North European Oil Royalty Trust
Annual Report 2021

Plain-text annual report

Annual Report (cid:21)(cid:19)(cid:21)1 North European Oil Royalty Trust ATTENTION: PLEASE RETAIN CRITICAL TAX INFORMATION ENCLOSED In light of public health concerns related to the Coronavirus (COVID-19) outbreak, and to help protect the health and well-being of the Trust’s Unit Owners, employees and representatives, the Annual Meeting of North European Oil Royalty Trust will be held on Wednesday, February 16, 2022, in the Emerson Meeting Room at the Courtyard Marriott, 75 Railroad St., Keene, N.H. (near the Managing Director’s office) at 11:00 a.m. Owners who cannot attend in person may observe the annual meeting and ask questions during the question period by using the following Zoom link, https://us02web.zoom.us/j/82364882053. When you enter the meeting, you will be muted. At the start of the question period if you wish to pose a question, please click on the “Participants” button at the bottom of the Zoom screen. A window will open to the right. Click on the “…” at the bottom of the window and click “Raise Hand.” You will then be called on to unmute yourself and pose your question. Unit owners are urged to vote by proxy in the manner provided in the proxy card. Table of Contents Report to Unit Owners . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Description of Trust Assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Management’s Discussion and Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Critical Accounting Policies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Report of Independent Registered Public Accounting Firm . . . . . . . . . . . . . . . . Financial Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Notes to Financial Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Disclosure Controls and Procedures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Internal Control over Financial Reporting . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Trustees, Administration and Important Contacts . . . . . . . . . . . . . . . . . . . . . . . 2021 Tax Letter (Removable) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2 3 4-7 8 9-10 11-12 13-15 16 16 17 18-21 IMPORTANT TAX INFORMATION For your convenience, the information necessary to prepare your 2021 tax return is included in the removable “2021 Tax Letter” on Pages 18 through 21. Please note that there will be no separate mailing of the tax letter. The 2021 Tax Letter is also available at the Trust’s website, www.neort.com. Report to Unit Owners: FOURTH QUARTER 2021 Net income for the Trust for the fourth quarter of fiscal 2021 was $1,302,678, an increase of 495.79% from net income of $218,649 for the fourth quarter of fiscal 2020. The Trust receives nearly all of its royalties under two royalty agreements. The Mobil Agreement is the 4% royalty rate agreement covering gas sales from the western half of a concession in the Federal Republic of Germany (the “Oldenburg concession”). The OEG Agreement is the 0.6667% royalty rate agreement covering gas sales from the entire Oldenburg concession. Total royalties under the Mobil Agreement, including sulfur royalties under the 2% Mobil Sulfur Agreement, for the fourth quarter of fiscal 2021 were reduced by negative adjustments from prior periods of ($120,777), as compared to negative adjustments totaling ($483,809) for the fourth quarter of fiscal 2020. Total royalties under the OEG Agreement for the fourth quarter of fiscal 2021 were reduced by negative adjustments from prior periods of ($70,329), as compared to negative adjustments of ($213,393) for the fourth quarter of fiscal 2020. Net income in the fourth quarter of 2021 was higher than the fourth quarter of 2020 due to the impact of these prior period adjustments as well as increases in both gas prices and gas sales. Gas sales were higher due the combination of increased demand resulting from the reduced economic impact of COVID-19 and the uninterrupted operation of Grossenkneten during the fourth quarter of fiscal 2021. The relevant details for the fourth quarters of fiscal 2021 and 2020 for gas sales under the Mobil and OEG Agreements are shown in the table below. Quarterly Gas Data Providing Basis for Fiscal Quarter Royalties 3rd Calendar Quarter Ended 9/30/2020 3rd Calendar Quarter Ended 9/30/2021 Percentage Change Mobil Agreement: Gas Sales (Bcf1) Gas Prices2 (Ecents/kWh3) Average Exchange Rate4 Gas Royalties OEG Agreement: Gas Sales (Bcf) Gas Prices (Ecents/kWh) Average Exchange Rate Gas Royalties 3.985 1.9573 1.1703 $1,043,662 13.365 1.9961 1.1714 $441,458 3.186 0.9255 1.1761 $395,791 10.601 0.9438 1.1730 $97,128 + 25.08% +111.49% - 0.49% +163.69% + 26.07% +111.50% - 0.14% +354.51% 1Billion cubic feet 4Based on average Euro/dollar exchange rates of cumulative royalty transfers 2Gas prices derived from May-July period 3Euro cents per Kilowatt hour FISCAL 2021 REPORT For fiscal 2021, the Trust’s total royalty income increased 13.64% to $4,602,410 from $4,050,017 in fiscal 2020. The increase in royalty income was the result of a combination of factors including the reduction in the economic impact of COVID-19, higher gas prices and higher average exchange rates in comparison to fiscal 2020. As in prior years, the Trust receives information concerning adjustments from the operating companies based on their final calculations of royalties payable during the previous periods as well as other required adjustments. During fiscal 2021 and 2020, these adjustments decreased royalty income by $696,189 and decreased royalty income by - 1 - $653,916, respectively. During fiscal 2021 and 2020, Mobil sulfur royalties totaled $178,367 and $71,280, respectively. The total distribution for fiscal 2021 was $0.47 per unit compared to $0.32 per unit for fiscal 2020. The Trust’s German consultant periodically contacts the representatives of the operating companies to inquire about their planned and proposed drilling and geophysical work and other general matters. The following represents a summary of the most recent information the Trust’s German consultant received from representatives of the operating companies’ unified exploration and production venture, ExxonMobil Production Deutschland GmbH (“EMPG”). The Trust is not able to