Ladies and gentlemen, thank you for standing by, and welcome to Peabody's Second Quarter Earnings Call. As a reminder, today's call is being recorded. I'd now like to turn the call over to Mr. Vic Sweck, Senior Vice President, Global Investor and Corporate Relations. Please go ahead, sir.
Okay. Thank you, Ebony, and good morning, everyone. Welcome to BTU's 2nd quarter earnings call. And with us today are President and Chief Executive Officer, Glenn Kellow and Executive Vice President and Chief Financial Officer, Amy Schwetz. During our formal remarks this morning, we'll reference a supplemental presentation and that's available on our website atpeabodyenergy.com.
Now on Slide 2 of the deck, you'll find our statement on forward looking information. We encourage you to consider the risk factors that we reference here along with our public filings with the SEC. I would also note that we use both GAAP and non GAAP measures and we refer you to our reconciliation of those measures during the presentation and our earnings release. And with that, I'll now turn the call over to Glenn.
Thanks, Vic, and good morning, everyone. Peabody had yet another active quarter with several positive steps taken at both the operational and portfolio levels. We are also conducting a review of the project path for North Goonyella and I'll talk more about that later. Let's start with a few of the highlights. Once again, we had strong performance from our seaborne thermal business with 34% adjusted EBITDA margins.
Our seaborne metallurgical segment also generated healthy adjusted EBITDA margins of 29% when excluding project costs related to North Goonyella. These results were aided in part by our Shoal Creek mine, which remains a standout performer. Cash flows from that mine continue to be on pace for a less than 2 year payback period. As we strive for operational excellence, I'm pleased to note that multiple operating segments improved cost compared to the prior year. We also continue to shape our portfolio to create value for our shareholders.
In June, we announced the joint venture of our PRB and Colorado assets with Arch. This combination is aimed at unlocking extraordinary synergies and creating exceptional value for customers and shareholders by strengthening the competitiveness of coal against natural gas and renewables. We remain firmly committed to executing on our shareholder return program. Year to date through June, we have returned more than 120 percent of our free cash flow to shareholders through our share repurchase program, ongoing quarterly dividend and supplemental dividend. And we plan to accelerate our share repurchases in the second half of twenty nineteen following the required blackout period related to the JV transaction.
With that, Amy will now cover the financials in more detail.
Thanks, Glenn, and good morning, everyone. 2nd quarter revenues totaled $1,150,000,000 reflecting the combined impact of reduced metallurgical coal volumes and lower realized seaborne pricing compared to the prior year. In the Q2, DD and A totaled approximately $165,000,000 in line with the prior year and below the Q1 of 2019. We expect this downward trend to continue through the back half of the year. 2nd quarter SG and A was also in line with our expectations, declining 12% to $39,000,000 on lower outside services.
Income from continuing operations net of income taxes totaled $43,000,000 compared to $120,000,000 in the prior year. Diluted earnings per share declined $0.56 from the prior year to $0.37 per share. Adjusted EBITDA in the 2nd quarter was $228,000,000 versus $370,000,000 in the prior year. Adjusted EBITDA includes $2,300,000 in charges associated with voluntary employee reductions at North Goonyella and $1,600,000 in transaction costs related to the PRB Colorado joint venture. As reflected on Slide 4, our seaborne segments delivered over half of our total mining adjusted EBITDA in the second quarter.
Excluding North Goonyella project costs, our seaborne met segment led the company in adjusted EBITDA contributions of $86,000,000 with 2nd quarter shipments of 2,100,000 tons and an average realized price of $138.42 per ton. Shipments in the quarter were impacted by a planned longwall move at the Metropolitan Mine and ramp down of the Millennium Mine as well as lower than ratable volumes from the Coppabella Mine. Coppabella continues to improve from challenging conditions experienced in the Q1 of 2019 as evidenced by some $50 per ton of cost improvements in the 2nd quarter at the mine. Seaborne met costs excluding the impact of North Goonyella totaled $97.61 per ton. Year over year, met costs rose $8 per ton, largely attributable to the timing of the Metropolitan longwall move.
This impact was muted by the inclusion of lower cost Shoal Creek volumes. In regard to North Goonyella, project costs totaled $28,000,000 and were below the quarterly guidance range of $30,000,000 to $35,000,000 given activity levels at the mine. This is even with $2,300,000 in charges related to a voluntary reduction program extended at the mine. Adjusted EBITDA contributions were driven by another quarter of exceptional performance from the Shoal Creek mine, which delivered costs below the low end of the prior annual guidance range for the mine. During the 1st 6 months of the year, the mine has generated $110,000,000 in adjusted EBITDA.
