NGL Energy Partners LP (NYSE:NGL) Q3 2024 Earnings Call Transcript February 8, 2024
NGL Energy Partners LP misses on earnings expectations. Reported EPS is $0.08 EPS, expectations were $0.135. NGL Energy Partners LP isn’t one of the 30 most popular stocks among hedge funds at the end of the third quarter (see the details here).
Operator: Greetings and welcome to the NGL Energy Partners 3Q 2024 Earnings Call. At this time, all participants are in a listen-only mode and a question-and-answer session will follow the formal presentation. [Operator Instructions] Please note this conference is being recorded. I will now turn the conference over to your host, Brad Cooper, CFO. You may begin.
Brad Cooper: Good afternoon and thank you to everyone for joining us on the call today. Our comments today will includes plans, forecast and estimates that are forward-looking statements under the U.S. Securities Law. These comments are subject to assumptions, risks and uncertainties that could cause actual results to differ from the forward-looking statements. Please take note of the cautionary language and risk factors provided in our presentation materials and our other public disclosure materials. Before we enter the third quarter financial results, I want to take some time to discuss who accomplished this quarter. I first want to thank all the NGL employs for their dedication and extra efforts over the last few months. What we have accomplished over the last few months is astonishing and we should be proud of what we have achieved.
We have been able to execute on our long-term plan faster than we anticipated. Operationally, we recently held an open season on the Grand Mesa Pipeline. On January 5, we closed the open season on the Grand Mesa Pipeline and had a new 5-year MVC with the same counterparty, whose prior contract expired on December 31. Outside of entering into a new 5-year MVC agreement, this counterparty will also be the shipper on the pipeline, freeing up $18 million to $20 million of working capital. This is a permanent release of working capital. As we continue to negotiate new contracts and a free contract on the pipeline, we should continue to see further reductions in working capital. These reductions in working capital require us to hedge fewer barrels thus reducing earnings volatility and turns crude logistics into a more ratable long-term fee based type of business with more MVCs. A few weeks ago, we issued a press release on the expansion of the LEX produced water pipeline system into Andrews County.
This expansion of the Lee County Express Pipeline system takes the existing capacity of 140,000 barrels of water per day up to 340,000 barrels per day in 2024. The addition of a second large diameter pipeline, new disposal wells and new facilities will greatly expand the capabilities of NGL’s existing produced water supersystem and create a significantly larger outlet for Delaware Basin produced water. The construction of the 27-mile 30-inch produced water pipeline will transport water to areas outside the core of the basin, thereby further diversifying NGL’s geographic location on its disposal operations. The LEX II expansion is fully underwritten by a recently executed minimum volume commitment contract that includes an acreage dedication extension with an investment-grade oil and gas producer.
This is a strong example of the types of transactions we’re able to execute upon with our continued demonstration of being the most reliable and dependable water disposal company in the Lower 48. Financially, on February 2, we closed on the refinancing of our debt maturities. With this $2.9 billion refinancing, we extended the weighted average maturity of our debt by approximately 3 years, while rebalancing the corporate maturity stack towards prepayable debt, providing us the optionality to further accelerate our deleveraging plans. The new term loan also provides additional exposure to floating interest rates. With projected rate cuts on the horizon, we should be able to capture lower interest expense in the future. The combined 3 tranches were the largest midstream sector financing efforts since 2022, and the most significant capital raise effort in NGL’s history.
We have been very clear with our strategy over the last few quarters. Our plan was to address the debt maturities in the first half of calendar 2024, and we’ve been able to execute this refinancing months earlier than anticipated. With high-yield energy spreads trading the tighter space than over the last 2 years, we decided to accelerate this refinancing while simultaneously amending and extending the ABL. In connection with this transaction, all 3 rating agencies issued new ratings with S&P and Moody’s both raising the corporate credit rating one notch to single B. Fitch initiated coverage on the company as well and issued a corporate credit rating of single B and BB minus on the secured notes and term loan. ABL has been extended 5 years to 2029.
