EQT Corp (EQT) 2013 Q3 法說會逐字稿

Good morning, and welcome to EQT Corp's third-quarter earnings conference call.

All participants will be in listen-only mode.

(Operator Instructions)

After today's presentation there will be an opportunity to ask questions.

(Operator Instructions)

Please note, this event is being recorded.

I would now like to turn the conference over to Pat Kane.

Please go ahead.

Thanks, Chad.

Good morning, everyone, and thank you for participating in EQT Corporation's third-quarter 2013 earnings conference call.

With me today are Dave Porges, President and Chief Executive Officer; Phil Conti, Senior Vice President and Chief Financial Officer; Randy Crawford, Senior Vice President and President of Midstream Distribution and Commercial; and Steve Schlotterbeck, Senior Vice President and President of Exploration and Production.

This call will be replayed for a seven-day period beginning at approximately 1.30 PM Eastern time today.

The telephone number for the replay is 412-317-0088.

The confirmation code is 10025424.

The call will also be replayed for seven days on our website.

To remind you, the results of EQT Midstream Partners, ticker EQM, are consolidated in EQT's results.

There's a separate press release issued by EQM this morning, and there's a separate conference call today at 11.30 AM today, which creates a hard stop for this call at 11.25.

If you are interested in the EQM call, the dial-in number is 412-317-6789.

I would also like to mention that the year-end earnings conference call for both EQT and EQM is scheduled for February 13, 2014.

In just a moment, Phil will summarize EQT's operational and financial results for the third quarter, which were released this morning.

Then Dave will provide an update on strategic and operational matters.

Following Dave's remarks, Dave, Phil, Randy, and Steve will all be available to answer your questions.

Before that, I would like to remind you that today's call may contain forward-looking statements relating to future events and expectations.

You can find factors that could cause the Company's actual results to differ materially from these forward-looking statements listed in today's press release and under Risk Factors in EQT's Form 10-K for the year ended December 31, 2012, filed with the SEC, as updated by any subsequent Form 10-Qs which are on file at the SEC as well.

Today's call may also contain certain non-GAAP financial measures.

Please refer to this morning's press release for important disclosures regarding such measures, including reconciliations to the most comparable GAAP financial measure.

With that, I would like to turn the call over to Phil Conti.

Thanks, Pat, and good morning, everyone.

As you read in the press release this morning, EQT announced third-quarter 2013 earnings of $0.58 per diluted share.

Operating cash flow was just under $233 million in the quarter, or 36% higher than the third quarter of 2012.

Adjusted cash flow per share was $1.92 in the quarter, up 68% versus the third quarter 2012.

Our operational performance was again outstanding this quarter, with 42% higher production volume growth, 43% higher gathering volume growth, while net operating expenses increased by only 23%, resulting in continued reduction per unit operating costs.

EQT Midstream Partners results, as Pat mentioned, are consolidated in EQT's results, and EQT did record $14.4 million of net income attributable to the non-controlling interest unit holders of EQM in the quarter.

Early in the quarter, EQT completed the sale of the Sunrise Pipeline to EQT Midstream Partners for total consideration of $507.5 million, plus approximately 479,000 common units and 268,000 general partnering units in EQT Midstream Partners.

While there is no accounting gain from the sale on our income statement due to the consolidated reporting, EQT will recognize a federal income tax gain of approximately $475 million, resulting in cash taxes associated with that transaction of approximately $57 million.

That represents a cash tax rate on the drop-down of only 12%, as we were able to use our intangible drilling costs, deductions, accelerated tax depreciation, and net operating loss carry-forwards to reduce cash taxes for the year.

These tax synergies are actually a valuable benefit of our current corporate structure, as we continue to work through our inventory of drop-downs.

Continuing on an income tax topic for just a minute, you may have noticed we recorded a corporate effective book tax rate of 25% for the quarter, which is a little lower than normal.

I should first note that the accounting for the MLP structure had the effect of reducing our book federal tax rate, as all of the pretax income, including the portion that goes to the non-controlling interests of EQM, is consolidated at EQT, while we only record income taxes on EQT's share of the pretax income.