I'd also note that our share of the Middlemount mine added another $10,000,000 to adjusted EBITDA this quarter. As a reminder, this includes DD and A, asset retirement obligation expense, net interest expense and income taxes, which totaled about $9,500,000 in the second quarter. Moving on, approximately $74,000,000 of adjusted EBITDA was contributed by our Seaborne Thermal segment, which sold 2,700,000 tons of export thermal coal at an average realized price of $68.53 per short ton during the quarter. As expected, export volumes were muted by a scheduled longwall move at the Wambo mine. The longwall move also impacted our mix with Newcastle spec product representing only 58% of shipments during the quarter.
With the longwall move now complete, we still expect to be within our guidance range of 60% to 70% for Newcastle spec shipments for the year. Even with the longwall move, cost per ton for this segment improved 4% compared to the prior year. Cost came in below the low end of our annual guidance range, thanks to strong performance from our low cost Wupenzhong mine, improved mining conditions and favorable FX. Within our U. S.
Thermal operations, cost per ton improved 4% versus the prior year due to fewer repairs and favorable pit sequencing at the Kayenta and El Segundo mines even with lower volumes. Overall, U. S. Thermal adjusted EBITDA totaled $123,000,000 compared to $138,000,000 in the prior year. Moving to Slide 5, I'd like to walk through some key points on the balance sheet and cash flow.
2nd quarter operating cash flows of $179,000,000 and CapEx of $61,000,000 led to $154,000,000 in free cash flow. As of quarter end, cash and cash equivalents totaled $853,000,000 with $1,200,000,000 in available liquidity. Year to date through July, Peabody has returned $436,000,000 of cash to shareholders. Share repurchases during the Q2 totaled 57,000,000 dollars reflecting limitations on buying due to relatively low trading volumes and a required blackout period in relation to the joint venture announcement in mid June. We have since resumed buyback activities with an additional $51,000,000 repurchased in July.
I'm pleased to note that since the initiation of that program, we have repurchased 25% of our initial shares outstanding. That's a total of $1,200,000,000 bought back with approximately $283,000,000 remaining under the current program. Furthermore, in May, we announced the 3rd increase to our quarterly dividend per share in just 1 year. Dividends year to date have totaled $229,000,000 including our $200,000,000 supplemental dividend announced in February. With that, I'll now turn the call back to Glenn.
Thanks, Amy. I'd now like to focus on the 3 strategies we're executing to create value for our shareholders. First, we are continuing to reweight Peabody's investments to have greater access to seaborne thermal and seaborne metallurgical coal to capture higher growth demand. Case in point Shoal Creek, which has been a tremendous addition to our seaborne met portfolio over the past 6 months. 2nd, in the U.
S, we are focused on maximizing cash generation in a low capital fashion through our low cost, higher margin operations. Our recently announced joint venture is a prime example of industrial logic put into meaningful action. And finally, for some time now, we've been advancing our stated financial approach of generating cash, maintaining financial strength, investing wisely and returning cash to shareholders. The result some $1,500,000,000 has been returned to shareholders in less than 2 years. Let's now consider the industry fundamentals that play into each of these strategies and the actions we're advancing in response beginning on Slide 7.
Within seaborne met, we saw resilience in both hard coking coal and high vol A pricing on stable demand growth and muted supply responses during the quarter. Pricing has since eased, largely due to global concerns around trade and economic growth. In China, seaborne metallurgical coal demand was up 7,000,000 tons year to date through June on increased steel needs and stimulus measures. In addition, India seaborne demand increased some 7% year over year and we would expect India to continue to be the major growth driver over the longer term. Given this backdrop, we're continuing to capture value from our high quality, low cost Shoal Creek mine.
We're also paving the way to expand volumes from existing sources in the near term. This would include opportunities extend the life of the Morbarr mine beyond 2025 with increased quality as early as 2020 as well as reducing met costs in the back half of the year. Turning to North Goonyella. Major progress has been made to date, including re ventilation and reentry of the mine. We've also learned a substantial amount since we commenced activities underground earlier this month.
