Document/ExhibitDescriptionPagesSize 1: 10-Q Quarterly Report HTML 723K
2: EX-31.1 Certification -- §302 - SOA'02 HTML 28K
3: EX-31.2 Certification -- §302 - SOA'02 HTML 28K
4: EX-32.1 Certification -- §906 - SOA'02 HTML 23K
5: EX-32.2 Certification -- §906 - SOA'02 HTML 23K
12: R1 Cover HTML 73K
13: R2 Consolidated Balance Sheets HTML 118K
14: R3 Consolidated Balance Sheets (Parenthetical) HTML 34K
15: R4 Consolidated Statements of Comprehensive Income HTML 88K
16: R5 Consolidated Statements of Partners' Capital HTML 80K
17: R6 Consolidated Statements of Cash Flows HTML 129K
18: R7 Basis of Presentation HTML 25K
19: R8 Revenue from Contracts with Customers HTML 76K
20: R9 Common and Preferred Unit Distributions HTML 40K
21: R10 Net Income Per Common Unit HTML 61K
22: R11 Segment Information HTML 71K
23: R12 Equity Investment HTML 39K
24: R13 Mineral Rights, Net HTML 45K
25: R14 Debt, Net HTML 53K
26: R15 Fair Value Measurements HTML 45K
27: R16 Related Party Transactions HTML 31K
28: R17 Major Customers HTML 34K
29: R18 Commitments and Contingencies HTML 23K
30: R19 Unit-Based Compensation HTML 30K
31: R20 Credit Losses HTML 42K
32: R21 Financing Transaction HTML 24K
33: R22 Subsequent Events HTML 24K
34: R23 Basis of Presentation (Policies) HTML 24K
35: R24 Revenue from Contracts with Customers (Tables) HTML 79K
36: R25 Common and Preferred Unit Distributions (Tables) HTML 37K
37: R26 Net Income Per Common Unit (Tables) HTML 59K
38: R27 Segment Information (Tables) HTML 65K
39: R28 Equity Investment (Tables) HTML 38K
40: R29 Mineral Rights, Net (Tables) HTML 42K
41: R30 Debt, Net (Tables) HTML 47K
42: R31 Fair Value Measurements (Tables) HTML 42K
43: R32 Related Party Transactions (Tables) HTML 27K
44: R33 Major Customers (Tables) HTML 35K
45: R34 Unit-Based Compensation (Tables) HTML 30K
46: R35 Credit Losses (Tables) HTML 37K
47: R36 Basis of Presentation - Narrative (Details) HTML 27K
48: R37 Revenue from Contracts with Customers - Schedule HTML 61K
of Partnerships' Coal Royalty and Other Segment
Revenues from Contracts with Customers (Details)
49: R38 Revenue from Contracts with Customers - Schedule HTML 33K
of Receivables and Liabilities from Contracts with
Customers (Details)
50: R39 Revenue from Contracts with Customers Revenue HTML 27K
Recognition Deferred Revenue Rollforward (Details)
51: R40 Revenue from Contracts with Customers - Schedule HTML 44K
of Annual Minimums by Current Remaining Contract
Term (Details)
52: R41 Common and Preferred Unit Distributions Narrative HTML 30K
(Details)
53: R42 Common and Preferred Unit Distributions HTML 42K
Distributions declared and paid (Details)
54: R43 Net Income Per Common Unit (Details) HTML 77K
55: R44 Segment Information - Additional Information HTML 27K
(Details)
56: R45 Segment Information - Schedule of Segment HTML 60K
Reporting Information, by Segment (Details)
57: R46 Equity Investment - Additional Information HTML 24K
(Detail)
58: R47 Equity Investment Summary of Activity in Equity HTML 37K
Method Investment (Details)
59: R48 Equity Investment - Schedule of Summarized HTML 42K
Financial Information of Unaudited Financial
Statements (Detail)
60: R49 Mineral Rights, Net - Mineral Rights (Detail) HTML 43K
61: R50 Mineral Rights, Net - Additional Information HTML 30K
(Detail)
62: R51 Debt, Net - Debt (Detail) HTML 65K
63: R52 Debt, Net - Additional Information (Detail) HTML 78K
64: R53 Fair Value Measurements - Contracts Receivable and HTML 45K
Debt (Detail)
65: R54 Fair Value Measurements - Embedded Derivatives HTML 22K
(Detail)
66: R55 Related Party Transactions - Narrative (Details) HTML 34K
67: R56 Related Party Transactions - Summary of HTML 36K
Reimbursements (Details)
68: R57 Major Customers (Detail) HTML 37K
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activity (Details)
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72: R61 Financing Transaction (Details) HTML 29K
73: R62 Subsequent Events - Additional Information HTML 30K
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(Exact name of registrant as specified in its charter)
iDelaware
i35-2164875
(State
or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification No.)
i1201 Louisiana Street, Suite 3400
iHouston,
iTexasi77002
(Address of principal executive offices)
(Zip Code)
(i713)
i751-7507
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title
of each class
Trading Symbol(s)
Name of each exchange on which registered
iCommon Units representing limited partner interests
iNRP
iNew
York Stock Exchange
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. iYes☒ No ☐
Indicate
by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). iYes☒ No ☐
Indicate by check
mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See definition of "accelerated filer", "large accelerated filer", "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large Accelerated Filer
☐
iAccelerated
Filer
☒
Non-accelerated Filer
☐ (Do not check if a smaller reporting company)
Smaller Reporting Company
i☒
Emerging
Growth Company
i☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check
mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes i☐ No ☒
APPLICABLE ONLY TO ISSUERS INVOLVED IN BANKRUPTCY PROCEEDINGS DURING THE PRECEDING FIVE YEARS:
Indicate by check mark whether the registrant
has filed all documents and reports required to be filed by Section 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court. Yes ☐ No ☐
APPLICABLE ONLY TO CORPORATE ISSUERS
Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.
Class A Convertible Preferred Units (ii257,556/
and ii253,750/ units issued and outstanding at March
31, 2021 and December 31, 2020, respectively, at $ii1,000/
par value per unit; liquidation preference of $i1,850 per unit at March 31, 2021 and $i1,700
per unit at December 31, 2020)
$
i172,143
$
i168,337
Partners’
capital
Common unitholders’ interest (ii12,351,306/
and ii12,261,199/
units issued and outstanding at March 31, 2021 and December 31, 2020, respectively)
$
i132,377
$
i136,927
General
partner’s interest
i394
i459
Warrant
holders’ interest
i66,816
i66,816
Accumulated
other comprehensive income
i1,054
i322
Total
partners’ capital
$
i200,641
$
i204,524
Total
liabilities and partners' capital
$
i909,160
$
i921,877
The
accompanying notes are an integral part of these consolidated financial statements.
(1)Net
income includes $i7.727 million of income attributable to preferred unitholders that accumulated during the period, of which $i7.572
million is allocated to the common unitholders and $i0.155 million is allocated to the general partner.