The 25% effective tax rate in the quarter is also below the expected run rate for the year, due to an increase in our ability to utilize some state tax income tax deductions in the quarter compared to previous estimates.

For the full year 2013 we do currently project the EQT effective book tax rate will be around 35%, or right around the level that it was last year.

I will now shift gears briefly to discuss our operating results in a little bit more detail, starting with EQT Production, where sales volumes continue to grow rapidly.

The growth rate in the recently completed quarter was 42% over the third quarter of 2012.

That growth rate continues to be driven by sales from our Marcellus play, which contributed approximately 75% of the volumes in the quarter.

Marcellus volumes alone were 74% higher than they were in the quarter a year ago.

Realized gas prices were a bit higher in the quarter, consistent with higher NYMEX prices.

At the corporate level, EQT received an average of $4.20 per Mcf equivalent, compared to $4.04 per unit received last year.

However, the realized price at EQT Production was $3.13 per Mcf equivalent, compared to $2.85 last year.

A couple comments on our realized price, specifically as it pertains to basis.

Basis was a negative $25.1 million in the quarter, or a negative $0.26 per unit, compared to a negative $2 million, or essentially flat basis last year.

We were able to mitigate some of the basis impact through fixed price sales, which added $6.4 million, or about $0.07 per Mcf equivalent to our realized price in the current year quarter.

The impact of these sales is reported in our hedge gain line item and the price reconciliation table.

As we think about investments and economics, we do focus on our projected realized price, of which basis is only one part, and our projects are still quite profitable at current levels.

Moving on to the Midstream results, in the third quarter operating income here was up 54%.

The increase is consistent with the growth of gathered volumes and increased fixed capacity-based transmission charges.

Net gathering revenues increased 19%, to just under $92 million in the third quarter 2013, primarily due to a 43% increase in gathered volumes.

The average gathering rate paid by EQT Production will continue to decline as Marcellus Production continues to grow as a percentage of our total production mix.

Specifically, the average revenue deduction from EQT Production to EQT Midstream for gathering in the quarter of $0.84 per Mcf equivalent was $0.16 per unit lower than last year.

Transmission revenues for the third quarter 2013 increased by $13.4 million, or by 50%, driven by fixed capacity charges associated with Equitrans' expansion projects, including Sunrise.

Storage, marketing, and other net revenue was up $2.8 million, primarily from unrealized gains on derivatives and inventory in the quarter.

As we have mentioned several times before, the storage and marketing part of the Midstream business realized on natural gas price volatility and seasonal spreads in the forward curve, and those have continued to deteriorate year over year.

Given current marketing conditions, we continue to estimate that full-year 2013 net revenues in storage, marketing, and other will total approximately $30 million.

Operating expenses at Midstream for the quarter of $61.4 million were about $3.5 million higher than last year, consistent with our growth in the business.

Just a quick note on guidance.

We are currently estimating our operating cash flow for 2013 full year to be approximately $1.2 billion.

We closed the quarter with no outstanding balance on our $1.5 billion credit facility, and had over $400 million of cash on our balance sheet as of September 30, 2013.

So we do remain in great position from both a liquidity and a balance sheet standpoint for the rest of the year and as we head into 2014.

And then with that, I'll turn the call over to Dave Porges.

Thank you, Phil.

As Phil summarized, operationally we are coming off another record quarter, with record volumes at Production and Midstream.

We have discussed the lumpiness of volume growth resulting from the timing of turning these big multi-well pads in line, Midstream projects, et cetera.

This was again evident in the third quarter.

We exceeded our Production sales guidance because some anticipated fourth quarter volumes were accelerated into the third quarter, due to the turn-in-line timing of some pads.

Much of this increased volume flowed through our gathering and transmission systems, driving the growth in those businesses also.

During the quarter we also turned in line our first three Utica wells.

The 30-day rates were published in today's press release.

We are encouraged by the results because they were in line with our expectations, and we are confident in our ability to improve well performance and reduce costs as we move up the learning curve.

From an absolute volume perspective, the wells in this part of the play, the volatile oil window, are not eye-popping.

However, what we still find attractive about this area are the significant amounts of high quality oil and very high BTU gas.

