adjusted EPS a little off and that explains a lot. Alan, in your prepared remarks, you talked about several other Transco projects not gone public with yet. Can you give us a picture of the range of opportunities in terms of size and maybe any updates on the Transco project one that was heavily foreshadowed on the 3Q call?

Alan Armstrong -- President and Chief Executive Officer

Yes, sure. First of all, on Project 1, remember, we had 2 there, we had Project 2 which was Leidy South which is moving ahead very nicely and fully contracted. Project 1, we continue to work with the counterparty -- primary counterparty on that and I would just say they continue to be very interested in the project and highly supportive of the project, but have some of their own internal issues to get through to be able to transact with this. But we remain very confident in the fundamentals and the drivers behind that project.

I would also say that we have several other new projects that are well on their way to development, a lot of strong interest that would continue to alleviate capacity constraints out of the Northeast PA area and so we're pretty excited about that. And that also helped to expand into some of the markets that are continuing to need expansion and will and despite what you might hear those markets are growing pretty nicely in terms of their demand for natural gas there in Zone 6. And so we've got several projects that are pointed at that and again, the interest in those projects is very strong right now.

Craig Kenneth Shere -- Tuohy Brothers -- Analyst

So it sounds like there is incremental pipeline development that can further add to the Northeast G&P opportunities?

Alan Armstrong -- President and Chief Executive Officer

Absolutely. Yeah, and I'm not going to call it Project 3, because we're growing weary of that, but it is a nice project flowing right behind the other two.

Craig Kenneth Shere -- Tuohy Brothers -- Analyst

Okay. And here is a little bit of my bigger-picture question. I understand the Barnett is not a 2019 headwind. But I want to get some sense of the longer term gives and takes at G&P? If we look out to 2021, as you target a 15% CAGR on Northeast G&P volume growth of 2018, depending on assumed margin growth per M, is it reasonable to assume that Northeast G&P EBITDA can rise $600 million to $900 million plus of 2018 levels and then would Barnett maybe be a headwind of as much as $150 million?

Alan Armstrong -- President and Chief Executive Officer

Yeah, we're not going to provide guidance individually on Barnett, but I would say this, Craig, the lowering or the impairment, we took on Barnett is -- I don't want to drag everybody through all the accounting details, but we were -- that asset was held according to the un-discounted cash flows on the asset when the per M and obviously that was dependent on gas prices in the area both by the way that contract is set up as well as drilling expectations from Total, our primary customer in that area. When the Permian price per head, so every year we would test an asset like that for its cash flows looking forward, against the held value.

And this year when we had to take into account the very large basis differential in the Permian and how that would affect both the rate that we receive as well as the actions of -- the what we estimate would be the actions of the producing customer that brought us down below that estimate and therefore that triggered us to have to remarket to fair value in other words what we think we could sell the asset for in the market and that was very different than the some of the undiscounted cash flows which is what was way was marked earlier.

So it was I said in another way, it was a relatively small movement and expected cash flows from the asset, but it put us down below that fair value and that triggered a different way of value in the asset and that's why we got such a large impairment. So, you shouldn't read into that, that the business is collapsing there, but it moved enough on the far out values that moved enough that we had to reposition the way we value. So nothing's really changed all that much there other than again the Permian gas supply if the -- pipelines all get built adequately and we see the Permian gas prices come back up, then that avenue will change for the area. But for the meantime, we have to take the facts as they are and look at the forward curve for the basis differential out there.

John D. Chandler -- Senior Vice President, Chief Financial Officer

And I'd just add to that, if you go to the third quarter of 2017, we impaired our Mid Continent assets and it was the exact same scenario that was set up. There wasn't a material change in the actual EBITDA generation for the Mid Continent assets, but the gross cash flow dropped to make us take it from a historically high carrying value down to its fair value. So the same is happening with the Barnett, we don't see any meaningful change in the EBITDA stream, but it was just in that the trip that write down from carrying value to fair value.

Craig Kenneth Shere -- Tuohy Brothers -- Analyst

No major change even looking out say to 2021?

Alan Armstrong -- President and Chief Executive Officer

No, not really just the impact of gas prices long-term for the asset just brought it down just enough. So we do not see a major shift in the cash flows from that business, we have had pretty modest growth expectations in the past for that. But this effectively just strip that out, the growth expectations completely stripped out of there in terms of drilling activity and so that's what I attribute that, but we have had very modest expectations.