Common
Unitholders
General Partner
Warrant Holders
Accumulated Other Comprehensive Loss
Partners' Capital Excluding Non-Controlling Interest
(1)Net
income includes $i7.5 million of income attributable to preferred unitholders that accumulated during the period, of which $i7.35
million is allocated to the common unitholders and $i0.15 million is allocated to the general partner.
The accompanying notes are an integral part of these consolidated financial statements.
Natural Resource Partners L.P. (the "Partnership") engages principally in the business of owning, managing and leasing a diversified portfolio of mineral properties in the United States, including interests in coal and other natural resources and owns a non-controlling i49% interest in Ciner Wyoming LLC ("Ciner Wyoming"), a trona ore mining and soda ash production business. The Partnership is organized into itwo
operating segments further described in Note 5. Segment Information. As used in these Notes to Consolidated Financial Statements, the terms "NRP,""we,""us" and "our" refer to Natural Resource Partners L.P. and its subsidiaries, unless otherwise stated or indicated by context.
iPrinciples of
Consolidation and Reporting
The accompanying unaudited Consolidated Financial Statements of the Partnership have been prepared in accordance with generally accepted accounting principles in the United States of America ("GAAP") for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. These financial statements should be read in conjunction with the financial statements for the year ended December 31, 2020 and notes thereto included in the Partnership's Annual Report on Form 10-K, which was filed with the SEC on March 15, 2021.
The following table presents the Partnership's Coal Royalty and Other segment revenues by major source:
For
the Three Months Ended March 31,
(In thousands)
2021
2020
Coal royalty revenues (1)
$
i15,365
$
i19,102
Production
lease minimum revenues (1)
i3,450
i802
Minimum
lease straight-line revenues (1)
i6,096
i3,809
Property
tax revenues
i1,469
i1,599
Wheelage
revenues
i1,781
i2,204
Coal
overriding royalty revenues
i1,859
i1,322
Lease
amendment revenues
i868
i843
Aggregates
royalty revenues
i454
i576
Oil
and gas royalty revenues
i1,366
i1,103
Other
revenues
i219
i73
Coal
royalty and other revenues
$
i32,927
$
i31,433
Transportation
and processing services revenues (2)
i2,192
i2,509
Total
coal royalty and other segment revenues
$
i35,119
$
i33,942
(1)Beginning
April 1, 2020 and effective January 1, 2020, certain revenues previously classified as coal royalty revenues are classified as production lease minimum revenues or minimum lease straight-line revenues due to contract modifications to certain leases that fixed consideration paid to the Partnership over a two year period.
/
(2)Transportation and processing services revenues from contracts with customers as defined under ASC 606 was $ii1.2/ million
for the three months ended March 31, 2021 and 2020, respectively. The remaining transportation and processing services revenues of $i0.9 million and $i1.3 million
for the three months ended March 31, 2021 and 2020, respectively, related to other NRP-owned infrastructure leased to and operated by third-party operators accounted for under other guidance. See Note 14. Financing Transaction for more information.
(1)Other
current assets, net includes short-term notes receivables from contracts with customers.
(2)Other long-term assets, net includes long-term lease amendment fee receivables from contracts with customers.
/i
The
following table shows the activity related to the Partnership's Coal Royalty and Other segment deferred revenue:
For the Three Months Ended March 31,
(In thousands)
2021
2020
Balance
at beginning of period (current and non-current)
$
i61,554
$
i51,821
Increase
due to minimums and lease amendment fees
i4,358
i17,153
Recognition
of previously deferred revenue
(i4,504)
(i8,888)
Balance
at end of period (current and non-current)
$
i61,408
$
i60,086
/
i
The
Partnership's non-cancelable annual minimum payments due under the lease terms of its coal and aggregates royalty leases are as follows as of March 31, 2021 (in thousands):
Lease Term (1)
Weighted Average Remaining Years
Annual Minimum Payments (2)
0
- 5 years
i4.5
$
i14,686
5
- 10 years
i5.2
i8,122
10+
years
i14.3
i28,463
Total
i9.6
$
i51,271
(1)Lease
term does not include renewal periods.
/
(2)Annual minimum payments do not include $i14.5 million of the $i30.0 million
of fixed consideration owed to NRP for the remainder of 2021 resulting from contract modifications entered into during the second quarter of 2020. Additionally, $i3.8 million of this remaining $i14.5 million
relates to a coal infrastructure lease that is accounted for as a financing transaction. See Note 14. Financing Transaction for more information.
3. iCommon and Preferred Unit Distributions
The
Partnership makes cash distributions to common and preferred unitholders on a quarterly basis, subject to approval by the Board of Directors of GP Natural Resource Partners LLC (the "Board of Directors"). NRP recognizes both common unit and preferred unit distributions on the date the distribution is declared.
Distributions made on the common units and the general partner's general partner ("GP") interest are made on a pro-rata basis in accordance with their relative percentage interests in the Partnership. The general partner is entitled to receive i2%
of such distributions.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
Income available to common unitholders and the general partner is reduced by preferred unit distributions that accumulated during the period. NRP reduced net income available to common unitholders and the general partner by $i7.7
million and $i7.5 million during the three months ended March 31, 2021 and 2020, respectively, as a result of accumulated preferred unit distributions earned during the period. In February 2021, the Partnership paid in kind one-half of the preferred unit distribution related to the
three months ended December 31, 2020, which resulted in the issuance of an additional i3,806 preferred units during the three months ended March 31, 2021.
i
The
following table shows the cash distributions declared and paid to common and preferred unitholders during the three months ended March 31, 2021 and 2020, respectively:
(1)Totals
include the amount paid to NRP's general partner in accordance with the general partner's i2% general partner interest.
/
4. iNet
Income Per Common Unit
Basic net income per common unit is computed by dividing net income, after considering income attributable to preferred unitholders and the general partner’s general partner interest, by the weighted average number of common units outstanding. Diluted net income per common unit includes the effect of NRP's preferred units, warrants, and unvested unit-based awards if the inclusion of these items is dilutive.
The dilutive effect of the preferred units is calculated using the if-converted method. Under the if-converted method, the preferred units are assumed to be converted at the beginning of the period, and the resulting common units are included in the denominator of the diluted net income per unit calculation for the period being presented. Distributions declared in the period and undeclared distributions on the preferred units that accumulated during
the period are added back to the numerator for purposes of the if-converted calculation. The calculation of diluted net income per common unit for the three months ended March 31, 2021 does not include the assumed conversion of the preferred units because the impact would have been anti-dilutive. The calculation of diluted net income per common unit for the three months ended March 31, 2020 includes the assumed conversion of the preferred units.