On a BOE basis, these wells averaged 42% oil, 28% NGLs, including ethane, and 30% gas.

When processing becomes available around year-end, we will receive premium pricing by stripping and selling the natural gas liquids.

Let's put the economics in perspective.

When using today's prices, the average 30-day initial production from these first three Utica wells is the revenue equivalent of natural gas wells with IPs of nearly 9 million cubic feet per day.

We're on track to drill eight wells this year.

We are still at approximately 14,000 net acres in our focus area within the Ohio Utica.

We have not added to our position since the last call, as we believe the currently high acreage prices warrant patience, certainly compared with the value we see in tack-on acreage additions near our core Marcellus hold-ups.

We will keep you informed on our future well performance and our acreage position.

As you also saw, we will be achieving a milestone of sorts in mid-November, when the recently announced EQM distribution becomes payable.

At that point, the EQM distribution will be $0.43 per unit, which is above the $0.4025 cents, or forty and a quarter cents, per unit threshold, at which incentive distribution rights for the general partner begin.

To remind you, EQM guided these investors to $0.03 per unit per quarter increases through at least 2014, which would mean reaching the top incentive distribution split for the GP late next year.

Given that there are only two months left in the year, we have very little to provide regarding guidance.

Fourth quarter production sales volumes are expected to be flat sequentially, in large part due to those pads, which were accelerated into the third quarter.

This would result in 2013 production sales volumes that are 42% higher than 2012 volumes, and fourth quarter volumes at 27% higher than the fourth quarter of 2012.

We are in the process of developing our 2014 capital and operating budget, which will be presented to our Board for approval in mid-December, so it's a little bit later Board meeting than normal.

At that time, we will inform you of our drilling plans, CapEx forecast, Production sales guidance, cash flow guidance, and Midstream EBITDA guidance.

This, of course, is our normal timing, given our Board's authorities and the governance procedures that we have in place.

We have, however, completed our annual strategy review with our Board.

None of what we agreed upon should surprise you, but at a high level, you should expect us to -- one, continue to accelerate the pace of development of our Marcellus play, which is our highest returning asset.

Two, continue co-development of the Upper Devonian play, where appropriate.

Third, continue to focus acreage acquisitions in our core Marcellus development areas.

Fourth, pursue monetization of non-core or less core assets.

Fifth, continue to accelerate drops into EQM above the level of EQT Midstream investments.

And six, increase investment in Midstream projects, increasingly directly at the EQM level rather than the EQT level, to serve other producers.

On that last point, there is a tremendous need for additional gathering and take-away capacity, and our Midstream system is strategically situated to make profitable investments.

Also, EQM has the appropriate cost of capital to pursue more of those investments.

We have little new to report on the regulatory reviews related to the sale of our gas utility, Equitable Gas Company, except that the Kentucky Public Service Commission concluded that it did not need to approve the transaction.

We had previously listed them as an organization that did to have approve it.

As you already know, the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act expired, and we are free to proceed from a Federal Trade Commission perspective.

We have also submitted filings with the Pennsylvania Public Utility Commission, West Virginia Public Service Commission, and Federal Energy Regulatory Commission, each of which must approve the transaction as part of the regulatory process.

There have not been any unexpected developments in this lengthy process, and we still expect to receive all necessary approvals by around year-end.

In summary, EQT remains committed to increasing the value of our vast resource by accelerating the monetization of our reserves and other opportunities.

We continue to be focused on earning the highest possible returns from our investments, and are doing what we can to increase the value of your shares.

We look forward to continuing to execute on our commitment to our shareholders, and we appreciate your continued support.

And with that, I'll turn the call back over to Pat Kane.

Thank you, Dave.

This concludes the comments portion of the call.

Chad, can we please now open the call to questions?

Certainly.

We will now begin the question-and-answer session.

(Operator Instructions)

Neal Dingmann, SunTrust.

Morning, guys.

Say, Dave, maybe for you or Steve, question -- you've got that big acreage -- Marcellus play in the northern West Virginia area -- your wet gas area there.

I'm wondering -- in that position, what you all's thoughts?