Craig Kenneth Shere -- Tuohy Brothers -- Analyst

And finally, the bookend that I put out there depending on margin per M of Northeast G&P gaining, say, $600 million to $900 million plus an EBITDA over 2018 through 2021, is that a decent bookend?

Alan Armstrong -- President and Chief Executive Officer

Well, I would just say we are very much on our way toward that $0.50 to $0.55 EBITDA per Mcf range that we've talked about earlier. And, so with the volume growth and with that kind of margin improvement, the answer is yes, and I'm not crystal clear on the timing that you're laying out just to be very fair, just haven't thought through that versus that amount. But in terms of what we laid out here at Analyst Day, we're feeling very good right now about both the volume growth and the margin growth that we're experiencing.

Craig Kenneth Shere -- Tuohy Brothers -- Analyst

Great. Thank you.

Operator

From Wells Fargo, we'll hear from Sharon Lui.

Sharon Lui -- Wells Fargo Securities LLC -- Analyst

Hi, good morning.

Alan Armstrong -- President and Chief Executive Officer

Good morning.

Sharon Lui -- Wells Fargo Securities LLC -- Analyst

When you look at, I guess, the annualized Q4 numbers for your adjusted EBITDA from equity investments, that would kind of suggest the much higher run rate versus your 2019 guidance of $825 million. And I guess, if you assume contributions from Jackalope, as well as Rocky Mountain continue to ramp, maybe help us try to reconcile to your 2019 outlook based on what you guys reported in Q4?

John D. Chandler -- Senior Vice President, Chief Financial Officer

Well off hand I don't know that I have the details in front of me to be able to answer that. So I might have you call Dr. John Porter on that question.

Sharon Lui -- Wells Fargo Securities LLC -- Analyst

Okay. Sure. And I guess just a housekeeping question on the impairment charge. So there is no impact on cash flows only on DD&A expense, is that correct going forward?

John D. Chandler -- Senior Vice President, Chief Financial Officer

If there is an impact on cash flows, it's very minimal on Barnett. So, yes, it's just that it's an uplift or it's an improvement, a reduction of DD&A. That's correct.

Sharon Lui -- Wells Fargo Securities LLC -- Analyst

Okay. And then the amount that Williams actually recognize in terms of the amortization of deferred revenues, is that still about $100 million going forward?

John D. Chandler -- Senior Vice President, Chief Financial Officer

Yeah that sounds right. Yes.

Sharon Lui -- Wells Fargo Securities LLC -- Analyst

Okay. Great. Thank you.

Alan Armstrong -- President and Chief Executive Officer

Thank you, Sharon.

Operator

Next up is Jean Ann Salisbury with Bernstein.

Jean Ann Salisbury -- Sanford C. Bernstein & Co. LLC -- Analyst

Good morning. Just a couple of quick ones from me. So it seems like Mountain Valley and the Atlantic Coast projects have hit some difficulties. In the theoretical event that one of these projects is ultimately canceled, could Transco address that demand with new laterals, could that be a source of new projects?

Alan Armstrong -- President and Chief Executive Officer

We are very well positioned on the market end for those projects, in other words, being able to help using existing right away, but not fully. So said another way, some of that market expansion will be required. But I would certainly say that we have a lot to offer in that regard in terms of the use of our existing right-of-ways and systems to be able to help supply that growth. So, yes, we have a lot to offer there to the degree that that occurs. But I would also say that particularly as it relates to Mountain Valley that there is so much continued growth in demand on our system that those supplies coming in, we're going to be -- we'll have synergies with Mountain Valley whether gets built as planned or not we would have quite a bit of synergies there with that system. So, I would say they're little different, because they serve two very different needs. But, clearly, we have the ability to help out both projects.

Jean Ann Salisbury -- Sanford C. Bernstein & Co. LLC -- Analyst

That makes sense. And then just a quick clarification, the Bluestem EBITDA is all incremental from the EBITDA that you'd expected on the initial discovery deal, I assume so, but just want to make sure.

Micheal G. Dunn -- Chief Operating Officer

Yeah, I think that's probably a good way to look at it. We did anticipate some NGL uplift in the Rocky Mountain Midstream acquisition model. So we knew that we would be able to acquire some of those barrels ultimately and some of that's factored into that.

Jean Ann Salisbury -- Sanford C. Bernstein & Co. LLC -- Analyst

Okay. So maybe a little bit of double dipping, but a lot of it's incremental?

Micheal G. Dunn -- Chief Operating Officer

Yes.

Jean Ann Salisbury -- Sanford C. Bernstein & Co. LLC -- Analyst

Okay. That's all from me. Thank you.