The dilutive effect of the warrants is calculated using the treasury stock method, which assumes that the proceeds from the exercise of these instruments are used to purchase common units at the average market price for the period. The calculation of diluted net income per common unit for the three months ended March 31, 2021 and 2020
does not include the net settlement of warrants to purchase ii1.75/
million common units at a strike price of $ii22.81/
or the net settlement of warrants to purchase ii2.25/
million common units with a strike price of $ii34.00/
because the impact would have been anti-dilutive.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
i
The
following tables reconcile the numerator and denominator of the basic and diluted net income per common unit computations and calculates basic and diluted net income per common unit:
For the Three Months Ended March 31,
(In thousands, except per unit data)
2021
2020
Allocation
of net income
Net
income
$
i8,381
$
i18,779
Less:
income attributable to preferred unitholders
(i7,727)
(i7,500)
Net
income attributable to common unitholders and the general partner
$
i654
$
i11,279
Less:
net income attributable to the general partner
(i13)
(i226)
Net
income attributable to common unitholders
$
i641
$
i11,053
Basic
net income per common unit
Weighted average common units—basic
i12,292
i12,261
Basic
net income per common unit
$
i0.05
$
i0.90
Diluted
net income per common unit
Weighted average common units—basic
i12,292
i12,261
Plus: dilutive
effect of preferred units
i—
i23,187
Plus: dilutive
effect of unvested unit-based awards
i116
i—
Weighted
average common units—diluted
i12,408
i35,448
Net
income
$
i8,381
$
i18,779
Less:
income attributable to preferred unitholders
(i7,727)
i—
Diluted
net income attributable to common unitholders and the general partner
$
i654
$
i18,779
Less:
diluted net income attributable to the general partner
(i13)
(i376)
Diluted
net income attributable to common unitholders
$
i641
$
i18,403
Diluted
net income per common unit
$
i0.05
$
i0.52
/
5. iSegment
Information
The Partnership's segments are strategic business units that offer distinct products and services to different customers in different geographies within the U.S. and that are managed accordingly. NRP has the following itwo operating segments:
Coal Royalty and Other—consists primarily of coal royalty properties and coal-related transportation and processing assets. Other assets include industrial mineral royalty properties, aggregates
royalty properties, oil and gas royalty properties and timber. The Partnership's coal reserves are primarily located in Appalachia, the Illinois Basin and the Northern Powder River Basin in the United States. The Partnership's industrial minerals and aggregates properties are located in various states across the United States. The Partnership's oil and gas royalty assets are primarily located in Louisiana and its timber assets are primarily located in West Virginia.
Soda Ash—consists of the Partnership's i49% non-controlling
equity interest in Ciner Wyoming, a trona ore mining operation and soda ash refinery in the Green River Basin of Wyoming. Ciner Wyoming mines trona and processes it into soda ash that is sold both domestically and internationally to the glass and chemicals industries.
Direct segment costs and certain other costs incurred at the corporate level that are identifiable and that benefit the Partnership's segments are allocated to the operating segments accordingly. These allocated costs generally include salaries and benefits, insurance, property taxes, legal, royalty, information technology and shared facilities services and are included in operating and maintenance expenses on the Partnership's Consolidated Statements of Comprehensive Income.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
Corporate and Financing includes functional corporate departments that do not earn revenues. Costs incurred by these departments include interest and financing, corporate headquarters and overhead, centralized treasury, legal and accounting and other corporate-level activity not specifically allocated to a segment and are included in general and administrative expenses on the Partnership's Consolidated Statements of Comprehensive Income.
i
The
following table summarizes certain financial information for each of the Partnership's business segments:
The Partnership accounts for its i49% investment in Ciner Wyoming using the equity method of accounting. iActivity related to this investment
is as follows:
For the Three Months Ended March 31,
(In thousands)
2021
2020
Balance
at beginning of period
$
i262,514
$
i263,080
Income
allocation to NRP’s equity interests
i3,216
i7,493
Amortization
of basis difference
(i1,243)
(i1,221)
Other
comprehensive income (loss)
i732
(i1,023)
Distribution
(i3,920)
(i7,105)
Balance
at end of period
$
i261,299
$
i261,224
The
following table represents summarized financial information for Ciner Wyoming as derived from their respective unaudited financial statements for the three months ended March 31, 2021 and 2020:
Depletion
expense related to the Partnership’s mineral rights is included in depreciation, depletion and amortization on its Consolidated Statements of Comprehensive Income and totaled $i4.7 million and $i1.9
million for the three months ended March 31, 2021 and 2020, respectively.
During the three months ended March 31, 2021, the Partnership recorded $i4.0 million of impairment expense primarily due to lease termination that resulted in the full impairment of a coal property. The Partnership has developed procedures to evaluate its long-lived assets for
possible impairment periodically or whenever events or changes in circumstances indicate an asset's net book value may not be recoverable. Potential events or circumstances include, but are not limited to, specific events such as a reduction in economically recoverable reserves or production ceasing on a property for an extended period. This analysis is based on historic, current and future performance and considers both quantitative and qualitative information. While the Partnership's impairment evaluation as of March 31, 2021 incorporated an estimated impact of the global COVID-19 pandemic, there is significant uncertainty as to the severity and duration of this disruption. If the impact is worse than we currently estimate, an additional impairment charge may be recognized in future periods.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
8. iDebt, Net
i
The
Partnership's debt consists of the following:
March 31,
December 31,
(In thousands)
2021
2020
NRP LP debt:
i9.125%
senior notes, with semi-annual interest payments in June and December, due June 2025, issued at par ("2025 Senior Notes")
$
i300,000
$
i300,000
Opco
debt:
Revolving credit facility
$
i—
$
i—
Senior
Notes
i5.55% with semi-annual interest payments in June and December, with annual principal payments in June, due June 2023
$
i7,094
$
i7,094
i4.73%
with semi-annual interest payments in June and December, with annual principal payments in December, due December 2023
i18,013
i18,013
i5.82%
with semi-annual interest payments in March and September, with annual principal payments in March, due March 2024
i38,053
i50,738
i8.92%
with semi-annual interest payments in March and September, with annual principal payments in March, due March 2024
i12,035
i16,047
i5.03%
with semi-annual interest payments in June and December, with annual principal payments in December, due December 2026
i68,524
i68,524
i5.18%
with semi-annual interest payments in June and December, with annual principal payments in December, due December 2026
i17,464
i17,464
Total
Opco Senior Notes
$
i161,183
$
i177,880
Total
debt at face value
$
i461,183
$
i477,880
Net
unamortized debt issuance costs
(i6,020)
(i6,381)
Total
debt, net
$
i455,163
$
i471,499
Less:
current portion of long-term debt
(i39,042)
(i39,055)
Total
long-term debt, net
$
i416,121
$
i432,444
/
NRP
LP Debt
2025 Senior Notes
The 2025 Senior Notes were issued under an Indenture dated as of April 29, 2019 (the "2025 Indenture"), bear interest at i9.125% per year and mature on June 30, 2025. Interest
is payable semi-annually on June 30 and December 30.