confirm the accuracy of any of the information supplied by the operating companies. In addition, the operating companies are not required to take any of the actions outlined and, if they change their plans with respect to any such actions, they are not obligated to inform the Trust. Information on wells that are not named or are in preliminary planning stages is not divulged by EMPG. EMPG has not planned any new wells for calendar year 2022. On the exploration side, there has been no major work initiated. Desktop studies are continuing to satisfy mining authorities. The operator has performed a study, The Sour Gas Study, dealing with all matters which could help to optimize the tail end production from all sour gas wells in the gas fields of Oldenburg concessions. The focus of the study was on how to optimize the gas compression in the flowline grids from each well to the gathering stations, compressor stations and finally towards the processing plant in Grossenkneten. Some optimization potential has been found. Grossenkneten plant operation will soon be reduced to one train from the current two trains in parallel thus optimizing cost and efficiency. It is expected that the Trust’s consultant will learn additional details about The Sour Gas Study and its impact when he meets EMPG in March 2022. Based on the limited information available, Graves & Co. Consulting LLC, the Trust’s petroleum consultant (“Graves & Co.”), has prepared and submitted their report on the cost depletion percentage applicable to Trust unit owners for calendar 2021. The 2021 cost depletion percentage of 17.7008% and related tax information is contained in the removable "2021 Tax Letter" on Pages 19 through 22 of this report. The calculation of the cost depletion percentage is based on Graves & Co.’s estimate of remaining net proved producing reserves as of October 1, 2021. (The complete text of the report is available in the Trust’s 2021 Report on Form 10-K as exhibit 99.1.) The report indicates that net Trust gas reserves increased 20.05% to 5.431 Bcf from 4.524 Bcf on net sales for 2021 of 0.882 Bcf and a positive reserve adjustment of 1.789 Bcf. December 30, 2021 Respectfully submitted, John R. Van Kirk Managing Director - 2 - Description of Trust Assets The properties of the Trust, which the Trust and Trustees hold pursuant to the Trust Agreement on behalf of the unit owners, are overriding royalty rights on sales of gas, sulfur and oil under the Oldenburg concession. The Oldenburg concession covers approximately 1,386,000 acres, is located in the German federal state of Lower Saxony, and is the area from which natural gas, sulfur and oil are extracted. The Oldenburg concession currently provides nearly 100% of all the royalties received by the Trust. The Oldenburg concession is held by Mobil Erdgas-Erdol GmbH ("Mobil Erdgas"), a German operating subsidiary of ExxonMobil, and by Oldenburgische Erdolgesellschaft ("OEG"). BEB Erdgas und Erdol GmbH (“BEB”), a joint venture in which ExxonMobil and the Royal Dutch/Shell Group each own 50%, administers the concession held by OEG. In 2002, Mobil Erdgas and BEB formed EMPG to carry out all exploration, drilling and production activities. All sales activities upon which the calculation of royalties is based are still handled by either Mobil Erdgas or BEB (the “operating companies”). Under the Mobil Agreement covering the western part of the Oldenburg concession (approximately 662,000 acres), the Trust receives a royalty payment of 4% on gross receipts from sales by Mobil Erdgas of gas well gas, oil well gas, crude oil and condensate. Under the Mobil Agreement there is no deduction of costs prior to the calculation of royalties from gas well gas and oil well gas. Historically, the Trust has received significantly greater royalty payments under the Mobil Agreement (as compared to the OEG Agreement described below) due to the higher royalty rate specified by that agreement. The Trust is also entitled under an agreement with Mobil Erdgas to receive a 2% royalty on gross receipts of sales of sulfur obtained as a by-product of sour gas produced from the western part of Oldenburg (the “Mobil Sulfur Agreement”). The payment of the sulfur royalty is conditioned upon sales of sulfur by Mobil Erdgas at a selling price above an agreed upon base price adjusted annually by an inflation index. When the average quarterly selling price falls below the indexed base price, no sulfur royalties are paid. Sulfur royalties under the Mobil Agreement totaled $178,367 and $71,280 during fiscal 2021 and 2020, respectively. Under the OEG Agreement covering the entire Oldenburg concession, the Trust receives royalties at the rate of 0.6667% on gross receipts from sales by BEB of gas well gas, oil well gas, crude oil, condensate and sulfur less a certain allowed deduction of costs. Under the OEG Agreement, 50% of the field handling and treatment costs as reported for state royalty purposes are deducted from the gross sales receipts prior to the calculation of the royalty to be paid to the Trust. - 3 - Management’s Discussion and Analysis of Financial Condition and Results of Operations Executive Summary The Trust is a passive fixed investment trust which holds overriding royalty rights, receives income under those rights from certain operating companies, pays its expenses and distributes the remaining net funds to its unit owners. As mandated by the Trust Agreement, distributions of income are made on a quarterly basis. These distributions, as determined by the Trustees, constitute substantially all of the funds on hand after provision is made for Trust expenses then anticipated. The Trust does not engage in any business or extractive operations of any kind in the areas over which it holds royalty rights and is precluded from engaging in such activities by the Trust Agreement. There are no requirements, therefore, for capital resources with which to make capital expenditures or investments in order to continue the receipt of royalty revenues by the Trust. The operating companies pay royalties to the Trust based on their sales of natural gas, sulfur and oil. Of these three products, natural gas provided approximately 90% of the total royalties in fiscal 2021. The amount of royalties paid to the Trust