Alan Armstrong -- President and Chief Executive Officer

Thank you.

John D. Chandler -- Senior Vice President, Chief Financial Officer

I would say this though, when you collectively put in the investment on Bluestem with investment in the Rocky Mountain Midstream assets, we still accomplish a 6 times multiple on even the combined investment when openly that systems is fully up and operational.

Operator

Next up is Colton Bean with Tudor, Pickering, Holt & Company.

Colton Bean -- Tudor, Pickering, Holt & Co. Securities, Inc. -- Analyst

Good morning. So, Alan, you mentioned a continued focus on portfolio management. So, just wanted to touch on that with the vertical integration here, the Rocky Mountain processing fleet with some further downstream opportunities, does that change the way you as assess those assets and kind of how they fit in the broader asset footprint?

Alan Armstrong -- President and Chief Executive Officer

No, I would say that we've always looked at vertical integration as one of the facets to consider when we think about whether asset is strategic or not, because obviously the aggregation of barrels for instance gives us value opportunities and investment opportunities just like Bluestem. So we definitely think about when we think about what assets we would want to hold and that we add value as an organization, as a corporation, what we add value to that vertical integration is obviously a key part of that. So, that is a facet that would be dependent on and certainly to the degree that we've got combined downstream investments, it makes those assets more valuable to us as a company often than to somebody else. And so I think that's the way to think about that.

Colton Bean -- Tudor, Pickering, Holt & Co. Securities, Inc. -- Analyst

Got it. That's helpful. And then just touch briefly on the West, so you mentioned gathering volumes the net of the Four Corners adjustment they are down around 3% Q-on-Q. Just interested in what you're seeing on the Haynesville system and maybe a longer term outlook there as well?

Alan Armstrong -- President and Chief Executive Officer

Yeah. As we said in 2017, we had a really big growth rate on Haynesville in 2017 and we forecasted that we didn't expect that to occur again in 2018 because that where there was so much new flush production and the decline rates on that new flush production is pretty high. And we -- at the first of the year, we actually saw some growth but toward the end of the year, we did see some decline on the Haynesville system so, and most of that from Chesapeake production. The good news is on the Haynesville system is our team has been doing a really nice job of capturing new acreage out there from third parties other than Chesapeake. So we're encouraged for the way that looks not on the base dedicated acreage out there, not really a change on that, but in bringing -- we've been winning some new business out there. So that will help to maintain the volumes in the Haynesville.

Colton Bean -- Tudor, Pickering, Holt & Co. Securities, Inc. -- Analyst

Great. And just on those incremental agreements at a high level, could you comment on whether those are weighted toward public or private producers?

Alan Armstrong -- President and Chief Executive Officer

Mostly private.

Colton Bean -- Tudor, Pickering, Holt & Co. Securities, Inc. -- Analyst

Got it. And I'll leave it there. Thank you very much.

Operator

From Jefferies, we'll hear from Chris Sighinolfi.

Chris Sighinolfi -- Jefferies -- Analyst

Hey, good morning, Alan.

Alan Armstrong -- President and Chief Executive Officer

Good morning.

Chris Sighinolfi -- Jefferies -- Analyst

Thanks for taking my questions. Not sure if this one is for you, Michael or Chad, but I do want to circle back on the NGL project just one more time. More from a philosophical perspective I guess regarding the Conway market, you guys make clear the advantage of gaining better access or greater access to Belvieu through Targa system both the pipe and the frac. And it's clearly an advantage moving barrels on your own system versus a third-party system. So I guess two follow-up questions with regard to that setup. First, your views on the Conway purity product market outlook over time and your regional frac volumes there given these announcements seem all Y-grade in nature. And then two, do you have Y grade contracts now on third-party assets sales from Conway that you can transition to Bluestem Grand Prix over time? And if so, what sort of schedule should we anticipate there?

Alan Armstrong -- President and Chief Executive Officer

That's a lot of questions, but I'll take a stab at here. Let's say, first of all, on the Conway market, yeah, I think it's important to know that, if we flatten out the spread between Conway and Belvieu, we're a winner in that, so you should think about that being somewhat of a natural hedge for our business because we already own those assets and so to the degree that Conway product, spec product prices come up in the purity market then that makes Conway and the services that we offer there that much more attractive.

So that's the way that we think about that obviously. And in terms of whether that's spec product or Y-grade that's just a matter of how much incremental fractionation capacity there is on both ends of the pipe basically in terms of being able to make those markets. Let's see. And yes, we do have contracts with third parties on Y-grade that have fixed margin built into them.