NRP and NRP Finance have the option to redeem the 2025 Senior Notes, in whole or in part, at any time on or after October 30, 2021, at the redemption prices (expressed as percentages of principal amount) of i104.563% for the 12-month period beginning October 30, 2021, i102.281% for
the 12-month period beginning October 30, 2022, and thereafter at i100.000%, together, in each case, with any accrued and unpaid interest to the date of redemption. Furthermore, before October 30, 2021, NRP may on any one or more occasions redeem up to i35% of
the aggregate principal amount of the 2025 Senior Notes with the net proceeds of certain public or private equity offerings at a redemption price of i109.125% of the principal amount of 2025 Senior Notes, plus any accrued and unpaid interest, if any, to the date of redemption, if at least i65% of
the aggregate principal amount of the 2025 Senior Notes issued under the 2025 Indenture remains outstanding immediately after such redemption and the redemption occurs within 180 days of the closing date of such equity offering. In the event of a change of control, as defined in the 2025 Indenture, the holders of the 2025 Senior Notes may require us to purchase their 2025 Senior Notes at a purchase price equal to i101% of
the principal amount of the 2025 Senior Notes, plus accrued and unpaid interest, if any. The 2025 Senior Notes were issued at par.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
The 2025 Senior Notes are the senior unsecured obligations of NRP and NRP Finance. The 2025 Senior Notes rank equal in right of payment to all existing and future senior unsecured debt of NRP and NRP Finance and senior in right of payment to any of NRP's subordinated
debt. The 2025 Senior Notes are effectively subordinated in right of payment to all future secured debt of NRP and NRP Finance to the extent of the value of the collateral securing such indebtedness and are structurally subordinated in right of payment to all existing and future debt and other liabilities of our subsidiaries, including the Opco Credit Facility and each series of Opco’s existing senior notes. None of NRP's subsidiaries guarantee the 2025 Senior Notes. As of March 31, 2021 and December 31, 2020, NRP and NRP Finance were in compliance with the terms of the Indenture relating to their 2025
Senior Notes.
Opco Debt
All of Opco’s debt is guaranteed by its wholly owned subsidiaries and is secured by certain of the assets of Opco and its wholly owned subsidiaries, other than BRP LLC and NRP Trona LLC. As of March 31, 2021 and December 31, 2020, Opco was in compliance with the terms of the financial covenants contained in its debt agreements.
Opco Credit Facility
In April 2019, the Partnership entered into the Fourth Amendment (the “Fourth Amendment”) to the Opco Credit Facility (the "Opco Credit
Facility"). The Fourth Amendment extended the term of the Opco Credit Facility until April 2023. Lender commitments under the Opco Credit Facility remain at $i100.0 million. The Opco Credit Facility contains financial covenants requiring Opco to maintain:
•A leverage ratio of consolidated indebtedness to EBITDDA (as defined in the Opco Credit Facility) not to exceed i4.0x;
provided, however, that if the Partnership increases its quarterly distribution to its common unitholders above $i0.45 per common unit, the maximum leverage ratio under the Opco Credit Facility will permanently decrease from i4.0x
to i3.0x; and
•a fixed charge coverage ratio of consolidated EBITDDA to consolidated fixed charges (consisting of consolidated interest expense and consolidated lease expense) of not less than i3.5
to 1.0.
During the three months ended March 31, 2021 and 2020, the Partnership did not have any borrowings outstanding under the Opco Credit Facility and had $i100.0 million in available borrowing capacity at both March 31, 2021 and December 31, 2020.
The
Opco Credit Facility is collateralized and secured by liens on certain of Opco’s assets with carrying values of $i360.3 million and $i364.5 million classified as mineral
rights, net and other long-term assets, net on the Partnership’s Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020, respectively.
Opco Senior Notes
Opco has issued several series of private placement senior notes (the "Opco Senior Notes") with various interest rates and principal due dates. As of March 31, 2021 and December 31, 2020, the Opco Senior Notes had cumulative principal balances of $i161.2
million and $i177.9 million, respectively. Opco made mandatory principal payments of $ii16.7/
million during the three months ended March 31, 2021 and 2020.
The i8.92% Opco Senior Notes also provides that in the event that Opco’s leverage ratio of consolidated indebtedness to consolidated EBITDDA (as defined in the Note Purchase Agreements) exceeds i3.75
to 1.00 at the end of any fiscal quarter, then in addition to all other interest accruing on these notes, additional interest in the amount of i2.00% per annum shall accrue on the notes for the two succeeding quarters and for as long thereafter as the leverage ratio remains above i3.75
to 1.00. Opco has not exceeded the i3.75 to 1.00 ratio at the end of any fiscal quarter through March 31, 2021.
NOTES
TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
9. iFair Value Measurements
Fair Value of Financial Assets and Liabilities
The Partnership’s financial assets and liabilities consist of cash and cash equivalents, a contract receivable and debt. The carrying amounts
reported on the Consolidated Balance Sheets for cash and cash equivalents approximate fair value due to their short-term nature. The Partnership uses available market data and valuation methodologies to estimate the fair value of its debt and contract receivable.
i
The following table shows the carrying value and estimated fair value of the Partnership's debt and contract
receivable:
(1)The
fair value of the Opco Senior Notes are estimated by management using quotations obtained for the NRP 2025 Senior Notes on the closing trading prices near period end, which were at i96% and i92% of par value at March 31, 2021 and December
31, 2020, respectively.
/
(2)The fair value of the Partnership's contract receivable is determined based on the present value of future cash flow projections related to the underlying asset at a discount rate of ii15/%
at March 31, 2021 and December 31, 2020.
NRP has embedded derivatives in the preferred units related to certain conversion options, redemption features and the change of control provision that are accounted for separately from the preferred units as assets and liabilities at fair value on the Partnership's Consolidated Balance Sheets. Level 3 valuation of the embedded derivatives are based on numerous factors including the likelihood of the event occurring. The embedded derivatives are revalued quarterly and changes in their fair value would be recorded in other expenses, net on the Partnership's Consolidated Statements of Comprehensive Income. The embedded derivatives had iizero/
value as of March 31, 2021 and December 31, 2020.
10. iRelated Party Transactions
Affiliates of our General Partner
The Partnership’s general partner does not receive
any management fee or other compensation for its management of NRP. However, in accordance with the partnership agreement, the general partner and its affiliates are reimbursed for services provided to the Partnership and for expenses incurred on the Partnership’s behalf. Employees of Quintana Minerals Corporation ("QMC") and Western Pocahontas Properties Limited Partnership ("WPPLP"), affiliates of the Partnership, provide their services to manage the Partnership's business. QMC and WPPLP charge the Partnership the portion of their employee salary and benefits costs related to their employee services provided to NRP. These QMC and WPPLP employee management service costs are presented as operating and maintenance expenses and general and administrative expenses on the Partnership's Consolidated Statements of Comprehensive Income. NRP also reimburses overhead costs incurred by its affiliates to manage the Partnership's business. These overhead costs include
certain rent, information technology, administration of employee benefits and other corporate services incurred by or on behalf of the Partnership’s general partner and its affiliates and are presented as operating and maintenance expenses and general and administrative expenses on the Partnership's Consolidated Statements of Comprehensive Income.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
i
Direct
general and administrative expenses charged to the Partnership by QMC and WPPLP are included on the Partnership's Consolidated Statement of Comprehensive Income as follows:
During the three months ended March 31, 2021 and 2020, the Partnership recognized $i0.2 million and $i0.1
million, respectively, in operating and maintenance expenses on its Consolidated Statements of Comprehensive Income related to an overriding royalty agreement with WPPLP. At March 31, 2021 and December 31, 2020 the Partnership had $i0.1 million and $i0.3 million,
respectively, of other long-term assets, net on its Consolidated Balance Sheets related to a prepaid royalty for this agreement.