While the milestones achieved in recent weeks have been significant, we also have progressed at a much slower rate than originally contemplated. We recognize that this work is unprecedented in Queensland. All advancement during the recovery phase has been subject to the discretion of the regulatory authority, special protocols and substantial related administrative requirements. As you recall last quarter, we noted that if further delays were to occur, the company would reevaluate our plans for the mine. We did in fact experience greater delays than we would have anticipated.
We continue to take action to appropriately scale on-site activities based on underground conditions and external factors. We assure that all work has been and is currently being undertaken including the highest regard for safety and is required to preserve value. These actions include the completion of a voluntary redundancy program as well as further engagement with the Queensland mines inspector on the evolving recovery protocols. Because this new information likely influences our future progress, now is the right time to review the project and determine if delays can be overcome, current plans should be advanced or other alternatives should be pursued to create the most value out of this significant asset. Let's focus a moment on the prospective path we are assessing.
Right now, our team is performing extensive value engineering activities aimed at maximizing returns on a risk adjusted NPV basis and payback period as well as reducing spending on non critical items. Parts we are pursuing include determining the base case to access the 10 North Panel remains the most attractive given timing, costs and project risk. We are also evaluating an alternative route through the 2nd zone to the southern panels of the mine among other scenarios. Note that all paths will preserve the opportunity to access more than 40,000,000 tons of high quality hard coking coal from the lower seam reserves over time as well as potential for commercial alternatives. Given our ongoing activities, we are suspending North Goonyella related targets at this time and intend to resume targets around production timetables and costs when the preferred path is chosen.
And we would expect to complete the evaluation within the next 3 months. I would note the costs related to activities conducted in July were consistent with our previous run rate of $30,000,000 to $35,000,000 per quarter. Our preferred path will ultimately determine our costs going forward. The underlying goal of our approach is simple, to create the most value from this asset over time. Moving to seaborne thermal on Slide 9.
Quarter after quarter, this segment achieves adjusted EBITDA margins well in excess of 30%. While seaborne thermal pricing declined due to weak Atlantic demand, strong supply and temporary low cost LNG, Newcastle spec pricing has since rebounded from the lows observed in the Q2. API 5 pricing for Asia Pacific demand has held in nicely compared to other benchmarks such as API 2, which is tied to imports in Northwestern Europe. As you see in the graph to the right, the spread between Newcastle and API 5 has compressed over the last year. As we look closer at demand fundamentals, we've seen a surge in thermal imports into China in the second quarter.
In addition, India thermal imports were up some 13,000,000 tons year to date through June driven by strong industrial sector demand. Strong demand from Asian countries including Vietnam and Malaysia continues as well. Through the first half of the year increased generation and new coal fuel capacity led to an 11,000,000 ton increase in the ASEAN seaborne demand. Refocusing now on Peabody, we benefit from strong contracting strategies particularly on the seaborne thermal side of the business. Let's consider our positioning for a moment.
In the Q2, average spot Newcastle pricing declined 23% compared to the prior year. In contrast, Peabody's realized seaborne thermal pricing declined only 14% as we previously locked in contracts at more favorable pricing. And that's with only 58% of our volumes equivalent to Newcastle spec product in the quarter. We believe we are well positioned with 3,600,000 export tons priced at an average price of about $83 per short ton for 2019. We also have 2,100,000 tons of both Newcastle and API 5 coal price for 2020 at an average price which is currently above the Newcastle forward curve.
In regard to our thermal portfolio, we have Tier 1 assets and are continuing to enhance these operations avenues such as the United Wambo joint venture with Glencore. The JV is anticipated to form later this year with production expected in 2020. Let's now move to U. S. Thermal, which continues to face headwinds.
Through June, total electricity generation declined 2% year over year on fewer cooling and heating degree days in the demand heavy months of January June. Year to date, coal accounted for just 24% of the generation mix as natural gas pricing declined to a 3 year low and captured additional share. Also during the quarter, flooding across the U. S. Again impacted rail shipments and contributed in a 6% reduction in production year to date.
In addition, the PRB has had more activity during the past quarter than we've seen in years between the Chapter 11 filings as well as our JV announcement. On the regulatory front, the implementation of the Affordable Clean Energy or ACE rule offers individual states greater flexibility in the development and timing of state implementation plans, avoiding a one size fits all approach to managing distinct and diverse needs. While early days, WoodMac suggests that this new rule could potentially increase coal consumption by about 3% annually, all other things being equal. Still given the challenges that remain in the current U. S.