is primarily based on four factors: the amount of gas sold, the area from which the gas is sold, the price of that gas and the exchange rate. For purposes of the royalty calculation, the determination of the gas price is explained in detail in the following two paragraphs. On August 26, 2016, the Mobil and OEG Agreements were amended to establish a new base to determine gas prices for the calculation of the Trust’s royalties. This new base is set as the state assessment base for natural gas used by the operating companies in their calculation of royalties payable to the State of Lower Saxony. This change reflects a shift from the use of gas ex-field prices (“contractual prices”) to the prices calculated for the German Border Import gas Price (“GBIP”). The average combined totals of the GBIP for the relevant three-month period are used to provide an average gas price for the quarter. This average gas price is increased by 1% and 3% per the terms of the Mobil and OEG Royalty Agreements and is used by the operators to calculate the royalties payable to the Trust for a given quarter. The change to the GBIP was intended to be revenue neutral for the Trust in comparison to the previous pricing methodology. Additionally, this change was intended to reduce the scope and cost of the accounting examination, eliminate ongoing disputes with OEG and Mobil regarding sales to related parties, and reduce prior year adjustments to the normally scheduled year-end reconciliation. The pricing basis has eliminated certain costs (transportation and plant gas storage) that were previously deductible prior to the royalty calculation under the OEG Agreement. There are two types of natural gas found within the Oldenburg concession, sweet gas and sour gas. Sweet gas has little or no contaminants and needs no treatment before it can be sold. Sour gas, in comparison, must be processed at the Grossenkneten desulfurization plant before it can be sold. The desulfurization process removes hydrogen sulfide and other contaminants. The hydrogen sulfide in gaseous form is converted to sulfur in a solid form, which is sold separately. With full operation of the two units, raw gas input capacity stands at approximately 400 million cubic feet (“MMcf”) per day. As needed, EMPG conducts maintenance on the plant generally during the summer months when demand is lower. As part of the regular 10-year scheduled maintenance, Grossenkneten underwent an overhaul from September 8, 2020 through October 13, 2020. During this time the plant was completely shut down and - 4 - no sour gas was processed. Since sour gas accounts for 75% of overall gas sales and 98% of western gas sales, this shutdown significantly impacted royalty income during the fourth quarter of fiscal 2020 and the first quarter of fiscal 2021. The Trust has no means of ensuring continued income from overriding royalty rights at their present level or otherwise. The Trust’s consultant in Germany provides general information to the Trust on the German and European economies and energy markets. This information provides a context in which to evaluate the actions of the operating companies. The Trust's consultant receives reports from EMPG with respect to current and planned drilling and exploration efforts. However, EMPG and the operating companies continue to limit the information flow to that which is required by German law, and the Trust is not able to confirm the accuracy of any of the information supplied by EMPG or the operating companies. Results: Fiscal 2021 versus Fiscal 2020 For fiscal 2021, the Trust’s gross royalty income increased 13.64% to $4,602,410 from $4,050,017 in fiscal 2020. The increase in the amount of royalty income resulted in the higher distribution. The total distribution for fiscal 2021 was $0.47 per unit compared to $0.32 per unit for fiscal 2020. Gas prices and the average exchange rates under both royalty agreements were higher while gas sales were down. The royalty income attributable to gas sales under the Mobil Agreement in fiscal 2021 increased by $195,626 as compared to fiscal 2020. Royalty income attributable to gas sales under the OEG Agreement in fiscal 2021 increased by $156,179 as compared to fiscal 2020. As in prior years, the Trust receives adjustments from the operating companies based on their final calculations of royalties payable during the previous periods. During fiscal 2021, the adjustments based on royalties payable for 2020 decreased royalty income by $696,189. During fiscal 2020, the adjustments based on royalties payable for 2017, 2018 and 2019 decreased royalty income by $653,916. In fiscal 2021 and 2020, Mobil sulfur royalties totaled $178,367 and $71,280, respectively. Gas sales under the Mobil Agreement decreased 8.33% to 15.821 Billion cubic feet (“Bcf”) in fiscal 2021 from 17.259 Bcf in fiscal 2020. The most significant factor resulting in the decrease in gas sales for 2021 was the continuing negative impact of COVID-19 on the German, European and global economies. In addition, according to the Trust’s consultant in Germany, some portion of the decline in gas production is due to the normal reduction in well pressure that is experienced over time. Quarterly and Yearly Gas Sales under the Mobil Agreement in Billion cubic feet Percentage Change - 34.03% - 5.84% - 6.70% + 25.11% - 8.33% 2021 Gas Sales 3.222 4.354 4.259 3.986 15.821 2020 Gas Sales 4.884 4.624 4.565 3.186 17.259 Fiscal Quarter First Second Third Fourth Fiscal Year Total - 5 - Average prices for gas sold under the Mobil Agreement increased 20.71% to 1.5915 Euro cents per kilowatt hour (“€cents/kWh”) in fiscal 2021 from 1.3185 €cents/kWh in fiscal 2020. Average Gas Prices under the Mobil Agreement in Euro cents per Kilowatt Hour Fiscal Quarter First Second Third Fourth Fiscal Year Average 2021 Average Gas Prices 1.1935 1.5395 1.6032 1.9573 1.5915 2020 Average Gas Prices 1.3550 1.6349 1.2326 0.9255 1.3185 Percentage Change - 11.92% - 5.84% + 30.07% +111.49% + 20.71% Converting gas prices into more familiar terms, using the average exchange rate, yielded a price of $5.43 per thousand cubic feet (“Mcf”), a 28.98% increase from fiscal 2020’s average price of $4.21/Mcf. For fiscal 2021, royalties paid under the Mobil Agreement were converted and transferred