The commitment level stayed the same with $600 million of commitments from the Bank Group, while at the same time getting relief within the documents across a few key covenants that provide us more flexibility. The new debt consists of $2.2 billion of senior secured notes with $900 million of 5 year non-call 2 notes at 8.125% interest due 2029 and $1.3 billion of 8 year non-call 3 notes at 8.375% due 2032. In addition to the secured notes, we entered into a 7 year $700 million term loan facility. The term loan facility is floating rate debt, and as I mentioned earlier, we went into the refinancing wanting a mix of fixed and floating rate debt. The term loan also gives us the ability to reprice the facility as we continue to execute on our operational plans, as we strengthen the balance sheet along the way.
The net proceeds from the transactions are being used to fund the redemption of the ’25 unsecured notes, the ’26 unsecured notes and the ’26 senior secured notes, including any applicable premiums and accrued and unpaid interest. The funds will also be used to pay fees and expenses in connection with the transaction and to repay borrowings under the ABL. This refinancing allows us to take the next step in addressing our capital structure. On Tuesday of this week, we announced the payment for 50% of the outstanding arrearages on the 3 classes of the preferred securities. Over the last few months, we’ve been using free cash flow to pay down our ABL and position ourselves to quickly address arrearages after the refinancing. We believe we are catching up on these arrearages quicker than anyone anticipated.
The first 50% payment will be made to holders of record as of February 16, with payments being made on February 27. For the holders of the Class B preferred securities, they will receive $4.44 per unit and each holder of the Class Cs will receive approximately $4.07 per unit. In addition to the payments of the Class B and C holders, we are also making a $115 million payment to the holders of the Class D preferreds. The first question we expect to receive in the Q&A session is when do we plan to make the second half payment and declare we are current on the preferred distributions. In the press release we issued after market today, we are raising the full year guide on asset sales from $100 million to $150 million. The remaining asset sales should close by 331.
With free cash flow, asset sales and the release of working capital in the Liquids segment, we will make the remaining 50% payment in the very near future. We will be thoughtful on the timing of this payment as we assess what the fiscal 2025 cash flow and capital budget could be as we kick off the budget process in late February. Over the last several quarters, we have positioned the partnership to take advantage of a market window to address the debt maturities. Our ability to execute quickly allows us the flexibility to take the next step of our long-term strategy, addressing the preferred arrearages. As we achieve these milestones, our long-term strategy will continue to evolve. We have additional steps to complete, but all of our stakeholders should feel comfortable with the progress we have made and our consistent messaging along the way.
With that, let’s get into the third quarter financial results. Water Solutions’ adjusted EBITDA was $121.3 million in the third quarter versus $121.7 million in the prior third quarter. Water disposal volumes were 2.38 million barrels per day in the third quarter versus 2.43 million barrels per day in the prior quarter. As Mike mentioned on the previous earnings call, we expected water disposal volumes would be down versus the fiscal second quarter. There are 2 main drivers that impacted our third quarter disposal volumes. First, producers are keeping produced water on location for completion activity. This activity will create lumpiness in our disposal volumes going forward. The good news is NGL will receive these disposal volumes once all completion activity is completed at that location.
NGL isn’t losing any volume, it’s just a timing issue on when those volumes will be received. Second, we have a large MVC with an investment-grade integrated energy major. This producer pressured up its own water gathering system and was limited to the amount of water volumes they can get on our system. This producer is currently working on reducing pressures on their water gathering system. The volume impact for the third quarter was approximately 170,000 barrels per day for the quarter. It’s important to remember that we get paid for these volumes and these deficiency volumes are not included in the physical disposal volumes we report. Also, this MVC has approximately 9 years remaining. Water Solutions continues to maintain operating expenses at $0.25 per barrel, best in the industry.