Environment, Peabody is taking what we believe to be the appropriate actions to improve our competitiveness within an oil fuels market. To start, we are continuing to operate complexes where possible allowing us to move contracts, people and equipment as needed to meet custom demand. And as mentioned, we're executing a highly synergistic joint venture to allow us to better compete against natural gas and subsidized renewables for the benefit of many, including our customers and our shareholders. Let's talk about those synergies in more detail on Slide 11. The JV expects to unlock synergies with a pretax NPV of $820,000,000 We expect the average synergies on 100% basis to be approximately $120,000,000 per year over initial 10 years.
Perhaps the greatest synergies can be achieved through optimization of mine plans, particularly at the North End Loeb Rochelle Mine and Black Thunder Mine. These two adjacent operations are well capitalized and share a common border that stretches more than 7 miles. There are 4 loadout facilities and numerous mining pits with multiple products and cost profiles. Additional synergies include better deployment of fleets and more efficient procurement. Through the transaction, we believe we'll be able to enhance our blending capabilities to more closely meet the requirements of our customers.
We also expect to improve utilization of the combined rail loadout system among other rail efficiencies. With more efficient mine planning and deployment, we also expect to reduce long term capital requirements while leveraging our scalable shared services model. Since our announcement in June, necessary Hart Scott Rodino filings have been submitted to advance regulatory approval and the transaction is under review by the U. S. Federal Trade Commission.
To date, we've received early support from multiple stakeholders. At this time, synergies are continuing to be refined and evaluated for further opportunities. I'll now turn the call back to Amy to discuss our 3rd strategy, which emphasizes our financial approach.
Strong operational performance drives our cash generation and prudent deployment ensures our financial strength. In fact, we converted 2 thirds of our adjusted EBITDA into free cash flow in the Q2, in part due to our substantial NOL position in both the U. S. And Australia. Within that context, I'd like to focus on the last two components of the approach, invest wisely and return cash to shareholders.
In terms of investment, whether that be investment in our current portfolio of assets or M and A, our investment filters remain the centerpiece of all activity. The hurdles for investment are considerable, but not impossible, as demonstrated by transactions over the past year. Our dollars also continue to be spent on the investment in the company that we believe represents the best value, BTU. As such, we have continued to execute a robust share repurchase program in addition to a quarterly and supplemental dividend. To date, we have returned more than $1,500,000,000 to our shareholders in just under 2 years.
And in 2019, we intend to return to an amount greater than our free cash flow with second half share buybacks expected to accelerate relative to the 1st 6 months of the year. Turning to Slide 13, I'd like to discuss our outlook for the second half of twenty nineteen. First, based on current pricing levels, we expect second half adjusted EBITDA contributions to be largely in line with first half results and would expect the 4th quarter to be stronger than the 3rd. 2nd half adjusted EBITDA reflects North Goonyella and JV related expenses as well as 2 mines reaching the end of their economic life. We would anticipate a progressive increase in our seaborne thermal and met coal volumes in the 3rd and 4th quarters.
In addition, Kayenta Mine is scheduled to cease production and sales early in Q3 of 2019 despite strong year to date demand from the Navajo Generating Station. As we talk about the timing of shipments, I'd also note that Shoal Creek shipments will generally be ratable throughout the year given the seamless nature of longwall moves at the mine and inventory levels that are expected to offset any planned reductions in yield. 3rd, we continue to believe our share price represents a compelling investment and we are committed to accelerating our share repurchase activity in the second half of the year. Glenn?
On Slide 13, I will note that we've launched a review of the company's organizational structure and functional support activities. The aim is to further enhance our capabilities while streamlining processes across a number of fronts. We are also working to ensure our operational leadership continues to focus on key value drivers within those portfolios and have the best resources about readily available. We've retained the process improvement arm of Alvarez and Marcell to assist us in this comprehensive review. We've also made several changes to the company's leadership.
Charles Menkes has been named Executive Vice President and Chief Operating Officer with responsibility for operations, sales and marketing and technical services as well as the responsibility of achieving the PRB Colorado joint venture synergies. As some of you may recall, Charles has led both business units in the past and has deep operational experience on 3 continents. In addition, Jaime's role as Executive Vice President and Chief Financial Officer has been expanded to include responsibility for corporate development, information technology, shared services and coal generation emissions technology. The aim of these changes also allows for Amy and Charles to guide their respective operational and functional areas as part of the organizational review. Also current group executive of U.