I know there's been chatter recently after the [race on] Entero and some other deals about dry Utica potential in a part of that.

I would say maybe even a large part of that.

Just wondering if, Dave -- yours or Steve's thoughts about that, around that area, if that's something you would be looking at, or are you going to continue to focus on the wet Marcellus there?

Well, eventually we will look at any area that has the potential for economic resources.

I'll let Steve give a more specific response, but I would say it's not top of our list right now.

We've got plenty of things on -- at that top of the list, and that's not really one of them.

I really don't have much to add.

I agree, it is on our radar, but not at the top of our list.

It's deeper, it's more expensive, it's dry gas.

We are going to be focused on the more profitable Marcellus opportunity in that area for now, and we'll see what develops with the dry gas Utica.

Certainly, there's some potential there, but not a high priority right now for us.

And then, guys, in that same area, have you picked up any acreage recently there?

I have heard of prices, certainly recently, increasing there pretty substantially.

I'm just wondering if you have, and any thoughts on what sort of M&A deals are going for?

Neal, we really haven't picked up anything of any significant size.

We're always continually picking up pieces to fill in drilling units.

And prices fluctuate, but they're more -- the small pieces we're picking up are more location specific.

So, I don't know that we have much of a read on any major changes in acreage pricing in that area.

So, I think you know, Neal, a lot of times we get a little bit better deals on acreage in the Marcellus because it is closer.

The stuff we focus on is the stuff that's closer to our own development areas, and probably has a little bit less value to others.

Okay.

And then, again, with your Midstream, I know there's been, for some other people, some take-away challenge -- infrastructure challenges there.

But, Steve, it sounds like, I know with your Company, it sounds like you're well on the way as far as Midstream or infrastructure there.

Isn't that the case?

Yes, though Randy's really probably a better one to comment on that.

Yes.

Neal, this is Randy.

Absolutely, we're in strong shape.

We had the Sunrise pipeline that was completed last year that added incremental capacity in that area as well.

And we continue to add additional infrastructure to keep ahead of the pace of Steve's team.

So, I think we're in solid position.

Okay.

Then, very last one, if I could, just very quickly -- on that Utica acreage, 13,000 or 14,000 acres -- any thoughts on a type curve or how you, Steve, feel like those wells will hold up?

I think, obviously, it's pretty early.

Those three wells are fairly new.

I think the IPs were about where we expected, given that it's our first venture into the play.

I'll say they're performing much better than our first wells in the Marcellus did, from a relative standpoint.

We're sure hopeful that we'll be able to improve our drilling completion practices, lower costs, and increase productivity.

So, I think we're fairly encouraged.

And the returns, even at what the first three wells are doing, are not bad.

So, I think we're encouraged, but I think acreage prices in the Utica have been pretty high.

It's a pretty competitive area right now.

And I think our view is -- we're going to be patient, and only pay what price the resource warrants.

Time will tell how much acreage we're able to gather.

That's perfect.

Thanks, Steve.

Nice quarter.

Thanks.

Drew Venker, Morgan Stanley.

Morning, guys.

Just wondering after Devon announced its midstream transaction this week, if you would be open to considering a similar transaction if the right opportunity arose?

Or if you've looked really at that transaction at all?

We've looked at it a little bit.

We actually rely on bankers, probably including colleagues of yours on the other side of the Chinese wall, to give us better feels for what those transactions entail, because basically we're open to anything that's going to help create shareholder value.

Okay.

Is there anything -- any other avenues you have looked at recently to monetize your GP interests, or your other wholly owned Midstream assets that you can discuss?

We're monitoring all of that.

We've got a notion of what our inventory, as it were, is for droppable assets.

And I think, as we have probably mentioned in the past, maybe not in these broad calls, but there's often a number of contracts that have to be put into place.

And that we keep working on those for the ones that are at the top of the list as being the first ones to get dropped, and doing other things that are necessary to make some of the assets droppable, as it were.

As far as the GP, yes, eventually we're going to have to do something with that.

But right now, our attitude is -- let's get the drops going, or keep them going at a good pace.

And that's why we commented on exceeding the level that we had talked about initially of what Midstream investments EQT makes.