at an average Euro/U.S. dollar exchange rate of $1.1932, an increase of 7.06% from the average Euro/U.S. dollar exchange rate of $1.1145 for fiscal 2020. Average Euro Exchange Rate under the Mobil Agreement Fiscal Quarter First Second Third Fourth Fiscal Year Average 2021 Average Euro Exchange Rate 1.2116 1.2020 1.2004 1.1703 1.1932 2020 Average Euro Exchange Rate 1.1105 1.0943 1.1143 1.1761 1.1145 Percentage Change + 9.10% + 9.84% + 7.73% - 0.49% + 7.06% Excluding the effects of differences in prices and average exchange rates, the combination of royalty rates on gas sold from western Oldenburg results in an effective royalty rate approximately seven times higher than the royalty rate on gas sold from eastern Oldenburg. This is of particular significance to the Trust since gas sold from western Oldenburg provides the bulk of royalties paid to the Trust. For fiscal 2021, the volume of gas sold from western Oldenburg accounted for only 29.33% of the volume of all gas sales. However, western Oldenburg gas royalties provided approximately 79.98% or $3,326,874 out of a total of $4,159,420 in overall Oldenburg gas royalties. Gas sales under the OEG Agreement decreased 3.39% to 53.947 Bcf in fiscal 2021 from 55.841 Bcf in fiscal 2020. The most significant factor resulting in the decrease in gas sales for 2021 was the continuing negative impact of COVID-19 on the German, European and global economies. In addition, according to the Trust’s consultant in Germany, some portion of the decline in gas production is due to the normal reduction in well pressure that is experienced over time. - 6 - Quarterly and Yearly Gas Sales under the OEG Agreement in Billion cubic feet Fiscal Quarter First Second Third Fourth Fiscal Year Total 2021 Gas Sales 11.622 14.495 14.465 13.365 53.947 2020 Gas Sales 16.026 15.266 13.948 10.601 55.841 Percentage Change - 27.48% - 5.05% + 3.71% +26.07% - 3.39% Average gas prices for gas sold under the OEG Agreement increased 20.19% to 1.6175 €cents/kWh in fiscal 2021 from 1.3458 €cents/kWh in fiscal 2020. Average Gas Prices under the OEG Agreement in Euro cents per Kilowatt Hour Fiscal Quarter First Second Third Fourth Fiscal Year Average 2021 Average Gas Prices 1.2171 1.5700 1.6349 1.9961 1.6175 2020 Average Gas Prices 1.3818 1.6672 1.2570 0.9438 1.3458 Percentage Change - 11.92% - 5.83% + 30.06% +111.50% + 20.19% Converting gas prices into more familiar terms, using the average exchange rate, yielded a price of $5.38/Mcf, a 28.71% increase from fiscal 2020’s average price of $4.18/Mcf. For fiscal 2021, royalties paid under the OEG Agreement were converted and transferred at an average Euro/U.S. dollar exchange rate of $1.1931, an increase of 7.35% from the average Euro/U.S. dollar exchange rate of $1.1114 for fiscal 2020. Average Euro Exchange Rate under the OEG Agreement Fiscal Quarter First Second Third Fourth Fiscal Year Average 2021 Average Euro Exchange Rate 1.2123 1.2022 1.1998 1.1714 1.1931 2020 Average Euro Exchange Rate 1.1115 1.0955 1.1141 1.1730 1.1114 Percentage Change + 9.07% + 9.74% + 7.69% - 0.14% + 7.35% Interest income for fiscal 2021 of $641 decreased from interest income of $2,853 for fiscal 2020 due to lower interest rates in effect. Trust expenses decreased $140,013, or 18.27%, to $626,494 in fiscal 2021 from $766,507 in fiscal 2020 due to reduced Trustees’ fees as specified in the provisions of the Trust Agreement, cost savings realized through the suspension of in-person meetings due to the pandemic, lower legal expenses, lower insurance costs and the absence of accounting costs associated with the biennial examinations of the royalty calculations by the German operating companies during fiscal 2021. - 7 - Critical Accounting Policies The financial statements, appearing subsequently in this Report, present financial statement balances and financial results on a modified cash basis of accounting, which is a comprehensive basis of accounting other than accounting principles generally accepted in the U.S. (“GAAP basis”). Cash basis accounting is an accepted accounting method for royalty trusts such as the Trust. GAAP basis financial statements disclose income as earned and expenses as incurred, without regard to receipts or payments. The use of GAAP would require the Trust to accrue for expected royalty payments. This is exceedingly difficult since the Trust has very limited information on such payments until they are received and cannot accurately project such amounts. The Trust’s cash basis financial statements disclose revenue when cash is received and expenses when cash is paid. The one modification of the cash basis of accounting is that the Trust accrues for distributions to be paid to unit owners (those distributions approved by the Trustees for the Trust). The Trust's distributable income represents royalty income received by the Trust during the period plus interest income less any expenses incurred by the Trust, all on a cash basis. In the opinion of the Trustees, the use of the modified cash basis provides a more meaningful presentation to unit owners of the results of operations of the Trust and presents to the unit owners a more accurate calculation of income and expenses for tax reporting purposes. ___________________________________________________________ This Annual Report may contain forward-looking statements intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. Such statements address future expectations and events or conditions concerning the Trust. Many of these statements are based on information provided to the Trust by the operating companies or by consultants using public information sources. These statements are subject to certain risks and uncertainties that could cause actual results to differ materially from those anticipated in any forward-looking statements. These include: • • risks and uncertainties concerning levels of gas production and gas sale prices, general economic conditions and currency exchange rates; the ability or willingness of the operating companies to perform under their contractual obligations with the Trust; • potential disputes with the operating companies and the resolution thereof; and • the effects of the novel coronavirus identified as COVID-19 on our financial results. All such factors