S. Operations, Mark Hathorn has been named Head of our Australian Operations, bringing sharp operating focus to these important assets. To wrap up today, Peabody is defined by our diverse set of assets and our ability to continue to shape the portfolio, take the PRB Colorado JV as well as Shoal Creek, which by the way contributed more adjusted EBITDA this quarter than North Goonyella did in quarter 2, 2018. As to that, our commitment to sharing our returns with shareholders in a tangible way, I believe the result is a compelling value opportunity. With that, I'd like to turn the call over for questions.
Operator?
Thank
We'll take our first question from Daniel Scott with Clarksons. Please go ahead.
Thanks. Good morning. Glenn, looks like a real good quarter. Shares are getting hit a little bit, I assume, on the North Goonyella developments. Is there a scenario where potentially this mine would be closed or is this are you really just trying to find the most optimal way to continue production?
From our perspective, we're looking at the most optimal way to create value and to continue to capture value. So that's the scenarios around which was the base case of accessing 10 North. We talked in the past about alternatives and at this point, we're continuing to evaluate an alternative path of moving through the 2nd zone and optimizing or accessing those southern panels. And in any scenario, having reentered the mine and particularly having opened up now Zone A, opens up the lower seams available to us. So this is about seeking to maximize the value given what we now know about the operating conditions particularly the regulatory environment, the protocols that we're operating under.
Given the reserve life, it sounds like it's highly unlikely that this mine would be closed. It's just finding a way to get to the coal most economically?
That's exactly right from our perspective. We believe this is a tremendous mine with great infrastructure and significant reserves of high quality hard coking coal. We want to make sure that we execute the right path using appropriate evaluation.
Okay, great. Interesting comment, obviously Shoal Creek has been a real positive and having it outperformed the year ago levels in North Goonyella is impressive. It still kind of looks like a one off asset given it's whatever 13,000 miles away from the next coking coal asset in the portfolio. You talked in the slides about reweighting investment towards Greater Seaborne Met and Thermal. At some point, does that mean more add ons?
Is it North America? Is it Australia? And on both sides really thermal and that.
Look, we've talked about our strategy being about re weighting the seaborne met, seaborne thermal as you've indicated. I think Shoal Creek has been an example of that and what we talked about, although Shoal Creek is closer to St. Louis than some of our U. S. Thermal operations.
Really what we liked about Shoal Creek other than the quality of the coal, the cost structure was its access to those seaborne markets. And we talked previously about the fact that we actually share common customers with some of our Australian portfolio. So that indicates that if we could do a Shoal Creek, if Shoal Creek comes a lot, we'd certainly be highly interested in it. But as we've said, we've also articulated a pretty strict set of investment filters to which you've seen us being disciplined by operating within that. Wouldn't leave out the U.
S. Portfolio because you can see we've been highly active on that front as well. And what I think and believe is can potentially be a transformation transaction in the Powder River Basin with the objective of that being about increasing the competitiveness against coal against natural gas renewables.
We'll take our next question from Michael Dudas with Vertical Research.
First question is, you talked about the drink venture that was announced last month and in the slides you talk about stakeholder support. So maybe you can elaborate a little bit like what type of stakeholders,
what's been
some of the feedback, positive and even some negative, you can share that from what you've had for the last 5, 6 weeks?
Sure, Mike. Well, we've been pleased from the reaction from a variety of stakeholders be they government organizations, the state authorities, representative organizations, suppliers. We've certainly had some positive comments from some customers. Probably the negative, not unexpected is we've seen some criticism being directed at us from environmental agencies. But overall I'd say to date, we've been pleased by the reaction that we've received.
And do you think some of the difficulties we've seen in Powder River with some of the bankruptcies etcetera help support a detriment from the opportunity to drive this forward?
Well, there's no doubt I think what we've seen in some of the challenges in the last quarter have really underlined the fact that this transaction of this nature in order to be able to shape the competitiveness against coal, of coal against natural gas and renewables really does highlight that objective. Look, I think and obviously what's been going on in that basin has attracted a lot of publicity in the last several weeks. And there's no doubt that we recognize the impact that has occurred on the workforce, on their families and on the community in that area and thoughts and certainly appreciate and understand how tough it is in that county. We've actually taken on 30 employees, believe highly skilled to be able to fill existing positions, but we do recognize how tough it has been. Having said that, I think we've got clean on the filings, there's really been no change in pricing following either announcement as far as we can tell.
And I think that just underscores the fact that for us this is about day in, day in, day out competition versus natural gas and renewables.