And that will be a nice problem to have -- when we have created enough value there that we need to figure out ways to monetize it.

We fully expect that that is going to be a fork in the road that we reach.

Okay.

Makes sense.

And then, one on the Marcellus.

It looks like you guys have completed something like 80 wells year to date, or connected 80 to sales.

And, if I'm not mistaken, your plan for the year is to connect, or to complete 146.

Can you help me with the pace of completions in the back half of the year?

Yes, I think our pace is always lumpy.

And if you look back over the previous several quarters, you will see the number of stages we bring online in any quarter.

Just so far this year it's varied from, I think, a low of right around 300 stages to a high of 1,500 stages.

That's heavily driven by the timing of our large, multi-well, multi-frac, 30-foot cluster-spaced wells.

So, it's going to continue to be lumpy.

I think the fourth quarter we plan to bring on more stages than we did in the third, but it will be far from the number we did in the second.

So, it will be sort of a modest quarter in terms of [PILs] with -- I think our projection is first quarter will likely be probably above average, when we look at likely timing of the frac jobs and the drilling rigs.

Okay.

So, some of the wells you are drilling this year maybe will be completed into next year -- maybe a meaningful portion?

Yes, a meaningful portion.

Okay.

That's all I had.

Thank you.

Michael Hall, Heikkinen Energy Advisors.

Good morning.

Appreciate you taking my call.

Drew got one of my key questions there.

It was just on timing of completions, and it sounds like fourth-quarter 2013 may be a bump to the third quarter, but don't make up the full year.

As I look at the third quarter, you tied on fewer wells than I had expected, and yet had a very strong production result.

Implied good efficiency from the wells.

Just wondering if there's any updated commentary around Marcellus type curves in that context?

And how wells are hanging in, relative to the curves you put up earlier this year, and how we might think about that heading into 2014?

Michael, we updated our curves earlier this year, and I think we tend to like to gather a lot of data before we update those.

So, no further updates at this point, other than to say we were pretty comfortable with the new curves when we put them in place, and continue to be comfortable with those.

So, I think the wells are doing what we expected.

Great.

And then, on the NGL guidance front, just a little curious on that.

It was a little lighter than I had expected.

Is there any continued impact from a Midstream side on the NGLs and the outlook for the fourth quarter?

Any sort of Midstream things we're getting through, or is that just a --?

The issue in the quarter was there was a MarkWest facility that ran into some operational issues.

Right.

I don't know if Randy wants to provide some timing updates on that.

But that would have -- if you are wondering why it was not as high as you would have thought, it was due to that type of a short-term issue.

Right.

But has that flowed into the fourth quarter then?

That's what I was trying to get at.

I thought that was more of a third-quarter event than fourth.

You're right, Michael.

That NGL line that David referenced, MarkWest take-away out of the Mobley plant, has been back in service.

So, that impact doesn't extend into the fourth quarter.

Okay.

And then last one on my end -- we've talked about it in the past.

You've got a lot of cash coming in.

Some recent things in the market have suggested use of proceeds around share buybacks.

What's you all's view on share buybacks in terms of using the cash you've got coming in?

Just curious on your thoughts there.

It's a good benchmark to be using when we're comparing it to other investment opportunities.

And let's face it, the realistic other investment opportunities for us, as I mentioned when I talked about strategy, are increased development in our core areas, the possibility of those tack-on acreage acquisitions.

On the Midstream side, though, this would typically be at the EQM level -- projects that would tend to serve other producers.

The kind of projects that are attractive with EQM's cost of capital, but that EQT was never particularly interested in pursuing.

So, those are the things that you look at, and we just think, as a discipline, you should always be comparing those to share repurchases.

And our main point was -- we're not afraid of what happens if we wind up with a lot of cash, because we have dropped quicker than we need money, or sold non-core assets before we need cash.

If the right thing to do is to drop the assets at a quicker pace into EQM, or if the right thing to do is to sell some other non-core or less core assets, then that's what we're going to do.

And we'll figure out what to do with the cash that results.

As you look at that -- and that's helpful -- how do share buybacks stack up in that context at present, relative to the other potential uses of the cash?