are difficult to predict, contain uncertainties that may materially affect actual results, and are generally beyond the control of the Trust. New factors emerge from time to time and it is not possible for the Trust to predict all such factors or to assess the impact of each such factor on the Trust. Any forward-looking statement speaks only as of the date on which such statement is made, and the Trust does not undertake any obligation to update any forward-looking statement to reflect events or circumstances after the date on which such statement is made. - 8 - REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM To the Board of Trustees and the Unit Owners of North European Oil Royalty Trust Opinion on the Financial Statements We have audited the accompanying statements of assets, liabilities and trust corpus of North European Oil Royalty Trust (the “Trust”) as of October 31, 2021 and 2020, and the related statements of revenue collected and expenses paid, undistributed earnings, and changes in cash and cash equivalents for each of the two years in the period ended October 31, 2021, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the assets, liabilities and trust corpus of the Trust as of October 31, 2021 and 2020, and its revenue collected and expenses paid, undistributed earnings and changes in its cash and cash equivalents for each of the two years in the period ended October 31, 2021, in conformity with the modified cash basis of accounting described in Note 1. Basis for Opinion These financial statements are the responsibility of the Trust’s management. Our responsibility is to express an opinion on the Trust’s financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“PCAOB”) and are required to be independent with respect to the Trust in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Trust is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting, but not for the purpose of expressing an opinion on the effectiveness of the Trust’s internal control over financial reporting. Accordingly, we express no such opinion. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion. Basis of Accounting As described in Note 1, these financial statements have been prepared on the modified cash basis of accounting, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America. - 9 - Critical Audit Matters Critical audit matters are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. We determined that there are no critical audit matters. /s/ Mazars USA LLP We have served as the Trust’s auditor since 2006. New York, NY December 30, 2021 - 10 - NORTH EUROPEAN OIL ROYALTY TRUST STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS (NOTE 1) OCTOBER 31, 2021 AND 2020 Current assets - - Cash and cash equivalents ASSETS 2021 2020 $1,409,437 $649,585 Producing gas and oil royalty rights, net of amortization (Notes 1 and 2) 1 1 Total Assets $1,409,438 $649,586 LIABILITIES AND TRUST CORPUS 2021 2020 Current liabilities - - Distributions to be paid to unit owners, paid November 2021 and 2020 Trust corpus (Notes 1 and 2) Undistributed earnings Total Liabilities and Trust Corpus $1,286,683 $183,811 1 1 122,754 465,774 $1,409,438 $649,586 NORTH EUROPEAN OIL ROYALTY TRUST STATEMENTS OF REVENUE COLLECTED AND EXPENSES PAID (NOTE 1) FOR THE FISCAL YEARS ENDED OCTOBER 31, 2021 AND 2020 Gas, sulfur and oil royalties received Interest income Trust Income Non-related party expenses Related party expenses (Note 3) Trust Expenses Net Income Net income per unit Distributions per unit paid or to be paid to unit owners 2021 2020 $4,602,410 $4,050,017 641 2,853 $4,603,051 $4,052,870 ($587,476) ($715,490) (39,018) (51,017) ($626,494) ($766,507) $3,976,557 $0.43 $0.47 $3,286,363 $0.36 $0.32 The accompanying notes are an integral part of these financial statements. - 11 - NORTH EUROPEAN OIL ROYALTY TRUST STATEMENTS OF UNDISTRIBUTED EARNINGS (NOTE 1) FOR THE FISCAL YEARS ENDED OCTOBER 31, 2021 AND 2020 Balance, beginning of year Net income Less: Current year distributions paid or to be paid to unit owners Balance, end of year 2021 2020 $465,774 $120,399 3,976,55 3,286,363 $4,442,331 $3,406,762 4,319,577 2,940,988 $122,754 $465,774 NORTH EUROPEAN OIL ROYALTY TRUST STATEMENTS OF CHANGES IN CASH AND CASH EQUIVALENTS (NOTE 1) FOR THE FISCAL YEARS ENDED OCTOBER 31, 2021 AND 2020 Sources of Cash and Cash Equivalents: Gas, sulfur and oil royalties received Interest income Uses of Cash and Cash Equivalents: Payment of Trust expenses Distributions paid 2021 2020 $4,602,410 $4,050,017 641 2,853 $4,603,051 $4,052,870 $626,494 $766,507 3,216,705 4,227,671 $3,843,199 $4,994,178 Net increase (decrease) in cash and cash equivalents during the year 759,852 (941,308) Cash and cash equivalents, beginning of year Cash and cash equivalents, end of year 649,585 1,590,893 $1,409,437 $649,585 The accompanying notes are an integral part of these financial statements. - 12 - NORTH EUROPEAN OIL ROYALTY TRUST NOTES TO FINANCIAL STATEMENTS OCTOBER 31, 2021 AND 2020 (1) Summary of significant accounting policies: Basis of accounting - The accompanying financial statements of North European Oil Royalty Trust (the “Trust”) are prepared in accordance with the rules and regulations of the SEC. Financial statement balances and financial results are presented on a modified cash basis of accounting, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States (“GAAP basis”). In the opinion of management, all adjustments that are considered necessary for a fair presentation of these financial statements, including adjustments of a normal, recurring nature, have been included. On a modified cash basis, revenue is earned when cash is received and expenses are incurred when cash is paid. GAAP basis financial statements disclose revenue as earned and expenses as incurred, without regard to receipts or payments. The modified cash basis of accounting is utilized to permit the accrual for distributions to be paid to unit owners (those distributions approved by the Trustees for the Trust). The Trust’s distributable income represents royalty income received by the Trust during the period plus interest income less any expenses incurred by the Trust, all on a cash basis. In the opinion of the Trustees, the use of the modified cash basis of accounting