Our next question will come from Chris Terry with Deutsche Bank. Please go ahead.
Hi, Glenn and Amy. A couple of questions for me. Just following on the JV, do you have an update on when you might potentially expect the deal to close?
So Chris, at this point in time, I think we're doing everything that we can to move the process forward. As we indicated, we have made the necessary regulatory filings this month and we're continuing to see that process play out. We understand that it is fluid in nature and we'll continue to update as we hear back from those agencies. I would only just highlight what Glenn pointed out, which is we think that the market backdrop that we're having these discussions in certainly highlights the need for a transaction of this nature to increase competitiveness and ensure surety of supply out of what is a very important basin for electricity generation.
Okay. Thanks, Amy. And then just one another one for you. On the buyback, so you said you'll accelerate from here. Is that taking the July rate of $51,000,000 Is that are you talking about accelerating from the 2nd quarter run rate or accelerating from the July run rate?
Thanks.
Looking at really accelerating from that first half of the year run rate, we experienced a 1st part of the year where we were under blackout under numerous situations and also saw some lower trading volumes over that period of time, which hampered our ability to execute buybacks quickly. We have been back in the market late in June and into July and we would expect to see that program continue throughout the remainder of the year.
Our next question will come from Mark Levin with Seaport Global. Please go ahead.
Great. Just a quick question on capital. So I think the budget is $350,000,000 to $375,000,000 and then maybe through the first half of the year, you got to spend a little less than $100,000,000 So I guess two questions related to that. One is, I realize the CapEx is back end loaded, but do you feel like there's more negative that there's more of a likelihood of cutting that budget or keeping it where it is? And then second, related to that to the buyback question, I guess you guys are guiding to EBITDA in the second half that is roughly the same as the first half, but there's still, I guess, a lot of capital to spend.
So how should we think about that in terms of buyback activity second half versus first half if there's still a lot of capital to spend?
Sure. Maybe starting with your question on capital. We did anticipate that capital would be back end loaded. We had some progress payments that we'll be making on the longwall at North Goonyella throughout the remainder of 2019. And we also have some project capital associated with the extension of the life of Wubanjong and the Wambo Open Cut JV that fall in the back half of the year.
You can rest assured that capital discipline is something that we employ at Peabody and that relates not just to the dollars that we're spending, but the timing of the dollars that we're spending. And if there's no impact on operations, we view that later is better. So we'll continue to look at that capital budget and make the right decision for our operations over time while not accepting incremental risk at the operating level. As we look at the back half of the year, certainly CapEx is something that will impact our free cash flow as we move into the back half, but I'd also note that we are operating well above our current liquidity target. And so as we approach the back half of the year, we would anticipate drawing down our cash balances to get us closer to that liquidity target as we close out 2019.
And we'll take our next question from Lucas Pipes with B. Riley FBR. Please go ahead.
Hey, good morning, everyone. And Amy and Charles, congratulations on the additional responsibilities. I wanted to ask Glenn a follow-up question on North Goonyella. It sounds like you look at a couple of different options there, keeping the mine open. And I understand it's early and we'll get an update within 3 months, but could you share kind of rough figures in terms of ballpark for CapEx, of the various options that you're looking at?
I would appreciate your thoughts.
Lucas, I think those sorts of things are still under review as we reevaluate prospective pass. Our original approach to access 10 North is something that we're considering as to whether it still remains attractive based on timing costs and what we reflect now as risk. I mentioned the alternative, which would probably be accessing through that second zone and accessing the southern panels through that zone. There are all things that we've got under evaluation at this point in time and really we'll get back to you as soon as we can, but we'd expect that evaluation within the next 3 months.
Lucas, the only thing that I would point out is that the mix of those costs between capital and OpEx would look different under the two scenarios we've gone down the path that we're under currently, which is as Glenn has pointed out is the path that we need under any scenario to sort of recover Zone A and moving into Zone B. The costs associated with that have all been including in our have all been included in our operating expenses. If we look at options towards the southern panels of the mine that the mix of that between OpEx and capital would look different and we would anticipate there would be more capitalization of the costs associated with the project as we would focus on development. But still early days on that and we'll look forward to providing an update as soon as we can.
I appreciate that. Thank you. And then one quick follow-up question on North Goonyella and then another one on the domestic markets. On North Goonyella, could you explain a little bit more the voluntary reduction program? Labor in Australia has a reputation for being pretty tight.