Chris Sighinolfi -- Jefferies -- Analyst

Okay. And is that something we can expect in a reasonable timeframe, maybe the next two to five years to be up that could transition to this new collection of Williams Targa assets or is it a long...

Alan Armstrong -- President and Chief Executive Officer

No, those are -- I would say when we start up in 2021, I think we'll be well positioned there to be able to start taking advantage of that immediately.

Chris Sighinolfi -- Jefferies -- Analyst

Okay. Great. Thanks for that. I guess switching gears and just a quick follow-up for me on one of Jean's earlier questions, you had noted, I think when you entered the DJ JV with KKR that you were retaining some options to acquire from KKR additional interest. And so I'm wondering, Michael, you had said that you contemplated other NGL solutions as part of that investment. I'm wondering now that they've maybe more formalized with this agreement with Targa, if it shapes your view on whether or not or how swiftly you'll exercise options with them?

Alan Armstrong -- President and Chief Executive Officer

Yeah, I would you say, first of all, we've got seven years I think total on that options so long time to decide what that is. And I'll just remind you the investment that we have with KKR is so leave the G&P assets and so there's not a investment in the downstream value chain on that outside of that JV. It's just in the G&P assets their proper. So it didn't really affect so much that option value, if you will, because it's really just going to be the cash flows from that G&P business that will drive the option value there. But it does, I would say, the relationship there with KKR's very solid, it's well aligned and the fact that we have that option does keep us very focused on driving the value in the JV as well. So it's actually a pretty nice feature in terms of keeping us aligned there.

Micheal G. Dunn -- Chief Operating Officer

And us being able to provide these NGL solutions downstream creates value for the partnership there with KKR because we can go to the producers and provider a value chain there that we can give them fixed pricing.

John D. Chandler -- Senior Vice President, Chief Financial Officer

And Alan did mentioned earlier that we've been successful with some new connections there at pretty attractive returns. If you remember our option with KKR's at a fixed return. So to the extent we can add new gathering business at higher returns. It just becomes that much more valuable course in the future to exercise that option.

Chris Sighinolfi -- Jefferies -- Analyst

So I guess final point on that then, John, assuming you're got the guided leverage number you gave for 2019, is it safe to assume that does not include any option exercise on that asset?

John D. Chandler -- Senior Vice President, Chief Financial Officer

That's not, that's the beauty of this agreement, we have quite a period of time to execute that. So we've got plenty of time to continue to bring our leverage down and find that opportunity sometime in the future to execute that option.

Chris Sighinolfi -- Jefferies -- Analyst

Wonderful. Thanks for time. Happy Valentine's Day.

Alan Armstrong -- President and Chief Executive Officer

Thank you. You too.

Operator

It appears there are no further questions at this time. And I'd like to turn the conference back to our speakers for any additional or closing remarks.

Alan Armstrong -- President and Chief Executive Officer

Okay. Great. Well, thanks everybody for joining us really excited about the platform for growth that we've got set here for '19. Teams continue to work very well together to take advantage of all these opportunities. And I would say our execution just continues to get better and better and really proud of the way the teams are operating. And we like the macro conditions that are set up ahead of us as well. So going very good about both 2018 and the platform for growth that we've got set for '19 and beyond. So thank you again for joining us.

Operator

This concludes today's conference. Thank you for your participation. You may now disconnect.

Duration: 71 minutes

Call participants:

John Porter -- Vice President of Investor Relations, Financial Planning and Analysis

Alan Armstrong -- President and Chief Executive Officer

Shneur Gershuni -- UBS -- Analyst

Chad J. Zamarin -- Senior Vice President, Corporate Strategic Development

Christine Cho -- Barclays -- Analyst

Micheal G. Dunn -- Chief Operating Officer

Jeremy Tonet -- JPMorgan -- Analyst

Torrey Joseph Schultz -- RBC Capital Markets -- Analyst

Dennis Coleman -- Bank of America -- Analyst

John D. Chandler -- Senior Vice President, Chief Financial Officer

Michael Lapides -- Goldman Sachs -- Analyst

Craig Kenneth Shere -- Tuohy Brothers -- Analyst

Sharon Lui -- Wells Fargo Securities LLC -- Analyst

Jean Ann Salisbury -- Sanford C. Bernstein & Co. LLC -- Analyst

Colton Bean -- Tudor, Pickering, Holt & Co. Securities, Inc. -- Analyst

Chris Sighinolfi -- Jefferies -- Analyst

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