provides a more meaningful presentation to unit owners of the results of operations of the Trust. The Trust receives adjustments from the operating companies based on their final calculations of royalties payable during the prior periods, including the immediately preceding calendar quarter. Negative adjustments are carried over to the succeeding quarter. A negative adjustment of €444,931 ($538,651) from the fourth quarter of fiscal 2020 was carried over and offset against royalty revenue received in the first quarter of fiscal 2021. Producing gas and oil royalty rights - The rights to certain gas and oil royalties in Germany were transferred to the Trust at their net book value by North European Oil Company (the “Company”) (see Note 2). The net book value of the royalty rights has been reduced to one dollar ($1) in view of the fact that the remaining net book value of royalty rights is de minimis relative to annual royalties received and distributed by the Trust and does not bear any meaningful relationship to the fair value of such rights or the actual amount of proved producing reserves. Federal and state income taxes - The Trust, as a grantor trust and also under a private letter ruling issued by the Internal Revenue Service, is exempt from federal income taxes. The Trust has no state income tax obligations. - 13 - Cash and cash equivalents - Cash and cash equivalents are defined as amounts deposited in bank accounts and amounts invested in certificates of deposit and U. S. Treasury bills with original maturities generally of three months or less from the date of purchase. The investment options available to the Trust are limited in accordance with specific provisions of the Trust Agreement. As of October 31, 2021, the uninsured amounts held in the Trust’s U.S. bank accounts were $1,147,939. In addition, the Trust held €9,942, the equivalent of $11,498, in its German bank account at October 31, 2021. Net income per unit - Net income per unit is based upon the number of units outstanding at the end of the period. As of October 31, 2021 and 2020, there were 9,190,590 units of beneficial interest outstanding. New accounting pronouncements – The Trust is not aware of any recently issued, but not yet effective, accounting standards that would be expected to have a significant impact on the Trust’s financial position or results of operations. (2) Formation of the Trust: The Trust was formed on September 10, 1975. As of September 30, 1975, the Company was liquidated and the remaining assets and liabilities of the Company, including its royalty rights, were transferred to the Trust. The Trust, on behalf of the owners of beneficial interest in the Trust, holds overriding royalty rights covering gas and oil production in certain concessions or leases in the Federal Republic of Germany. These rights are held under contracts with local German exploration and development subsidiaries of ExxonMobil Corp. and the Royal Dutch/Shell Group of Companies. Under these contracts, the Trust receives various percentage royalties on the proceeds of the sales of certain products from the areas involved. At the present time, royalties are received for sales of gas well gas, oil well gas, crude oil, condensate and sulfur. (3) Related party transactions: John R. Van Kirk, the Managing Director of the Trust, provides office services to the Trust at cost. For such office services, the Trust reimbursed the Managing Director $5,613 and $4,020 in fiscal 2021 and 2020, respectively. Lawrence A. Kobrin, a Trustee of the Trust, is no longer a partner of the firm but remained a Senior Counsel at Cahill Gordon & Reindel LLP, which serves as counsel to the Trust. For legal services, the Trust paid Cahill Gordon & Reindel LLP $33,405 and $46,997 in fiscal 2021 and 2020, respectively. (4) Employee benefit plan: The Trust has established a savings incentive match plan for employees (SIMPLE IRA) that is available to both employees of the Trust, one of whom is the Managing Director. The Trustees authorized the making of contributions by the Trust to the accounts of employees, on a matching basis, of up to 3% of cash compensation paid to each such employee for the 2021 and 2020 calendar years. - 14 - (5) Quarterly results (unaudited): The tables below summarize the quarterly results and distributions of the Trust for the fiscal years ended October 31, 2021 and 2020: Fiscal 2021 by Quarter and Year First Second Third Fourth Year Royalties received $283,439 $1,400,159 $1,480,863 $1,437,949 $4,602,410 Net income $111,842 $1,198,447 $1,363,590 $1,302,678 $3,976,557 Net income per unit $0.01 $0.13 $0.15 $0.14 $0.43 Distributions paid or to be paid Distributions per unit paid or to be paid to unit owners $367,624 $1,286,682 $1,378,588 $1,286,683 $4,319,577 $0.04 $0.14 $0.15 $0.14 $0.47 Fiscal 2020 by Quarter and Year First Second Third Fourth Year Royalties received $1,025,965 $1,275,824 $1,399,614 $348,614 $4,050,017 Net income $747,737 $1,041,902 $1,278,075 $218,649 $3,286,363 Net income per unit $0.08 $0.11 $0.14 $0.02 $0.36 Distributions paid or to be paid Distributions per unit paid or to be paid to unit owners $735,247 $1,010,965 $1,010,965 $183,811 $2,940,988 $0.08 $0.11 $0.11 $0.02 $0.32 - 15 - Disclosure Controls and Procedures The Trust maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed by the Trust is recorded, processed, summarized, accumulated and communicated to its management, which consists of the Managing Director, to allow timely decisions regarding required disclosure, and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. The Managing Director has performed an evaluation of the effectiveness of the design and operation of the Trust’s disclosure controls and procedures as of October 31, 2021. Based on that evaluation, the Managing Director concluded that the Trust’s disclosure controls and procedures were effective as of October 31, 2021. Internal Control over Financial Reporting Part A. Management’s Report on Internal Control over Financial Reporting The Trust’s management is responsible for establishing and maintaining adequate internal control over financial reporting (as such term is defined in Exchange Act Rule 13a-15(f)) for the Trust. There are inherent limitations in the effectiveness of any internal