So how long would those folks be kind of away from Peabody before essentially being hired back, I assume, when the mine is up and running again for that program to be economical? That's question number 1. And then question 2, on the JV, obviously very exciting in terms of the synergies. Do you think that is a blueprint for potentially other JVs in other regions of the country? So those are my 2 follow ups.
Thank you.
Yes, I think we'd expect the voluntary reduction program which had about 20 people participate in that program to have a relatively quick payback on that activity. As you'd indicated, we'd expect to rehire when we as appropriate as we continue to rephase production. But at this point in time, we want to make sure that we're appropriately I think it's a I think it's an extraordinary combination of assets that has been put together as part of the Powder River Basin in Colorado between ourselves and Arch. But this type of methodology as you can imagine is not uncommon outside of the United States. We participate in a number of joint ventures in Australia and we mentioned the joint venture between ourselves and Glencore related to the Wambo and United mine combinations.
So it's not unusual in that sense and really is a template that we thought was appropriate in bringing out of bringing together this unique set of assets in a unique combination that will enable that competitiveness against natural gas and renewables.
And as we look at our investment filters that include and highlight payback period in that the idea and the concept of cashless transactions like this joint venture continue to be extremely compelling when there are synergies involved in them.
We'll take our next question from Matthew Fields with Bank of America.
I wanted to talk about the domestic market as well just a little bit. With difficulties at Cloud Peak and Blackjewel, are you seeing potentially any opportunities for your Illinois Basin mines to kind of get into some of these adjacent states that Powder River has gotten into like Illinois, Iowa, Missouri where these guys are selling into and you'd have an extraordinary cost advantage.
I think obviously we believe that the customers that are being supplied through those types of operations and those types of activities would tend to be customers that came out of the Powder River Basin type areas. But they obviously manage wider portfolios with respect to having gas in their mix or having other burn or other coal generation activities in their mix. So I would have thought that we'd probably look to supply out of the broader Powder River Basin market.
Okay. And then on the flip side, your fellow Illinois producers like Alliance and Foresight are taking down their export guidance and bringing some tons home. Are you seeing difficulties contracting with sort of competing additional domestic volumes that potentially weren't there last year?
So as we look at our Midwestern operations, we are fully committed for 2019 and that tends to be our strategy, particularly with the Midwest as we go into each year, but also with our Powder River Basin operations that that contracted position is really important going into any given year. So we're not heavily dependent. In fact, we export little to no coal out of the Illinois Basin that would factor into our sales plans. As we look at our export position into markets out of Australia, we continue to be extremely pleased with where we sit from a contracted position, not only for the remainder of 2019, but really going into 2020 with over 2,000,000 tons price above the Newcastle forward curve currently going into 2020. And then also note that as we look at export prices that have dipped a bit, we are benefiting from that corresponding dip in FX that we've seen that we've seen over this period of time as well, which highlights sort of the strength of that seaborne thermal position out of Australia.
We'll take our next question from Matt Vittorioso with Jefferies. Please go ahead.
Yes, good morning. Just in the context of accelerating returns to shareholders in the back half of the year, could you comment on your ability to do so under the indentures of the existing or the outstanding secured bonds?
Sure. So with respect to our capacity, we believe that we have capacity to execute our current buyback program under the indenture and so that has factored into our plans for the back half of the year.
Is there any point where that starts to get tight? I mean, how do we think about the outstanding RP capacity under the bonds? Is that something you can quantify for us?
So it's not something that we quantify, but it is a calculation that's based on net income. That net income calculated on a quarterly basis. So it builds throughout the year as we generate net income with some adjustments that have been made to that. And as you probably recall, we had put an amendment in place back in 2018 to address that RP capacity to give us a one time basket as well with an indication of that. So we don't see the bond indentures at this point as a constraint to our current program.
Our next question will come from Nick Jarmoszuk with Stifel. Please go ahead. Good
question. Piggybacking on the indenture question, given that you need to go to bondholders for the JV for consent for the JV, how do you balance an overall refinancing of the 22s and 25s so you can free up cash flows and not have to go back to bondholders for additional RP baskets, not have to go to bondholders for JV approvals versus having to go and pay consent fees? Thanks.
Sure. So, we're going through or working through our strategy right now with respect to refinancing. And I think you've pointed out a pointed out a couple of options that are available to us as we do so. Over time, we would aspire to get to a more regular way bond indenture that would allow us appropriate flexibility with respect to shareholder returns. We're also not insensitive to pricing of these types of transactions.