11. iMajor Customers
i
Revenues
from customers that exceeded 10 percent of total revenues for any of the periods presented below are as follows:
Foresight
Energy Resources LLC ("Foresight") (1) (2)
$
i8,572
i23
%
$
i8,661
i22
%
Alpha
Metallurgical Resources, Inc. (1)
i8,043
i22
%
i8,571
i21
%
(1)Revenues
from Foresight and Alpha Metallurgical Resources, Inc. (formerly Contura Energy Inc.) are included within the Partnership's Coal Royalty and Other segment.
/
(2)In June 2020, the Partnership entered into lease amendments with Foresight pursuant to which Foresight agreed to pay NRP fixed cash payments to satisfy all obligations arising out of the existing various coal mining leases and transportation infrastructure fee agreements between the Partnership and Foresight for calendar years 2020 and 2021.
12. iCommitments
and Contingencies
NRP is involved, from time to time, in various legal proceedings arising in the ordinary course of business. While the ultimate results of these proceedings cannot be predicted with certainty, Partnership management believes these ordinary course matters will not have a material effect on the Partnership’s financial position, liquidity or operations.
13. iUnit-Based
Compensation
The Partnership's unit-based awards granted in 2021 and 2020 were valued using the closing price of NRP's units as of the grant date. The grant date fair value of these awards granted during the three months ended March 31, 2021 and 2020 were $i3.8
million and $i3.5 million, respectively. Total unit-based compensation expense associated with these awards was $i1.1
million and $i0.7 million for the three months ended March 31, 2021 and 2020, respectively, and is included in general and administrative expenses and operating and maintenance expenses on the Partnership's Consolidated Statements of Comprehensive Income. The unamortized cost associated with unvested outstanding awards as of March 31, 2021 is $i6.6
million, which is to be recognized over a weighted average period of i2.0 years. The unamortized cost associated with unvested outstanding awards as of December 31, 2020 was $i3.7
million.
The Partnership owns rail loadout and associated infrastructure at the Sugar Camp mine in the Illinois Basin operated by a subsidiary of Foresight Energy. The infrastructure at the Sugar Camp mine is leased to a subsidiary of Foresight Energy and is accounted for as a financing transaction (the "Sugar Camp lease"). The Sugar Camp lease expires in 2032 with renewal options for up to i80 additional years. Minimum payments are $i5.0
million per year through the end of the lease term. The $i5.0 million due to the Partnership in 2021 is included in the fixed cash payments from Foresight resulting from contract modifications entered into during the second quarter of 2020 as discussed in Note 11. Major Customers.
The Partnership is also entitled to variable payments in the form of throughput fees determined based on the amount of coal transported and processed utilizing the Partnership's assets. In the event the Sugar Camp lease is renewed beyond 2032, payments become a fixed $i10 thousand per year for the remainder of the renewed term.
15. iCredit
Losses
The Partnership is exposed to credit losses through collection of its short-term trade receivables resulting from contracts with customers and a long-term receivable resulting from a financing transaction with a customer. The Partnership records an allowance for current expected credit losses on these receivables based on the loss-rate method. NRP assessed the likelihood of collection of its receivables utilizing historical loss rates, current market conditions that included the estimated impact of the global COVID-19 pandemic, industry and macroeconomic factors, reasonable and supportable forecasts and facts or circumstances of individual customers and properties. Examples of these facts or circumstances include, but are not limited to, contract
disputes or renegotiations with the customer and evaluation of short and long-term economic viability of the contracted property. For its long-term contract receivable, management reverts to the historical loss experience immediately after the reasonable and supportable forecast period ends.
As of March 31, 2021 and December 31, 2020, NRP had the following current expected credit loss (“CECL”) allowance related to its receivables and long-term contract receivable:
NRP
recorded $i0.4 million and $(i0.4) million in operating and maintenance expenses on its Consolidated Statements of Comprehensive Income related to the change in the
CECL allowance during the three months ended March 31, 2021 and 2020, respectively.
NRP has procedures in place to monitor its ongoing credit exposure through timely review of counterparty balances against contract terms and due dates, account and financing receivable reconciliation, bankruptcy monitoring, lessee audits and dispute resolution. The Partnership may employ legal counsel or collection specialist to pursue recovery of defaulted receivables.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
16. iSubsequent Events
The following represents material events that have occurred subsequent to March 31, 2021 through the time of the Partnership’s filing of its Quarterly
Report on Form 10-Q with the SEC:
Common Unit and Preferred Unit Distributions
In May 2021, the Board of Directors declared a distribution of $i0.45 per common unit with respect to the first quarter of 2021. The Board of Directors also declared a distribution on NRP's preferred units with respect to the first quarter of 2021 to be paid one-half in cash equal to $i3.86 million
and one-half in kind through the issuance of i3,863 additional preferred units.
ITEM
2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following review of operations for the three months ended March 31, 2021 and 2020 should be read in conjunction with our Consolidated Financial Statements and the Notes to Consolidated Financial Statements included in this Form 10-Q and with the Consolidated Financial Statements, Notes to Consolidated Financial Statements and Management’s Discussion and Analysis included in the Natural Resource Partners L.P. Annual Report on Form 10-K for the year ended December 31, 2020.
As used herein, unless the context otherwise requires: "we,""our,""us" and the "Partnership" refer to Natural Resource Partners L.P. and, where
the context requires, our subsidiaries. References to "NRP" and "Natural Resource Partners" refer to Natural Resource Partners L.P. only, and not to NRP (Operating) LLC or any of Natural Resource Partners L.P.’s subsidiaries. References to "Opco" refer to NRP (Operating) LLC, a wholly owned subsidiary of NRP, and its subsidiaries. NRP Finance Corporation ("NRP Finance") is a wholly owned subsidiary of NRP and a co-issuer with NRP on the 9.125% senior notes due 2025 (the "2025 Senior Notes").
INFORMATION REGARDING FORWARD-LOOKING STATEMENTS
Statements included in this 10-Q may
constitute forward-looking statements. In addition, we and our representatives may from time to time make other oral or written statements which are also forward-looking statements. Such forward-looking statements include, among other things, statements regarding: the effects of the global COVID-19 pandemic; our business strategy; our liquidity and access to capital and financing sources; our financial strategy; prices of and demand for coal, trona and soda ash, and other natural resources; estimated revenues, expenses and results of operations; projected production levels by our lessees; Ciner Wyoming LLC’s ("Ciner Wyoming's") trona mining and soda ash refinery operations; distributions from our soda ash joint venture; the impact of governmental policies, laws and regulations, as well as regulatory and legal proceedings involving us, and of scheduled or potential regulatory or legal changes; and global and U.S. economic conditions.
These
forward-looking statements speak only as of the date hereof and are made based upon our current plans, expectations, estimates, assumptions and beliefs concerning future events impacting us and involve a number of risks and uncertainties. We caution that forward-looking statements are not guarantees and that actual results could differ materially from those expressed or implied in the forward-looking statements. You should not put undue reliance on any forward-looking statements. See "Item 1A. Risk Factors" included in this Form 10-Q and in our Annual Report on Form 10-K for the year ended December 31, 2020 for important factors that could cause our actual results of operations or our actual financial condition to differ.