control, including the possibility of human error and the circumvention or overriding of controls. Accordingly, even effective internal controls can provide only reasonable assurance with respect to financial statement preparation. Further, because of changes in conditions, the effectiveness of internal control may vary over time. Management has evaluated the Trust’s internal control over financial reporting as of October 31, 2021. This assessment was based on criteria for effective internal control over financial reporting described in the standards promulgated by the Public Company Accounting Oversight Board and in the Internal Control-Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on this evaluation, management concluded that the Trust’s internal control over financial reporting was effective as of October 31, 2021. - 16 - NORTH EUROPEAN OIL ROYALTY TRUST Managing Director John R. Van Kirk Office of the Managing Director PO Box 187 5 N. Lincoln St. Keene, NH 03431 Tel: (732) 741-4008 E-Mail: neort@neort.com Website: www.neort.com Counsel Cahill Gordon & Reindel 32 Old Slip New York, NY 10005 Auditors Mazars USA LLP 135 West 50th Street New York, NY 10020 Petroleum and Natural Gas Consultants Graves and Co. Consulting, LLC 2777 Allen Parkway Suite 1200 Houston, TX 77019 Transfer Agent American Stock Transfer & Trust Company, LLC 6201 15th Avenue Brooklyn, NY 11219 Tel: (800) 937-5449 (718) 921-8200 E-Mail: help@astfinancial.com Website: www.astfinancial.com Trustees Robert P. Adelman Managing Trustee, Director or Trustee of various profit and non-profit companies Ahron H. Haspel Audit Comm. Chairman Member of the Board of Directors of Hanover Bank Corp. Lawrence A. Kobrin Clerk to the Trustees, Senior Counsel, Cahill Gordon & Reindel LLP Nancy J. Prue A Director of the National Assoc. of Petroleum Investment Analysts Willard B. Taylor Of Counsel, Sullivan and Cromwell LLP A copy of the Trust’s Form 10-K Annual Report for fiscal 2021 as filed with the Securities and Exchange Commission will be sent upon written request to John R. Van Kirk, Managing Director, P.O. Box 187, Keene, New Hampshire 03431. In addition to the 2021 10-K, other pertinent filings and documents are available on the Trust’s website. www.neort.com - 17 - North European Oil Royalty Trust P.O. Box 187 Keene, New Hampshire 03431 (732) 741-4008 IMPORTANT – 2021 TAX LETTER RETAIN THIS LETTER FOR PREPARATION OF YOUR 2021 INCOME TAX RETURNS January 3, 2022 To the Current and Former Unit Owners of North European Oil Royalty Trust: There are three parts to the tax letter. PART ONE applies to all unit owners. PART TWO applies to unit owners who have held their units for the entire year. PART THREE applies to unit owners who have held their units for only a portion of the year. The following is provided to assist current and former unit owners of North European Oil Royalty Trust (the “Trust”) to prepare their personal income tax returns for the tax year ended December 31, 2021. This letter serves to assist Owners, and their tax professionals, in determining the accurate and true income from the Trust for income tax reporting purpose. Further, this letter is for informational purposes and neither the Trust nor Trust employees intend, nor may it be construed, for this letter to serve as either legal or tax advice. It is recommended that you seek the advice of your trusted tax professional or attorney should you require further guidance. PART ONE – ALL UNIT OWNERS To determine your proportional and, therefore, reportable, share of Trust income you must first know how many Trust units you owned during 2021, the periods during which you owned the units, and the cost or tax basis of the units. The information contained in this letter is applicable to those unit owners who held their units for either the entire year or only a portion of the year. Please note that Trust distributions are not dividends and should not be included on your income tax return as dividend income. The Trust is considered a “grantor trust” for federal income tax purposes and each unit owner is deemed a “grantor” of the Trust. As such, unit owners realize income, in proportion to the owned units, when royalty income is paid to the Trust. Further, unit owners may deduct, from income, a proportional share of Trust expenses. Because realization of proportional Trust income and expenses is a time sensitive inquiry, you should not use the amount of quarterly Trust distributions received for income tax reporting purposes. Additionally, you should disregard the amounts listed on any 2021 Form 1099-Misc you receive from your broker or other nominee. The listed amounts are incomplete because they do not include your proportional share of Trust expenses and/or the cost depletion allowance. Income and expenses should be reported on Federal Income Tax Form 1040, Schedule E. Royalty income is generally considered portfolio income under the passive loss rules enacted by the Tax Reform Act of 1986. Under Part I, Income or Loss from Rental Real Estate and Royalties, under Line 1b the type of property is royalties. Royalty income should be entered on Line 4, expenses should be entered on Line 19 as "miscellaneous Trust expenses" and the cost depletion deduction should be entered on Line 18. Some tax preparation computer programs ask for a tax identification number. North European Oil Royalty Trust's tax identification number is 22-2084119. - 18 - A unit owner may be entitled to cost depletion for tax reporting purposes. At the outset, in the first year of ownership, the unit owner’s cost or tax basis for the units is the basis for computing cost depletion. In each subsequent year, the basis for computing cost depletion is that original cost less the cumulative amount of depletion previously taken. The Trust retains Graves & Co. Consulting, LLC, of Houston, Texas, a petroleum engineering company, to calculate the cost depletion percentage each year. The cost depletion percentage is calculated based upon computations of proved producing reserves estimated in accordance with accepted engineering analytical principles. Graves & Co. Consulting, LLC has recommended an annual cost depletion percentage of 17.7008% for the 2021 calendar year. The IRS periodically changes the