So the team is looking at the way to best execute this to achieve what is really 2 separate objectives over time. The most urgent of one being to ensure that we've got the flexibility to complete the joint venture arrangement and secondarily making sure that we have the flexibility over time to execute our shareholder returns program.
Thank you.
Our next question will come from Paul Quinlan with Morgan Stanley. Please go ahead.
Sorry to harp on the RP issue, but correct me if I'm wrong, but I think you had a one time $650,000,000 basket and then $175,000,000 annually. Can you just clarify if anything is left on the $650,000,000 And then if you are in the sort of 2nd year period where the new $175,000,000 kicks in?
So I wouldn't comment specifically what basket we're using, but I think the other piece that is missing from that equation is the fact that we have a builder basket as well that is based on net income that builds quarterly over time that also is included in that indenture.
Okay, got it. Thanks.
We'll take our next question from Karl Blunden with Goldman Sachs. Please go ahead.
I guess it's another one for Amy here just on the capital structure. Interested in thoughts you have there with regard to timing of a refi. I understand you're monitoring the markets. Markets have performed pretty well. Do you need to see more progress toward getting the JV finalized for the market to give you credit for those savings and therefore potentially a better interest rate?
Or how do you weigh those factors at strong credit market today versus getting full credit for the operating initiatives that you're planning?
So I think that certainly we want to hit the market right and we want to get the market to understand that this is a credit enhancing transaction that we're looking at over time. We're working through that strategy right now in terms of the right time to hit the market. But there again maybe other objectives that we hope to that we would achieve as part of a broader transaction. So certainly weighing the benefits of trying to get a one off approval for a transaction like this to a larger scale transaction or larger scale set of transactions that would achieve both flexibility around the joint venture, but also move us to a more regular way bond indenture over time. So I think that under any scenario, the second that regular way indenture is something that for a company with the strength of credit that Peabody has should be doable.
The timing of that though is something that we've yet to determine.
Thanks.
We'll take our next Lucas Pipes with Riley FBR. Please go ahead.
Yes. Thank you very much for taking my follow-up question. A quick one in regards to the seaborne hedges for 2020, could you give us a breakdown of what is hedged against API V and what is hedged against Newcastle?
So, what I would say, Lucas, is that that blended cost of $77 per ton is a blend of Newcastle and API5 and that overall the range of quality that we see in 2019 is consistent with the range of quality that we would expect to see in 2020. So that blended rate would be consistent with our current portfolio.
So essentially, I should think about the hedge as being proportional to your to the quality of your sales book in 2020?
That's right.
Got it. Very helpful. Thank you.
We'll take our next question from Matthew Fields with Bank of America. Please go ahead.
Hey, thanks for the follow-up. I don't mean to sound rude here, but you guys have spent about $1,000,000,000 on share repurchases over the last year and the stock has gone from $40,000,000 to $20,000,000 So I know you're fighting a very difficult environment on multiple fronts, but what are the other strategies for capital deployment to boost shareholder returns in a way that sort of works for all stakeholders?
So Matt, I would say we've actually engaged in what is a very comprehensive approach to capital allocation throughout the year. And frankly, throughout the period since April of 2017, we've paid down over $500,000,000 of debt. We've used cash and put that towards liability management in the form of pension and retiree healthcare. We've performed reclamation over that period of time.
I'd add the acquisition of Shoal Creek.
We've engaged in investing, reinvesting in our business, the acquisition of Shoal Creek and the transaction with Arch that we've announced, which is perhaps the most synergistic transaction that could be pondered in the U. S. Coal space. On top of that, we've initiated a sustainable dividend, which we've increased three times. We have announced a supplemental dividend of $200,000,000 in the Q1 of the year.
I can't control the share price, but I'm pretty proud of the actions that we've taken today to provide value to shareholders. So you can question our methods. I'm not going to. I think that we've been flexible. We've been comprehensive and the results have not yielded what we wanted them to, but we don't think it's because it's the wrong path.
And ladies and gentlemen, this concludes today's question and answer session. I'd like to turn the call back over to Mr. Glenn Fello for additional or closing remarks.
Well, thank you for your questions and participating in today's call. At Peabody, our mission is predicated on creating superior value for our shareholders. That's our commitment and that's our focus every single day and we look forward to keeping you appraised of our progress. Operator, that concludes today's call.