NON-GAAP FINANCIAL
MEASURES
Adjusted EBITDA
Adjusted EBITDA is a non-GAAP financial measure that we define as net income (loss) less equity earnings from unconsolidated investment, net income attributable to non-controlling interest and gain on reserve swap; plus total distributions from unconsolidated investment, interest expense, net, debt modification expense, loss on extinguishment of debt, depreciation, depletion and amortization and asset impairments. Adjusted EBITDA should not be considered an alternative to, or more meaningful than, net income or loss, net income or loss attributable to partners, operating income, cash flows from operating activities or any other measure of financial performance presented in accordance with GAAP as measures of operating performance, liquidity or ability to service debt obligations. There are significant limitations to using Adjusted EBITDA as a measure of
performance, including the inability to analyze the effect of certain recurring items that materially affect our net income, the lack of comparability of results of operations of different companies and the different methods of calculating Adjusted EBITDA reported by different companies. In addition, Adjusted EBITDA presented below is not calculated or presented on the same basis as Consolidated EBITDA as defined in our partnership agreement or Consolidated EBITDDA as defined in Opco's debt agreements. For a description of Opco's debt agreements, see Note 8. Debt, Net in the Notes to Consolidated Financial Statements included herein as well as in "Item 8. Financial Statements and Supplementary Data—Note 11. Debt, Net" in our Annual Report on Form 10-K for the year ended December
31, 2020. Adjusted EBITDA is a supplemental performance measure used by our management and by external users of our financial statements, such as investors, commercial banks, research analysts and others to assess the financial performance of our assets without regard to financing methods, capital structure or historical cost basis.
Distributable cash flow ("DCF") represents net
cash provided by (used in) operating activities of continuing operations plus distributions from unconsolidated investment in excess of cumulative earnings, proceeds from asset sales and disposals, including sales of discontinued operations, and return of long-term contract receivables; less maintenance capital expenditures and distributions to non-controlling interest. DCF is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating, investing or financing activities. DCF may not be calculated the same for us as for other companies. In addition, DCF presented below is not calculated or presented on the same basis as distributable cash flow as defined in our partnership agreement, which is used as a metric to determine whether we are able to increase quarterly distributions to our common unitholders. DCF is a
supplemental liquidity measure used by our management and by external users of our financial statements, such as investors, commercial banks, research analysts and others to asses our ability to make cash distributions and repay debt.
Free Cash Flow
Free cash flow ("FCF") represents net cash provided by (used in) operating activities of continuing operations plus distributions from unconsolidated investment in excess of cumulative earnings and return of long-term contract receivables; less maintenance and expansion capital expenditures, cash flow used in acquisition costs classified as investing or financing activities. FCF is calculated before mandatory debt repayments. FCF is not a measure of financial performance under GAAP and should not be considered as an alternative to cash
flows from operating, investing or financing activities. FCF may not be calculated the same for us as for other companies. FCF is a supplemental liquidity measure used by our management and by external users of our financial statements, such as investors, commercial banks, research analysts and others to assess our ability to make cash distributions and repay debt.
Introduction
The following discussion and analysis presents management's view of our business, financial condition and overall performance. Our discussion and analysis consists of the following subjects:
We
are a diversified natural resource company engaged principally in the business of owning, managing and leasing a diversified portfolio of mineral properties in the United States, including interests in coal and other natural resources and own a non-controlling 49% interest in Ciner Wyoming, a trona ore mining and soda ash production business. Our common units trade on the New York Stock Exchange under the symbol "NRP." Our business is organized into two operating segments:
Coal Royalty and Other—consists primarily of coal royalty properties and coal-related transportation and processing assets. Other assets include industrial mineral royalty properties, aggregates royalty properties, oil and gas royalty properties and timber. Our coal reserves are primarily located in Appalachia, the Illinois Basin and the Northern Powder River Basin in the United States. Our industrial minerals and aggregates
properties are located in various states across the United States, our oil and gas royalty assets are primarily located in Louisiana and our timber assets are primarily located in West Virginia.
Soda Ash—consists of our 49% non-controlling equity interest in Ciner Wyoming, a trona ore mining and soda ash production business located in the Green River Basin of Wyoming. Ciner Wyoming mines the trona and processes it into soda ash that is sold both domestically and internationally into the glass and chemicals industries.
Corporate and Financing includes functional corporate departments that do not earn revenues. Costs incurred by these departments include interest and financing, corporate headquarters and overhead, centralized treasury, legal and accounting and other corporate-level activity not specifically allocated to a segment.
Our
financial results by segment for the three months ended March 31, 2021 are as follows:
Operating Segments
(In
thousands)
Coal Royalty and Other
Soda Ash
Corporate and Financing
Total
Revenues and other income
$
35,178
$
1,973
$
—
$
37,151
Net
income (loss)
$
20,488
$
1,953
$
(14,060)
$
8,381
Adjusted EBITDA (1)
$
29,646
$
3,900
$
(4,110)
$
29,436
Cash
flow provided by (used in) continuing operations
Operating activities
$
25,962
$
3,888
$
(6,650)
$
23,200
Investing
activities
$
600
$
—
$
—
$
600
Financing activities
$
(132)
$
—
$
(26,691)
$
(26,823)
Distributable
cash flow (1)
$
26,562
$
3,888
$
(6,650)
$
23,800
Free cash flow (1)
$
26,503
$
3,888
$
(6,650)
$
23,741
(1)See
"—Results of Operations" below for reconciliations to the most comparable GAAP financial measures.
The global COVID-19 pandemic has had a significant negative impact on demand for steel, electricity and glass, which translates to lower demand for the coal and soda
ash that our properties produce. While demand for metallurgical and thermal coals and soda ash began to rebound during the third quarter of 2020, prices remain below pre-pandemic levels, and the coal and soda ash markets remain challenged. We are unable to predict the ultimate severity or duration of the COVID-19 pandemic or its impact on our or Ciner Wyoming's business. We generated $23.7 million of free cash flow during the quarter ended March 31, 2021, and ended the quarter with $196.8 million of liquidity consisting of $96.8 million of cash and cash equivalents and $100.0 million of borrowing capacity under our Opco Credit Facility. As a result, we believe we have the financial flexibility to navigate the effects of the pandemic on our business. We continue to employ remote work protocols and are conducting business as usual despite the pandemic.
Despite
our liquidity level at the end of the quarter, our consolidated leverage ratio has risen since early 2020 and was 4.5x at March 31, 2021. The indenture governing our 2025 parent company notes restricts us from paying more than one-half of the quarterly distribution on our preferred units in cash if our consolidated leverage ratio exceeds 3.75x. Accordingly, the Board of Directors of our general partner has declared a distribution on our preferred units to be paid one-half in kind through the issuance of additional preferred units (“PIK units”) for the past three quarters. We expect our leverage ratio to continue to rise through the second quarter of 2021 and then begin to decline as we continue to pay down debt. Under the terms of our partnership agreement, to the extent our consolidated leverage ratio remains above 3.75x
into 2022 and we therefore remain unable to redeem any outstanding paid-in-kind preferred units, we may be required to temporarily suspend distributions on our common units until the leverage ratio drops below 3.75x and the outstanding paid-in-kind preferred units are redeemed.