This is primarily due to lower chemical expenses, lower generator rental expenses and utilities expenses. These decreases were partially offset by higher repairs and maintenance expense due to the timing of repairs, the burden of maintenance and tank cleaning. Crude Oil Logistics adjusted EBITDA was $17 million in the third quarter versus $33.3 million in the prior third quarter. The adjusted EBITDA decrease was primarily due to lower crude sales margins as we receive lower contracted rates with certain producers as WTI pricing went below $75. And lower contract differentials negatively impacted certain other sales contracts. Volumes decreased due to lower production on acreage dedicated to the Grand Mesa pipeline. Also, our adjusted EBITDA when compared to the same quarter in the previous quarter is slightly impacted by the sale of our marine assets in March — on March 30, 2023.
We remain constructive on the DJ Basin and believe the results of the most recent open season on Grand Mesa demonstrate the important to producers of having long-term capacity contracted on the pipeline. We will continue to work with the producers in the DJ and look forward to having additional contracting updates in the near future. Liquids logistics EBITDA — adjusted EBITDA was $22.4 million in the third quarter versus $20.5 million in the prior third quarter. This increase was due to higher margins and higher demand for butane blending. This was partially offset by lower propane margins and volumes due to warmer weather in the third quarter. Also, lower margins on refined products as supply issues seen in certain markets in the prior year have been alleviated and have tightened margins.
Corporate and adjusted and other adjusted EBITDA was a loss of $11.9 million in the third quarter versus income of $19.5 million in the prior third quarter. I want to remind everyone that in the prior year third quarter, it included other income of $29.5 million to settle a dispute associated with commercial activities. I would now like to turn the call over to Mike Krimbill, our CEO. Mike?
Mike Krimbill : Thanks, Brad. As you have heard in the last year, we have achieved significant milestones as we position NGL for success and at the same time, continue exceeding expectations. First, as Brad described, we have reduced leverage on the balance sheet faster than expected due to the free cash flow and asset sales at attractive multiples. Second, this deleveraging allowed us to complete the refi of all of our indebtedness earlier than expected, reducing our refinancing risk of providing financial flexibility. And third, we announced the payment of 50% of the preferred dividend arrearages sooner than expected. We are trying not to disappoint, but rather establish a reputation for beating expectations. Looking forward, we are focused on following: payment of the remaining preferred distribution of arrearages as soon as possible, then reinstatement of the Class B, C and D distribution as soon as possible.
Third, continued deleveraging through debt reduction and increased EBITDA, balanced with addressing the Class D preferred. Debt reduction can be begin 6 months after the recent refi as the new high-yield debt has non-called provisions of 2 to 3 years and the term loan incurs breakage fees if repaid within the next 6 months; four, improve our credit rating with the agencies, debt reduction, payment of the distribution arrearages and increased EBITDA can accelerate this process; five, emphasize internal growth opportunities at attractive rates of return, underwritten and supported by MVCs. Rather than limiting growth capital as we have up until now, we will look for investments to expand our footprint, strengthen our competitive position that will also increase the quality, consistency and amount of our adjusted EBITDA.
One example of this is the recently announced expansion of Lea County Express Pipeline system. The growth CapEx and adjusted EBITDA for this project will be included in our fiscal 2025 guidance. Another example is the outcome of the open season Brad spoke about. We are currently working on multiple new growth projects and contracts, which we will announce if successful. Finally, we expect to grow adjusted EBITDA each year for the foreseeable future led by our Delaware Water Solutions business. With respect to our adjusted EBITDA, we are affirming the previous guidance of $500 million plus for water and $645 million for the partnership. Our guidance for adjusted EBITDA and growth CapEx in fiscal year ’25 will obviously be higher than the current fiscal year, so we will announce that at our year-end earnings call.
In closing over the last few years, we have made tremendous progress in many areas, increased efficiencies, cost reduction, asset sales, reduced leverage and increase in EBITDA. Going forward, we will have fewer opportunities to capitalize on most of these areas. So our renewed focus will be on internal growth with MVCs and hitting our numbers. NGL was one of the best-performing equities in the energy space in calendar ’23, we will do our utmost to repeat that performance. Thank you, we’ll open it for questions.
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