(multiple speakers) Are you limited somewhat in your ability to accelerate on the upstream side, and does that play into any sort of thought process?

I don't know if I want to say that we're limited in our ability to accelerate, but we do -- as this is just kind of the norm in this area -- we do run into judgment calls on whether you develop now with a pad that has fewer wells, shorter laterals, or whether you give it a little bit more time to try to get the acreage or the permits to be able to have more wells on a pad, longer laterals, et cetera.

So, you do run into those kinds of timing issues.

We also don't like to be -- have artificial milestones that would inhibit us from making the right economic decision there.

But more broadly, we're probably best off letting our whole capital budget process play out with our Board before we get into the other topics.

Obviously, the preference, of course, is -- if we have attractive investments in our core that create the value that we've been creating, we certainly recognize that that is the preferred route to go.

We just don't want to force it and get to the point where we're making investments that don't stack up versus share repurchases.

Okay.

That's helpful.

Appreciate it.

Actually, I had one last simple one.

The annual strategic review, just to be clear, that last bullet point you outlined -- drive spending on the Midstream side.

Is that at the EQM level that that spending would occur?

(multiple speakers)

Yes.

That was the point I was trying to make, is that you should expect to see more of that spending at the EQM level.

And we do recognize that that means when we start -- when we're providing CapEx guidance, we're going to have to be careful to provide guidance on what spending is occurring at the EQT level versus at the EQM level, because EQT's consolidated reports will include all of the EQM spending.

And that gets -- we recognize that can get tough to sort out, because the cash flow isn't really coming into or going out of EQT Corp.

It's going through EQM.

Great.

That's helpful.

I appreciate it.

Congrats on a good quarter, guys.

Ray Deacon, Brean Capital.

Randy, I was wondering if I could ask you a question about pricing at the M2 hub, and how you see that changing going forward, relative to other places where you're selling gas?

Sure.

Obviously, you saw what Phil reported today in terms of our basis.

I think he also pointed out that we had some forward sales that show up in the hedge line that contribute a positive $0.07.

But overall, Ray, with respect to basis and M2, from a short-term perspective, short-term basis mark, they're really fundamentally driven.

I think Tetco and the M2 is a strong pipeline with access to good markets, but really, any assumption for pricing for the winter, for next summer, is subject to a lot of inputs, as you know -- the weather, supply disruptions or growth, really, the absolute NYMEX, storage fills.

But the impact to the infrastructure projects to transport the gas out, that the M2 and Tetco are working on are more certain variables.

I think these projects are going to continue to help mitigate any supply and demand imbalances in the region.

Okay.

Got you.

And I was wondering, any further update on the Upper Devonian?

I was wondering if you could also talk about how development going forward might look on pads to incorporate Upper Devonian wells?

Ray, this is Steve.

No further technical update on the Upper Devonian.

And I think we still are looking at what we think the best development scenario for that is, regarding number of wells on a pad and timing of Upper Devonian versus Marcellus.

We haven't really concluded that study yet.

We're still gathering data.

But my gut feel is -- it is likely going to conclude that for -- especially for the bigger pads, pads where we have the potential to drill a total of 20 wells.

It is most likely to look like drilling a portion of the Marcellus and a portion of the Upper Devonian, and then de-mobing the rig and coming back in a year or two and drilling the other -- generally, it would probably be all in one direction, and then the other half in the other direction at another time.

But I think our thought is that from a completion standpoint, we are going to be better off fracking the Upper Devonian and the Marcellus, the stacked side, at the same time, rather than doing all of the Marcellus, and coming back and doing Upper Devonian later.

Then, when we look at the economics of doing, say, 20 wells from one pad, and the infrastructure and facility investments that would be required to handle those peak rates, I think it is going to be economically more optimum to split it into two pieces.

That's where I think we're headed.

But we're still studying it to find out for sure.

I don't know if that answer helps you or not.

That's very helpful.

Thanks.

Phillip Jungwirth, BMO.

Good morning, guys.

Sticking with the Upper Devonian, have you seen any change to the performance of the 2013 vintage wells versus the wells that you highlighted last quarter, which I think had EURs of 1.2 Bcf per 1,000 lateral foot?