Future distributions on NRP's common and preferred units will be determined on a quarterly basis by the Board of Directors. The Board of Directors considers numerous factors each quarter in determining cash distributions, including profitability, cash flow, debt service obligations, covenants in our debt and partnership agreements, market conditions and outlook, estimated unitholder income tax liability and the level of cash reserves that the Board determines is necessary for future operating and capital needs.
Coal Royalty and Other Business Segment
Metallurgical
coal markets remain challenged by the uncertainties around the COVID-19 pandemic, however prices have rebounded from the lows seen in the second quarter of 2020 and the outlook continues to strengthen. Domestic and export thermal coal markets continue to stabilize, but still face ongoing negative effects of the COVID-19 pandemic and the long-term challenges of lower utility demand, low natural gas prices, and the secular shift to renewable energy. Our lessees sold 6.6 million tons of coal from our properties in the first three months of 2021 and we derived approximately 50% of our coal royalty revenues and approximately 40% of our coal royalty sales volumes from metallurgical coal during the same period. In addition, we do not have significant sensitivity to thermal coal price movements primarily due to our lease amendments with Foresight Energy which we entered into in 2020.
Soda Ash Business Segment
While
Ciner Wyoming's business has yet to recover to pre-COVID levels, overall sales volumes increased and overall production volumes increased over second quarter 2020 lows, though global prices remain depressed. While we believe Ciner Wyoming's facility is competitively positioned as one of the lowest cost producers of soda ash in the world, we expect the market to remain volatile as a result of ongoing uncertainties with the COVID-19 pandemic.
Revenues and other income in the first quarter of 2021 were lower by $4.3 million compared to the prior year quarter primarily as a result of lower sales prices due to demand disruptions caused by the COVID-19 pandemic.
In order to have financial flexibility during the COVID-19 pandemic, Ciner Wyoming suspended its regular quarterly distributions in the third quarter of 2020.
Ciner Wyoming will continue to evaluate, on a quarterly basis, whether to reinstate the distribution. Ciner Wyoming’s ability to pay future quarterly distributions will be dependent in part on its cash reserves, liquidity, total debt levels and anticipated capital expenditures. Distributions received from Ciner Wyoming were $3.9 million in the first quarter of 2021 as compared to $7.1 million in the first quarter of 2020. Although Ciner Wyoming made a special distribution to its members in the first quarter of 2021, we do not believe Ciner Wyoming will resume regular quarterly distributions until they have greater visibility and confidence in global soda markets.
When
considering the significant investment required by Ciner Wyoming’s previously announced expansion project and the infrastructure improvements designed to increase overall efficiency, combined with the COVID-19 pandemic’s negative impact on Ciner Wyoming’s financial results, Ciner Wyoming has reprioritized the timing of the significant capital expenditure items in order to increase financial and liquidity flexibility until it has more clarity and visibility into the ongoing impact of the COVID-19 pandemic on its business.
Results of Operations
First Three Months of 2021 and 2020 Compared
Revenues and Other Income
The following table includes
our revenues and other income by operating segment:
For the Three Months Ended March 31,
Increase (Decrease)
Percentage Change
Operating
Segment (In thousands)
2021
2020
Coal Royalty and Other
$
35,178
$
33,942
$
1,236
4
%
Soda Ash
1,973
6,272
(4,299)
(69)
%
Total
$
37,151
$
40,214
$
(3,063)
(8)
%
The
changes in revenues and other income is discussed for each of the operating segments below:
The following table presents coal sales volumes, coal royalty revenue per ton and coal royalty revenues by major coal producing region, the significant categories of other revenues and other income:
For
the Three Months Ended March 31,
Increase (Decrease)
Percentage Change
(In thousands, except per ton data)
2021
2020
Coal sales volumes (tons)
Appalachia
Northern
120
327
(207)
(63)
%
Central
2,650
2,933
(283)
(10)
%
Southern
100
222
(122)
(55)
%
Total
Appalachia
2,870
3,482
(612)
(18)
%
Illinois Basin
2,658
505
2,153
426
%
Northern
Powder River Basin
1,059
527
532
101
%
Total coal sales volumes
6,587
4,514
2,073
46
%
Coal
royalty revenue per ton
Appalachia
Northern
$
3.64
$
1.81
$
1.83
101
%
Central
4.22
4.83
(0.61)
(13)
%
Southern
5.28
4.16
1.12
27
%
Illinois
Basin
2.06
4.35
(2.29)
(53)
%
Northern Powder River Basin
3.37
4.13
(0.76)
(18)
%
Combined
average coal royalty revenue per ton
3.22
4.44
(1.22)
(27)
%
Coal royalty revenues
Appalachia
Northern
$
437
$
593
$
(156)
(26)
%
Central
11,195
14,173
(2,978)
(21)
%
Southern
528
923
(395)
(43)
%
Total
Appalachia
12,160
15,689
(3,529)
(22)
%
Illinois Basin
5,483
2,199
3,284
149
%
Northern
Powder River Basin
3,573
2,177
1,396
64
%
Unadjusted coal royalty revenues
21,216
20,065
1,151
6
%
Coal
royalty adjustment for minimum leases (1)
(5,851)
(963)
(4,888)
(508)
%
Total coal royalty revenues
$
15,365
$
19,102
$
(3,737)
(20)
%
Other
revenues
Production lease minimum revenues (1)
$
3,450
$
802
$
2,648
330
%
Minimum
lease straight-line revenues (1)
6,096
3,809
2,287
60
%
Property tax revenues
1,469
1,599
(130)
(8)
%
Wheelage
revenues
1,781
2,204
(423)
(19)
%
Coal overriding royalty revenues
1,859
1,322
537
41
%
Lease
amendment revenues
868
843
25
3
%
Aggregates royalty revenues
454
576
(122)
(21)
%
Oil
and gas royalty revenues
1,366
1,103
263
24
%
Other revenues
219
73
146
200
%
Total
other revenues
$
17,562
$
12,331
$
5,231
42
%
Coal royalty and other
$
32,927
$
31,433
$
1,494
5
%
Transportation
and processing services revenues
2,192
2,509
(317)
(13)
%
Gain on asset sales and disposals
59
—
59
100
%
Total
Coal Royalty and Other segment revenues and other income
$
35,178
$
33,942
$
1,236
4
%
(1)Beginning
April 1, 2020 and effective January 1, 2020, certain revenues previously classified as coal royalty revenues are classified as production lease minimum revenues or minimum lease straight-line revenues due to contract modifications with Foresight that fixed consideration paid to us over a two-year period.