format for Schedule E (including the line numbers and descriptions), and may do so even after the date of this letter, so please make certain you follow the Form 1040 Schedule E directions carefully and enter the information on the correct lines. The Trust’s royalty income represents income from Germany. Although Germany does not tax the royalty income received by the Trust, this information should be considered if you have available foreign tax credits from other sources. The Trust will submit this letter and the listing of unit owners during 2021 to the Internal Revenue Service. This list will contain names, addresses and tax ID or Social Security Numbers. You may wish to attach a copy of this letter to your tax returns. This letter does not constitute legal or tax advice. Neither the Trust nor its employees may offer tax or legal advice relevant to your unique situation. The Trust recommends that you direct any questions to your tax advisor or attorney. PART TWO – OWNERSHIP OF UNITS FOR THE ENTIRE YEAR A. If you owned all your units for the entire year, you would calculate your royalty income by multiplying the number of units you owned by $0.6103. On Federal Income Tax Form 1040, Schedule E, royalty income should be entered on Line 4. B. If you owned all your units for the entire year, you would calculate your expenses by multiplying the number of units you owned by $0.0698. On Federal Income Tax Form 1040, Schedule E, expenses should be entered on Line 19 as "miscellaneous Trust expenses." C. If you owned all your units for the entire year, you would calculate your cost depletion deduction by multiplying your cost basis or adjusted cost basis by .177008. On the Federal Income Tax Form 1040, Schedule E, your cost depletion deduction should be entered on Line 18. PART THREE – OWNERSHIP OF UNITS FOR A PARTIAL YEAR If you owned your units for only a portion of the year, you should use the charts and instructions on the following pages to determine your royalty income, royalty expenses and cost depletion deduction. - 19 - First month during which Units were owned: January February March April May June July August September October November December ROYALTY INCOME PER UNIT FOR THE 2021 TAX YEAR Last month during which units were owned: January $0.0308 February $0.0582 $0.0274 March $0.0852 $0.0544 $0.0270 April $0.1832 $0.1524 $0.1250 $0.0980 May $0.2334 $0.2026 $0.1752 $0.1482 $0.0502 June $0.2831 $0.2523 $0.2249 $0.1979 $0.0999 $0.0497 July $0.3443 $0.3135 $0.2861 $0.2591 $0.1611 $0.1109 $0.0612 August $0.3951 $0.3643 $0.3369 $0.3099 $0.2119 $0.1617 $0.1120 $0.0508 September $0.4461 $0.4153 $0.3879 $0.3609 $0.2629 $0.2127 $0.1630 $0.1018 $0.0510 October $0.5008 $0.4700 $0.4426 $0.4156 $0.3176 $0.2674 $0.2177 $0.1565 $0.1057 $0.0547 November $0.5557 $0.5249 $0.4975 $0.4705 $0.3725 $0.3223 $0.2726 $0.2114 $0.1606 $0.1096 $0.0549 December $0.6103 $0.5795 $0.5521 $0.5251 $0.4271 $0.3769 $0.3272 $0.2660 $0.2152 $0.1642 $0.1095 $0.0546 A. To determine your royalty income per unit for your period of ownership, place your finger on the chart above on the first month in the left-hand column during which you owned your units and slide your finger to the right until you reach the column showing the last month during which you owned your units. This figure should be multiplied by the number of units you owned during that period to calculate your royalty income. On Federal Income Tax Form 1040, Schedule E, royalty income should be entered on Line 4. First month during which Units were owned: January February March April May June July August September October November December ROYALTY EXPENSES PER UNIT FOR THE 2021 TAX YEAR Last month during which units were owned: January $0.0068 February $0.0200 $0.0132 March $0.0235 $0.0167 $0.0035 April $0.0287 $0.0219 $0.0087 $0.0052 May $0.0338 $0.0270 $0.0138 $0.0103 $0.0051 June $0.0367 $0.0299 $0.0167 $0.0132 $0.0080 $0.0029 July $0.0415 $0.0347 $0.0215 $0.0180 $0.0128 $0.0077 $0.0048 August $0.0467 $0.0399 $0.0267 $0.0232 $0.0180 $0.0129 $0.0100 $0.0052 September $0.0497 $0.0429 $0.0297 $0.0262 $0.0210 $0.0159 $0.0130 $0.0082 $0.0030 October $0.0562 $0.0494 $0.0362 $0.0327 $0.0275 $0.0224 $0.0195 $0.0147 $0.0095 $0.0065 November $0.0622 $0.0554 $0.0422 $0.0387 $0.0335 $0.0284 $0.0255 $0.0207 $0.0155 $0.0125 $0.0060 December $0.0698 $0.0630 $0.0498 $0.0463 $0.0411 $0.0360 $0.0331 $0.0283 $0.0231 $0.0201 $0.0136 $0.0076 B. To determine your royalty expenses per unit for your period of ownership, place your finger on the chart above on the first month in the left- hand column during which you owned your units and slide your finger to the right until you reach the column showing the last month during which you owned your units. This figure should be multiplied by the number of units you owned during that period to calculate your expenses. On Federal Income Tax Form 1040, Schedule E, expenses should be entered on Line 19 as "miscellaneous Trust expenses." - 20 - C. If you owned your units for only a portion of the year you must prorate the depletion percentage to reflect your period of ownership. In the same way that you calculated your royalty income per unit, place your finger on the Royalty Income per Unit Chart on the first month in the left-hand column during which you owned your units and slide your finger to the right until you reach the column showing the last month during which you owned your units. This figure should be divided by $0.6103. The resulting figure is then multiplied by .177008 to yield the prorated depletion percentage. Multiply this prorated depletion percentage by your cost basis or adjusted cost basis to calculate your cost depletion deduction. Your cost depletion deduction should be entered on Line 18 on the Federal Income Tax Form 1040, Schedule E. This letter does not constitute legal or tax advice. Neither the Trust nor its employees may offer tax or legal advice relevant to your unique situation. If you dispose of some or all of your Trust units, you should consult your tax advisor as to the tax consequence of that disposition. The Trust recommends that you direct any questions to your tax advisor or attorney. Most sincerely yours, John R. Van Kirk Managing Director - 21 - 

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