So, are you asking if the Upper Devonian wells have impacted the Marcellus wells?

No, if the new wells --

No, if the newer wells have seen improvement versus the 1.2 Bcf that you quoted.

We don't have enough new data to really draw any conclusions on that.

So, I would say no at this point.

Okay.

And then, in terms of acreage acquisitions, do you have a target in the Marcellus, such as you think you could pick up maybe 10,000 acres over the next year, or 20,000 acres?

No, it's just whatever is economical.

Okay.

The only thing we're influenced by though, really, is that sometimes something is more economical if it can alter the existing development plants.

And a lot of times, that depends on what the opportunities are available.

That's certainly what happened with that Chesapeake acquisition earlier this year, and those are obviously the ideal situations.

But, no, we have not had a target.

We've tried to stay away from that.

Because, again, our fear is if we have targets on things like that, we'll wind up doing things that are not economical.

Okay.

And on the three Utica wells, what was the average well cost and lateral length there?

The average well cost for those first three wells, I believe, was around $8.5 million, but they included a significant amount of science, we call it -- so, coring, specialty logging, some fairly long well lines to get to our gathering system.

So, we don't think -- the well cost for the first three are not representative of what we expect.

We expect well costs there to be in the $6.5 million per-well range going forward.

Oh, and the average lateral length -- they range from 4,500 to 6,800.

I don't have the average in front of me -- 5,800 feet, I think it is.

Right.

And then last question on the Midstream drop-downs.

Can you just remind us of the historical guidance there?

I think it has been one drop a year, and then in terms of size, it would be Midstream CapEx, which was around $350 million.

For accelerating that, are you talking increasing the pace of drops, the size, or both?

Well, first of all, I don't know that we ever guided to the number of drops per year, but the dollar amount numbers that you were quoting, that's correct -- is that we were, at the time of the IPO, probably linking it to Midstream CapEx at the EQT level.

I guess you'd say, upon further review, that is -- EQM is the better place to own some of those assets.

So, the timing on the drops is really set more by when an asset at the EQT level is in a position, both legally and operationally.

A lot of times it might mean you filled a lot of it up contractually, as well, so that we can drop it, and the capital markets access as the EQM level.

But that's really what's setting it.

Therefore, I don't really want to give a number on what the dollar amount would be.

But you should expect that until we start running low, that we're going to be averaging well above that level of the EQT Midstream CapEx.

Of course, the other moving piece, as EQM continues to grow, it's a little easier for EQM to wear projects at the EQM level.

The main reason we haven't been doing very much investment at the EQM level is because, in that vehicle, it's very difficult to have a lot of cash, or a lot of investment in non-cash-generating projects.

So, that wait period from when you start putting the cash in, to when you get the cash flow out from fees -- that's tough.

It's tough to have too much of that.

But as EQM grows, it's easier to have more of that, and to be able to wear more projects at that level.

So, that's the other thing that you should be seeing, which we probably didn't -- we talked about the possibility of that happening at the time of the IPO, but we weren't really anticipating any specific projects.

And now we're tending to look more at projects that would be at the EQM level.

Okay, great.

And with that, should we think of any amount of CapEx -- Midstream CapEx -- that's now being spent by EQM as being used in the upstream business?

Is it a 1-for-1 type relationship there?

No, we've come to have more of a -- don't want to be too much of a purist, but money is fungible, and you make the right investment decisions based on what you think creates the most value.

And you don't necessarily say -- money from this area goes into that area.

It's much more -- what do we think will create the most value?

Practically speaking, we are focusing the EQM investments on projects that tend to support other producers a little bit more.

And the EQT Midstream projects are a little bit more the ones that support EQT.

But I think, at this point, that's just kind of happenstance.

It's not necessarily that there's some philosophy.

The philosophy is just -- keep assessing how can we create more shareholder value?

Great.

Thanks, guys.

This concludes our question-and-answer session.

I would like to turn the conference back over to Pat Kane for any closing remarks.

Thanks, Chad.

And thank you all for participating.

The conference is now concluded.

Thank you for attending today's presentation.

You may now disconnect.