Total coal royalty revenues decreased $3.7 million during the three months ended March 31, 2021 as compared to the prior year quarter primarily as a result of certain revenues previously classified as coal royalty revenues that are now classified as production lease minimum revenues or minimum lease straight-line revenues due to contract modifications with Foresight as mentioned above. Excluding the impacts of these reclassifications, coal royalty revenues increased $1.2 million period over period. The discussion by region is as follows:
•Appalachia: Coal royalty revenues decreased
$3.5 million primarily due to a 18% decrease in sales volumes primarily driven by the termination of certain coal leases in 2020 as a result of weakened coal markets compounded by the COVID-19 pandemic.
•Illinois Basin: Coal royalty revenues increased $3.3 million primarily due to a 426% increase in sales volumes, partially offset by a 53% decrease in sales prices as compared to the prior year quarter.
•Northern Powder River Basin: Sales volumes increased 101% and coal royalty revenues increased $1.4 million primarily due to our lessee mining on our property in accordance with its mine plan in 2021, partially offset by a 18% decrease in sales prices as compared to the prior year quarter.
Other Revenues
Other
revenues increased $5.2 million primarily due to a $2.6 million increase in production lease minimum revenues and a $2.3 million increase in minimum lease straight-line revenues, both primarily a result of the contract modifications with Foresight as discussed above.
Soda Ash
Revenues and other income related to our Soda Ash segment decreased $4.3 million compared to the prior year quarter primarily as a result of lower sales prices due to demand disruptions caused by the COVID-19 pandemic
Operating Expenses
The following table presents the significant categories of our consolidated operating expenses:
For
the Three Months Ended March 31,
Increase
Percentage Change
(In thousands)
2021
2020
Operating expenses
Operating and maintenance expenses
$
5,552
$
5,202
$
350
7
%
Depreciation,
depletion and amortization
5,092
2,012
3,080
153
%
General and administrative expenses
4,110
3,913
197
5
%
Asset
impairments
4,043
—
4,043
100
%
Total operating expenses
$
18,797
$
11,127
$
7,670
69
%
Total
operating expenses increased $7.7 million primarily due to a $4.0 million increase in asset impairments as a result of lease termination, and a $3.1 million increase in depreciation, depletion and amortization expense as a result of increased production at certain Illinois Basin coal properties. The remaining $0.6 million increase was due to a $1.3 million increase in certain costs primarily driven by increased bad debt expense, partially offset by a $0.7 million reduction in controllable costs as a result of our cost saving initiatives.
Less:
equity earnings from unconsolidated investment
—
(6,272)
—
(6,272)
Add: total distributions from unconsolidated investment
—
7,105
—
7,105
Add:
interest expense, net
—
—
10,308
10,308
Add:
depreciation, depletion and amortization
2,012
—
—
2,012
Adjusted EBITDA
$
28,756
$
7,089
$
(3,913)
$
31,932
Adjusted
EBITDA decreased $2.5 million primarily due to $3.2 million of lower cash distributions received from Ciner Wyoming in the first three months of 2021 as compared to the prior year quarter.
The following table reconciles net cash provided by (used in) operating activities of continuing operations (the most comparable GAAP financial measure) by business segment to DCF and FCF:
Less: proceeds from sale of discontinued operations
—
—
—
66
Free
cash flow
$
30,828
$
7,089
$
(7,490)
$
30,427
DCF and FCF decreased $6.6 million and $6.7 million, respectively, primarily due to the following:
•Coal Royalty and Other Segment
◦DCF and FCF
decreased $4.3 million primarily as a result of lease amendment fee payments received in the first quarter of 2020.
•Soda Ash Segment
◦DCF and FCF decreased $3.2 million as a result of lower cash distributions received from Ciner Wyoming in the first three months of 2021 as compared to the prior year period.
Liquidity and Capital Resources
Current Liquidity
As of March 31, 2021, we had total liquidity of $196.8 million, consisting of $96.8 million of cash and cash equivalents and $100.0 million of borrowing capacity under our
Opco Credit Facility. We have significant debt service obligations, including approximately $23 million of principal repayments on Opco’s senior notes throughout the remainder of 2021. We believe our liquidity position provides us with the flexibility to continue paying down debt and manage our business through the current market environment.
Cash Flows
Cash flows provided by operating activities decreased $8.7 million, from $31.9 million in the three months ended March 31, 2020 to $23.2 million in the three months ended March 31, 2021 primarily related to lower operating cash flow as a result of lease amendment fee payments received in the first quarter of 2020 in addition to lower cash distributions received from Ciner Wyoming in the first three months of 2021 as compared to the
prior year quarter.
Cash flows used in financing activities decreased $3.0 million, from $29.8 million in the three months ended March 31, 2020 to $26.8 million in the three months ended March 31, 2021 primarily due to lower preferred unit cash distributions in the first quarter of 2021 as a result of paying half of the distribution in kind through the issuance of additional preferred units.
We have
been and continue to be in compliance with the terms of the financial covenants contained in our debt agreements. For additional information regarding our debt and the agreements governing our debt, including the covenants contained therein, see Note 8. Debt, Net to the Consolidated Financial Statements included elsewhere in this Quarterly Report on Form 10-Q.
Off-Balance Sheet Transactions
We do not have any off-balance sheet arrangements with unconsolidated entities or related parties and accordingly, there are no off-balance sheet risks to our liquidity and capital resources from
unconsolidated entities.
The preparation of Consolidated Financial
Statements in conformity with generally accepted accounting principles in the United States of America requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and the accompanying notes. There have been no significant changes to our critical accounting estimates from those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2020.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
As a smaller reporting company, we are not required to include this disclosure in our Form 10-Q for the quarterly period ended March
31, 2021.
ITEM 4. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
NRP carried out an evaluation of the effectiveness of the design and operation of its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) as of the end of the period covered by this report. This evaluation was performed under the supervision and with the participation of NRP management, including the Chief Executive Officer and Chief Financial Officer of the general partner of the general partner of NRP. Based upon that evaluation, the Chief Executive Officer and Chief Financial
Officer concluded that these disclosure controls and procedures are effective in providing reasonable assurance that (a) the information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms, and (b) such information is accumulated and communicated to our management, including our CEO and CFO, as appropriate to allow timely decisions regarding required disclosure.
Changes in the Partnership’s Internal Control Over Financial Reporting
There were no material changes in the Partnership’s internal control over financial reporting during the first three months of 2021 that materially affected, or were reasonably likely to materially affect, the Partnership’s internal control over financial reporting.
From time to time, we are involved in various legal proceedings arising in the ordinary course of business. While the ultimate results of these proceedings cannot be predicted with certainty, we believe these ordinary course matters will not have a material effect on our financial position, liquidity or operations.
ITEM 1A. RISK FACTORS
During
the period covered by this report, there were no material changes from the risk factors previously disclosed in Natural Resource Partners L.P.’s Annual Report on Form 10-K for the year ended December 31, 2020.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
Fifth
Amended and Restated Agreement of Limited Partnership of Natural Resource Partners L.P., dated as of March 2, 2017 (incorporated by reference to Exhibit 3.1 to Current Report on Form 8-K filed on March 6, 2017).
Certificate
of Limited Partnership of Natural Resource Partners L.P. (incorporated by reference to Exhibit 3.1 to the Registration Statement on Form S-1 filed April 19, 2002, File No. 333-86582).
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned and thereunto duly authorized.